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193-067
• • STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I.Suprv-igle--5114/A9 BOPE Test Report for: DUCK IS UNIT MPI 2-50 ' Comm Contractor/Rig No.: Hilcorp ASR 1 " PTD#: 1930670 " DATE: 5/14/2018 ' Inspector Brian Bixby ' [ Insp Source Operator: HILCORP ALASKA LLC Operator Rep: Harold Soule Rig Rep: Tony Rico € Inspector [ Test Pressures: Type Operation: WRKOV Sundry No: Inspection No: bopBDB180517070319 9 Rams: Annular: Valves: MASP: Type Test: WKLY 318-173 250/3000 ' 250/2500- 250/3000 ' 2422 Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ' ACCUMULATOR SYSTEM: P/F Visual Alarm Time/Pressure P/F Location Gen.: P Trip Tank P_- P ' System Pressure 3050 P " Housekeeping: P Pit Level Indicators P_ P Pressure After Closure 1300 _ P PTD On Location P : Flow Indicator NA NA I 200 PSI Attained 18 P Standing Order Posted P Meth Gas Detector P - P - 1 Full Pressure Attained 86 P Well Sign P - H2S Gas Detector P - P - Blind Switch Covers: YES . P Drl. Rig P - MS Misc 0 NA Nitgn.Bottles(avg): 4@2600 - P Hazard Sec. P " ACC Misc 0 NA Misc NA 1 FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: r Quantity P/F E Quantity Size P/F Quantity P/F Upper Kelly 0 NA Stripper 0 _ NA 1 No.Valves 16 - FP -- Lower Kelly 0 NA Annular Preventer 1 - 13 5/8 - _ P 1 Manual Chokes 1 - P Ball Type 1 ' P' #1 Rams _1 2 7/8 x 5 - P - Hydraulic Chokes 1 - P 1 Inside BOP 1 P ` #2 Rams 1 - Blind Rams _ P CH Misc 0 NA FSV Misc 0 NA #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln.Valves 1 -2 1/16 P " Quantity P/F HCR Valves 1 2 1/16 p . Inside Reel Valves 0 NA Kill Line Valves 2 '2 1/16 ' P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 2 Test Results Test Time 15.5 Remarks: Tested with 2 7/8"test joint,Tested all gas alarms.CMV#10 and#15 failed were chagned out and passed retest. Long test due to leaking TWC and having to get slickline on well to set a downhole plug to test. SCAB JUN 0 42016 OF T7� S THE STATE •• Alaska Oil and Gas ofA LASKA Conservation Commission 333 West Seventh Avenue kms_ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF'�mR';' Q. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York scow Operations Manager Hilcorp Alaska, Inc. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, MPI 2-50 Permit to Drill Number: 193-067 Sundry Number: 318-173 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this 2-' day of April, 2018. Oti RECEIVED • • STATE OF ALASKA APR 19 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION kf S I 24(I APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑✓ • Operations shutdown❑ Suspend ❑ Perforate El Other Stimulate ❑ Pull Tubing 9 • Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well El Alter Casing ❑ Other: Fishing 9 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: 'v✓//U4 Hilcorp Alaska LLC Exploratory ❑ Development 9 • 193-067 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-22367-00-00 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462 • Will planned perforations require a spacing exception? Yes ❑ No 0 DUCK IS UNIT MPI 2-50 • 9.!Pr�operty Designation(Lease Number): 10.Field/Pool(s): —.1:12- C-'0-.3z1/44135 ADL0034634 ;- t'.(pig ENDICOTT/ENDICOTT OIL • 11. f PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15,530' • 10,405' • 15,448' 10,348' 2,422 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 131' 30" 131' 131' N/A N/A Surface 2,873' 13-3/8" 2,873' 2,706' 5,020psi 2,260psi Production 12,123' 9-5/8" 12,123' 8,180' 6,870psi 7,100psi Production 3,405' 9-5/8" 15,528' 10,404' 8,150psi 5,090psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 4-1/2" 12.6#/L-80 14,900 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 14,678(MD)/9,812'(TVD)&14,836(MD)/9,920(TVD) 9-5/8"DB&9-5/8"SABL-3 and 4-1/2"SSSV and 1,457(MD)/1,451(TVD) 12.Attachments: Proposal Summary ❑ Wellbore schematic 9 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch 9 Exploratory ❑ Stratigraphic❑ Development ffj Service ( • 14.Estimated Date for 15.Well Status after proposed work: 5/3/2018 Commencing Operations: OIL ❑ WINJ ❑✓ • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Taylor Wellman Authorized Title: Operations Manager Contact Email: twellman cr hilcorp.com Authorized Signature: c�.rJ�t//� Date: 4/19/2018 Contact Phone: 777-8449 COMMISSION USE ONLY Conditions of approva. otify C mission so that a representative may witness Sundry Number: 5 11 I1; 55,1/'��.� U Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance CI Other: k 3 9O PSo 6ccrP les t ❑ ❑ � R252018 Post Initial Injection MIT Req'd? Yes No RBDM ��._- Spacing Exception Required? Yes ❑ No Subsequent Form Required: /6 4/6 y •' APPROVED BY Approved by: 4 . � COMMISSIONER THE COMMISSION Date: 'd (2_44 Le RdIUIj_V ents in Form ane Form 10-403 Revised 4/2 Approved applicatioant�=�����►iiiiiii��ie date of approval. attachments in Duplicate RWO—Conversion to PWI • Well: END 2-50 PTD: 193-067 IIilcoro Alaska,ILAPI:50-029-22367-00 Well Name: END 2-50 API Number: 50-029-22367-00 Current Status: SI Producer Pad: Endicott Estimated Start Date: May 3, 2018 Rig: Innovation/x4S, L Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 193-067 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) AFE Number: 1722383 Well EZ Inputs Required: Yes Current BHP: 3,422 psi @ 10,000'TVD (SBHPS 7/15/2017/6.58 ppg EMW) Maximum Expected BHP: 3,422 psi @ 10,000'TVD (No new perfs added) MPSP: 2,422 psi (0.1 psi/ft gas gradient) Brief Well Summary: The Endicott 2-50 well was drilled as an upper sub zone development well into the FIII, FIV, and FV zones. The well was TD'd at 15,528' and with a 9-5/8" production casing in July 1993. The well was worked over to squeeze existing perforations and isolate additional perforations at 14,798'-14,800'. In July 2007 the well developed TxIA communication with a failed MIT-IA. A leak detect log found a tubing leak at 14,670'. The tubing was . successfully patched from 14,659'-14,674' and the well was returned to service. The well remained online until developing IAxOA communication through a casing leak and was shut-in in April 2014. OK An attempted OA downsqueeze was performed that resulted in failure as the tubing plug began to leak during • • the job and most of the cement was circulated back to surface. The downsqueeze failed to repair the well. . After this point the tubing tail plugs were attempted to be pulled in prep for RWO. The 4-1/2" PXN plug body at 14,887' and became stuck and fishing operations began. During the fishing attempts, 0.25" braidedline was ,y4...1 used and ended with the SL toolstring stuck to the plug. A Kinley Cutter was dropped which cut high leaving 9,700' of 0.25" braided cable in the hole. Attempts to fish this have resulted in recovery of "175' of cable. 317-2-"The tubing pressure has remained Opsi and the fluid level has remained at surface since fishing operations began. Notes Regarding Wellbore Condition The current status of the well is not operable and shut in. The well has TxIA communication through a leak in the seal assembly at 14,670' (tbg patch was pulled in June 2015). The well has IAxOA communication through a hole in the 9-5/8" casing. The 9-5/8" casing does not have integrity as per a failing MIT-IA and an identified an anomaly at—1270' and &a leak at 1650' and (leak detect log 07/20/14). A tubing caliper run on 30June2015 indicated the tubing to be in good to fair condition with only 1 identified leak and no areas of metal body loss above 5%. Objectives: 1. Recover all cable from the well. 2. Recover SL toolstring and PXN plug. 3. Recovery 4-1/2"tbg(if contingency plan for cable recovery is used) • RWO—Conversion to PWI Well: END 2-50 PTD: 193-067 Hilcorp Alaska, API:50-029-22367-00 Pre-Workover Prep Procedure: 1. Clear and level pad area in front of wellhouse.Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services Pump.Setup reverse out skid and 500 bbl returns tank and additional upright tanks as needed. Pressure test lines to 3,000 psi. 4. Forward circulate at least one wellbore volume with 8.5 ppg seawater down the tubing (thru leaking sealbore assembly @ ±14,678' md),taking returns up the annulus to the 500 bbl returns tank. a. Annular volume from cut @ 14,678' =786bbls b. Tbg volume to the cut @ 14,678'=223bbls c. Total volume = 1009bbls 5. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 6. RD Little Red Services Pump and reverse out skid. Workover Procedure: 7. MIRU ASR#1 over from Endicott SDI. 8. Check for pressure and if needed, bleed off any residual pressure off tubing and casing. If needed, recirculate/kill well w/±8.5ppg seawater. 9. Set BPV. ND tree/ NU 13-5/8" BOPE. Set TWC. 10. Test BOPE to 250psi Low/33 001 0,Qj.biigh, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. ( S c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8" &4-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 11. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 12. Bleed any pressure off casing to 500bbl returns tank. Pull TWC. RWO—Conversion to PWI . Well: END 2-50 PTD: 193-067 Il;looro Alaska,Lb API: 50-029-22367-00 a. Contingency(If a rolling test was conducted): MU 4-1/2" landing joint or spear and BOLDS. Recover the tubing hanger. MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 13. MU ±3-1/8" Fishing BHA w/center prong spear utilizing 2-7/8" workstring. a. Confirm that workstring to be used was tested in the VBR's during the BOP test. 14. TIH to above fish and record PU/SO weights. Sit down and attempt to fish cable ball.Work as needed to spear cable. POOH and check for recovery. a. Recover and lay down wire,take pictures and approximate amount of wire recovered in report. 15. MU ±3-1/8" Fishing BHA w/various fishing tools and repeat step 14 to continue recovery of wire. A3 �,J}+� a. Possible options for fishing tool inside of 4-1/2"tubing (additional may be added upon wire `( L,✓• recovered):wire grab, wash-over shoe w/internal grabs, wall hook, crankshaft spear, cut lip 2.9 guide, magnets, reverse out baskets. Contingency—If determined that casing jacks will be needed during fishing inside 4-1/2" tubing. 16. PU Casing Jacks via the beaver slide and Tugger winches to rig floor. Set Casing Jacks on top of the BOP nular wit ggers. Connect Hydraulics to the ASR#1 control panel and function test same. a. Set pressure relief high point as 1,755 psi (equates to—198.3k#or 80%of yield strength). b. Yield strength of 2-7/8",7.9#, P-110= 247.9k it, and the PH6 connections=248k#. ea . tc. Cycle jacks up and down to ensure proper function (dry run without being connected to ,,; 1 hanger). d. Set Casing Jack pressure to 1,415 psi (160,000 lbs). Slowly pressure up on jacks. Hold for 1 min. e. If jars do not fire or movement is not seen, increase pressure in 10k#("88psi) increments holding each time to check for movement or jars firing. Note: do not exceed 1,755 psi (230,400#). If unmoved contact Ops Engineer for further discussion and possible other options. Contingency—If determined fishing cable is unsuccessful from inside the 4-1/2" tubing. 17. RU EL unit and RIH w/4-1/2" Chem Cutter. Cut tubing above the top of fish. a. Use CCL to not cut in collar. Also correlate depth to the tubing tally dated 14-Feb-1994. -k- k b`C 18. PU Casing Jacks via the beaver slide and Tugger winches to rig floor. Set Casing Jacks on top of the BOP �tv Annular with Tuggers. Connect Hydraulics to the ASR#1 control panel and function test same. a. Set pressure relief high point as 2,038 psi (equates to "230.4k#or 80%of yield strength). b. Yield strength of 4-1/2", 12.6#, L-80=288k#, and the Mannesmann TDS connections= 288k#. c. Cycle jacks up and down to ensure proper function (dry run without being connected to hanger). 19. MU 4-1/2" landing joint or spear and BOLDS. 20. Attempt to pull the tubing with the ASR#1. If unable to pull tubing. Use casing jacks. J N a. Set Casing Jack pressure to 1,415 psi (160,000 lbs). Slowly pressure up on jacks. Hold for 5 tdiIh min. RWO-Conversion to PWI • • Well: END 2-50 PTD: 193-067 Hilcorp Alaska LU API: 50-029-22367-00 b. If hanger does not unseat, increase pressure in 10k# (^'88psi) increments holding for 5 min between pressure increases. Note: do not exceed 2,038 psi (230,400#). If unmoved contact Ops Engineer for further discussion and possible recut. 21. RU control line spooler. POOH and lay down the 4-1/2"tubing to the cut above fish. a. The 4-1/2"TDS tubing will not be salvaged. b. From 0-1457'there are two%" control lines(balance and control line)to the OTIS HXO nipple. 22. MU 4-1/2" overshot fishing BHA and TIH to latch top of tubing. 23. Attempt to rotate and to release the DB seal assembly. PU and recover tubing if free. Release and TOOH if unable to jar free. 24. MU outside cutter BHA with 2-4 joints of washpipe.TIH and swallow top of tubing stub. Make outside cut and TOOH to recover pipe and wire. a. Multiple outside cuts may be required. b. LD washpipe and outside cutter if wire ball is fully recovered. 25. Once all wire is recovered and/or tubing is recovered to the seal assembly MU fishing BHA for SL toolstring. 26. TIH to overshot toolstring and TOOH. a. Note that the well is holding a fluid column. This is overbalanced to the reservoir. Removing the SL toolstring should put the well on a vacuum. 27. MU PXN plug milling BHA.TIH and mill out PXN plug at 14,887' md. 14.-tt . 28. Run 4-1/2" killstring to ±7,000'. 501 29. Circulate in 500' of freeze protect and set BPV.Test tubing hanger to 250/5,000psi thru test port. 30. RD Hilcorp ASR#1 WO Rig,ancillary equipment and lines to 500 bbl returns tank. Post Workover Procedure: El/1'e/ ,edt 31. RD mud boat. RD BOPE house. \y< � 32. RU crane. ND BOPE. Pull BPV. Set TWC. )-1-1";'" 33. NU 4-1/16" 5,000#tree and adapter flange and test to 500 psi low/5,000 psi high. �` 34. Test tubing hanger void to 500psi low/5,000psi high. 35. Pull TWC. RD crane. 36. Move 500bbl returns tank and rig mats. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Proposed Schematic-Contingency 4. BOPE Schematic 5. Wellhead/Tree schematic Duck Island Unit H . • Well: END 2-50 SCHEMATIC Last Completed: 7/23/1993 lilcorp Alaska,LLC PTD: 193-067 SAFETY NOTE TREE&WELLHEAD OPEN HOLE/CEMENT DETAIL KB Elev.:55.3'/BF Elev.:16..22' Tubing leak identified @ 14,671' Tree 4-1/2"OW 13-3/8" 4,185 cu/ft Permafrost in 17.5"Hole Casing leak identified @ 1,270' Wellhead 13-5/8"McEvoy 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole 30 ,� 1 7" 645 cu/ft Class"G"in 8-1/r Hole ' CASING DETAIL ,,a 1 it Size Type Wt/Grade/Conn Drift ID Top Btm BPF 4. 30" Conductor N/A/N/A/N/A N/A Surface 131' N/A 13 3/8" I' 13-3/8" Surface 68/L-80/Btrs 12.415 Surface 2,873' 0.150 9-5/8" Production 47/L-80/NSCC 8.681 Surface 12,123' 0.0732 9-5/8" Production 47/NT95HS/BTC 8.681 12,123' 15,528' 0.0732 2 TUBING DETAIL I 4-1/2" Tubing 12.6/L-80/TDS 3.958 Surface 14,900' 0.0152 WELL INCLINATION DETAIL Max Hole Angle=57 deg. @ 11,100' Angle at Top Perf=45 Deg.@ 15,068' 3 JEWELRY DETAIL No Depth Item 1 1,457' BBE SSV&4-1/2"OTIS BVN Nip,ID=3.813 ul '' GLM DETAIL:Camco w/RK Latch&Port=O it 2 4,420' ST 6:Type=Circ,Dev.=52,TVD= 3,752',8/14/2017 5 3 8,139' ST 5:Type=DMY,Dev.=55,TVD= 5,889',4/1/2014 4 10,899' ST 4:Type=DMY,Dev.=56,TVD= 7,470',8/29/2004 6 �* 5 12,624' ST 3:Type=DMY,Dev.=50,TVD= 8,496',8/29/2004 11 6 13,685' ST 2:Type=DMY,Dev.=52,TVD= 9,185',9/12/1995 e@ 7 13,832' ST 1:Type=OPEN,Dev.=53,TVD= 9,276',6/27/2015 d; 8 14,657 4-1/2"SWS Nipple,ID=3.813" 9 14,678' Baker Bonded Seal Assembly w/GBH-22 LOC,ID=3.875" 10 14,678' 9-5/8"Baker DB Packer w/seal Extension,ID=4.75" 8 11 14,696' Baker Packer Guide,ID=3.937" 12 14,835' Baker EBH-22S Latch,ID=3.875" 13 14,836' 9-5/8"Baker SABL-3 Packer,ID=4.75" 14 14,870' 4-1/2"OTIS X-Nipple,ID=3.813 9&10 4-1/2"OTIS XN-Nipple***Set PXN plug on 8/29/2017*** 15 14,887' 11 Tool string and Approx 9763'IA"Braided Line. 17 14,899' 4-1/2"WLEG-Bottom @ 14,900' 12 13 PERFORATION DETAIL END Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Size USZ-LCU 14,798' 14,800' 9,894' 9,895 2 2/8/1994 Sqz. 3-3/8" 14 USZ-FV 15,068' 15,078' 10,082' 10,089' 30 8/31/2008 Open 2" ,di USZ-FV 15,072' 15,078' 10,084' 10,089' 6 2/8/1994 Sqz. 4-1/2" [ USZ-FV 15,084' 15,103' 10,093' 10,106' 19 2/8/1994 Sqz. 4-1/2" 15 USZ-FV 15,084' 15,104' 10,093' 10,107' 20 8/31/2008 Open 2" 4 USZ-FV 15,084' 15,103' 10,093' 10,106' 19 7/30/1995 Open 3-3/8" 16 USZ-FV 15,090' 15,103' 10,097' 10,106' 13 2/8/1994 Sqz. 3-3/8" 9 5/8" USZ-FV 15,107' 15,122' 10,109' 10,120 5 8/31/2008 Open 2" F• USZ-FV 15,108' 15,122' 10,110' 10,120' 4 2/8/1994 Sqz. 3-3/8" USZ-FV 15,108' 15,122' 10,110' 10,120' 4 7/30/1995 Open 3-3/8" USZ-FV 15,112' 15,120' 10,113' 10,118' 8 2/18/1994 Sqz. 3-3/8" USZ-FV,FIV 15,130' 15,150' 10,125' 10,139' 20 8/31/2008 Open 2" ��- USZ-FIV 15,160' 15,210' 10,146' 10,181' 50 8/31/2008 Open 2" Sand Dump , .JE. USZ-FIV 15,215' 15,235' 10,185' 10,199' 20 11/25/1994 Open 3-3/8" 15,2 rte USZ-FIV 15,215' 15,245' 10,185' 10,206' 30 2/18/1994 Sqz. 3-3/8" @ 15,295' USZ-FIV 15,235' 15,245' 10,199' 10,206' 10 11/25/1994 Open 3-3/8" USZ-FIII 15,316' 15,330' 10,256' 10,265' 14 4/4/1996 Sqz. 3-3/8" GENERAL WELL INFO API:50-029-22367-00-00 TD=15,530'(MD)/TD=10,40515/D) Original Completion -7/23/1993 PBTD=15,448'(MD)/PBTD=10,348'(TVD) RWO -2/18/1994 Set PXN Plug-2/29/2006 GLV C/O XX Plug -4/01&2/14 Revised By:JCM 9/12/2017 • , 14 PROPOD SCE EMATIC - Duck Island Unit • Well: END 2-50 PO T F I S H I N G Last Completed: 7/23/1993 !blear')Alaska,LLC PTD: 193-067 SAFETY NOTE TREE&WELLHEAD OPEN HOLE/CEMENT DETAIL KB Elev.:55.3'/BF Elev.:16..22' Tubing leak identified @ 14,671' Tree 4-1/2"CIW 13-3/8" 4,185 cu/ft Permafrost in 17.5"Hole Casing leak identified @ 1,270' Wellhead 13-5/8"McEvoy 9-5/8" 575 cu/ft Class`G'in a 12-1/4"Hole 7" 645 cu/ft Class"G"in 8-1/2"Hole CASING DETAIL 4 1 Size Type Wt/Grade/Conn Drift ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 131' N/A ]33/8 13-3/8" Surface 68/L-80/Btrs 12.415 Surface 2,873' 0.150 -K,4 9-5/8" Production 47/L-80/NSCC 8.681 Surface 12,123' 0.0732 `aN= 9-5/8" Production 47/NT95HS/BTC 8.681 12,123' 15,528' 0.0732 2 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TDS 3.958 Surface 14,900' 0.0152 II WELL INCLINATION DETAIL Max Hole Angle=57 deg. @ 11,100' Angle at Top Perf=45 Deg.@ 15,068' 3 111 a No Depth Item JEWELRY DETAIL 1 1,457' BBE SSV&4-1/2"OTIS BVN Nip,ID=3.813 GLM DETAIL:Camco w/RK Latch&Port=O 5 2 4,420' ST 6:Type=Circ,Dev.=52,TVD= 3,752',8/14/2017 3 8,139' ST 5:Type=DMY,Dev.=55,TVD= 5,889',4/1/2014 II D 4 10,899' ST 4:Type=DMY,Dev.=56,TVD= 7,470',8/29/2004 6 5 12,624' ST 3:Type=DMY,Dev.=50,TVD= 8,496',8/29/2004 6 13,685' ST 2:Type=DMY,Dev.=52,TVD= 9,185',9/12/1995 7 13,832' ST 1:Type=OPEN,Dev.=53,TVD= 9,276',6/27/2015 7 I 8 14,657' 4-1/2"SWS Nipple,ID=3.813" if '�,` 9 14,678' Baker Bonded Seal Assembly w/GBH-22 LOC,ID=3.875" 30 14,678' 9-5/8"Baker DB Packer w/seal Extension,ID=4.75" 8 C.d�� 11 14,696' Baker Packer Guide,ID=3.937" I 12 14,835' 9B -225 Latch,ID=3.875" „ N. 13 14,836' 9-5/8"Baker SABL-3 Packer,ID=4.75" �/ 14 14,870' 4-1/2"OTIS X-Nipple,ID=3.813 "� 9&10 !O n 15 14,887' 4-1/2"OTIS XN-Nipple 11 -., ,,,,.. 2'_9 17 14,899' 4-1/2"WLEG-Bottom @ 14,900' F. sr45 1z PERFORATION DETAIL . 13 END Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status Size USZ-LCU 14,798' 14,800' 9,894' 9,895 2 2/8/1994 Sqz. 3-3/8" 't 14 USZ-FV 15,068' 15,078' 10,082' 10,089' 10 8/31/2008 Open 2" ()/ USZ-FV 15,072' 15,078' 10,084' 10,089' 6 2/8/1994 Sqz. 4-1/2" USZ-FV 15,084' 15,103' 10,093' 10,106' 19 2/8/1994 Sqz. 4-1/2" '0,7".*0 15 �it ` USZ-FV 15,084' 15,104' 10,093' 10,107' 20 8/31/2008 Open 2" �, USZ-FV 15,084' 15,103' 10,093' 10,106' 19 7/30/1995 Open 3-3/8" 16 9-5/8" /(5°-. USZ-FV 15,090' 15,103' 10,097' 10,106' 13 2/8/1994 Sqz. 3-3/8" USZ-FV 15,107' 15,122' 10,109' 10,120 5 8/31/2008 Open 2" USZ-FV 15,108' 15,122' 10,110' 10,120' 4 2/8/1994 Sqz. 3-3/8" USZ-FV 15,108' 15,122' 10,110' 10,120' 4 7/30/1995 Open 3-3/8" USZ-FV 15,112' 15,120 10,113' 10,118' 8 2/18/1994 Sqz. 3-3/8" USZ-FV,FIV 15,130' 15,150' 10,125' 10,139' 20 8/31/2008 Open 2" USZ-FIV 15,160' 15,210' 10,146' 10,181' 50 8/31/2008 Open 2" USZ-FIV 15,215' 15,235' 10,185' 10,199' 20 11/25/1994 Open 3-3/8" @1G 5 Px "-' USZ-FIV 15,215' 15,245' 10,185' 10,206' 30 2/18/1994 Sqz. 3-3/8" USZ-FIV 15,235' 15,245' 10,199' 10,206' 10 11/25/1994 Open 3-3/8" ^ " � USZ-FIII 15,316' 15,330' 10,256' 10,265' 14 4/4/1996 Sqz. 3-3/8" r `^�?, t+a. c : : ? GENERAL WELL INFO API:50-029-22367-00-00 TD=15,530'(MD)/TD=10,405'(TVD) Original Completion -7/23/1993 PBTD=15,448'(MD)/PBTD=10,348'(TVD) RWO -2/18/1994 Set PXN Plug-2/29/2006 GLV C/O XX Plug -4/01&2/14 Revised By:JCM 9/12/2017 ItirPROPWED SCHEMATIC - Duck Island Unit • Well: END 2-50 Last 067 'Licari,Alaska,LLC POST F I H I N G C O n t i n g e n c y 1 PTD 193 plet d: 7/23/1993 SAFETY NOTE TREE&WELLHEAD OPEN HOLE/CEMENT DETAIL KB Elev.:55.3'/BF Elev.:16..22' Tubing leak identified @ 14,671' Tree 4-1/2"CIW 13-3/8" 4,185 cu/ft Permafrost in 17.5"Hole 1 J1 1 Casing leak identified @ 1,270' Wellhead 13-5/8"McEvoy 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole , , 30' 7" 645 cu/ft Class"G"in 8-1/2"Hole CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF z 30" Conductor N/A/N/A/N/A N/A Surface 131' N/A . 13-3/g' 13-3/8" Surface 68/L-80/Btrs 12.415 Surface 2,873' 0.150 9-5/8" Production 47/L-80/NSCC 8.681 Surface 12,123' 0.0732 9-5/8" Production 47/NT95HS/BTC 8.681 12,123' 15,528' 0.0732 TUBING DETAIL 4-1/2" Killstring 12.6/L-80/TDS 3.958 Surface ±10,000' 0.0152 WELL INCLINATION DETAIL Max Hole Angle=57 deg. @ 11,100' Angle at Top Perf=45 Deg.@ 15,068' \\ JEWELRY DETAIL t`y` my JO No Depth Item - 9 14,678' Baker Bonded Seal Assemblyw/GBH 22 LOC,ID-3.875" S ii 10 14,678' 9-5/8"Baker DB Packer w/seal Extension,ID=4.75" ►j' 11 14,696' Baker Packer Guide,ID=3.937" 0 12 14,835' Baker EBH-22S Latch,ID=3.875" (0 0iji. 13 14,836' 9-5/8"Baker SABL-3 Packer,ID=4.75" to 14 14,870' 4-1/2"OTIS X-Nipple,ID=3.813 15 14,887' 4-1/2"OTIS XN-Nipple 17 14,899' 4-1/2"WLEG-Bottom @ 14,900' mums ,r I I 9&10 11 21 12 PERFORATION DETAIL i 1 13 END Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status Size ric USZ-LCU 14,798' 14,800' 9,894' 9,895 2 2/8/1994 Sqz. 3-3/8" w14 USZ-FV 15,068' 15,078' 10,082' 10,089' 10 8/31/2008 Open 2" .' USZ-FV 15,072' 15,078' 10,084' 10,089' 6 2/8/1994 Sqz. 4-1/2" ," 5✓ R USZ-FV 15,084' 15,103' 10,093' 10,106' 19 2/8/1994 Sqz. 4-1/2" USZ-FV 15,084' 15,104' 10,093' 10,107' 20 8/31/2008 Open 2" USZ-FV 15,084' 15,103' 10,093' 10,106' 19 7/30/1995 Open 3-3/8" 16 '+1 USZ-FV 15,090' 15,103' 10,097' 10,106' 13 2/8/1994 Sqz. 3-3/8" 9-5/8" USZ-FV 15,107' 15,122' 10,109' 10,120 5 8/31/2008 Open 2" USZ-FV 15,108' 15,122' 10,110' 10,120' 4 2/8/1994 Sqz. 3-3/8" USZ-FV 15,108' 15,122' 10,110' 10,120' 4 7/30/1995 Open 3-3/8" USZ-FV 15,112' 15,120' 10,113' 10,118' 8 2/18/1994 Sqz. 3-3/8" -1- USZ-FV,FIV 15,130' 15,150' 10,125' 10,139' 20 8/31/2008 Open 2" -1-, USZ-FIV 15,160' 15,210' 10,146' 10,181' 50 8/31/2008 Open 2" _ USZ-FIV 15,215' 15,235' 10,185' 10,199' 20 11/25/1994 Open 3-3/8" ©15,2955' - " USZ-FIV 15,215' 15,245' 10,185' 10,206' 30 2/18/1994 Sqz. 3-3/8" USZ-FIV 15,235' 15,245' 10,199' 10,206' 10 11/25/1994 Open 3-3/8" USZ-FIII 15,316' 15,330' 10,256' 10,265' 14 4/4/1996 Sqz. 3-3/8" a-”,,t- j GENERAL WELL INFO API:50-029-22367-00-00 TD=15,530'(MD)/TD=10,405'(TVD) Original Completion -7/23/1993 PBTD=15,448'(MD)/PBTD=10,348'(TVD) RWO -2/18/1994 Set PXN Plug-2/29/2006 GLV C/O XX Plug -4/01&2/14 Revised By:JCM 9/12/2017 13 5/8" BOP Stack for • • Endicott well MPI 2-50 • v Aiiiii 54%" Shaffer Annular 13 5/8" 5m 1 . A — ,e .( Double Cameron "U" CO .*0 3 imi 2 7/8" to 5" VBR Rams 33 5/16" — U,,.r. _ 13 5/8" 5Mj _p=p CSO Rams (Blinds) /—r, *©* 14' 11 13/16" \/ V A IiE Mud Cross : '. a24" • e' ��-� 13 5/8�� 5M II '! r ,t� _ .- ��� # Drilling Spool W/4 _a ■ OUtS MGV 4 1/16" 5M CIW ® _____ ._______._._ HCR 4 1/16" 5M CIW -- Spacer spool 68" 13 5/8"5m • • 13"x4-1/2"hanger w/4"BPV profile Endicott MPU 2-50 Wellhead Schematic II e.,1711 enII ONNEMEMON illt e„. ,, E, 41116 Cameron tree I ` fir,; Eromionil_torm___un a $: tj 6ill PaaQtie� tin 1111111171MU 5\$ EMMEN <5' Hi � MI 13-5/8"3M x 13-5/8"5M McEvoy �:_1L (..- Casing Spool Ii lit '1. .Oil I11111111 "11W..40--0 , 1- - III 11L1:11� a . 3-1/8"5M McEvoy Valve 13-5/8"3M McEvoy b.. W Startinghead is _ `f 3-1/8"5M McEvoy Valve ,.r a 13 5/8" 95/8" 41/6 tubing III III 0 3 C 0 i io _ 5 lip U i1 s =_ m , . 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OTv ti mm Q S Zf228 - - .1 . ,,mD �i m - om r fV a n ti u1 as a Nmti Z WJ `, 1m " ry § w T N mwm; ,1mN$ ,1 6,, ,,g Z • ry .fl Q a ea9, ammPmmg$gmnn, a.mmC1m NF, o 0W 0 03 O 2 t 5 2 Ui z Ea 1 z _EE _ < ' IgM M 3 -3 z z z uu� o u¢i w 2 Y Y �' f g g 2 t f"/88 a / f i'9..� a h a a 3 3 g N n n m m e 3 ry m e x zz'oo w z t »cc0000 tic K 5= c rc a ? w w Z =�Q � 3az'oLLe°rco� �,� g i W w 8n oa,cOmmcezz g g md WR Wzao11 o`��gRag» oa zurcrc wd zsoz,„2zzoo gr 2 Eo �oola ygffff f� / t 7 ao33333.9 3 odd� > > oE00000000 2O o z 3 o Ci ,n v, r,n>>>> >>r r f • • Davies, Stephen F (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Thursday, April 19, 2018 9:02 PM To: Davies, Stephen F (DOA) Subject: RE: DIU MPI 02-50 (PTD 193-067; Sundry 318-173) - Question Steve, There is an approved Sundry in place for the RWO. During the prep work for the RWO the plug became stuck and the fishing operations ended leaving the cable in the hole.The intent is to use the ASR#1 to fish the cable and then use the Innovation rig later in the year to complete the RWO and convert to an injector. Please let me know if you'd like further explanation on this. Thank you, Taylor From: Davies, Stephen F (DOA) [steve.davies@alaska.gov] Sent:Thursday,April 19, 2018 4:13 PM To:Taylor Wellman Subject: DIU MPI 02-50(PTD 193-067; Sundry 318-173)-Question Taylor, DIU MPI 02-50 is currently classified as a development well. After Hilcorp's planned fishing and repair, is Hilcorp planning to convert the well to injection? The "Well Class after proposed work"section of the Sundry Application form is marked Service, and 1WINJ, but I don't see conversion to injection mentioned within the work program description. ThankY ou Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or Steve.davies@alaska.gov<mailto:steve.davies@alaska.gov>. 2_5S 2-t Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 Hilrnp tIsrka,LTA. RECEIVED Fax: 907 777-8510 DATA LOGGED E-mail: doudean@hilcorp.com Ib i3I,i201-1 VI.K, BENDER OCT 2 4 2017 DATE 10/25/2017 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPI 2-50 193-067 Prints: Thermal Multigate Decay Three Detector CD 1: p END 2-50 LDL 24AUG17.pdf 9/27/2017 10:42 A... PDF Document 5,961 KB END 2-50_LDL 24AUG17 img.tif 9/27/2017 10:42 A... TIFF image 16,139 KB MAIN_DOWNLOG..Ias 9/27/2017 10:42 A... LAS File 9,095 KB 2 MAIN IJPLOG.las 9/27/2017 10:42 A... LAS File 9,012 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: .�i /Date: (?),agerszo....7/7) V OF Tit • • ,,,,,�,„,*. THE STATE Alaska Oil and Gas ti�;,;—s �, of e T e T Conservation Commission ,lt itt I _ .�= 333 West Seventh Avenue ' '. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 • t..., Main: 907.279.1433 OF ALAS V. Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager1 Hilcorp Alaska, LLCM A !' 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU MPI 2-50 Permit to Drill Number: 193-067 Sundry Number:317-353 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1 , /6 •7171/4- Cathy P. 'oerster Commissioner DATED this 4 day of August, 2017. RBDMS (,`' AUG - 9 2017 4110 11110 REaCi; V!D STATE OF ALASKA j ,L ? S 20 / ALASKA OIL AND GAS CONSERVATION COMMISSION ��� g 1 1 APPLICATION FOR SUNDRY APPROVALS AG 'j 7 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑✓ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑✓ Other onversion 0 r 2.Operator Name: 4.Current Well Class: 5.Permit to Dall Number: -r) WE M 3- Hilcorp Alaska LLC Exploratory ❑ Development Q- 193-067 3.Address: 3800 Centerpoint Dr,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number Anchorage Alaska 99503 50-029-22367-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 462 • Will planned perforations require a spacing exception? Yes ❑ No Q / DUCK IS UNIT MPI 2-50 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0034634 ENDICOTT/ENDICOTT OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 15,530' • 10,405' , 15,448' . 10,348' . 2,422 N/A N/A Casing Length Size MD ND Burst Collapse Conductor 131' 30" 131' 131' N/A N/A Surface 2,873' 13-3/8" 2,873' 2,706' 5,020psi 2,260psi Production 12,123' 9-5/8" 12,123' 8,180' 6,870psi 7,100psi Production 3,405' 9-5/8" 15,528' 10,404' 8,150psi 5,090psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Schematic See Schematic 4-1/2" 12.6#/L-80 14,900 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): • 14,678(MD)/9,812'(1VD)&14,836(M Dy 9,920(TVD) 9-5/8"DB&9-5/8"SABL-3 and 4-1/2"SSSV , and 1,457(MDy 1,451(TVD) 12.Attachments: Proposal Summary ❑ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development❑ Service ❑✓ 14.Estimated Date for 15.Well Status after proposed work: 1-Sep-17 Commencing Operations: OIL ❑ WINJ ❑ ' WDSPL ❑ Suspended 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Taylor Wellman 'Tr„J Authorized Title: Operations Manager Contact Email: tjellrt'lane hjIcoracom t .I Contact Phone: 777-8449 Authorized Signature: - Date: 2 i J—, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. peo C„a116N i 3/7. 35 3 r-��/ t - Plug Integrity ❑ BOP TestrLJ Mechanical Integrity Test Location Clearance ❑ Other: ;(t 3 SOD fr.,' lj 2 7 s f ( i ). 4'ti�+. 0-j) 4 /414_, 414 ec�-�,L P1,, ..t (> {-t-) — -.�P r zc: .a,4G zs.,iii C b) Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No LrJ Subsequent Form Required: iv —I-0 1-1 RBDMS LL AUG - 9 2017 APPROVED BY Approved by: / P , COMMISSIONER THE COMMISSION Date:e._ T'_/7 ?i • 8/.t) A' g/7/? 1Z. 5 s"7 Submit Form and Form 10-403 Revised 4/2017 Approved application is valid GRIGINALapproval. Attachments in Duplicate • RWO—Conversion to PWI •14 • Well: END 2-50 PTD: 193-067 API: 50-029-22367-00 Hikurp Alaska,LU Well Name: END 2-50 API Number: 50-029-22367-00 Current Status: SI Producer Pad: Endicott Estimated Start Date: September 1, 2017 Rig: Innovation Reg. Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 193-067 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: 1722383 Well EZ Inputs Required: Yes Current BHP: 3,422 psi @ 10,000' TVD (SBHPS 7/15/2017 /6.58 ppg EMW) Maximum Expected BHP: 3,422 psi @ 10,000' TVD (No new perfs added) MPSP: 2,422 psi (0.1 psi/ft gas gradient) Brief Well Summary: The Endicott 2-50 well was drilled as an upper sub zone development well into the Fill, FIV, and FV zones. The well was TD'd at 15,528' and with a 9-5/8" production casing in July 1993. The well was worked over to squeeze existing perforations and isolate additional perforations at 14,798'-14,800'. In July 2007_the well developed TxIA communication with a faited-_VIII-IA. A leak detect log found a tubing leak at u4,b70'y The tubing was successfully patched from�1�4,659'-14,674',and the well was returned to service. The well remained online until developing IAxOA communication through a casing leak and was shut-in in April 2014. Given the SBHP trending with 2-58 & 2-46B through time and a PPROF indicating all UPSZs did contribute production,we assume all the sands open in 2-50 should expect to see WINJ. Notes Regarding Wellbore Condition The current status of the well is not operable and shut in. The well has TxIA communication through a leak in the seal assembly at 14,670' (tbg patch was pulled in June 2015). The well has lAxOA communication through a hole in the 9-5/8" casing. The 9-5/8" casing does not have integrity as per a failing MIT-IA and an identified an anomaly at 1270' and &a leak at 1650' and (leak detect log 07/20/14). A tubing caliper run on 30June2015 indicated the tubing to be in good to fair condition with only 1 identified leak and no areas of metal body loss above 5%. The OA has an open shoe that has an injectivity of 2.5bpm at 1200psi with seawater. Objectives: Orr- 6. P.rimar —Non-rig Repair 1. Restore mechanical integrity to the 9-5/8" casing by pumping a cement downsqueeze in the OA(9- 5/8"x13-3/8" annulus) 2. Restore mechanical integrity to the 4-1/2" tubing by placing a tubing patch. �( Second . - RWO 0 3. Restore mechanical integrity to the well: pull the existing completion, run and cement in a 7" tie-back to surface and run a new 4-1/2" completion. 4. Convert the well to water injection. fr04 c lea ct 14,et/ Ci J To ,V /d0-/1, - hp NI T/t f Cr Com' ?V% qhd c Co, oer19 MCF/ j 6it>t' q U/ �'�Rl�CIOr I�O/ /1¢l i✓���l,e.G 4rif)t ilio LA4111 aid C ower �+- / rec"v� /fo Z , vo/7i 04 644 A.( s€ !//"//7 RWO—Conversion to PWI • • Well: END 2-50 PTD: 193-067 API: 50-029-22367-00 Hilcora Alaska,LI) Variance Requested: 20AAC25.412(b) Packer will be set greater than 200ft measured depth from open perfs due to the mechanical configuration of the completion of the well. This design places the packer above the depths of the milled out landing and float collars of the 7" tie-back liner. � - Area of Review—Endicott DIU 2-50(193-067) S g .c at otr Z Table 1:Wells within AOR Well Name PTD Distance, Ft. Annulus Integrity 2-50 193-067 0' 9-5/8" casing: MIT-IA on 04/02/14 failed w/communication to OA 1.-e 4-k- 9 sj 4-1/2" tubing: LDL confirms a leak in the tubing seal assembly at 14,670' (tbg patch repaired tbg leak from 8/8/07—3/21/14. 1, Objective of procedure to remediate all leaks prior to conversion. U k` Table 2:Completion Detail U )4141-PNOW permit Well Current Status Zonal isolation (method) Cement Bond Log run on 11/10/1993 „„ ‹ T•°''✓1 indicates poor cement up to the tubing tail '.-' js at 14,899' and (CBL run post completion). Drilling records indicate an okay cement S/I Producer- 50-029-22367-000 193-067 2-50 Endicott Oil Pool job: no noted losses during job but did not bump plug. A remedial cement squeeze to circulate cement behind the liner was conducted in Feb 1994. CBL was run on 13Feb1994. See attached / - P Downsqueeze Procedure: /v '+� IA-)C• OPIi 1. MIRU slickline unit. Pressure test lubricator to 250 psi low/2,000 psi high. , 3°)- .k 2. Pull DGLV from Sta#6 at 4,420' and and set circ valve. 3. RD SL unit. 4. RU LRS pump truck to the tubing and cementers to the OA. Pressure test all lines to 250psi low/4000psi high. 5. LRS to begin pumping seawater down the tubing while taking returns from the IA to open top tank.Target rate is 4bpm while holding"'200psi backpressure on the IA. Measure for 1:1 returns from the TxIA. 6. Cementers to come online pumping down the OA while taking returns out the 9-5/8"x13-3/8" casing shoe. Pump±100bbls of mutual solvent. a. Confirm 1:1 returns from the TxIA. If cement is entering the IA from the OA(higher returns from the IA than pumped down the tubing), increase backpressure until reaching 1:1 returns. 7. Cementers swap to cement(15.6ppg Permafrost C)for±200bbls. a. Confirm 1:1 returns from the TxIA. Vary backpressure as needed to maintain 1:1 returns from TxIA. • • RWO-Conversion to PWI Well: END 2-50 PTD: 193-067 API: 50-029-22367-00 IIilcorp A laska,LU b. At a rate of 4bpm and a leak depth of 1650' and any cement that makes it into the IA takes -22min (88bbls)to reach surface. 8. Shut down on the cementers pumps. Continue LRS circulating for an additional 100bbIs or until returns are clean. a. If cement returns are observed in the returns, pump a "10bbI Powervis gel pill down the tbg to chase up and carry out any cement from the IA. 9. LRS to reduce pumping rate and continue circulating heated seawater (>150° F)for an additional ^'2 hrs to help cure cement. 10. Shut down on all pumps. RD both pumping crews. a. OA pressure > IA pressure by"'600psi due to hydrostatic difference between seawater& cement. 11. Wait on cement for a minimum of 48 hours. Perform a CMIT-TxIA to 3000psi for 30 min (charted). tov v. 12. RU SL unit and pressure test lubricator to 250 psi low/2,000 psi high. P"^�� 5. f‹ 461 13. Pull 4-1/2" PXN plug from 14,887' md. 14. Set 4-1/2"x2-7/8" nipple reducer and plug at 14,887' md. 15. Pull circ valve from Sta #6 at 4,420' and and set DGLV. 16. RD SL unit. 17. RU E-Line unit and pressure test lubricator to 250 psi low/2,000 psi high. .661- 18. Set lower patch element at±14,676' md. Use SLB LDL dated 13July2007 as the correlation log. fk14 19. RD E-Line unit. 20. RU SL unit and pressure test lubricator to 250 psi low/2,000 psi high. 21. RIH and stab into lower packer element with upper patch section. Set upper packer for patch set±14,661'- 14,676'md (element to element depths). 22. Perform an MIT-IA to 2500psi (charted). a. AOGCC witness required for this test (pre-conver . 23. Pull 2-7/8" plug from 14,887' md. 24. RD SL unit. Contingency if Downsqueeze Fails �. -� lg ( l� wo) Pre-Wor over •rep •rocedure: 25. MIRU slickline unit. Pressure test lubricator to 250 psi low/2,000 psi high. 26. Pull PXN plug from 14,887' md. 27. RD SL unit. 28. MIRU E-Line unit. 29. Pressure test lubricator to 250 psi low and 2,000 psi high. 30. RIH and set composite bridge plug at±14,727' md. Dump bail-10' of cement on top of plug (6.4gal). 31. RIH with tubing cutter for 4-1/2" 12.6#/ft L-80 tubing. Cut tubing at±14,672' MD, mid-joint in the 10' pup joint above the packer. Note pressure equalization in report. —. a. Use tubing tally dated 02/14/1994 as reference log. 32. Clear and level pad area in front of wellhouse. Spot rig mats and containment. 33. RD well house and flowlines. Clear and level area around well. RWO—Conversion to PWI • • Well: END 2-50 PTD: 193-067 API: 50-029-22367-00 lIikorp Alaska,LLQ 34. RU Little Red Services Pump. Setup reverse out skid and 500 bbl returns tank and additional upright tanks as needed. Pressure test lines to 3,000 psi. 35. Forward circulate at least one wellbore volume with 8.5 ppg seawater down the tubing (thru tubing cut @ ±14,672' md),taking returns up the annulus to the 500 bbl returns tank. a. Annular volume from cut @ 14,672' =786bb1s b. Tbg volume to the cut @ 14,672' = 223bb1s c. Total volume = 1009bbls 36. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 37. RD Little Red Services Pump and reverse out skid. Workover Procedure: 38. MIRU Innovation 39. Check for pressure and if needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/±8.5ppg seawater. 40. Set BPV. ND tree/ NU BOPE. Set TWC. 41. Test BOPE to 250 psi Low/3,500 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per Innovation BOPE Test Procedure. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 4-1/2" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 42. Contingency: (If the tubing hanger won't pressure test due to either a control line leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor \� the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking Xt4 anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 43. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/±8.5ppg seawater as needed. 44. MU 4-1/2" landing joint or spear and BOLDS. Recover the tubing hanger. • RWO—Conversion to PWI Well: END 2-50 PTD: 193-067 API: 50-029-22367-00 Hileorp Alaska,LL Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 45. RU control line spooler. POOH and lay down the 4-1/2"tubing to the cut at+/-14,672'. a. The 4-1/2"TDS tubing will not be salvaged. b. From 0—1457'there are two%" control lines (balance and control line)to the OTIS HXO nipple. 46. PU tubing stub dress off assembly and scraper for 9-5/8" casing and cleanout to at least' 14,650' MD. RIH, dress tubing stub, circulate well clean with seawater and POOH. 47. Change out rams for 7" casing and BOPE test to 3,500psi. "'/ 48. RIH with 7"tie-back assembly: - 4-1/2" unique machine overshot (modified to have 3 shear screws in the middle of the overshot body. - 10' pup joint - 7"x4-1/2" ported crossover(drill 4 x'A" holes every 90 degrees) - Full joint - 7" HES float collar - 7", 26#, L-80 casing to surface 49. Record PU/SO weights above the tubing stub. Set down over the tbg stub. Note the shear screws to ensure fully over the stub in the report. Space out and land the 7" casing in the existing casing spool. 50. Begin mixing cement and pump down the 7" while taking returns from the 7"x9-5/8" annulus. Launch 7" wiper dart as needed and displace to pump a total of 415bbls (1.1 x annulus volume) of 15.8ppg Class G cement. a. Fluid spacers to be pumped as per cementing company design. 51. Bump plug with 1000psi and hold for 10 minutes. RD cementers. 52. Change out rams for 4" DP and BOPE test to 3,500psi. 53. MU and RIH with 6-1/8" bit and scraper assembly. Clean out down to the landing collar. Scrape across the casing around ±14,490' and where the production packer will be set. 54. WOC for compressive strength to reach 500psi. Perform an MIT on the casing to 2500psi for 30 min (charted). Contact Ops Engineer if test does not pass. 55. Hang off 6-1/8" bit and scraper assembly off of a 7" storm packer. 56. ND the BOP stack and install new 13-5/8"x13-5/8" spool piece for the tubing hanger. NU BOPE and test the broken connection to 3500psi. a. At this point in the operation the reservoir is isolated via the cement plugs in the well (confirmed with MIT of the 7" tie-back) and with a full column of seawater in the well. 57. RIH and pull 7" storm packer. 58. Drill out float equipment and clean out the 7" casing to the 7"x4-1/2" ported crossover. Circulate a bottoms up at max rate or until clean seawater returns are observed. TOOH. • RWO—Conversion to PWI Well: END 2-50 PTD: 193-067 API: 50-029-22367-00 Hilcorp Alaska,LU kr 59. MU and RIH with 3.75" and cleanout assembly. Drill out the cement plug and CBP set at±14,727' md. Drift down to±14,800' to ensure tubing tail is clear. TOOH. a. Note that the well may begin to take fluids once the plug is drilled out. 60. Prep to run 4-1/2", 12.6#/ft, L-80,TXP completion. 61. RIH with 4-1/2" completion. Record PU and SO weights. Space out to be close to the 7"x4-1/2" crossover without setting down on the crossover to avoid pinching the WLEG. a. Packer setting depth is ±14,490' MD. 62. Reverse circulate 100 bbls of seawater water followed by 225 bbls seawater with corrosion inhibitor and 40bbls of diesel at 3 BPM. 63. Land the tubing hanger and RILDS. Lay down landing joint. Test tubing hanger packoff to 5,000 psi. 64. Drop the ball & rod and set the packer. Increase the pressure and test the tubing to 3,500 psi for 30 minutes. 65. Bleed down the tubing pressure and perform an MIT-IA to 3000psi for 30 min (charted). NarI 1:7 ...moi J a. This test will need to be witnessed by the AOGCC. ✓ �s� 66. Set TWC and ND BOPE and NU adapter flange and tree. Test to 5,000 psi. 67. Pull TWC and install BPV. 68. RDMO. Post Workover Procedure: 69. Pull BPV. 70. RU SL and PT to 250 psi low/2,000 psi high. Fish ball & rod and plug body. Drift through the tubing tail w/ dummy perf gun. RD SL 71. Set SSSV. 72. RD Slickline. 73. Turn well over to Production Attachments: L .� - -Gr 1. As-built Schematic ("el 2. Proposed Schematic L,�s ` d-;" 3. Proposed Schematic-Contingency �! 4. BOPE Schematic 5. Wellhead/Tree schematic ,s43.(7 7 6. AOR Map 7. SLB CBL 13Feb1994 8. Blank RWO Sundry Revision Change Form • Duck Island Well: END 2-50Unit H 0 S H E MAT C Last Completed: 7/23/1993 Ililcorp Alaska,LLC ECit i ,4-; PTD: 193-067 SAFETY NOTE "I-REE&WELLHEAD OPEN HOLE/CEMENT DETAIL KB Elev.:55.3'/BF Elev.:16..22' Tubing leak identified @ 14,671' Tree 4-1/2"CIW 13-3/8" 4,185 cu/ft Permafrost in 17.5"Hole Casing leak identified @ 1,270' Wellhead 13-5/8"McEvoy 9-5/8" 575 cu/ft Class`G'in a 12-1/4"Hole 7" 645 cu/ft Class"G"in 8-1/2"Hole 30'41 rA� CASING DETAIL 1 Size Type Wt/Grade/Conn Drift ID Top Btm BPF , 30" Conductor N/A/N/A/N/A N/A Surface 131' N/A 13-3/8" I 13-3/8" Surface 68/L-80/Btrs 12.415 Surface 2,873' 0.150 9-5/8" Production 47/L-80/NSCC 8.681 Surface 12,123' 0.0732 9-5/8" Production 47/NT95HS/BTC 8.681 12,123' 15,528' 0.0732 2 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TDS 3.958 Surface 14,900' 0.0152 WELL INCLINATION DETAIL Max Hole Angle=57 deg. @ 11,100' Angle at Top Perf=45 Deg.@ 15,068' 3 JEWELRY DETAIL No Depth Item 4 1 1,457' BBE SSV&4-1/2"OTIS BVN Nip,ID=3.813 s. GLM DETAIL:Camco w/RK Latch &Port=O 2 4,420' ST 6:Type=SPMG,Dev.=52,TVD= 3,752',7/18/2017 J 6 3 8,139' ST 5:Type=DMY,Dev.=55,TVD= 5,889',4/1/2014 4 10,899' ST 4:Type=DMY,Dev.=56,TVD= 7,470',8/29/2004 .. 6 5 12,624' ST 3:Type=DMY,Dev.=50,TVD= 8,496',8/29/2004 6 13,685' ST 2:Type=DMY,Dev.=52,TVD= 9,185',9/12/1995 7 13,832' ST 1:Type=OPEN,Dev.=53,TVD= 9,276',6/27/2015 7 8 14,657' 4-1/2"SWS Nipple,ID=3.813" 9 14,678' Baker Bonded Seal Assembly w/GBH-22 LOC,ID=3.875" 10 14,678' 9-5/8"Baker DB Packer w/seal Extension,ID=4.75" I 18 ,Yk' 11 14,696' Baker Packer Guide,ID=3.937" / �.�L p°` iv/1- 12 14,835' Baker EBH-22S Latch,ID=3.875" 13 14,836' 9-5/8"BakerSABL-3 Packer,ID=4.75" r (5°‘'.) 14 14,870' 4-1/2"OTIS X-Nipple,ID=3.813" 110,- --.10 1►�t.r, 9&10 15 14,887' 4-1/2"OTIS XN-Nipple***Set PXN plug on 7/15/2017*** CES 17 14,899' 4-1/2"WLEG-Bottom @ 14,900' ,A II 11 zst 540_2 u 12 w PERFORATION DETAIL s Y 1 wr1„.13 ,; END Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Size "' USZ-LCU 14,798' 14,800' 9,894' 9,895 2 2/8/1994 Sqz. 3-3/8" 14 USZ-FV 15,068' 15,078' 10,082' 10,089' 10 8/31/2008 Open 2" a x 4, USZ-FV 15,072' 15,078' 10,084' 10,089' 6 2/8/1994 Sqz. 4-1/2" USZ-FV 15,084' 15,103' 10,093' 10,106' 19 2/8/1994 Sqz. 4-1/2" ,iv- : 15 m USZ-FV 15,084' 15,104' 10,093' 10,107' 20 8/31/2008 Open 2" FlfCI 16 51 USZ-FV 15,084' 15,103' 10,093' 10,106' 19 7/30/1995 Open 3-3/8"9-5/8" USZ-FV 15,090' 15,103' 10,097' 10,106' 13 2/8/1994 Sqz. 3-3/8" USZ-FV 15,107' 15,122' 10,109' 10,120 5 8/31/2008 Open 2" , USZ-FV 15,108' 15,122' 10,110' 10,120' 4 2/8/1994 Sqz. 3-3/8" USZ-FV 15,108' 15,122' 10,110' 10,120' 4 7/30/1995 Open 3-3/8" USZ-FV 15,112' 15,120' 10,113' 10,118' 8 2/18/1994 Sqz. 3-3/8" USZ-FV,FIV 15,130' 15,150' 10,125' 10,139' 20 8/31/2008 Open 2" USZ-FIV 15,160' 15,210' 10,146' 10,181' 50 8/31/2008 Open 2" Sand Dump F USZ-FIV 15,215' 15,235' 10,185' 10,199' 20 11/25/1994 Open 3-3/8" -Carboy USZ-FIV 15,215' 15,245' 10,185' 10,206' 30 2/18/1994 Sqz. 3-3/8" @15' USZ-FIV 15,235' 15,245' 10,199' 10,206' 10 11/25/1994 Open 3-3/8" r USZ-FIII 15,316' 15,330' 10,256' 10,265' 14 4/4/1996 Sqz. 3-3/8" GENERAL WELL INFO API:50-029-22367-00-00 TD=15,530'(MD)/TD=10,405'(TVD) Original Completion -7/23/1993 PBTD=15,448'(MD)/PBTD=10,348'(TVD) RWO -2/18/1994 Set PXN Plug-2/29/2006 _ GLV C/O XX Plug -4/01&2/14 Revised By:JCM 7/17/2017 14 • io Duck Island Unit ND 2-50 Well: E SCHEMATIC (Proposed) Last Completed: 7/23/1993 Hileorp Alaska,LLC. WL)N- R;3_ PTD: 193-067 SAFETY NOTE TREE&WELLHEAD OPEN HOLE/CEMENT DETAIL KB Elev.:553'/BF Elev.:16..22' Tubing leak identified @ 14,671' Tree 4-1/2"CIW 13-3/8" 4,185 cu/ft Permafrost in 17.5"Hole WI, : Casing leak identified @ 1,270' Wellhead 13-5/8"McEvoy 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole k, x 7" 645 cu/ft Class"G"in 8-1/2"Hole CASING DETAIL P, . '�A• Size Type Wt/Grade/Conn Drift ID Top Btm BPF fi"t `�� � 13-3/8",� 30" Conductor N/A/N/A/N/A N/A Surface 131' N/A , .Ir 13-3/8" Surface 68/L-80/Btrs 12.415 Surface 2,873' 0.150 9-5/8" Production 47/L-80/NSCC 8.681 Surface 12,123' 0.0732_ 9-5/8" Production 47/NT95HS/BTC 8.681 12,123' 15,528' 0.0732 2 . VA' TUBING DETAIL 1/2" Tubing 12.6/L-80/TDS 3.958 Surface 14,900' 0.0152 ©fr ' � WELL INCLINATION DETAIL 'i`'JV Max Hole Angle=57 deg. @ 11,100' 3 �8f>�` Angle at Top Perf=45 Deg.@ 15,068' I JEWELRY DETAIL No Depth Item 4 1 1,457' BBE SSV&4-1/2"OTIS BVN Nip,ID=3.813 GLM DETAIL:Camco w/RK Latch& Port=O 2 4,420' ST 6:Type=DMY,Dev.=52,TVD= 3,752',Future 5 3 8,139' ST 5:Type=DMY,Dev.=55,TVD= 5,889',4/1/2014 "` , 4 10,899' ST 4:Type=DMY,Dev.=56,TVD= 7,470',8/29/2004 ,f 6 . 5 12,624' ST 3:Type=DMY,Dev.=50,TVD= 8,496',8/29/2004 I. 6 13,685' ST 2:Type=DMY,Dev.=52,TVD= 9,185',9/12/1995 it 7 13,832' ST 1:Type=DMY,Dev.=53,TVD= 9,276',6/27/2015 7 ., 8 14,657' 4-1/2"SWS Nipple,ID=3.813" 9 ±14,661' 4-1/2"Patch(14,661'-14,676'md)ID= Y 10 14,678' Baker Bonded Seal Assembly w/GBH-22 LOC,ID=3.875" 8 44, ,i_}.__ 11 14,678' 9-5/8"Baker DB Packer w/seal Extension,ID=4.75" a P,-i- 1-1 12 14,696' Baker Packer Guide,ID=3.937" 11,,J-) � 13 14,835' Baker EBH-22S Latch,ID=3.875" 9 f, Le�`'' 14 14,836' 9-5/8"Baker SABL-3 Packer,ID=4.75" 14(07 10&11 15 14,870' 4-1/2"OTIS X-Nipple,ID=3.813" O'rk) 16 14,887' 4-1/2"OTIS XN-Nipple w/2-7/8"Nipple reducer,ID=231" , ill e` 17 14,899' 4-1/2"WLEG-Bottom @ 14,900' PERFORATION DETAIL 14 END Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Size rSt,' USZ-LCU 14,798' 14,800' 9,894' 9,895 2 2/8/1994 Sqz. 3-3/8" b9 '.15 USZ-FV 15,068' 15,078' 10,082' 10,089' 10 8/31/2008 Open 2" Q s USZ-FV 15,072' 15,078' 10,084' 10,089' 6 2/8/1994 Sqz. 4-1/2" l16 USZ-FV 15,084' 15,103' 10,093' 10,106' 19 2/8/1994 Sqz. 4-1/2" a USZ-FV 15,084' 15,104' 10,093' 10,107' 20 8/31/2008 Open 2" it USZ-FV 15,084' 15,103' 10,093' 10,106' 19 7/30/1995 Open 3-3/8" 24 17 USZ-FV 15,090' 15,103' 10,097' 10,106' 13 2/8/1994 Sqz. 3-3/8" /�IUSZ-FV 15,107 15,122' 10,109' 10,120 5 8/31/2008 Open 2" USZ-FV 15,108' 15,122' 10,110' 10,120' 4 2/8/1994 Sqz. 3-3/8" 4 7/30/1995 Open 3-3/8" / '� USZ-FV 15,108' 15,122' 10,110' 10,120' USZ-FV 15,112' 15,120' 10,113' 10,118' 8 2/18/1994 Sqz. 3-3/8" USZ-FV,FIV 15,130' 15,150' 10,125' 10,139' 20 8/31/2008 Open 2" ' USZ-FIV 15,160' 15,210' 10,146' 10,181' 50 8/31/2008 Open 2" Sand Dump ' USZ-FIV 15,215' 15,235' 10,185' 10,199' 20 11/25/1994 Open 3-3/8" -Dar,95 @15 x ,2295' . USZ-FIV 15,215' 15,245' 10,185' 10,206' 30 2/18/1994 Sqz. 3-3/8" @ 15 USZ-FIV 15,235' 15,245' 10,199' 10,206' 10 11/25/1994 Open 3-3/8" e. 'Y T USZ-FI11 15,316' 15,330' 10,256' 10,265' 14 4/4/1996 Sqz. 3-3/8" + r '= GENERAL WELL INFO API:50-029-22367-00-00 TD=15,530'(MD)/TD=10,405'(1VD) Original Completion -7/23/1993 PBTD=15,448'(MD)/PBTD=10,348'(TVD) RWO -2/18/1994 Set PXN Plug-2/29/2006 GLV C/O XX Plug -4/01&2/14 Revised By:TTW 07/28/2017 Scher t14ic (PROPOSED - • Duckll:IslandEND Unit We Contingency) Last Completed: 7/23/1993 Hamra Alaska,LLC fq 1....A) bp ri C"N- PTD: 193-067 CASING DETAIL KB Elev.:55.3'/BF Elev.:16..22' Size Type Wt/Grade/Conn Drift ID Top Btm 0 I 30" Conductor N/A/N/A/N/A N/A Surface 131' 30 Jr 4.4 p 13 3/8" Surface 68/L-80/Btrs 12.415 Surface 2,873' A,* 9-5/8" Production 47/L-80/NSCC 8.681 Surface 12,123' 9-5/8" Production 47/NT95HS/BTC 8.681 12,123' 15,528' 'fit 6 7" Tie-Back 13-3/8',4-,"'4= � ,off, TUBING DETAIL 4 ( 4-1/2" Tubing 12.6/L-80/TDS 3.958 Surface 14,900' JEWELRY DETAIL ' No Depth Item 1 ±1,500' 4-1/2"Nip,ID=3.813 l; 2 ±14,450' X-Nipple 1"x, 3 ±14,490' 'x 4-1/2"Production Packer 11 4 ±14,530' X-Nipple b�� 5 ±14,570' XN-Nipple 4-;4- 6 ±14,610' WLEG I I Gµt�r > 7 ±14,670' 7"x 4-1/2"xo overshot(ported) C -iv 5 8 14,678' 9-5/8"Baker DB Packer w/seal Extension,ID=4.75" \ 9 14,696' Baker Packer Guide,ID=3.937" 10 14,835' Baker EBH-22S Latch,ID=3.875" 11 14,836' 9-5/8"Baker SABL-3 Packer,ID=4.75" V4I 2 1 12 14,870' 4-1/2"OTIS X-Nipple,ID=3.813" "` 13 14,887' 4-1/2"OTIS XN-Nipple ei 0 14 14,899' 4-1/2"WLEG-Bottom @ 14,900' ILO 4. u3 A 57 7'lading& *. #=i 4 float cellars ' vit (drilled cut) , p 5 ; e 6. 7 PERFORATION DETAIL 8 END Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Size s '- Cf�''^p USZ-LCU 14,798' 14,800' 9,894' 9,895 2 2/8/1994 Sqz. 3-3/8" r1 NI USZ-FV 15,068' 15,078' 10,082' 10,089' 10 8/31/2008 Open 2" ii USZ-FV 15,072' 15,078' 10,084' 10,089' 6 2/8/1994 Sqz. 4-1/2" USZ-FV 15,084' 15,103' 10,093' 10,106' 19 2/8/1994 Sqz. 4-1/2" USZ-FV 15,084' 15,104' 10,093' 10,107' 20 8/31/2008 Open 2" ItO USZ-FV 15,084' 15,103' 10,093' 10,106' 19 7/30/1995 Open 3-3/8" "° k h12 t USZ-FV 15,090' 15,103' 10,097' 10,106' 13 2/8/1994 Sqz. 3-3/8" USZ-FV 15,107' 15,122' 10,109' 10,120 5 8/31/2008 Open 2" 13 USZ-FV 15,108' 15,122' 10,110' 10,120' 4 2/8/1994 Sqz. 3-3/8" USZ-FV 15,108' 15,122' 10,110' 10,120' 4 7/30/1995 Open 3-3/8" 14 USZ-FV 15,112' 15,120' 10,113' 10,118' 8 2/18/1994 Sqz. 3-3/8" 9-5/8"4.. USZ-FV,FIV 15,130' 15,150' 10,125' 10,139' 20 8/31/2008 Open 2" s.+ �~ USZ-FIV 15,160' 15,210' 10,146' 10,181' 50 8/31/2008 Open 2" x ' USZ-FIV 15,215' 15,235' 10,185' 10,199' 20 11/25/1994 Open 3-3/8" Y USZ-FIV 15,215' 15,245' 10,185' 10,206' 30 2/18/1994 Sqz. 3-3/8" I 5'1'7 USZ-FIV 15,235' 15,245' 10,199' 10,206' 10 11/25/1994 Open 3-3/8" L' USZ-FIII 15,316' 15,330' 10,256' 10,265' 14 4/4/1996 Sqz. 3-3/8" said Dump -Cabdite ,.; x WELL INCLINATION DETAIL OPEN HOLE/CEMENT DETAIL @ 15,295' Max Hole Angle=57 deg. @ 11,100' 13-3/8" 4,185 cu/ft Permafrost in 17.5"Hole Angle at Top Perf=45 Deg.@ 15,068' 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole �-,64 7" 645 cu/ft Class"G"in 8-1/2"Hole a ,f42:1 - GENERAL WELL INFO API:50-029-22367-00-00 TREE&WELLHEAD TD=15,530'(MD)/TD=10,405'(TVD) Original Completion -7/23/1993 Tree 4-1/2"CIW PBTD=15,448'(MD)/PBTD=10,348'(TVD) RWO -2/18/1994 Wellhead 13-5/8"McEvoy Set PXN Plug-2/29/2006 GLV C/0 XX Plug -4/01&2/14 Revised By:TTW 07/27/2017 • Endicott—Well END 1-29 2017 Innovation BOP Stack n-Q 1 13-5/8 SM Control Technology Annular BOP II EIE:3 OA 511' 5M Control C:=Js Technology Double Ram C.9 F-C4 410",t, ai 3-118"Kill Line ,11 A-raer.,11 Choke Line Nr\ditV 13 5'8 1111 -1C= Er3 SM Control Technology Single Ram 17.27171.1 13-5/8"x 5M Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 121/4" 13-5S"51..1 CTI Immix BOP re? diverter Function.Test Only • 13-5/S"x 5M Control.TPAndonv bgAnnular BOP • 13-518"x 5M Control Technoloff bgnouble Gate InIal Test 25014000 o Blind rain in Um.caxity- ..Annular 2500 psi) • 1,61:1 crass 3"x 5M side outlets • 13-5,S"x 5M Control Teclinoloev Sinale 17.316. • 3-1/"x 511 Choke Li3se Subsequent Tests: • x 51.111(111 line 250'4000 ▪ 3-1S",5M Choke manifold (Annular 2500 psi) • Standpipe,Boor valves.gc, Primary closing unit:Control Technology Inc.(CTI), 6 station,3000 psi,220 gallon accumulator unit Primary closing hydraulics is provided by an electrically driven triplex pump.Secondary back-up is an electric triplex pinup on a different electrical circuit and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: • Well control event(30Ps utilized to shut in the well to control influx of formation fluids). • 24 tLonr¬igg prior to spud. • 24 baumnoticg prior to testing BOP& • 24 wft prior to casing running&cement operations. • Any other notifications required in APD. • 0 13"x4-1/2"hanger w/4"BPV profile Endicott MPU 2-50 Wellhead Schematic N gram■ tip ( 1 I I 1 i 1 tit ......11,,w.- a iu //tr/ ,;- s 41/16 Cameron tree ' 1 fir, : / is. ,s c0 ________, gin.. .. O PdaP�e� Ofo X1`16 13-5/8"3M x 13-5/8"5M McEvoy ._ Casing Spool �' —� 41 1s, I tut 1 . 00 a / '�� r: —_ IIID dir ,. /' i i°1-1".. Z R �l ° 'w�I' 3-1/8"5M McEvoy Valve 13-5/8"3M McEvoy l Startinghead ��—OE ! =. L �� 3-1/8"5M McEvoy Valve �_ 13 5/8" 9 5/8" 41/6 tubing • • . f rn,r},T Endicott MPU 2-50 =, 13"x4-1/2"hanger w/4"BPV • Wellhead Schematic(Proposed) Lgul4777-..4 7-.. profile SCJ, "k 4-1/16"5M CIW Tree \ tai nraatp Alat ,o2knrk 31 itt (t7l) 13-5Ia SgoILZJ 4L_.,__1 (/�'� .. sIi(= _Nin A W 13-5/8"x 13-5/8"5M McEvoy - I,a I ` ti CFI")Tubing Spool I i ' :Mit st.. ,,,,,_ ...„ir 2-1/16"5M CIW Valve -14.- SPc� 13-5/8"3M x 13-5/8"5M McEvoy _ �+r Casing Spool 'Y ,P ' 11 II 1a1� '11-. 3-1/8"5M McEvoy Valve ' • 3-1/8"5M McEvoy Valve 13-5/8"3M McEvoy Startinghead �� 1 i • U F o U LL a LL d o g Z (c, o W F w Eri o Q a N p `uo 0 '''(`,) .,;-8, ��' n` J I co w N d co P w E .. amt W O a za • L- — - ¢-m n^ W O i a p oN _,O - = w`o cru _ 0 1E2 2 � � Waz5 _ �oto� JO Z O O 3 moi¢ o m a ? m 2.25 0 :C ¢ QF-EC 7 r ■• Ol • a) •r rs i d,'rn N` N- M O H I1:: Ja' o 00 N CD‘-• �,-.2 mi (.9 fir . v N n aft • / . ` / co � NI . . ,‘ fil4b 400 emo Me. coV N1 N 4 Q W k M 999 s 1M N N 8 P. • • II IIVA[ IIIIIIIIIIIIIIIIIIIJill!IllIIIIllirdr t.'... HEC00613379 00 ATLAS SEGMENTED BOND L_C WIRELINE Western SERVICES Gamma Ray / CCL International kk 1 FILE NO. COMPANY BP EXPLORATION (ALASKA) INC. 6001.07 WELL_ z-50 / U: 8 MP API NO. FIELD ENDICOTT 50-029-22367-00 COUNTY NORTH COPE STATE ALASKA _ I 5",100' LOCATION: I OTHER SERVICES SURFACE: NONE 3218' ESL R 2317' FEL I FINAL PRINT SEC 36 TWE' I2N RGE 16E I MEAN SEA LEVEL ELEUATION A.0' FT. ELEVATIONS Fb PERMANENT DATUMKB �� LOG MEASURED FROM R.K.B. _ __ 56 FT. ABODE PERMANENT DATUM 56'DF - DRILL. MEAS. FROM ROTARY KELLY BUSHING GL 10' PAD DATE I3-FEB-94 RUN 1 SERVICE ORDER 141169 _____—___ DEPTH-DRILLER 1544B' PBTD DEPTH-LOGGER 15425' TAGGED BOTTOM LOGGED INTERVAL 15417' _ 1 TOP LOGGED INTERVAL 14397' ---- TYPE FLUID IN HOLE BRINE _. _ SALINITY PPM CL. - -- DENSITY LB/GAL. LEVEL FULL MAX. REC. TEMP. DEG. F NOT RECORDED OPR. RIG TIME 5.6 HOURS _ EQUIP. NO. / LOCATION HL 6491 N. SLOPE (--- ._-.__ ! RECORDED BY BRAD ESARY --.- - WITNESSED BY D. CHESTER / R. LOVELAND , PERFORATION PROTOCOL CASING RECORD GUN RUN 1 SHOTS/FT FROM TO SIZE WEIGHT FROM TO j - 13 3/B" GB LB SURFACE 2873' 9 5/B" 47 LB.___. SURFACE 15530' ' I , .r ■ .. _ t 11111110=111N1• -- -_- +f h: _ _ G a u nc .......... �' . PAIIIMENIMIN MOW .b: i 1 ' 9 ' r - 1111111111 • ii ' ,j "-- II -}"N ' . i 1 ` IIi. Y ,4 � 10iiiiii;: r : U ;' .:4 t T ...1 dillIMIL , 1 fl II l •sS.s I 'F i. I ill 441. '41 , .... .--- i , f.:" ill . , . • i f ' 1 1111ilillON I a a ��__�' :' tri. t 11111111111111111111.1• ==�� -- 44 J1 •:4'.-4 g •,-- .... S-_-.-:::Z 11,•. ''- l ---INIIIIM:-� ' xtu ls 111 (3y EM 0 is i i 1 ttliq.414-11. . • It [ tri.III:4- i,1 r . 6 5 __ rk lit 1 _�_ E r.+ rte*t ; r c ".....k l ;:II I' ,s , c —'1.------- 1 V--;.7i#11- ir•J ._ " i'IS -i''-'-.?1 till 1 I, i .,..„.0'44.. 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I ; i I' D cn g s d" 11 ohm II :I._ ' i -o -, A.,,, 4 • -a mu MIMI ..N I .4 - II r-- I 1 ill Ilimina. r, . -_. i IIIN —— ' m i' • II #10 11111` .L. iiii - -- iiitix :,- ., AL 1 NI 111111111111A, & j--- lik tr"4 il1-" Mil killThill' ill 1 1111 " - ` 1.:t..1 f� -:-.2i-J.C.:- a ' : III , , , a • IT;HI_ � of g , -4__ ! x h MIME :ii.111 11111111111158e: :.. t o :ti ii 01111111111111 (412 III III III II MP" = W. I. flok. .� ■.�_ -- � —s t f_ s , - _ -____ 1." la - -I - t M 111111111Tii1111111r■1111Irr 'r'• MOS"!'' COC 11,1w.4.- 6 ` r 4 4 is 1 SIMI 1111•111111111 -d— �# �� H� �� �� -�-i (14C-�IIIIIIIIIIIIIPPMIIIMIIE•1 EOM MI6. "I ; r WA� nil IMMO WALI 1 -- - ■ ... .• 0 r- MEM ... • W '—11111M11111111.11 r1111111111111REFIIN Mill - i .-. + z I er .i 11111111=111111111.....� M=� - ' a., =� — .. I i1IIIIIIIIIIIIIIII - :I 11111 MM. IM 1 11 Iill. 1 n = - i) . - I w.1111111111111111:1111111 -1 EINIIIIIMIIIMI =111 I AM 111111=1:=111111111111ftm... -- - I - 1 i i't A immiour.m.11 . miiimmumming 1 r• --`- I - tido C��.._ ...... wt• �� t.. _ � � ►. jIJIJ � BIMi - ) I. . , , I WIIICIIIIIIIII- i . 111111111111111111111111111 v r� ��_�� 111111111 I r 3 i4: a>• ., Er: 71"." II 11 g = i 1111111•11111h. '1 7, t IIIIIBMIIIIIIOIIIIIIMIIIIIOMNIWI" ' ., .i., -. N 1111111111111MItrisiAl lir. 01.1111111111111111111MM ...... 1 .. , f / r, 41 - R r i1111111•111e, [ 1111111111P DTMN - �l __ - ' _ ME. _ > -2;r., 1 i- C, illiri 116.11...1111111 lala ''. 7 i II: f i -FR- � 1'lI 4 N f 4 ; r1 6 __ is -TO } P 1 pl - .__ 5 . . 11 , ------1- , , DTMX(MICS'FT) VARIABLE DENSITY 280 80 DTMN(MICS/FT) ATMN(DB/FT) • • 75 C 04-. 0 .> 0 a) '`=r. ca) ❑ S. Ce nsC -'' 6 UCC _ � � Q cp 0_m � � <a 0_ E O c ms U) O N Y a) 1 p Qv a Q >.E am c L • I2 > 0" c D . a L N = d ... CL CT a > ca CI asII co 1 L § 1 V C 0 19 N co (3) ^L N O N C �i ❑ 0.--,• a-. co was U 'a — a U L ca0 1 -o 0 -a ' O a) CO cO Q O CD i E N a = U N 0 -13 °p 'a N i 2 ▪ °' ms o +1 ,� L L (t11 rl N ../ 0 O a) 'a> > > Ct a) U �,. Q C c-4o a L t. < ca 0 c0 * w CC 0. O r0 C ❑ N u) Qd o O O rr '--, 0 N C C ._ 00 2 1-i >+ 0 0 4) 0 C' C' c 0 as U a O O V >= • ) ! W t U co 2 �a1 H . • Endicott Unit Well: END 2-58 SCHEMATIC Last Completed: 6/5/1990 Hiker"'Alaska,LLC PTD: 190-052 TREE&WELLHEAD RTE=55.1'/BFE=16.4'(DOYON 15) Tree 4-1/16",5,000psi,CIW JI ! I j Wellhead 13-5/8",5,000psi, FMC OPEN HOLE/CEMENT DETAIL - [_,I 30 30 Driven '�-- ' 1 13-3/8" 2,912 cu/ft Permafrost in 17-1/2"Hole ,' 9-5/8" 1,239 cu/ft Class"G"in 12-1/4"Hole 13-3/8" ..a 7" 718 cu/ft Class"G"in 8-1/2"Hole " CASING DETAIL 2 I Size Type Wt/Grade/Conn ID Top Btm 30" Conductor N/A/N/A/N/A N/A Surface 111' 13-3/8" Surface 6847/NT80CYNT80STHE/Btrc.Btrs. 12.415 Surface 2,477' 9-5/8" Intermediate / / 8.681 Surface 11,222' 3 9-5/8" Intermediate 47/NT95HS/N/A 8.681 11,222' 13,389' I 7" Liner 29/TKC/N/A 6.184 13,070' 15,275' TUBING DETAIL 4 3-1/2" Tubing 12.6/13Cr80/ 2.992 Surface 13,102' I WELL INCLINATION DETAIL Max Hole Angle=58 deg.@ 11,719' Angle at Top Perf=53Deg @ 14,000' 5I JEWELRY DETAIL No Depth Item 6 1 1,563' 3-1/2"OTIS SSSV,Nipple ID=2.750" GLM Detail-KBMG w/Dummy Valves and Ports=0 Except STA 8&7 2 4,133' ST 8: Dev.=35,Latch=RM,TVD= 4,061',VLV=Dome,Port=16/64,7/29/2016 Restriction- 7 3 7,134' ST 7: Dev.=55,Latch=RM,TVD= 6,020',VLV=5/0,Port=20/64, 7/29/2016 Unable to pass thuwl2-1/T 8 Patch from 4 9,322' ST 6: Dev.=56,Latch=RA,TVD= 7,255',6/5/1990 DMY,ID=2.125 g 12,725'to 5 10,854' ST 5: Dev.=52,Latch=RA,TVD= 8,161',6/5/1990 Tagged 6/14/12IIII 12,928'.MIN 6 11,792' ST 4: Dev.=58,Latch=RA,TVD= 8,712',6/5/1990 @±12,950' 111.60" 10 7 12,354' ST 3: Dev.=54,Latch=RA,TVD= 9,017',6/5/1990 8 12,725' Tubing Patch-Btm @ 12,928'-ID=1.6" % 9 12,758' ST 2: Dev.=49,Latch=RM,TVD= 9,269',4/27/2010 10 12,944' ST 1: Dev.=46,Latch=RA,TVD= 9,396',6/5/1990 i i 1112 11 13,005' 3-1/2"SWS X Nipple,ID=2.750" 12 13,022' 3-1/2"x 4-1/2"XO&Latch Assy,ID=2.92" 13 13 13,025' 9-5/8"x 4-1/2"TIW HBBP Packer,ID=4.00" 14 15 14 13,029' 5-1/2"Millout Extension,ID=4.00" 16 15 13,035' 5-1/2"x 3-1/2"XO,ID=4.892" r , _ i 17 16 13,055' TIW'SNAT'Packer and Seal Assy. ✓ i i 18 17 13,069' 3-1/2"OTIS X Nipple,ID=2.750" 18 13,090' 3-1/2"OTIS X Nipple,ID=2.750" 19 19 13,101' WLEG,ID=2.992"-Bottom @ 13,102' ' PERFORATION DETAIL 9-5/8" END Oil Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status FV 14,000' 14,044' 10,038' 10,064' 44 6/9/1990 Open Fish 3-1/2"BBE FV 14,050' 14,118' 10,068' 10,109' 68 6/9/1990 Open D 141 fit' E. FIV 14,154' 14,180' 10,131' 10,146' 26 6/9/1990 Open - _ CMTRetainerw/5' FIV 14,232' 14,254' 10,178' 10,191' 22 6/9/1990 Closed of Sand @14,219' FIll 14,306' 14,334' 10,223' 10,239' 28 6/9/1990 Squeezed '4 10/27/1993 FIll 14,375' 14,395' 10,264' 10,276' 20 6/4&6/7/1990 Plug&Squeezed CIBP @ 14,363' F6: 7 TOC @14,365' -=- GENERAL WELL INFO SAFETY NOTE 6/8/1990 API:50-029-22041-00-00 H2S Readings Average 230-260 PPM on A/L&Gas Injectors. Marker Joint @ toCompleted-6/5/1990 14,445 1"44r. Plug&Cmt Sqz Lnr-6/8/1990 7"I Pull / 93 KB Patch-5/16/0&Cmt Sqz /11 A TD=15,276'(MD)/1D=10,804(IVD) Set 2 Patches -6/2013 PBTD=15,198'(MD)/PBTD=10,759'(TVD) Pull 2 Patches-3/13/2014 Install Patch-9/15/2015 Revised By:TTW 08/01/2017 • • 0—J� o 21 Y V '51E 0 w z > Q N e M 5 W t w W `4,- 0 6 J LL 4�C Q. O R J EDI m y3 le�u._N^ 1- N J d • Qam'EP'?�^' W _ Ce N 2y • L. 3 ic`ma ._ W - o x * % WOCpl1L LL U K 2 x 2. W.1 's ao c c z a 3a o a? 3aZ a =gavddh re ok� OtiM aN "411 dQ<_�zs N N� • N of M O H n 00 Q Dill M O/ 0 4 NCR _ t .i i... • M O OOf ' ......... in.- N V. / Co • � l 4E*, I °° coco°2 I. t____ _ I c co o,- 5 M 43 g� 1 N S c1" • • Bettis, Patricia K (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Tuesday, August 1, 2017 4:46 PM To: Bettis, Patricia K(DOA) Subject: FW: Duck IS Unit MPI 2-50 (PTD 193-067): Sundry Application Attachments: END 2-50 AOR with Faults.pdf; END 2-58 SCHEMATIC 08-01-2017.doc Patricia, Enclosed below is a brief explanation from my RE discussing the confinement of the faults compared to migration conduits. Also included is a little further explanation of where the wellpath actually crosses into the radius as mapped in the AOR. Please take a look at these and let me know if you'd like further information to make a determination. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907)777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com From: Chris Kanyer Sent: Tuesday, August 01, 2017 2:23 PM To: Taylor Wellman Subject: RE: Duck IS Unit MPI 2-50 (PTD 193-067): Sundry Application Taylor, As requested, please see attached AOR mapping that includes the faulting from seismic data that are isolating the 2-50 wellbore. On the basis of confidential data available to Hilcorp, it is apparent that the upper subzones within the Endicott Oil Pool are particularly discontinuous, unpredictable and drain small areas. This data indicates that the upper subzones open in well 2-50 are isolated to 50 to 250 acres.The mapped seismic faults are also likely barriers to the North and Southwest. Furthermore,the data strongly suggests that the current open zones in the 2-58 and 2-46B wells are also isolated in this common reservoir"tank". Note that the PBTD of 15,198'MD of the 2-58 well is roughly at the point at which the wellbore enters into the mapped AOR. Moreover,the cement plug installed in the 2-58 well isolate the lower perforations(see 2-58 schematic)and provides an additional barrier of the wellbore "tail"that resides within the mapped 1/4 mile radius AOR of the 2-50 well. Please let me know if you have any further questions. Chris Kanyer I Reservoir Engineer Hikorp Alaska,11.1k 1 • S • ckanyer@hilcorp.com Direct: (907) 777-8377 Mobile: (907) 250-0374 From:Taylor Wellman Sent:Tuesday,August 01,2017 12:07 PM To:Chris Kanyer<ckanyer@hilcorp.com> Subject: FW: Duck IS Unit MPI 2-50(PTD 193-067): Sundry Application Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907) 777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com From: Bettis, Patricia K (DOA) [mailto:patricia.bettisftalaska.gov] Sent: Tuesday, August 01, 2017 11:33 AM To: Taylor Wellman Subject: Duck IS Unit MPI 2-50 (PTD 193-067): Sundry Application Good morning Taylor, Please the following information for the MPI 2-50 sundry application: (1) an analysis of the mechanical condition of MPI 2-58. This analysis will, at minimum, consist of a review of the actual casing and cementing program. These data will be used to infer if the MPI 2-58 wellbore is adequately cemented through the proposed injection zone. All additional information relevant to either the pressure integrity or zonal isolation of the subject wellbore, such as cement quality logs or casing pressure tests must also be included; (2) an analysis of MPI 2-58 assessing the probability that it may serve as a fluid migration conduit. The mechanical integrity of those portions of the wellbore that have some probability of experiencing injection related pressures must be demonstrated as in item(4)above; and (3) plat of mapped faults within the injection zone from seismic data, and an assessment of the faults ability to serve as migration conduits. If there are no faults within the AOR,please advise. For your convenience, I have attached a copy of the Area of Review Guidance for you use. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage, AK 99501 Tel: (907)793-1238 2 ! S CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 3 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, May 19,2016 3:12 PM To: 'Tom Fouts' Cc: Taylor Wellman; Chris Kanyer, samantha.carlisle@alaska.gov Subject: RE: Hilcorp Alaska LLC Withdrawal Request for Sundry#'s 315-376&316-131 Tom, AOGCC will withdraw sundries 315-376 (END 2-50) and 316-131 NS-15)as requested. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell %MNNED SEP. 2`7 2016 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Tom Fouts [mailto:tfouts@)hilcorp.com] Sent: Thursday, May 19, 2016 2:26 PM To: Schwartz, Guy L(DOA) Cc: Taylor Wellman; Chris Kanyer Subject: Hilcorp Alaska LLC Withdrawal Request for Sundry #'s 315-376 &316-131 Guy, Hilcorp Alaska LLC requests the withdrawal of the following Sundries: 1. Sundry#315-376/PTD 193-067/END 2-50 2. Sundry#316-131/PTD 202-054/NS-15 Please feel free to contact me if you have any questions. Thanks, Tom Fouts Senior Ops/Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907)777-8398 Mobile: (907)351-5749 1 RBDMS V✓Mih3 1 2016 • • RECEIVED Post Office Box 244027 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC JUL 3 0 2015 3800 Centerpoint Drive Suite 100 AOId=�i,i,•!'A^c Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 satit4ED AUG 2 3 2016 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 913_o 67 a- 5° Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/121" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp 411) Orig • it New I API_We?INo I PermitNumber' WelHName I WellNumber WellNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/S13 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 7'50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/S14 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/S09 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-66SD12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/S17 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-17B 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E V OF T4� ,§)-, ��j,�s, THE STATE Alaska Oil and Gas N. �A of Conservation Commission : =_ __ ALASIc:A Ott ,-,__.�^= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279 1433 OF ALAS- Fax: 907-276 7542 www aogcc alaska gov Taylor Wellman SCANNED JUL. 0 6 201r Operations Engineer3 — © (07 Hilcorp Alaska, LLC r 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU MPI 2-50/U08 Sundry Number: 315-376 Dear Mr. Wellman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /,/ /O: s Cathy '. Foerster �y�, Chair DATED this 3v day of June, 2015 Encl. RECEIVED STATE OF ALASKA JUN 1 7 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 6 / - ‘711S APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.250 1.Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing Q . Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑✓ • Change Approved Program ❑! Plug for Redril❑ Perforate New Pool 0 Repair Well Q • Re-enter Susp Well 0 Other. CR 51 n y 1,4 tCh t] J 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Hilcorp Alaska,LLC Exploratory ❑ Development Q • 193-067 • 3.Address: Stratigraphic ❑ Service 1=16.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22367-00-00 • 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.462 Will planned perforations require a spacing exception? Yes ❑ No E DUCK IS UNIT MPI 2-50/U08 ' 9 Property Designation(Lease Number): 10.Field/Pool(s). ADL0034634. ENDICOTT/ENDICOTT OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft). Effective Depth TVD(ft): Plugs(measured): Junk(measured). 15,530 • 10,405 . 15,528 10,404 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 131' 30" 131' 131' N/A N/A Surface 2,873' 13-3/8" 2,873' 2,706' 5,020psi 2,260psi Production 12,123' 9-5/8" 12,123' 8,180' 6,870psi 7,100psi Production 3,405' 9-5/8" 15,528' 10,404' 8,150psi 5,090psi Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size: Tubing Grade. Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/L-80 14,900 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 14,678(MD)/9,812'(TVD)&14,836(MD)/9,920(TVD) and 1,457(MD)/1,451(TVD) 9-5/8"DB&9-5/8"SABL-3 and 4-1/2"SSSV 12.Attachments. Description Summary of Proposal Q 13.Well Class after proposed work: • Detailed Operations Program ❑ BOP Sketch ❑., Exploratory 0 Stratigraphic El Development E Service ❑ 14.Estimated Date for 15 Well Status after proposed work: 7/15/2015 Commencing Operations: OIL Q . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative. N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor Wellman Email twellman@hilcorp.com Printed Name Ta for Wellman Title Operations Engineer Signature / Phone 777-8449 Date 6/17/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test (i Mechanical Integrity Test ❑ Location Clearance ❑ Other: 00p fits¢ fo 3Oov ps i (/EPSP I3 ZG 7--z)/05; ) /-/-2n v I a v rr_r✓G:,? e-, st 71-4? Z5-Uv /75 1 _ Spacing Exception Required? Yes ❑ No [/ Subsequent Form Required: /0 — ¢C 4— APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 6-36—/..s v7--.)11:67/30//5-- / 4•%, /S- Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attacknpelots in Duplicate C1 P I 1 NI A i RBDMS JUL - 1 2015 111 RWO:Tbg Swap/Csg Patch Well: 2-50 PTD: 1930670 Hilcorp Alaska,LL API: 50-029-223674-00-00 Well Name: 2-50 API Number: 50-029-223674-00-00 Current Status: SI Producer Pad: Endicott Estimated Start Date: July 15, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 1930670 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907)947-9533 (M) Second Call Engineer: Mike Dunn (907) 777-8382 (0) (907) 351-4191 (M) AFE Number: TBD Current BHP (FIII/FIV/FV): 3668 psi © 10,000' TVD (Last BHP taken from 2-44 in 2014) Maximum Expected BHP (FIII/FIV/FV): 3668 psi @ 10,000' TVD (Last BHP taken from 2-44 in 2014) Equivalent Mud Weight: 7.1 ppg Max. Anticipated Surface Pressure: Opsi XX plug set at 14,887' and and loaded w/fluid 2670 psi (Based on a gas gradient of 0.1 psi/ft and exposed to the F-series BHP from 2014) Brief Well Summary: The Endicott 2-50 well was drilled as an upper sub zone development well into the FIII, FIV, and FV zones. The well was TD'd at 15,528' and with a 9-5/8" production casing and liner in July 1993. The well was worked over to squeeze existing perforations and isolate additional perforations at 14,798'-14,800'. In July 2007 the well developed TxIA communication with a failed MIT-IA. A leak detect log found a tubing leak at 14,670'. The tubing was successfully patched from 14,659'-14,674' and the well was returned to service. The well remained online until developing IAxOA communication and a casing leak in July 2014. Notes Regarding Wellbore Condition The current status of the well is not operable and shut in. The tubing has mechanical integrity. The 9-5/8" casing does not have integrity as per a failing MIT-IA and an identified anomalies at^'1270' and & 1650' and (leak detect log 07/20/14). The well is secured on the tubing side with an XX plug in a nipple reducer at 14,887' md. The tubing has been loaded with 1% KCI, diesel freeze protect and was pressure tested to 3000psi. RWO Objectives: 1. Restore 9-5/8" casing integrity via a casing patch s 2. Pull & replace 4-1/2" tubing with new tubing Planned well condition upon rig arrival: 1. PXN Plug set at 14,887'. Pressure tested to 2500psi. 2. Well circulated to 8.5ppg seawater. Workover Procedure: 1. Mobilize ASR#1 to Endicott. 2. Spot and RU ASR#1 and supporting equipment. RWO:Tbg Swap/Csg Patch Well: 2-50 PTD: 1930670 u.,k: i.i. API: 50-029-223674-00-00 3. ND tree, NU 13-5/8" BOP's, and set TWC. 4. Test BOPE to Sundry Requirements/250psi low/3,000psi high,Annular to 250psi low/2,500psi high. Notify AOGCC 24 hours in advance to witness test. Contingency: (If the tubing hanger won't pressure test due to the BPV profile is eroded and/or corroded and TWC cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mrs. Victoria Loepp (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 5. Pull TWC. Note: If tubing patches were not able to be pulled pre-rig see Contingency section below. 6. Pull hanger, and PU "'15k lbs over on the tubing using the casing jacks. RU E-Line unit on the rig. 7. Jet cut tubing at +/- 14,670' and and RD E-Line from the rig. 8. Pull 4-1/2" tubing from cut at+/-14,670', and lay down the same in singles. 9. PU 2-7/8" 7.9#, P-110 PH-6 workstring. 10. MU and RIH with 9-5/8" casing string mill and dress off mill BHA to+/-14,650. 11. Engage tubing stub at+/-14,670' and dress off stub. Pick up. 12. Reverse circulate 2 wellbore volumes to or until clean returns are observed. POOH. 13. Rig up slickline and caliper 9-5/8" casing from 3000' and to surface. 14. MU test packer and RIH to below the lower patch setting depth. Set test packer and test down the workstring to test the tubing plug, packer, and lower 9-5/8" casing to 2000psi. a. If unsuccessful test, unseat and RIH and test lower section of 9-5/8" casing until passing test is obtained. 15. Pull uphole above upper patch setting depth. Set test packer and test backside (2-7/8" workstring x 9-5/8" casing annulus) to 2000psi. a. If unsuccessful test, unseat pull up hole and test 9-5/8" casing until passing test obtained. 16. MU lower completion and packer assembly. 17. Trip in hole and overshoot tubing stub with non-sealing overshot. 18. Set packer(drop 1-5/16" ball and rod) into RCM Plug at+/-14,640' md. 19. Unlatch from packer and POOH. 20. MU 9-5/8" casing patch. RIH with patch on 2-7/8" workstring to set from +/-1250' to+/-1650' (predicted patch setting depths, subject to change based on above diagnostic steps) and hydraulically set patch. POOH. RWO:Tbg Swap/Csg Patch Well: 2-50 PTD: 1930670 Hamra laska,LL' API: 50-029-223674-00-00 A21. Run 4-1/2", L-80,TCII completion assembly to packer setting depth. SSSV control line will be run from+/- 1600' and to surface. 22. Space out and land the tubing into the hanger. Terminate the control ie. Pressure test control line to 5000psi and the tubing hanger to 5000psi. / lj_; �y 3 �����si eh G r 7-. 23. Conduct and chart an MIT-IA to 2500psito ensure fully stung into packer. 14A--,N 24. RU Slickline unit onto rig. 25. RIH and pull ball and rod from XN nipple @ +/-14,640 md. 26. MU 3-3/8" dummy gun and drift to 14,800' and to ensure tubing is fully stabbed and continuous. 27. Pull dummy GLV from top GLM at+/-4990' and and freeze protect to 2000'with diesel (tubing and IA). 28. Set TWC, ND BOP's, NU tree, and test tree to 300psi low and 5000psi high. a. Clean and replace all ring gaskets and seals prior to re-installation. 29. RD and move to next well. Contingency if tubing patches could not be pulled prior to rig arrival: A. Pull hanger, and PU ^'15k lbs over on the tubing using the casing jacks. RU E-Line unit on the rig. B. Cut tubing directly below closest joint above the tubing patch at+/-14,659' md. C. Ensure tubing is cut and then RD E-Line from the rig. D. Pull 4-1/2" tubing from cut and lay down the same in singles. E. PU 2-7/8" 7.9#, P-110 PH-6 workstring and overshot with jars BHA. F. Trip in hole, swallow and latch tubing stub. G. Jar tubing stub to unseat bonded seal assembly from packer. H. POOH and recover tubing section. I. MU and RIH with 9-5/8" mule shoe casing scraper assembly to+/-14,650. J. Return to step 12 in the above procedure. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Duck Island Unit Well: END 2-50 11 SCHEMATIC Last Completed: 7/23/1993 Mean)Alaska,LLC PTD: 193-067 CASING DETAIL KB Elev.:55.3'/BF Elev.:16..22' Size Type Wt/Grade/Conn Drift ID Top Btm 4 .,,L 30" Conductor N/A/N/A/N/A N/A Surface 131' 30' ,, 13-3/8" Surface 68/L-80/Btrs 12.415 Surface 2,873' 9-5/8" Production 47/L-80/NSCC 8.681 Surface 12,123' "e,- 1 9-5/8" Production 47/NT95HS/BTC 8.681 12,123' 15,528' t,t 133/8 4 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TDS 3.958 Surface 14,900' JEWELRY DETAIL 2 No Depth Item II 1 1,457' BBE SSV&4-1/2"OTIS BVN Nip,ID=3.813 2 4,420' GLM w/Dummy Valve and RK Latch,Dev.=52 3 8,139' GLM w/Dummy Valve and RK Latch,Dev.=55 4 10,899' GLM w/Dummy Valve and RK Latch,Dev.=56 3 5 12,624' GLM w/Dummy Valve and RK Latch,Dev.=50 I 6 13,685' GLM w/Dummy Valve and RK Latch,Dev.=52 7 13,832' GLM w/Dummy Valve and RK Latch,Dev.=53 4 8 14,657' 4-1/2"SWS Nipple,ID=3.813" 9 14,659' 4-1/2"Baker Patch,ID=2.37" III 10 14,678' Baker Bonded Seal Assembly w/GBH-22 LOC,ID=3.875" 11 14,678' 9-5/8"Baker DB Packer w/seal Extension,ID=4.75" 5 12 14,696' Baker Packer Guide,ID=3.937" I 13 14,835' Baker EBH-22S Latch,ID=3.875" 6 p 14 14,836' 9-5/8"Baker SABL-3 Packer,ID=4.75" 15 14,870' 4-1/2"OTIS X-Nipple,ID=3.813" 7 16 14,887' 4-1/2"OTIS XN-Nipple w/2-7/8"Nipple Reducer,ID=2.31 17 14,887' 2-7/8"XX Plug r" 18 14,899' 4-1/2"WLEG-Bottom @ 14,900' 8 PERFORATION DETAIL END Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Size 9 USZ-LCU 14,798' 14,800' 9,894' 9,895 2 2/8/1994 Sqz. 3-3/8" USZ-FV 15,068' 15,078' 10,082' 10,089' 10 8/31/2008 Open 2" 0.= ® 10&11 USZ-FV 15,072' 15,078' 10,084' 10,089' 6 2/8/1994 Sqz. 4-1/2" al 12 USZ-FV 15,084' 15,103' 10,093' 10,106' 19 2/8/1994 Sqz. 4-1/2" IA USZ-FV 15,084' 15,104' 10,093' 10,107' 20 8/31/2008 Open 2" s 13 USZ-FV 15,084' 15,103' 10,093' 10,106' 19 7/30/1995 Open 3-3/8" 1 "' 14 USZ-FV 15,090' 15,103' 10,097' 10,106' 13 2/8/1994 Sqz. 3-3/8" USZ-FV 15,107' 15,122' 10,109' 10,120 5 8/31/2008 Open 2" n USZ-FV 15,108' 15,122' 10,110' 10,120' 4 2/8/1994 Sqz. 3-3/8" 15 USZ-FV 15,108' 15,122' 10,110' 10,120' 4 7/30/1995 Open 3-3/8" - I i USZ-FV 15,112' 15,120' 10,113' 10,118' 8 2/18/1994 Sqz. 3-3/8" Ip a 16&17 ' USZ-FV,FIV 15,130' 15,150' 10,125' 10,139' 20 8/31/2008 Open 2" i USZ-FIV 15,160' 15,210' 10,146' 10,181' 50 8/31/2008 Open 2" 14 18 USZ-FIV 15,215' 15,235' 10,185' 10,199' 20 11/25/1994 Open 3-3/8" 61 9-5/8" USZ-FIV 15,215' 15,245' 10,185' 10,206' 30 2/18/1994 Sqz. 3-3/8" f USZ-FIV 15,235' 15,245' 10,199' 10,206' 10 11/25/1994 Open 3-3/8" t4 USZ-FIII 15,316' 15,330' 10,256' 10,265' 14 4/4/1996 Sqz. 3-3/8" i g WELL INCLINATION DETAIL OPEN HOLE/CEMENT DETAIL $ ¢ ,t Max Hole Angle=57 deg. @ 11,100' 13-3/8" 4,185 cu/ft Permafrost in 17.5"Hole Sand 0.rrip Angle at Top Perf=45 Deg.@ 15,068' 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole -Carbdde t 7" 645 cu/ft Class"G"in 8-1/2"Hole @15,295' . GENERAL WELL INFO API:50-029-223674-00-00 TREE&WELLHEAD . Tree 4-1/2"CIW t ," Original Completion -7/23/1993 Wellhead 13-5/8"McEvoy " e " RWO -2/18/1994 Set PXN Plug-2/29/2006 TD=15,530'(MD)/TD=10,405'(IVD) GLV C/O XX Plug -4/01&2/14 PBTD=15,448'(MD)/PBTD=10,348'(TVD) Revised By:TDF 5/19/2015 Duck Island Unit Well: END 2-50 14 PROPOSED Last Completed: 7/23/1993 Ililcora Alaska,LLC PTD: 193-067 CASING DETAIL KB Elev.:55.3'/BF Elev.:16..22' Size Type Wt/Grade/Conn Drift ID Top Btm 30" Conductor N/A/N/A/N/A N/A Surface 131' 3Cr ii, 0,4 13-3/8" Surface 68/L-80/Btrs 12.415 Surface 2,873' -i 9-5/8" Production 47/L-80/NSCC 8.681 Surface 12,123' 1 J 2 9-5/8" Production 47/NT95HS/BTC 8.681 12,123' 15,528' .K rgi TUBING DETAIL 13-3/8. 4 k• 4-1/2" Tubing 12.6/L-80/TDS 3.958 Surface 14,900' JEWELRY DETAIL 3 No Depth Item I ±1,250'- 1 ±1,650' 7-5/8"x 9-5/8"Patch 2 ±1,500' BBE SSV&4-1/2"OTIS BVN Nip,ID=3.813 3 ±4,990' GLM w/Dummy Valve 4 4 ±8,328' GLM w/Dummy Valve 5 ±11,140' GLM w/Dummy Valve 6 ±13,237' GLM w/Dummy Valve 5 7 ±14,580' X-Nipple I 8 ±14,586' GLM w/Dummy Valve 9 ±14,600' 9-5/8"x 4-1/2"Production Packer 6 10 ±14,620' X-Nipple ±14,640' X-Nipple f 12 14,678' 9-5/8"Baker DB Packer w/seal Extension,ID=4.75" 1 Ill 7 }' 13 14,696' Baker Packer Guide,ID=3.937" 14 14,835' Baker EBH-22S Latch,ID=3.875" 8 ,, 15 14,836' 9-5/8"Baker SABL-3 Packer,ID=4.75" r' 16 14,870' 4-1/2"OTIS X-Nipple,ID=3.813" 1.---_-_-49 17 14,887' 4-1/2"OTIS XN-Nipple w/2-7/8"Nipple Reducer,I0=2.31 s 18 14,899' 4-1/2"WLEG-Bottom @ 14,900' i 10 i ", a 11 PERFORATION DETAIL END Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Size i um USZ-LCU 14,798' 14,800' 9,894' 9,895 2 2/8/1994 Sqz. 3-3/8" } ' '4 e-=5 y12 USZ-FV 15,068' 15,078' 10,082' 10,089' 10 8/31/2008 Open 2" b 111 13 0 USZ-FV 15,072' 15,078' 10,084' 10,089' 6 2/8/1994 Sqz. 4-1/2" r J' USZ-FV 15,084' 15,103' 10,093' 10,106' 19 2/8/1994 Sqz. 4-1/2" ' 14 ® ---.. - 15 USZ-FV 15,084 15,104' 10,093' 10,107' 20 8/31/2008 Open 2" USZ-FV 15,084' 15,103' 10,093' 10,106' 19 7/30/1995 Open 3-3/8" USZ-FV 15,090' 15,103' 10,097' 10,106' 13 2/8/1994 Sqz. 3-3/8" 7 USZ-FV 15,107' 15,122' 10,109' 10,120 5 8/31/2008 Open 2" J 16 ! USZ-FV 15,108' 15,122' 10,110' 10,120' 4 2/8/1994 Sqz. 3-3/8" USZ FV 15,108' 15,122' 10,110' 10,120' 4 7/30/1995 Open 3-3/8" -,17 y USZ-FV 15,112' 15,120' 10,113' 10,118' 8 2/18/1994 Sqz. 3-3/8" i' USZ-FV,FIV 15,130' 15,150' 10,125' 10,139' 20 8/31/2008 Open 2" 18 USZ-FIV 15,160' 15,210' 10,146' 10,181' 50 8/31/2008 Open 2" 9-5/8"r, USZ-FIV 15,215' 15,235' 10,185' 10,199' 20 11/25/1994 Open 3-3/8" y. USZ-FIV 15,215' 15,245' 10,185' 10,206' 30 2/18/1994 Sqz. 3-3/8" USZ-FIV 15,235' 15,245' 10,199' 10,206' 10 11/25/1994 Open 3-3/8" d USZ-FIII 15,316' 15,330' 10,256' 10,265' 14 4/4/1996 Sqz. 3-3/8" i; -_ WELL INCLINATION DETAIL OPEN HOLE/CEMENT DETAIL ='K Max Hole Angle=57 deg. @ 11,100' 13-3/8" 4,185 cu/ft Permafrost in 17.5"Hole Sand airrp CarteR Angle at Top Perf=45 Deg.@ 15,068' 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole Cd115, _ 7" 645 cu/ft Class"G"in 8-1/2"Hole GENERAL WELL INFO - j TREE&WELLHEAD API:50-029-223674-00-00 Original Completion -7/23/1993 Tree 4-1/2"CIW • :`e *'" RWO -2/18/1994 Wellhead 13-5/8"McEvoy 1D=15,530'(MD)/TD=10,405,() Set PXN Plug-2/29/2006 PBTD=15,448'(MD)/PBTD=10,348'(TVD) GLV C/O XX Plug -4/01&2/14 Revised By:TDF 5/19/2015 13 5/8"" BOP Stack for Endicott well MPI 2-50 A O O iiia ii 54%2" Shaffer Annular 13 5/8" 5m , rilialaialli V Double Cameron "U" _r_ j* 27/8" toy" VBRRams L 33 5/16" � — =IC C , 13 5/8" SM _Om CSO Rams (Blinds) 14' 11 13/16" / * --/ - V — A 111PAIF.711 _ —Th' �� Mud Cross �� 1 24" I 1)f _, .,-,:f. li 13 5/8" 5M f hi, ��.�� ) , - �� /; Drilling Spool W/4 outs MGV 4 1/16" 5M CIW --' HCR 4 1/16" 5M CIW Spacer spool 68" 13 5/8"5m XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type OVERSIZED -[] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly_~cent TO RE-SCAN Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si ,fs,P*I j/j- A THE STATE Alaska Oil and Gas °fALASKA Conservation Commission T*,, GOVERNOR SEAN PARNELL 333 West Seventh Avenue OFAS tgP ,.#� Anchorage, Alaska 99501-3572 satitiE0 NOV 3. ` 1014 Main: 907.279.1433 G Fax: 907.276.7542 Josiah Igwe Petroleum Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Endicott Field, Endicott Oil Pool, EPA 2-50/U-08 Sundry Number: 313-500 Dear Mr. Igwe: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair, Commissioner DATED this U day of September, 2013. Encl. • • `4 °'fig .. . D STATE OF ALASKA k" ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 17 201 APPLICATION FOR SUNDRY APPROVALS /7TS 7/41 0 20 AAC 25.280 AOGCC 1.Type of Request: Abandon❑ Plug for Redrill El Perforate New Pool El Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate El Alter Casing El Other. Convert to Infector ii• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development 19 - 193-067-0 - 3.Address: Stratigraphic ❑ Service Li 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22367-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? EPA 2-50/U-08 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0034634 • ENDICOTT, ENDICOTT OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 15530 . 10405 • 15528 10404 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 94 30"Conductor 37-131 37-131 Surface 2829 13-3/8"68#L-80 44-2873 44-2706.54 5020 2260 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None None None Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 15068-15072 10081.48-10084.31 4-1/2"12.6#L-80 L-80 22-14900 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths 4-1/2"HES HXO SSV 1457',1451.22' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 151 BOP Sketch ❑ Exploratory ❑ Development ❑ Service Ell • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: WINJ 0 . GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR El SPLUG El 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josiah lgwe Email Josiah.lgwe @BP.Com Printed Name Josiah Igwe Title Petroleum Engineer Signature ^ .— Phone 564-4753 Date Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number ) \2 J — S 0 0 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test re Location Clearance El Other: M / r ,, Cj�t4l t'c fil/1•tint rsStd) re. i,!`"C d 4,Ftt r� 0.Fa 1•Ii 75--C W a fry Flow 100 rec,1K rd 4 ft( v warn phi5 / r, JCC-t-I) Spacing Exception Required? Yes Cl No 1 Subsequent Form Required: /0 4 O 4 RBDMS OCT 1 ert APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 7'43 ,o kli ag7 Form 10-403 Revised 10/2012 ci/ il Apprwdil [gp`s��dAtnonths from the date of approval. Submit Form and Attachments in Duplicate 4,, 3 v � Vt ' v {� Casing Summary ADL0034634 Casing Length Size MD Top MD Base ND Top ND Base Burst Collapse Grade CONDUCTOR 94 30" Conductor 37 131 37 131 PATCH 15 4-1/2" Baker Patch 14659 14674 9800 9810 3500 3500 PRODUCTION 12084 9-5/8"47#NT95HS 39 12123 39 8180 8150 5080 NT95HS PRODUCTION 3405 9-5/8"47#L-80 12123 15528 8180 10404 6870 4760 L-80 SURFACE 2829 13-3/8"68#L-80 44 2873 44 2707 5020 2260 L-80 TUBING 14878 4-1/2" 12.6#L-80 22 14900 22 9964 8430 7500 L-80 • III • • Packers and SSV's Attachment ADL0034634 Well Facility Type MD Top Description TVD Top 2-50/U-08 SSSV 1457 4-1/2" HES HXO SSV 1451 2-50/U-08 PACKER 14678 4-1/2" Baker DB Packer 9812 2-50/U-08 PACKER 14836 4-1/2" Baker SABL-3 Packer 9920 • • Endicott DIU 2-50/U-08 (1930670) Current Status: END2-5o/Uo8 is a naturally flowing well drilled in 1993 in MPI USZ that has cumulative production of 2.6 MMBO. It has 4-1/2" L-8o tubing and 9-5/8" casing. Initial perfs were in the FIV and FV. Perfs were added in the FIII in Oct95 but were wet and isolated with a cement cap in Jan96. END2-5o has a 4-1/2"tubing patch at 14,659'MD in L-8o tubing The reservoir management plan forward is to convert from Fiii, Fiv and FV production to Fiii, Fiv and Fv Water Injection for additional water handling for the field. Well 2-5o/U-o8 will require additional perforations in Fiii, coil tubing fill clean out, and a passing MIT-IA to 4,000 psi to be compliance with BP internal well integrity policy for operation. 92 barrels of class G cement was pumped therefore 1/2 barrel of shoe volume displaced since the plug was not bumped.A cement squeeze with 50 barrels of Class G cement was pumped and the analysis of Schlumberger 13-Feb-1994 Segmented bond log is interpreted by me and BP in-house log experts is as per below; tNO � - sa /Uo � Bottom Top Depth Depth Cement Comment feet feet 15,402 15,344 Good Isolated 15,344 15,245 Poor Not Isolated (VDL showing formation arrivals probably due to eccen. Circumferential SBT showing no isolation.) 15,245 15,190 Good Isolated 15,190 15,124 Poor Not Isolated (patchy cement with continuous low side channel) 15,124 (‘(1.5,056 Good Isolated 15,056 15,020 Fair Not Isolated (with possible communicated low side channel) 15,020 14,820 ` Not Isolated (with patchy cement pockets) 14,820 14,790 Fair Not Isolated (with possible communicated low side channel) 14,790 14,400t ��404 Not Isolated The logs are included in this package. END2-58 is a long time shut in due to tubing by inner annulus (TxIA) communication. . End2-58/S-o9 is the only well that penetrated 1/4" radius of End2-5o reservoir. It was completed in June 1990. The 7"liner was cemented with 117 bbls of 15.15 ppg slurry of which 5o bbls were lost during displacement. The analysis of Schlumberger o1-Jun-1990, Cement Evaluation log interpreted by BP in-house log experts are as per below; -t s r_ Q Q rp4e e 5 )1.-rr / Se 1,-,/ v P r 60^C r / N Qh i o opc /,G VP I S i'Ve l 4 / w Gat 0- u -Fs cf./in wells odd 'yr() f PCO✓efik 410A P61 fcr fé Wei • • ENO 2 -. 5-E Bottom Top Depth Depth Cement Comment feet feet 15,180 14,970 Poor Poor to no cement 14,970 14,635 Good Fair to good cement with some void 14,635 14,440 Poor Poor Cement 14,440 13,900 Fair Poor to fair cement 13,900 13,750 Poor Poor cement with channel 13,750 13,070 Bad Little or no cement The logs are included in this package. Completions: Well Name Casing Size Hole Size Vol Cement Kekiktuk Depth 2-50/U-o8 9-5/8" 12-1/4" 92 bbls, 15069 2-58/S-o9 7" 8-1/2" 496 bbls 14404 Ili End t - 5O E n 2 - 58 Area Map E-0, • 141 2 „inikm 2 _Niiiki4,‘ • 24W.10 ..., • -■ *%\ Al Interpr are opinions based on inferences from electrical or o easurernents and we cannot, and do not gu a the accuracy or correctness of any interpretations, a shall not, except in the case of gross or fii negigence on our part, be liable or responsible for loss, costs,damages or expenses Incurred or sustained by anyone resulting from any interpretations made by any of our officers, agents or employees. These interpretations are also subject to Clause 4 of our General Terms and Conditions as set out In our current Price Schedule. 4 Run No. IONE Eervloe Order No. 391413 Logging speed 3000.0 F/FR ECUPWENT DATA TOOT Number 1 CEMS A 819 Tool Number 2 CEEC C 745 Tool Number 3 CBS DA 82 Tooi Number 4 CBC DB 90 Tool Number 5 SGC SA 598 Toot Numbers TCC B 839 Tool Number 7 CAL YA 30 Tool Number Tool Number 11 Tool Number 10 Tool Number 11 TOW Number 12 ♦ REMARKS: 7" CEMENT DETAIL: DATE:5-29-90; START: 1300; END: 1500. PUMPED 570 SX OF CLASS G WITH 5% HALAD 344, 0. 16'%. LWL, 0.2% CFR-3, 50/B GILSONNITE. MIXED AT 15. 15 PPG; PUMP RATE: 3 BPM AT 850 PSI. PARTIAL LOST RETURNS WHILE CIRC, PIPE WOULD NOT GO TO BOTTOM, UNABLE TO ROTATE/RECIPROCATE DURING CMT JOB, LINER HUNG 75' OFF BOTTOM, LOST 50 BBL CMT DURING DISP, CIRC 2 HRS ABOVE LINER W/150 0 CSG PRESSURE, LINER LAP LEAKED @I BPM W/2100 PSI. CEMENT INTERPRETATION: FROM PBTD OF 15180 TO 14970: POOR TO NO CEMENT 14970 TO 14635: FAIR TO GOOD CEMENT W/SOME VOIDS 14635 TO 14440: POOR CEMENT 14440 TO 13900: POOR TO FAIR CEMENT 13900 TO 13750: POOR CEMENT W/CHANNEL 13750 TO TOP OF LINER AT 13070: LITTLE OR NO CEMENT MAIN PASS (UNPRESSURED) 5chlumher ger CSI! Field Lag DT (US/F) 107.00 7.0000 TT2 <US ) 400.00 200.00 CCL NATN(DB/F) VOL -19.00 1.0000 15.000 0.0 200 1 GR (GAPI) DATN<DB/F> X0.0 100.04 _ _ 15.000 0.0 . . , , i '; • . ; ,___ _ --- i i 1=IIIIM1111= 1■■IIMIIIMINMEIMIA_ E-. .-- • , 1 M I= 1 M 1 11 1 1 M I 1 1 INIM■1 M EMMA!I ....- ,..--7--;-..v" 111111111111111111•11=1111•111111111111MIIIIIIIIIIIIIIIIIM =_-.---: ; -- • i. • IIIIIIIIIIIIMIMIMII•1M1111111M=IIMIP'..eAI- t 1 IIIIMINIM111111111111.=IIME11111111111111WAIN- 1- 4 MIIIIIMIIIINIMIllan 143 1 0 111•111111111111MMI ■Mil=r:ME= .;.. ..... 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IP:,a4"4.41"...:47. 7.1.3ai'*ZIOar. .",t■)!k'ilf*.'.. * **4‘, 7.: _ , .:*"""rw b‘‘'s.1. 0040,0,00 .4.i0;iiittilu,7rft,404ANopookovoy•F. , NININ.0741w,, -Nrepii, se.oeftwo,oteftwol.wek ;r1:::;/$6'S'AlitAwie aN "*Ittk'w°'1""it".."11.°‘1"4".44./ i " .;:*:■mmkv_ .......1 Zrdie1411: ftss*,":1C "NPoei ' 4467. - ---... "* -^ .7 APINAltamorm000.w - ■,, ,S /47 /0',S, / `' 4 \ -- d -,-/ - --7-77 ,, "IPIN"1111114.171111+InniF721147111.11111111 IIIIMMitilla Illialli 1 in ilittinin Al 1 11111.-_,. :_`.. .. tit iiill'A;%. ' '0%e :‘RN' u • 11111110111i MI i . MIMI 11111011L1110 _ i lie All AI 1 i td‘ i 4, mln, 11111111 II mum t illidnall I L. Ur . idll lil 'ffiladharigallik u Alla 11 MIMI Nag L migurimop , 'um' mummuniquommumusgrogr_ 1_, . 1 rilli Aii..,.: 1 niidang I Ildi 1111h111111111 rblaillliiirMillit 016 1 i 11 . A 1 iM I Mill dr_ .AdJ IIIIPBM1111 , ATI .11.,... 1.....,....,...r.. ...,, , ,, , ....„....., Lamminpopp IN 1 q pp opmmi nummuhanomm 1111 1_ nannumnanommdmida Ill 1 n di 110111111111110111111HIMMIIIII MINN 1 PROD. PERF. \ N,, - -rz >/‘ 151110 --- c - - - , , erwo a-s ,-, .,--c.4 OA --iNJ T-E9 ,r5-.ThALL.,51.5 2 0 0 SQZ. PERF. SQZ. PE•F ONinminialoppliam_ ,_ , .- - IIM , riiimirmiimmMurimiimiiuiimiiipliimpmpgropiiunip riiiiii 1 11 11111 I iii iiiiiIriiii ii i um iii li IipH Mill PM rHIMIHINIMMU il II INH II Mil h 1 MI MUN MU IMIMMISMIMME11 1111 11 lilbil MI II •_,i 11111 . _ , , 1 Ill NI HMI I 1 11 1111111 1111111 II TREE= 4-1/2"CIW • WELLHEAD= 13-5/8"MCEVOY E N D 2_5 0 S Y NOTES:H2S READINGS AVERAGE 230-260 ACTUATOR= PPM ON A/L&GAS INJECTORS. WELL REQUIRES A KB.ELEV= 55.3' SSSV. BF.ELEV= 16.22' KOP= 1457' H 4-1/2"SSSV LANDING NIP,ID=3.813" Max Angle= 57 @ 11100' Datum MD= 15031' Datum TVD= 10000'SS 13-3/8"CSG,68#, L-80 BTRS, -I GAS LIFT MANDRELS 2873' ST MD TVD DEV TYPE VLV LATCH PORT DATE ID=12.415" 6 4420 3752 52 DOME CAMCO RK 16 08/11/07 5 8139 5889 55 SO CAMCO RK 20 08/11/07 4 10899 7470 56 DMY CAMCO RK 0 08/29/04 9-5/8"CSG,47#,NT80S XO NT95HS, —1 12123' I / 3 12624 8496 50 DMY CAMCO RK 0 08/29/04 ID=8.681" u0 + 2 13685 9185 52 DMY CAMCO RK 0 08/29/04 � , 1P( t 1 13832 9276 53 DMY CAMCO RK 0 08/29/04 I I I 14657' I-14-1/2"PKR SWS NIP,ID=3.813" I Minimum ID =2.31 @ 14887 6 f 14659'-14674'I-14-1/2"BKR PATCH(08/01/07) I 4-1/2" XN NIP w12-7/8" NIP REDUCER t 14678' —BKR BONDED SEAL ASSEMBLY k 1 5 w/GBH-22 LOC,ID=3.875" v� 14678' I—9-5/8"BKR"DB"PKR p 09 � I q g w/SEAL BORE EXT,ID=4.75" VI 14696' I-1 BKR PKR GUIDE,ID=3.937" I• imelfr 4-1/2"TBG, 12.6#,L-80,.0152 bpf,ID=3.958" -I 14900' �1 I 14835' I—)BKR EBH-22S LATCH,ID=3.875" I 1 14836' 1-19-5/8"BKR SABL-3 PKR,ID=4.75" I PERFORATION SUMMARY REF LOG: SBT-GR(07/18/93)) ANGLE AT TOP PERF: 45 @ 15068' \ ' 11 14$70 1-14-1/2"OTIS X NIP,ID=3.813" Note:Refer to Production DB for historical pert data kr SIZE SPF INTERVAL Opn/Sqz DATE S 6 4 I 14887' I—4-1/2"OTIS XN NIP w/2-7/8"NIP REDUCER,ID=2.31" 3-3/8" 6 14798-14800 S 02/08/94 V (REDUCER SET 07/29/07) 2" 6 15068-15078 0 08/31/08 4-1/2" 6 15072-15078 S 02/08/94 1 \ 4-1/2" 6 15084-15103 S 02/08/94 CT 2" 6 15084-15104 (ilb----\ 08/31/08 ' - 14900' H4-1/2"WLEG I 3-3/8" 6 15084-15103 — O) 07/30/95 I I 3-3/8" 6 15090-15103 `SS 02/08/94 14895' —I ELMD LOGGED(??) 2" 6 15107-15122 0 08/31/08 I yv`� �= 3-3/8" 6 15108-15122 S 02/08/94 3-3/8" 6 15108-15122 0 07/30/95 % ‘I t6 1 1'_ 3-3/8" 6 15112-15120 S 02/18/94 a ' ' 2" 6 15130-15150 0 08/31/08 A t"t-` ' 2" 6 15160-15210 0 08/31/08 V 4� 'a ' 3-3/8" 6 15215-15235 0 11/25/94 i (.:=.r a 3-3/8" 6 15215-15245 S 02/18/94 1 3-3/8" 6 15235-15245 0 11/25/94 I 15295' H SAND DUMP-CA RBOLRE(10/23/95) I 3-3/8" 6 15316-15330 S 04/04/96 a0 PBTD 1 15448' 1.•.•.•V•.•WAY 9-5/8"CSG,47#,NT95HS,ID=8.681" —1 15528' 444444444444 DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 07/23/93 D15 ORIGINAL COMPLETION 08/17/07 GJB/PJC SET BKR PATCH(08/01/07) WELL: 2-50/U-08 02/18/94 D15 RWO 08/17/07 KSB/PJC GLV C/O(08/11/07) PERMIT No: 1930670 09/29/06 MSS/PJC SET PXN PLUG 08/21/07 SID/PJC NIP RED/PULL PXN(07/27/07) API No: 50-029-22367-00 12/10/06 JCM/PJC CONVERT NEW FORMAT 09/20/08 TFA/SV ADPERF(08/31/08) SEC 36,T12N,R16E,3218'NSL&2317'WEL 08/16/07 DTR/PJC PULL PXN(07/27/07) 02/17/11 MB/JMD ADDED SSSV SAFETY NOTE 08/16/07 DTR/PJC SET NIP RED/XX PLUG(07/2-08y15/11 DW/JMD ADDED H2S SAFETY NOTE BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519-6612 May 22, 2012 S E P 2 1 Mr. Jim Regg 3 ' 7 M J Alaska Oil and Gas Conservation Commission o f f 0 - O g 333 West 7 Avenue , � � Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, r 1 Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Endicott Row 2 Date: 03/28/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # _ cement pumped - cement date inhibitor sealant date ft bbls ft na gal END2 -02 / P -18 1860630 50029215680000 15.0 3.0 0.5 8/28/2010 1.70 9/29/2010 END2 -04 / M -19 1860820 50029215850000 4.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -06 / J -22 1870180 50029216990000 2.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -08 / K-16 1880040 50029217710000 1.5 0.1 0.5 9/2/2010 3.40 9/29/2010 END2 -12 /0-16 1921170 50029223020000 0.5 1.0 0.0 9/2/2010 NA 3/28/2012 END2 -14 / 0-16 1861490 50029216390000 2.5 3.0 0.5 9/2/2010 1.70 9/28/2010 END2 -16 / M -16 1881340 50029218850000 2.0 0.5 0.5 9/2/2010 1.70 9/28/2010 END2 -18 / L -16 1900430 50029220320000 2.0 0.3 0.5 9/2/2010 , 2.60 9/28/2010 END2 -20 / L -15 1900600 50029220480000 5.0 3.0 0.5 8/28/2010 3.40 9/28/2010 _ END2 -22 / L -14 1890340 50029219310000 5.0 5.0 - 0.5 8/28/2010 6.80 9/28/2010 END2 -24 / M -12 1931730 50029224180000 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -26 / N-14 1880550 50029218150000 2.0 1.8 0.5 9/2/2010 1.70 9/28/2010 END2 -28B / 0 -19 2030060 50029218470200 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -30B / ME-01 2081870 50029222280200 3.0 3.0 0.5 8/28/2010 2.60 9/28/2010 END2 -32 / SN-03 1901190 50029220840000 3.0 2.0 0.5 8/28/2010 2.60 9/28/2010 END2-34 / P -14 1861720 50029216620000 1.0 NA 1.0 NA 12.80 9/25/2010 END2 -36 / 0 -14 1900240 50029220140000 5.0 3.0 0.5 8/28/2010 2.55 9/25/2010 _ END2 -38 / SN -01 1901290 50029220900000 3.0 4.0 0.5 8/28/2010 1.70 9/25/2010 END2 -40 / S -22 1941520 50029225270000 15.0 13.0 0.5 9/2/2010 4.00 9/25/2010 END2 -42 / P -13 1881450 50029218920000 5.0 4.0 0.5 8/28/2010 2.55 9/25/2010 _ END2 -44A / 0 -11 1970710 50029217670100 0.5 NA 0.5 NA 22.10 10/5/2010 END2 -46B / S -13 1971370 50029219210200 4.0 1.0 0.5 9/2/2010 3.40 9/25/2010 END2 -48 / 0 -13 1951660 50029226120000 2.0 2.0 0.5 8/28/2010 1.70 9/25/2010 END2 -50 / U-08 1930670 50029223670000 2.0 _ 1.0 0.5 8/28/2010 1.70 9/25/2010 END2 -52 / S -14 1870920 50029217500000 ` 1.0 0.3 0.5 9/2/2010 0.85 9/25/2010 END2 -54 / 0-12 1911220 50029222180000 4.0 3.0 0.5 8/28/2010 1.70 9/25/2010 _ END2 -56A / E101 1980580 50029228630100 0.5 NA 0.5 NA 25.50 9/25/2010 END2 -58 / S-09 1900520 50029220410000 7.0 5.0 0.5 8/28/2010 3.40 9/25/2010 END2 -62 / 0-17 1861580 50029216480000 10.0 7.0 0.5 8/28/2010 8.50 9/25/2010 END2 -64 / U -10 1900770 50029220550000 2.0 1.0 0.5 8/28/2010 2.55 9/25/2010 END2 -66 / SD -12 1930790 50029223740000 0.3 NA 0.3 NA 1.70 9/24/2010 END2 -68 / S-17 1880970 50029218580000 2.0 3.0 0.5 8/28/2010 1.70 9/24/2010 END2 -70 / U -15 1881530 50029218990000 0.7 NA 0.7 NA 3.40 9/24/2010 2U- Dhu -2U1 1 Schlberger 5843 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer 4TTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 09 -18 BVYC -00017 SLIM CEMENT MAP TOOL 26- Nov -11 1 1 MPS -01A BY05 -00003 ISOLATION SCANNER 25- Nov -11 _ 1 1 F -05A BINC -00084 LEAK DETECTION LOG 19- Nov -11 _ 1 1 P1 -03 BINC -00082 PPROF W/ DEFT & GHOST 17- Nov -11 1 1 17 -19A BJGT -00082 SBHPS 17- Nov -11 1 1 09 -12 BD88 -00183 MEMORY LDL 28- Nov -11 1 1 • C -02 BYS4 -00005 PRIMARY DEPTH CONTROL 16- Nov -11 1 1 04 -350 BYS4 -00006 USIT 16- Nov -11 1 1 GC -2E BYS4 -00011 RST WATERFLOW 6- Dec -11 1 1 15 -09A BINC -00085 PRIMARY DEPTH CONTROL 8- Dec -11 1 1 09 -17 BAUJ -00104 MEMORY INJECTION PROFILE 30- Nov -11 1 _ 1 MPE -12 BD88 -00185 MEMORY INJECTION PROFILE 14- Dec -11 1 1 16 -03 BG4H -00099 INJECTION PROFILE 28- Oct -11 1 1 MPL -24 BUTT -00004 MEMORY INJECTION PROFILE --- 6- Aug -11 1 1 2- 501U -08 BD88 -00184 MEMORY (PROF W /DEFT GHOST I Q 3— wi, 7 11- Dec -11 1 1 A -11 BSM4 -00018 INJECTION PROFILE 30- Oct -11 1 1 • • . .. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 S ANN D MAR S 1 2012 ~~~ STATE OF ALASKA ~~ ALA OIL AND GAS CONSERVATION COMI~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q • Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De~,elopment ~ ~ Exploratory 193-0670- 3. Address: P.O. Box 196612 Stratigraphic >~ Service 1.... 6. API Number: Anchorage, AK 99519-6612 50-029-22367-00-00 ` 7. KB Elevation {ft): 9. Well Name and Number: 55.3 KB ~ 2-50/U-08 - 8. Property Designation: 10. Field/Pool(s): ADLO-034634 ENDICOTT Field/ ENDICOTT OIL Pool 11. Present Well Condition Summary: Total Depth measured 15530 feet Plugs (measured) 15295' CARBOLITE-10/23/95 true vertical 10405 feet Junk (measured) None Effective Depth measured 15528 feet true vertical 10403.6 feet Casing Length Size MD TVD Burst Collapse Conductor 94' 30" Surface - 131' Surface - 131' Surface 2829' 13-3/8" 68# L-80 Surface - 2873' Surface - 2706' 5020 2260 Production 15484' 9-5/8" 47# NT95FlS Surface - 15528' Surface - 10404' 8150 5080 -~ ., t. s ~ ~~ t ~ / r ~ Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 14900' 0 ~ 0 - Packers and SSSV (type and measured depth) 9-5/8"BAKER SABL-3 PACKER 14836' 9-5/8" BKR DB PKR 14678' 4-1/2 BKR PATCH 14659' 4-1/2 BKR PATCH 14674' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 150 4292 1716 455 Subsequent to operation: 156 4675 1840 408 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~ Development '' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas ~" WAG GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature ~ ~~ Phone 564-4944 Date 10/6/2008 Form 10-404 Re sed 04/2006 .' ` . }~ [J ,~ L ~:~ ~n ~ (: ii ~ ~~~~ Submit Original Only ~pt~ 2-50/U-08 193-0670 PERF ATTACHMENT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 2-50/U-08 7/21/93 PER 15,072. 15,078. 10,084.31 10,088.56 2-50/U-08 7/21/93 PER 15,084. 15,103. 10,092.81 10,106.26 2-50/U-08 7/21/93 PER 15,112. 15,120. 10,112.63 10,118.28 2-50/U-08 7/21/93 PER 15,215. 15,245. 10,184.96 10,205.91 2-50/U-08 11/3/93 SOZ 15,072. 15,078. 10,084.31 10,088.56 2-50/U-08 11/3/93 SOZ 15,084. 15,103. 10,092.81 10,106.26 2-50/U-08 11/3/93 SOZ 15,112. 15,120. 10,112.63 10,118.28 2-50/U-08 11/3/93 SOZ 15,215. 15,245. 10,184.96 10,205.91 2-50/U-08 _ 11/5/93 SOZ 15,072. 15,078. 10,084.31 10,088.56 2-50/U-08 11/5/93 SQZ 15,084. 15,103. 10,092.81 10,106.26 2-50/U-08 11/5/93 SOZ 15,112. 15,120. 10,112.63 10,118.28 2-50/U-08 11/5/93 SOZ 15,215. 15,245. 10,184.96 10,205.91 2-50/U-08 11/15/93 APF 15,108. 15,122. 10,109.8 10,119.69 2-50/U-08 11/15/93 RPF 15,090. 15,103. 10,097.05 10,106.26 2-50/U-08 2/15/94 SQZ 15,072. 15,078. 10,084.31 10,088.56 2-50/U-08 2/15/94 SQZ 15,084. 15,103. 10,092.81 10,106.26 2-50/U-08 2/15/94 SOZ 15,108. 15,122. 10,109.8 10,119.69 2-50/U-08 2/15/94 SOZ 15,215. 15,245. 10,184.96 10,205.91 2-50/U-08 3/8/94 RPF 15,084. 15,103. 10,092.81 10,106.26 2-50/U-08 3/8/94 RPF 15,108. 15,122. 10,109.8 10,119.69 2-50/U-08 11/25/94 RPF 15,215. 15,245. 10,184.96 10,205.91 2-50/U-08 7/30/95 RPF 15,084. 15,103. 10,092.81 10,106.26 2-50/U-08 7/30/95 RPF 15,108. 15,122. 10,109.8 10,119.69 2-50/U-08 10/18/95 APF 15,316. 15,330. 10,255.51 10,265.29 2-50/U-08 1/4/96 SOZ 15,316. 15,330.1 10,255.51 10,265.29 2-50/U-08 8/31/08 APF 15,185. 15,210. 10,163.99 10,181.46 2-50/U-08 9/1/08 APF 15,084. __ _ 15,104. 10,092.81 10,106.97 2-50/U-08 9/1/08 APF 15,107. ~/' 15,122. 10,109.09 10,119.69 2-50/U-08 9/1/08 APF 15,130. / 15,150. 10,125.34 10,139.43 2-50/U-08 9/1/08 APF 15,160. .,/' 15,185. 10,146.46 10,163.99 2-50/U-08 9/1/08 APF 15,185. 15,210. 10,163.99 10,181.46 2-50/U-08 9/2/08 APF 15,068. ,/' 15,078. 10,081.48 10,088.56 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SOF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SOZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 2-50/iJ-08 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITY DATE SUMMARY 8/31/2008""`"'WELL SHUT IN ON ARRIVAL""" ', ~ INITIAL T/I/O = 2000/1300/200 ', '' RIH W/ MH-22/UPCT/FIRING HEAD/ 25' 2" PJ HMX GUN. TOTAL LENGTH = ', ! 36.3', MAX OD = 2". `'"CURRENTLY CORRELATING TO ATLAS SBT-GR 18-JULY-1993 IN PROGRESS. !'***CONTINUE JOB ON 9/1/08 WSR"'`'` 9/1/2008;`*`CONTINUE FROM 31-AUG-2008'`'`'` PERFORATED W/ 2" HSD PJ, 2006 GUNS. INTERVALS: 15160'-15210', 15130'- :15150', 15107'-15122', & 15084'-15104' `:TIED-IN TO ATLAS BT-GR LOG DATED 18-JULY-1993. :CURRENTLY POOH TO PREPARE FOR FINAL GUN RUN. ` ""*CONTINUE JOB ON 9/2/08 WSR*'`* ...._ 9/2/2008;***CONTINUE FROM 01-SEP-2008**" WELL SHUT-IN UPON ARRIVAL. SSV CLOSED. INITIAL T/I/O = 2000/1300/200. ;TIED-IN TO ATLAS SBL-GR LOG DATED 7-18-1993. '??PERFORATED WITH 2" HSD PJ2006 GUNS. INTERVAL 15068-15078'. `'SSV LEFT CLOSED, PAD OP NOTIFIED. VERIFIED ALL CASING VALVES ';:OPEN TO GAUGES. FINAL T/I/O = 2000/1350/150. MOVE OUT OF LOCATION. ="""JOB COMPLETED'`'`'` FLUIDS PUMPED BBLS 1 diesel 1 Total UNDER EVALUATION: END2 PTD #1930670) IAxOA Comm Page 1 of 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] /~ ,G 1~,~'~ Sent: Friday, December 21, 2007 8:15 PM mil/ l To: END/BAD Area Manager; END, Operations Lead Tech; END, O&M TL; Soto, Jose A; Regg, James B (DOA); Maunder, Thomas E (DOA); Engel, Harry R; Rossberg, R Steven; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot; Winslow, Jack L. Subject: UNDER EVALUATION: END2-50 (PTD #1930670) IAxOA Comm Attachments: 2-50.pdf; END2-50 TIO plot.BMP Hi all, Well END2-50 (PTD #1930670) has been found to have IAxOA Comm. During an OA repressure test, the OA pressure ~, increased due to IAxOA Communication. The wellhead pressures were 2020/1940/1420 on 12/19/07 after gas lift system pressure was applie o e o eva uate a report of possible IAxOA communication. The well has been shut-in and pressure bled off the IA and OA. The plan forward is to: 1. D: OART -FAILED, confirmed IAxOA Comm 2. W: PPPOT-IC to evaluate wellhead seals for cause of IAxOA communication ~~ 3. WIE: Eval PPPOT-IC results for mitigation methods Please keep the well shut-in while conducting evaluation of the wellhead seals. A Well Integrity Engineer may request that the well be brought back on for further evaluation once this work is complete. The well has been reclassified as Under Evaluation and is on a 28-day to evaluate the IAxOA communication. A wellbore schematic and a TIO plot are included for reference. «2-50.pdf» «END2-50 TIO plot.BMP» ~~`~~~~ JAN C ~ 2DD8 Please let us know if you have any questions. Thank you, „,fin ~u6e, ~ ~. ell Integrity Coordinator CPB ells Group Pcae: 9q7) 659-5102 Freer: (9i37) 659-5100 11a4 I2/24/2007 ~~~ 'sf ~0 'd0~- LOOZ! 4ZJ6 00~ L 00' Z 800ZlSJ ~ ~OOZI 4ZlZ 4 ~t00ZiSJZ ~ ~QOZlOZ~' 6 6 LOOZISJ 4 L LOJZ! 6Zl0 L ~OOZ1914 6 TREE = 4-1;2" CMI WELLHEAD= 13-5?8"MCEVOY ACTUATOR - KB. ELEV = 55.3' BF. ELEV = 16,22' KOP= Max Angle = 57 f~ 11100' Datum MD = 15031' Datum TVD = 10000' SS 13-318" CSG, 68#, L-80 BTRS, ~ 2$73` ID = 12.415" 9-51'8" CSG, 47#f, NT80S Xd Nf95H5, 12 ED = 8.6$1" inimum ID = 2.3't"' 14887' 4-1l2'° IP w! 2-718" NAP REDUCER ~4 1'2" TBG, 12.6#, L-80; .0152 bpf; ID= 3.958" I--~ 14900' PERFORATIdN SIJM(V1ARY REFLdG: SBT-GR(07?18?93}) ANGLE AT TOP PERT 45 @ 15084' Note: Refe€' to Production DB for historical perf data SIZE SPF INTERVAL dpE,?Sgz DATE 3-3?8" 6 14798 - 14800 S 02/08194 4-1?2" 6 15072 - 15078 S 02:08194 4-1?2" 6 15084 - 15103 S 02,`08!94 3-3.!8" 6 15084 -15103 d 07(30!95 3-3?8" 6 15090 - 15103 S 02,`08194 3-3.?8'° 6 15108 - 15122 S 02,'08194 3-3?8'° 6 15108 - 15122 O 07'30?95 3-3.'8" 6 15112 - 15120 S 02.~ 18194 3-3.!8" 6 15215 - 15235 ~J 11!25,'94 3-3?8" 6 15215 - 15245 S OZ?18,'94 3-3?8" 6 15235 - 15245 O 11?25,'94 3-3?8" 6 15316 - i 5330 S 04?0419£1 PBTD 1 $' 9-5?8" CSG. 47#, NT95HS, ID = 8,681 " 15528° GAS LIFT MANDRELS ST M© TVD DEV TYPE VLV LATCH PORT DATE 6 4420 3752 52 DOME CAMCd RK 16 08111107 5 8139 5889 55 SO CAMCd RK 20 08/11(07 4 10899 7470 56 DMY CAMCd RK 0 08129104 3 12624 8496 50 DMY CAMCd RK 0 08129/04 2 13685 9185 52 DMY CAMCd RK 0 08!29!04 1 13832 9276 53 DMY CAMCO RK 0 08/29!04 14657" - ~ 4 1 j2" PKR Se,'VS NfP, ID = 3.813" X659" - 14674' -~4-112" BKR PATCH (O8/01?07} 14678' BKR BONDED SEAL ASSE€v1BLY w; GBH-22 LOC, ID = 3.875" 1467$® 9-5?8" BKR "DB" PKR w,•` SEAL BORE E7(T, ID = 4.7,.5" 14696' BKR PKR GUIDE, ID = 3.937" 14$35" BKR EBH-22S LATCH, ID = 3.875" 14$36' 9-518" BKR SA BL-3 PKR, ID = 4.75" 14$70' 4-1?2" dTIS X NIP, ID = 3.813" 14$$7` 4-1/2°' OTIS XN NIP vv??_-7.8'° NIP REDUCER: ID = 2.31" {REDUCER SET 07/29107 j 14j 9~~' I--~4-112"WEED! 14$95" ELMD LOGGED {??} ~SANDDUMP-CARBOLITE(1G./23i95j DATE REV BY COMEVIENTS DATE REV BY CdMMENTS ENDICO°i ; UNft' Q7123t93 D15 C3RIGINAL CC7MPLET1t7N 08117?C'7 GJB?PJC SEi BKR PATCH {08!01.'07) WELL: 2-5(i 1 U-08 02118f94 D15 RWO 08,~17tC7 KSBPJC GLV C/d {08111;f?7} PERI~dfC No: 1930670 09,'29?06 MSS/PJC SET PXN PLUG 08;21/G'? SED?PJC NIP REDUCER? Pt3LL PXN {07f27 f© ) API N4: 50-029-22367-00 12/10106 JCI41fPJC CONVERT NE?N FdRE~'!AT SEC 36, T12N, R16E, 3218' idSL & 2317' V~iEL 08/16/07 DTF~1 PJC PULL PXN (07;27;07! 08116,'07 DTPJ PJC SET NIPREDI XX PL UG ({17129 %07j BP Exploration (Alaska) L ALAI OIL AND ~::;~g~S~~;~ON COM~ "~~:' ~_.~ ~~~ ¡U REPORT OF SUNDRY WELL OPERA TI~Oil & Gas Cons. Commission D StimulateD RS ~gJ>ATCH TUBING. D Waiver D Time Extension D D Re-enter Suspended Well D 5. Permit to Drill Number: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Exploratory Service 193-0670 . 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 6. API Number: 50-029-22367-00-00 r 3. Address: 9. Well Name and Number: 55.3 KB 2-50/U-08 ~ ADLO-034634 - 11. Present Well Condition Summary: 10. Field/Pool(s): ENDICOTT Field/ ENDICOTT OIL Pool - 8. Property Designation: Total Depth measured true vertical 15530 r 10405 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 15528 feet true vertical 10403.6 feet Casing Length Size MD TVD Burst Collapse Conductor 94' 30" Surface - 131 ' Surface - 131' Surface 2829' 13-3/8" 68# L-80 Surface - 2873' Surface - 2706' 5020 2260 Production 15484' 9-5/8" 47# NT95hs Surface - 15528' Surface - 10404' 8150 5080 Perforation depth: Measured depth: 14798' - 15330' True Vertical depth: 9894' - 10265' _ SCANNED AUG 162007 - - Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 Surface - 14900' 9-5/8" BAKER SABL-3 PACKER o o o ..~.. ··_t,' Packers and SSSV (type and measured depth) 14836' o o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS BFL AUG 152007 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 201 SHUT-IN Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 10717 1336 0 o 0 0 Tubing pressure 556 o 13. 15. Well Class after Droposed work: Exploratory Development P' 16. Well Status after proposed work: Oil '7 Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service x Contact Gary Preble WINJ WDSPL Sundry Number or N/A if C.O. Exempt: N/A Title Data Management Engineer Signature Phone 564-4944 Date 8/7/2007 Form 10-404 Revised 04/2006 OR\G\NAL Y-({ S Submit Original Only . . 2-501U -08 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/26/20071 ***WELL SHUT IN ON ARRIVAL*** (pre tubing patch) I DRIFT WI BKR DUMMY PATCH, UNABLE TO PASS 5220' SLM, RETRIEVE PXN PRONG @ 14877' i SLM, ATTEMPT TO PULL PLUG BODY @ 14,890' SLM, SHEAR OFF DUE TO BAD ACTIONI NO I OJ'S, CURRENTLY ATTEMPTING TO RETRIEVE PLUG BODY. i ***CONTINUE WSR ON 7-27-07*** - 7j27T2ÖÖ71~*~cONTINÜ EOFROM7:6:07WSR~*~(p;:etl.ibTñgpatchj· -- PULL PXN PLUG BODY @ 14895' SLM, DRIFT TO 14750' SLM WI 3.70" DUMMY PATCH SLOW I FROM 7423' TO TARGET, DRIFT WI 3.75 DMY PATCH (13.3' OAL) SID @ 5187' SLM, DRIFTW/3.70" WHIP STOCK (20' OAL) - SID @ 5,187' SLM. ***TURN WELL OVER TO DSO*** 7/28/2007 ***WELL SII ON ARRIVAL*** (pre t DRIFT WI DUMMY PATCH MAX 0 still in progress. ***CONTINUE WSR ON 7-29-07*** A_AU.WVV n_v' '. '._rr______r______________r_________'_T_C·_ ",_" ·"··h"'__"'~"""~""'m,'w,',',',',',',W^' w".", ***CONTINUED FROM 7-28-07 WS DRIFT WI DUMMY PATCH (MAX 0 SET 2 7/8" NIPPLE REDUCER IN X MULTIPLE ATTEMPTS TO SET 2 7 DETAILS) m ***CONTINUE WSR ON 7-30-07*** ***CONTINUED FROM 7-29-07*** RIH WI KJ, 2' 1 7/8" STM, 3.50" CE EXT OAL= 38") , SID @ 14895' SLM OF 4.5 NIPPLE REDUCER WITH 3. *** WELL LEFT SI TURN OVER TO 7/31/2007 SET BAKER ONE RUN PATCH FR DATED 13-JULY-07. SLACKED OF PATCH OAL = 22' PATCH MIN 10 = 2.37" ***JOB COMPLETE*** 'p_'.·"rm ubing patch) 03.72",17.3' OAL, TIGHT SPOT FROM 8130' TO 8145' SLM Drift ""."""'.'.',',',',',',',',',',',',',',',',',',','.'.·.'.·.'.·.'.·.·.·.·._.'._.'.·.·.·.·.·.'.·.·,·.·.·.w,',',',',',',',',',',',',',',',',','·'PP__A_A_A_ R*** (pre tubing patch) 0: 3.72" OAL: 17.3') TO 14750' SLM (SEE LOG FOR DETAILS), N @ 14893' SLM, CHECK SET TO NIP. REDUCER (GOOD SET), i 18" XX IN NIPPLE REDUCER, SID IN GLM'S. (SEE LOG FOR (pre tubing patch) NT, 2 7/8" X-LINE WI 2 7/8" XX PLUG ((4) 3/16" PORTS, 14" FILL , BLEED DOWN TEST SUCCESSFUL, DRIFT DOWN TO TOP 70" CENT, TAGGED @ 14,893' SLM DSO*** OM 14659' - 14674; AS PERPROGRAM.'flÊ"oINTOsCBLoC COG F AFTER SETTING TO CONFIRM SET. FLUIDS PUMPED BBLS 1 1 I Diesel Total 07/27/07 Sehlumhll'gl!' ,.. E C;"·E"tVE.·.~r) R.." .. ,;.~ w;.- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth JUL. 3 0 2001 ¡CiS ~ cì0 '1- NO. 4346 1\I~a on & Gas CQOs. Commission 01 i-\nct\O~ . t.\t.\t:'. n ~\JG 0 1 10 SG~hl'''''''' Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Well Job # Loa Descriotion Date BL Color CD 3-25/L-27 11686762 STATIC PRESSURE SURVEY 07/09/07 1 4-18/S-30 11813062 STATIC PRESSURE SURVEY 07/10/07 1 2-50/U-08 11676953 LDL 07/13/07 1 1-61/Q-20 11695066 SBHP SURVEY 07/13/07 1 3-41/K-39 11846795 WFL & PRESS GRADIENT 07/17/07 1 1-41/0-23 11695068 INJECTION PROFILE 07/24/07 1 3-41/K-39 11846795 IPROF & JEWELRY 07/16/07 1 L 1-09 11626109 LDL 06/27/07 1 02-30B 11626108 LDL 06/25/07 1 H-07A 11637346 LDL 06/30/07 1 12-05A 11638649 FPIT 07/04/07 1 12-12A 11661162 MEM STATIC TEMP/JEWELRY 07/05/07 1 P2-08 11686761 STATIC PRESSURE SURVEY 07/05/07 1 17-02 11745227 MEM GLS 07/10/07 1 09-11 11686765 STATIC PRESSURE SURVEY 07/11/07 1 X-19B 11801075 LDL 06/19/07 1 MPK-30 11676952 FPIT 07/12/07 1 11-08 11813061 STATIC PRESSURE SURVEY 07/07/07 1 03-14A 11849926 BHP SURVEY 07/25/07 1 01-16 11630486 PROD PROFILE 06/28/07 1 MPH-17 11813063 CBL & IMAGE LOG 07/21/07 1 . 01-15A 11849924 USIT 07/20/07 1 02-30B 11813058 USIT 07/04/07 1 MPJ-24 11638647 USIT 06/29/07 1 E-101 11630488 PRODUCTION PROFILE 06/30/07 1 G-18A 11209612 MCNL 07/19/06 1 1 . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: dlo FW: Problem Well Notification: Endicott 2-50 (PTD #1930670) ) ) Subject: FW: Problem Well Notification: Endicott 2-50 (PTD #1930670) From: "NSU, ADW Well Integrity Engineer" <NSUADWW ellIntegrityEngineer@BP.com> Date: Wed, 25 Aug 2004 21 :05 :24 -0800 To: "END, Production Operator" <ProdOper@BP.com>, END/BAD Area Manager <ENDBADOpsSuperintendent@BP.com>, "McMullen, John C" <McMullJC@BP.com>, "END, Operations Lead Tech" <ENDOperationsLeadTech@BP.com>, "Rossberg, R Steven" . <RossbeRS@BP.com>, "NSU, ADW.WeUOperations Supervisor" . . . <NSUADWWellOperationsSupervisor@BP.com.>, "AOGCC -. Jim Regg(E-mail)" <jiin_regg@admin.state.ak.us>, "NSU, ADW WL & Completion Supervisor". . <NŠUADWWL&CompletionSupervisor@BP.com>, "AOGCC - Winton Aubert (E-mail)" <winton - aubert@admin.state.ak.us> . . Please ignore if you have already received this message. Thanks! Joe -----Original Message----- From: NSU, ADW Well Integrity Engineer Sent: Wednesday, August 25, 2004 8:59 PM To: END, Production Operator; END/BAD Area Manager; McMullen, John C; END, Operations Lead Tech; Rossberg, R Steven; NSU, ADW Well Operations Supervisor; 'AOGCC Jim Regg (E-mail) '; 'AOGCC Winton Aubert (E-mail) '; NSU, ADW WL & Completion Supervisor Cc: NSU, ADW Well Integrity Engineer; Olsen, Clark A Subject: Problem Well Notification: Endicott 2-50 (PTD #1930670) All, Well Endicott 2-50 (PTD #1930670) has sustained casing pressure on the IA and the well has been classified as a Problem well. The TIO's on 08/24/04 were 3040/3040/40. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: CO OGLV 3. DHD: Re-TIFL Attached is a wellbore schematic. Please call if you have any questions. «2-50.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, xl154 Email: NSUADWWelllntegrityEngineer@bp.com Content-Description: 2-50.pdf Content-Type: application/octet-stream Content-Encoding: base64 SCANNED NOV 0 2 2004 1 of 1 9/2/20047:59 AM - 1-- ~ I ---.~ v v v v .. ) RT. ELEV = 55.3' BF. ELEV = 16.12' MAX DEV = 57%' @ 11,10O:t 13- 3/8", 68#/ ft, L-80, BTRS. CSG I 2873' ..... 4-1/2", 12.6#/f~ L-80, TDS TUBING 9-5/8", 4 7#/f~ I I NT80S XO TO 12,123' -..... NT95HS PERFORATION SUMMARY REF: LOG: SBT-GR (7/18/93) CO SIZE SPF INTERVAL AWS 4-1/2" DPC 15,072' -15,078' SOl 5 15,084' - 15,103' SQZ 15,112' -15,120' SQZ 15,215' - 15,245' SQZ 15,090' -15,103' SQZ 15,108' - 15,122' SQZ AWS 3-3/8" 6 14,798' -14,800' SQZ AWS 3-318" 6 15,084' -15,103' OPN AWS 3-3/8" 6 15,108'-15,122'OPN 15,215' - 15,245' OPN 15,316' -15,330' SOlD AWS 3-318" 6 PBTD 9-518", 47#/ft, NT95H S, I 15,448' I 15.528' DATE 3121/95 COMMENTS ADD REV. BY JLH 10118/95 10125195 ADD SANDBACK & CM NT JTP JTP A .. ~ z ') TREE: 4-1/2" ,CIW/OTIS/OTIS - 5000 psi WELLHEAD: 13 518" I 5000 psi / McEvoy . .....- SSSV LANDING NIPPLE I 1457' (3.813" MIN. 10) . W/SSSV MIN 1.0. is 2" GAS LIFT MANDRELS (CAMCO) - -1/')" "TG" lATCH 1-518" .IDS TOOL ..0IIII-- NO. MD-BKB TVO-8S #Ô 4,420 3,696 #5 8,139 5,834 #4 10,899 7,414 #3 12,624 8,440 ~ 1~6æ ~1~ #1 13.832 9.220 TVD DEPTHS FROM GYRO- . 1.- 4-1/2" PARKER'SWS' I 14657 NIPPLE (3.813" MIN. 10) , Baker Seal Assembly I 14678' 17' long, 3.875" 10 9-518" I 14,678' PACKER ~ r- ......- Squeeze Perfs I 14,798 -14800' I r ~ .---- Baker Latch Assembly I 14.835' ~ 9-518" PACKER I ~ (BAKER "SABL-3") 14,836' E 4-1/2", 12.6#/ft, L-80 TDS TAILPIPE 4-1/2" 'X: NIPPLE I (OTIS) (3.813"10) 14,870' 4-1/2" 'XN' NIPPLE I 14.887' (OTIS) (3.725" 10) . .... 4-1/2" WL Guide 114,899' 14,895' ELM I -. SANDBAC K CM NT 1 15,295' I ENDICOTT WELL 2-50 I U-08 API NO: 50-029-22367 COMPLETION DIAGRAM BP EXPLORATION, INC. MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser?~~ Commissioner v Tom Maunder, P. I. SupervisoK~-- ~.-,._)---0 ~ FROM: John Crisp, SUBJECT: Petroleum Inspector DATE: May 20, 2001 Safety Valve Tests Duck Island Unit Endicott MPI 1 & 2 May 20.,.200.!: I traveled to BP's Duck Island Unit Endicott Field to witness Safety Valve System tests. Mark Souve was BP's Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, the SSSV on well 1-19 failed to pass the DP test. The AOGCC test report is attached for reference. i inspected 25 well houses on MP! Row 1 & 2 w/no problems witnessed. SUMMARY: I witnessed SVS testing in BP's Endicott Field. 17 wells, 51 components tested. 1 failure witnessed. 1.96% failure rate. 25 well houses inspected. ,,Attachme, p,ts: SVS DIU 5-20-01jc CC; NON-CONFIDENTIAL SVS DIU 5-20-0 ljc Alaska Oil and Gas Conservation Commis..on Safety Valve System Test Report Operator: BPX Operator Rep: Mark Souve AOGCC Rep: John Cr~,' Submitted By: John Crisp Field/Unit/Pad: Endicott DIU MPI Pad Separator psi: - LPS '~35' Date: 5/20/01 HvS i i i ii i i i i Well Permit Separ Set L/P Test Test Test Date oil WAG, GIN J, Number Number PSI PSI ,,, Trip Code Code Code Pass, ed GAS or CYCLE 1-01/J19 1880370 235 150 125 P P P OIL 1-03/P16 1951500 235 150 135 P P P OIL , , , 1-05/O20 1861060 1-0VA/L2 1970290 '3~35 150 130 P 1:;' P ' 'OiL 1-15/P25 1930560 1-17A/Il 1961990 1-19/I1~ 1950930 '~35 150 125 p" p 9 OiI~ , ,. 1-21/K25 1900020 1-25MK2 ' '1970750 235 150 150 P P P " oii~ 1-27/P20 1870090 235 150 1~5 P P P OIL" 1-29/M25 18~31810 " 1-31/M21 1950720 235 150 125 e e P .... 0iL , , , , ,, , , 1-33B/L2 1982550 235 150 145 P P P OIL _ 1-35/02~ 18618'40 '235 150 135 P e P OiL 1.39/P17 ' 1880630 ' i1'-45/Q26 1891240 , , ' 1-47A/M2 1972030 1-49/P21 1880780 23~ 150 130 P "~ P P oIL . 1-55/R25 1880210 2351 150 145 P P P OIL 1-57/R23 1881140 235 150 140 P P P oIL , , , :1-61/Q20 1941420 235 150 135 P P P OIL 1-63/T22 18~0060 235 1501 145 P P P OIL 1-65/N25 1951880 235 150 150 P P P OIL 2-04/M19 1860820 2-06/J22 1870180 ..... 2-08/K16 1880040 .... 2712/Q16 ,1921170 ', .... , 2-14/016 1861490 2-18/L16 1900430 ......... 2-20/L15 ' 1'960600 " ,,, 2-26/N14 1880550 , 2-28/P 19 1880860 ....... 2-30A/E1 1981880 2-32/SN3 1901190 ......... , , 2-36/O14 1900240 ' ' , , 2-38/SN1 1901290 _ , ,, 2-~_t~S~ ,~6/,~!1941520 no., 1 ,~'9 ~x~'~ rTTI q.on_nli~ _ Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GASorCYCL~ 2-42/P13 1881450 ......... 2-44A/Q1 1970710 2-46B/S1 197137'i) ' 2-48/O 13 1951660 2-50)U08 193067'0' ' 3_35 '-150' 145 P 13 ' P OIL 2-52/S1,~ '"1870920 ....... 2-56A/EI 1980580 2-58/S09 1900520 2-60/ui3 19308~(J 235 150 130 P P .... P .... OILi ,.2'62/Q17 1861580 ~ , 2-68/S 17 1880970 5-01/SD7 1801200 Wells: 17 Components: 51 Failures: 1 Failure Rate: 1.0~% [3 9o Day Remarks: RJF 1/16/01 Page 2 of 2 SVS DIU 5-20-01jc THE MATERIAL UNDER THIS COVER HAS BEEN MICRO-FILMED ON OR BEFORE DECEMBER 01, 2000 E PL W M ATE IA L U N D I~ TH IS M ARK E R STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate Plugging__ Pull tubing__ Alter casing __ Repair well __ Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3218'NSL, 2317'WEL, SEC. 36, T12N, R16E At top of productive interval 4932'NSL, 2000'WEL, SEC. 34, T12N, R16E At effective depth 5039'NSL, 2235'WEL, SEC. 34, T12N, R16E At total depth 5064'NSL, 2305'WEL, SEC. 34, T12N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service ORiGii AL 6. Datum elevation (DF or KB) KBE=55.3' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-50/U-08 9. Permit number/approval number 93-67~Not required 10. APl number 50- 029-22367 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 15530' feet 10405' feet Plugs (measured) Effective depth: measured 15448' feet Junk (measured) true vertical 10349' feet Casing Length Size Cemented Structural Measured depth True vertical depth BKB BKB Conductor 94' 30" Drive 131' 131' Surface 2829' 13-3/8" 1194 cuft PF "E" & 2873' 2706' Intermediate 460 cu ft Class "G" Production 15484' 9-5/8" 517cu ft Class "G" Liner 15528' 10404' Perforation depth:measured 15084'-15103', 15108'-15122', 15215'-15245', 15316'-15330' (all open~ __ [ C IV [ D true vertical 10037'-10053', 10054'-10064', 10130'-10151', 10200'-10210' (all open) 9686'-9869', 10029'-10033', 10057'-10063' (all squeezed) ~ l l~ ] ~ ~ Tubing (size, grade, and measured depth) 4-1/2", L-80 tubing to 14900'MD ~..~.~',y,~ ,, Packers and SSSV (type and measured depth) 9-5/8" Baker SABL-3 packer @ 14836'MD; Baker DB packer @ 14678'MD;4-1/2 Otis 9cr SVLN @ 1457'MD 13. Stimulation or cement squeeze summary Scale Inhibitor Treatment (7/2/96) Intervals treated(measured) 14798'-14800', 15072;15078', 15084;15103', 15108'-15122', 15112' -15120', 15215;15245', 15316'-15330' Treatment description including volumes used and final pressure 46 bbls Seawater/Mutual Solvent Mix, 55 bbls Seawater/Scale Inhibitor Mix, 285 bbls Seawater~2% Surfactant Mix, 234 SW Tubing Volume. FS WHP=O 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 887 2097 1331 0 332 Subsequent to operation 1083 1902 1271 0 113 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations __ 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby~certify that the foregoing is true and correct to the best of my knowledge. Form 10-404~v 06/15/88 Date 8/9/96 SUBMIT IN DUPLICAT,,~ STATE OF ALASKA ALA3, ~ OIL AND GAS CONSERVATION COMMISSIOnl REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging__ Pull tubing __ Alter casing Repair well __ Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 3218' NSL, 2317' WEL, SEC. 36, T12N, R16E At top of productive interval 4932' NSL, 2000' WEL, SEC. 34, T12N, R16E At effective depth 5039' NSL, 2235' WEL, SEC. 34, T12N, R 16E At total depth 5064' NSL, 2305' WEL, SEC. 34, T12N, R16E ORigiNaL 12. Present well condition summary Total depth: measured true vertical 15530 feet 10405' feet Plugs (measured) 6. Datum elevation (DF or KB) KBE = 55.3' feet Unit or Property name Duck Island Unit/Endicott 8. Well number 2-50/U-08 9. Permit number/approval number 93-67~Not required 10. APl number 50- 029-22367 11. Field/Pool Endicott Oil. Pool ~..;,.:...~.,.~, ,.., ...... ~,~ !.~i'"~! Effective depth: measured 15448' feet Junk (measured) true vertical 10349' feet Casing Length Size Cemented Structural Conductor 94' 30" Drive Surface 2829' 13-3/8" 1194 cuft PF "E" & Intermediate 460 cuft Class "G" Production 15484' 9-5/8" 517 cu ft Class "G" Liner Perforation depth: Measured depth BKB True vertical depth BKB 131' 131' 2873' 2706' 15528' 10404' measured 14798'- 14800~ 15072'- 15078~ 15084'- 15103~ 15112'- 15120' 15215'- 15245~ 15084'- 15103~ 15108'- 15122', 15316'- 15330'(AflSqueeze¢ true vertical (subsea) 9686'- 9869', 10029'- 10033', 10037'- 10051', 10057'- 10063' 10130'- 10151', 10037'- 10051', 10054'- 10064 ', 10200'- 10210' (Afl Squeezed) Tubing (size, grade, and measured depth) 4-1/2", L-80 tubing to 14900' MD Packers and SSSV (type and measured depth) 9-5/8" Baker SABL-3 packer @ 14836'MD; Baker DB packer @ 14678'MD;4-1/2" Otis 9crSVLN @ 1457'MD 13. Stimulation or cement squeeze summary Add perforations (10/18/95) and water shut off cement squeeze (1/4/96) Intervals treated (measured) 14798'- 14800', 15072'- 15078', 15084'- 15103', 15112'- 15120' 15215'- 15245', 15084'- 15103', 15108'- 15122', 15316'- 15330' Treatment description including volumes used and final pressure $60 Bbls seawater, 338 fils effluent water, 40 bbls methanol and1.8 bbls class G cement. FSWHP = 1180 psig 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 85O 522 1039 0 70 56 4566 0 Tubing Pressure 3O9 311 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations __ 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~]ned ~ ~-~-~?~/"~ C;>~-~, ~~ ~-~--~' Title Senior Technical Assistant II Date ,/~/~/,/~'~-~ , Form 10~,4~0~4 Rev 06/15/88 SUBMIT IN DUPLICATE Endicott Production Engineering Department DATE: I 0/1 8/95 WELL N°-: 2-50/U-08 BP EXPLORATION REP: SERVICE COMPANY: Add-Perforations POWERS ATLAS/BARBA DATE/TIME OPERATIONS SUMMARY 1145 MIRU.ATLAS FWHP=350, IAP=1400, OAP=440 WHT=100 F. 1230 SI well and RIH with 14' gun. 1 345 POP well @ 60 beans. SIP=1400 psig. 1350 Tie in to SBT dated 2-13-94 Add 2'. 1430 Hang gun # 1 with CCL at 15,308 MDBKB. (8' to top shot). Shoot gun #1 from 15316 - 15330' MDBKB. Lost 900 Lbs. Must have been blown up hole some. Log off. 1445 SI well and POOH. 1603 OOH. All shots fired and have entire tool string back. 1618 POP well at FOC with lift gas. SIP=1650. Well is flowing hard!!! PERFORATION SUMMARY' GUN INTERVAL FEET SUBZONE I 15316 - 15330 14 3C2 Interval shot using 3-3/8" Alpha Jet at 6 spf, 60 degree orientation. phasing, random .r LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 16 January 1996 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL 3-11/M-30 (SDI) 3-35/ .-36 (sDi) DESCRIPTION 1PFC/PERF FINAL BL+RF 1PFC/PERF FINAL BL+RF 1PLS FINAL BL+RF Run # 1 Run # 1 Run # 1 ECC No. 5723.08 5921.12 6001.17 Received by: Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 2/FAnchorage, AK 99518 AX to (907) 563-7803 Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 7 November 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL ,~ ~ DESCRIPTION 2-68/S-17 - 1 PLS FINAL BL+RF , 2-16/M-16 ~ 1 PLS FIN~ 'BL+~ ECC No. Run ~' 1 5639.01 Run ~ 1 6001.16 Run ~ 1 6148.05 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services Suite 201 Anch°rage' AK 995~ 7803 / LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 1 November 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION 2-18/L-16 q0~~ i PL$ FINAL BL+RF ~-~o~-o~ ~ 5 ~ .o~1~ ~/cc~ ~ ~+~ 1 PLS FINAL BL+RF. .Run' #' 1 Run # 1 Run # 1 Run ~ 1 ECC No. 4297.10 - - 6001.15 6192.09 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 or ~ to (907) s6~-~~ Received by: ~, .~ Date: ;--Jaska OJj & Gas C0flS. Anchorage LARRY GRANT : Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 23 October 1995 Transmittal of Data Sent by: Hg~ND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL 3-09/ -28A DESCRIPTION PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PLS FINAL BL+RF PFC/PERF FINAL BL+RF ECC No. Run # 1 4297.09 Run # 1 5869.06 Run # 1 6001.14 Run # 1 6146.03 Run # 1 6397.11 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 . ~ Anchorage, AK 99518 // j Or FAX to (907) 563-7803 (,' ....,./ Date: '". STATE OF ALASKA ALA,.,,~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging Pull tubing m Alter casing __ Repair well __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 Perforate X Other__ 4. Location of well at surface. 3218' NSL, 2317' WEL, SEC. 36, T12N, R16E At top of productive interval 4932' NSL, 2000' WEL, SEC. 34, T12N, R16E At effective depth 5039' NSL, 2235' WEL, SEC. 34, T12N, R16E At total depth 5064' NSL, 2305' WEL, SEC. 34, T12N, R16E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service __ Casing Length Structural Conductor 94' Surface 2829' Intermediate Production 15484' Liner Perforation depth: 6. Datum elevation (DF or KB) KBE = 55.3' feet 7. Unit or Property name ~/D~,., 7k~lslandl, Unit/Endicott 8." W~n, drcber 9. Permit nur~lb~r/a~ro,val number 93-67~Not requi/:r~,~/~ 10. APl number 50- 029-22367 11. Field/Pool Endicott Off Pool 15530 feet Plugs (measured) 10405' feet 15448' feet Junk (measured) 10349' feet Size Cemented 30" Drive 13-3/8" 1194 cuft PF "E" & 460 cuft Class "G" 9-5/8" 517 cuft Class "G" Measured depth True vertical depth BKB BKB 131' 131' 2873' 2706' 15528' 10404' measured 14798'- 14800~ 15072'- 15078~ 15084'- 15103~ 15112'- 15120'(Afl squeezed) 15215'- 15245~ 15084'- 15103~ 15108'- 15122'(A#open) true vertical ¢ubsea)9686'-9869~ 10029'-10033~ 10037'-10051~ 10057'-10063'(AIIsqueezed) 10130'- 10151~ 10037'- 10051~ 10054'- 10064(Aflopen) Tubing (size, grade, and measured depth) 4-1/2", L-80 tubing to 14900' MD Packers and SSSV (type and measured depth) 9-5/8" Baker SABL-3 packer @ 14836' MD; Baker DB packer @ 14678' MD;4-1/2" Otis 9cr SVLN @ 1457' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 1456 4419 1144 0 1103 2477 676 0 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations x 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-4.0",4/Rev 06/15/88 Tubing Pressure 346 342 Title Senior Technical Assistant II Date :~.~-/~ ~'"' ~ SUBMIT IN DiJPL['CATE~.,, Endicott Production Engineering Department DATE: 7~30~95 WELL N=: 2-50/U-08 BP EXPLORATION REP: SERVICE COMPANY: Re-Perforation VARBLE ATLAS/BRUNER DATE/TIME OPERATIONS SUMMARY 0800 MIRU.ATLAS FWHP=350, IAP=1650, OAP=440 WHT=90 F. 0900 Arm GUN # 1 (14') 0920 SI well and RIH. Well was flowing liquid. 1045 POP well @ 65 beans ... 1055 Tie in to SBT dated 7/18/93 TAKE OUT 8 '. 111 0 Hang gun # I with top shot at 15108 MDBKB. (8' from CCL) 1112 Shoot gun #1 from 15108 - 15122' MDBKB, Log off and flag line for next run. FWHP= 440 psig. ., 1125 SI well and POH. 1225 OOH. ALL SHOTS FIRED. 1245 RIH WITH GUN# 2 (19') 1405 POP well @ 65 beans 1420 Tie in to SBT - ADD 4' 1430 Hang gun with top shot at 15084 MDBKB. (3' from CCL) 1432 Shoot gun #2 from 15084-15103' MDBKB, Log off FWHP- 450 psig. 1445 SI well and POH. 1530 OOH. Confirm all shots fired. 1600 RDMO -POP WELL & TURN OVER TO OPERATIONS PERFORATION SUMMARY: GUN INTERVAL FEET SUBZONE I 15108 - 15122 14 3C5 2 15084 - 15103 19 3C5 Interval shot using 3-3/8" Alpha Jet at 6 spf, 60 degree phasing, random orientation. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 14 August 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PLS FINAL BL+RF ECC No. Run # 1 6025.03 1 SBT/GR FINAL BL+RF Run # 1 6467.02 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services ~f~~reet ~- -~r-FAx ~O' (907)'''__ ~/ /~ v v~v / Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Date: RE: Reference: BP EXPLORATION (ALASKA) INC. 2-50/U-08 END I COTT ~~ NORTH SLOPE, AK Enclosed, please find the data as described belo 3 August 1995 Transmittal of Data ECC #: 6025.02 Sent by: ANCH.EXPRESS Data: PFC/PERF Prints/Films: 1 PFC/PERF FINAL BL+RF Run # 1 Please sign and return to:-At-~-~ney D. Paulso-~-n~ At las/~ireline Services 5600/B Street Su~e 201 .~ A~chorage, ~ 99518 ~ ~ ~ /~..~ ~ / ~ O /A ~ ~... ' ~9~ !:.3 3 .... 0 6 7 93 .... 08 7 93 93 .--06 7 93 .w 06 7 93"-067 93'.-067 93 .... 067 93 .... 067 Si 3 ..... 06 '? 93 .... 067 A O,2,3 ,S I ih d 'i v 'i ,:..-i u a ] W ::?~ i ] G e o '! o Cj 'i c a I H e 't: e r' 'i ,!.t'.., '1 s I ri v ~.~ i'~ 'i: o r" ',/ .D A 'T A T ..F.., A T A ..... F' l... !..! ~'i; 5 7 S 9 5 7 59 D A :[: !... Y W E L i... 0 F' GCT DZRECTT,..ONAL S !j R V E Y ,SCL (T'CR) (::CI../'PFC: (C!RC) C L / P F ('; ............ "~ N l //,c; F,:/ . ....... DGR/EWR pL,,./FEI' D G R/F \,,,,,, R ~- [-:' L,,. / F E T ,s~:/ccL ~ 'i00 .... 1.., ~'200. ~ 3500 ..... i 59[.-'..,0 / ./ '--~..~ 'i/,,. 625 -- 'i a. 820 ~ia. 690-.. lZ~900 G F', /r, I. ( C E 1'4 E N'T ) t...~- I q. a. 00 -- 'i .5 '/00 ~ t"~500 'i5'3'i7 L..-' H W D i a 928 ._. i 5 ~.~. 50 ~' j,,ik,',t.F.;, 9898 10278 · ~ la. 737 .... la-905 ~.._~... i ~ a- 95 ..... J .'h. 6 h. 3 I:;: A !~:, i[ U S F' D K /Ei tR/' T E H F' ,.,' ;$ ('; L ~-~i.. 'i/~. 750 i 50 '? 6 1 S '100'- i 5:i~ O0 i3500,-, i5h-52 Ri., '1a. 650 i5i95 1 00 ..... I [5200 C I I F-( V F ~-- .... STATE OF ALASKA -' ORIGINAL (A OIL AND GAS CONSERVATION OOMN.. N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing__ Alter casing Repair well Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3218' NSL, 2317' WEL, SEC. 36, T12N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service Datum elevation (DF or KB) KBE = 55.3' feet Unit or Property name Duck Island Unit/Endicott 8. Well number 2-50/U-08 At top of productive interval 9. 4932' NSL, 2000' WEL, SEC. 34, T12N, R16E At effective depth 5039' NSL, 2235' WEL, SEC. 34, T12N, R16E At total depth 5064' NSL, 2305' WEL, SEC. 34, T12N, R 16E Permit numbedapproval number 93-67/Not required 10. APl number 50- 029-22367 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 15530 feet 10405' feet Plugs (measured) Effective depth: measured true vertical 15448' feet Junk (measured) 10349' feet Casing Length Size Cemented Structural Conductor 94' 30" Drive Surface 2829' 13-3/8" 1194 cu ft PF "E" & Intermediate 460 cu ft Class "G" Production 15484' 9-5/8" 517 cu ft Class "G" Liner Measured depth True v~,~l depth BKB 131' 131' 2873' 27O6' 15528' 1O4O4' Perforation depth: measured 15072'- 15078' (Squeezed) ECEIVED true vertical (subsea) 10029'- 10033' (Squeezed) 10038'- 10051', 10054'- 10064', 10130'- 10151' (Ail open) M/XR 29 1995 Tubing (size, grade, and measured depth) 4-1/2", L-80 tubing to 14900'MD ~,~.~,sK~t u~ & Gas Cons. Commission P~c~rs ~nd SSSV (t~ ~nd m~su~ed d~pth) ~-~" ~.r SAS~-~ p~c*~r ~ ~' MO; ~k~ DB p~c~e~~ ~7~' MO;~-~/2" Otis 9cr SVLN @ 1457'MD 13. Stimulation or cement squeeze summary Scale inhibitor treatment on 2/11/95 .... Intervals-treated (measured) 15084'-- 15103', 15108'- 15122',' 15215'- 15245' 14. Treatment description including volumes used and final pressure 62 Bbls diesel/mutual solvent mix, 233 Bbls dead crude, 2 Bbls dieseJ 36 Bbls seawater/scale inhibitor mix and 85 Bbls seawater/2% surfactant mix. FWHP = 300 psiE Representative Daily Average production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1154 5340 128 0 33 7 1224 2669 631 0 303 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas__ Suspended Service 17. I hereby certify that the foregoing is true and correct, to the best of my knowledge. S i9 n ed ~-----~..~ ~?7./L.(~ ..~ .,-~. /~~.-¢;2 Tltle Senior Technical Assistant ll Form 10-~Rev 06/15/88 ORIGINAL SUBMIT IN D'd~d,~ATE DATE' I 1/25/94 WELL N°. 2-50/U-08 BP EXPLORATION REP' SERVICE COMPANY' i ii i EndicOtt Production 'Engineering , , Re-Perforation POWERS ATLAS/BRUNER DATE/TIME OPERATIONS SUMMARY 1/25 1 300 MIRU. FWHP=1100, lAP=800, ©AP=200,'~HT=SI. Well was dead. Turned on lift gas. Rehead. 1 51 0 Arm 20' 3-3/8" gun. 1 540 SI well and RIH. Well was flowing liquid. 1 705 POP well @ 80 beans 1715 Tie in to SBT dated 7/18/93 add 12'. 1 7'30 Hang gun with to~ shot at 15225' MDBKB. (2" fr'om CCL) 1735 Shoot gun #1 from 15225-15245' MDBKB. Log off and flag line"for next run. FWHP= 550 psig. 1 745 SI well and POH. 1900, CCH. Gun did not fire. 1930 I RIH with 10' gun. No apparent' reason for missfire. ... 2100I POP well @ 80 beans 2115 Tie in to SBT 2130 Hang gun with top. shot at 152.:~5' MDBKB. (2' from.CCL) 2135 Shoot gun #1 from 15235-15245' MDBKB. Log off and flag line for next run. FWHP= 550 psicj: ..... 2150 S! well and POH. 2300 CCH. Confirm all shots fired. RDFN. 1/26 0800 MIRU. SIHP--1950, lAP=200, CAP=200, WHT=SI. _ ... ,,., ,,., ~ ~ ~ r r 0930 RIH w/20' gun #2. -- 1030 ' POP wel @ !04 beans. 1040 Tie-in to SBT. ,~ ^ r) ~_ 9. lqq~ 1050 Hang,qun#2, top shot @15215'. (3'toCCL) FWHP=550PSIG. 1055 Shoot gun ¢2 from 15215'-15235'.-Log off. .,,~ st~,~ v. ~ Gas Cons, Coif 11056 SI well and POH. Anchor~ ~lssion PERFORATION SUMMARY' GUN INTERVAL CBL DEPTH FEET SUBZONE I 15235-15245 10 3C3 2 15215-15235 20 3C3 Interval shot using 3-3/8" Alpha Jet at 6 spf, 60 degree phasing, random orientation. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 1 December 1994 Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ~./.i~~ 2-30/O-09 1 PLa FINAL BL + RF 1 PFC/PERF FINAL BL+RF Run # 1 1 PLS FINAL BL + RF Run # 1 1 PFC/PERF FINAL BL+RF Run # 1 Run # 1 Run # 1 ECC No. 6025.01 6217.07 6235.06 6305.00 6310.01 Please sign and return t°:~l~aSBW~trelin~e/~~~. .~A~c hera__99518 ~ Attn. Rodney D.~a~n .~ Or FAX to (907) 563-78~-~-~ Received by: ~~_.~ /~~ f Date: STATE OF ALASKA OIL AND GAS CONSERVATION COMMIb,_...,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator BP Exploration (Alaska) inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3218' NSL, 2317' WEL, SEC. 36, T12N, R16E At top of productive interval 4932' NSL, 2000' WEL, SEC. 34, T12N, R16E At effective depth 5039' NSL, 2235' WEL, SEC. 34, T12N, R16E At total depth 5064' NSL, 2305' WEL, SEC. 34, T12N, R16E 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development Exploratory Stratigraphic Service Effective depth: measured true vertical .... ,,~ ~ ~ Gas Cons. C0mmissiot~ 15530 feet Plugs (measured) 10405' feet 15448' feet 10349' feet Junk (measured) 6. Datum elevation (DF or KB) KBE = 55.3' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-50/U-08 9. Permit number/approval number 93-67/Not required 10. APl number 50- O29-22367 11. Field/Pool Endicott Oil Pool ORIGINAL Casing Length Structural Conductor 94' Surface 2829' Intermediate Production 15484' Liner Perforation depth: measured true vertical Size Cemented 30" Drive 13-3/8" 1194 cu ft PF "E" & 460 cu ft Class "G" 9-5/8" 517 cuft Class "G" Measured depth BKB True verbal depth 131' 131' 2873' 2706' 15528' 1O4O4' 15072'-15078; 15084~15103~ 15112~15120~ 15215'-15245',14798L14800'¢queezed) 15084~15103~ 15108L15122'(open) 10039~10043~ 10047~10059~ 10065'-10071~ 10132~10151~ 9868'-9869'¢queezed) 10031~10105~ 10109L10119'(open) Tubing (size, grade, and measured depth) 4-1/2", L-80 tubing to 14900' MD Packers and SSSV (type and measured depth) 9-5/8" Baker SABL-3 packer @ 14836'MD; Baker DB packer @ 14678'MD;4-1/2" Otis 9cr SVLN @ 1457' MD 13. Stimulation or cement squeeze summary Cement Squeeze #1 (11/3/93), Cement Squeeze #2 (11/5/93), and add perforations (11/15/93) Intervals treated (measured) 15072'-15078', 15084'-15103', 15112'-15120', 15215'-15245', 14798'-14800' Treatment description including volumes used and final pressure Cement squeeze ttl (see attached summary). FWHP=O Cement Squeeze 112 (see attached summary). FWHP=1650 psig 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure The well was worked over with a rig in February, 1994. Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations __ 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is trL)e and correct to the best of my knowledge. Signed ~/'k,/~"'~, ~--~./~~' Title Senior Technical Assistant II Form 10~ Rev 06/15/88 Date..~ / ~)//~ ~' SUBMIT IN DOPLIG/ATE'~ WELL CTU Squeeze Cont. : 2-50/U-08 Page 5 SUMMARY LOAD AND COOL DOWN WELL WITH 591 BBLS SW. WELL INJECTIVITY OF 4.4 BPM AT 2200 PSI. PUMP "ARCO" PREFLUSH AND LAY 15 BBLS CEMENT ACROOS PERFS (3 BBLS BEHIND PIPE) AT 1600 PSI BP WHILE GAUGING RETURNS. BUILT WHP TO 2500 PSI. HESITATE, WHP FELLTO 1500 PSI. MIX BATCH # 2. WELL INJECTIVITY OF .75 BPM AT 2750 PSI. WHP BROKE BACK TO 2100 PSI. DISPLACE COIL VOL TO WELL GAUGING RETURNS. HOLD WHP 1800 PSI TO LAY IN CMT. TAG CMT AT 15,104. LAY IN CMT ACROSS PERFS AND BUILT WHP TO 2800 PSI. WHP BROKE BACK TO 2600 PSI. HESITATE. WHP DROPPED TO 1850 PSI. DISPLACE CMT INOT PERFS. CONTAMINATE ANY CMT LEFT IN WELL BORE. AND REVERSE OUT 3 BBLS. SDFN. FLUIDS '591 2O 25 26 0 5 5 25 3 15 15 26 76 26 24 0 4OO 5O 47 3 BBLS SW TO LOAD WELL BBLS EW ("ARCO PREFLUSH" WITH 1% BJ'S S400 SURFACTANT) CEMENT BATCH I - BBLS CEMENT BBLS EW (SPACER) BBLS DUO POLYMER (CONTAMINANT) BLS SW (DISPLACEMENT) CEMENT BATCH 2 - BBLS EW BBLS CEMENT BBLS EW (SPACER) BBLS SW BBLS DUO POLYMER (CONTAMINANT) BLS SW (DISPLACEMENT) BBLS SW (REVERSE OUT) BBLS MEOH (FREEZE PROTECTION CT) BBLS MEOH (FREEZE PROTECTION WELL) BBLS MEOH (FREEZE PROTECTION FLOWLINE) WELL CLEANED OUT TO 15260' BBLS LOAD FLUID BEHIND PIPE BBLS CEMENT PUMPED BBLS BEHIND PIPE BBLS CEMENT RECOVERED (DOES NOT INCLUDE CEMENT NOT PUMPED) CEMENT (B.J. SERVICES) 15.8 PPG CLASS "G" CMT CONTAINING 0.52% FL-33 0.1% CD-32 0.34% R-11 1.0 GAL PER SK FP-CL BATCH # 1 THICKTIME = 8 HRS 15 MIN INCLUDING 1 HOUR SURFACE TIME LAB APl F.L. -- 48 ML @ 170°F (REQUESTED RANGE 35 TO 55 ML) FIELD APl F.L. = 456ML FIELD APl FC = 3/4" FIRM LC FL = NA LC FC = NA BATCH # 2 THICK TIME = 8 HRS 15 MIN INCLUDING 1 HOUR SURFACE TIME LAB APl F.L. = 48 ML @ 170°F (REQUESTED RANGE 35 TO 55 ML) FIELD APl F.L. = 45 ML LC FL = 78 LC FC = 2.5 Gas Cons. Commission Anchorage CTU Squeeze Cont. WELL: 2-50/U-08 Page 6 SUMMARY COOLED DOWN WELL WITH 490 BBLS SW. CLOSE CHK AND PUMP 20 BBLS OF "ARCO" PREFLUSH. HOLD 1200 BP AND COVER PERFS WITH 12 BBLS CMT. WORK BP TO 2400 QAND PUMP 13 BBLS BEHIND PIPE. SD AND MIX CEMENT BATCH # 2. BJ DID NOT HAVE ENOUGH CEMENT ON LOCATION TO WEIGHT UP TO 15.8 PPG. CONFERRING WITH R. LOVELAND, THE 15.2 PPG CEMENT (FL = 77 CC) WAS PUMPED. BP BUILT TO 2900, WHILE HESITATING BP BLEED TO 2280, BP INC TO 2950 AND BROKE BACK TO 2850 AS CEMENT WAS SQZ BEHIND PIPE LEAVING 12 BBLS IN WELL BORE. A UVE REVERSE OUT PULLED 8 TO SURFACE. FINAL JET PASS FROM 14,700' TO TD AND FINAL REVERSE OUT DID NOT BRING OUT ANY MORE CEMENT, LEAVING 40 BBLS CEMENT BEHIND PIPE.S ,FLUIDS 490 20 23 4 36 4 23 4 36 140 46 256 - - 2 6 - BBLS MEOH (FREEZE PROTECTION CT) 8 BBLS MEOH (FREEZE PROTECTION WELL) 290 8 BBLS SW TO LOAD WELL BBLS PRE-FLUSH (EW W/1% S-400 SURFACTANT) BBLS CEMENT BBLS EW (SPACER) BBLS SW BBLS PRE-FLUSH OF EW BBLS CEMENT BBLS EW (SPACER) BBLS SW (DISPLACEMENT BBLS SW (REVERSE OUT) BBLS SW (JET PASS) BBLS SW (FINAL REVERSE OUT) WELL CLEANED OUT TO 15,241' BBLS LOAD FLUID BEHIND PIPE BBLS CEMENT RECOVERED (DOES NOT INCLUDE CEMENT NOT PUMPED) .CEMENT (B.J. SERVICES) 15.8 PPG CLASS "G" CMT CONTAINING 0.41% FL-33 0.1% CD-32 0.32% R-11 1.0 GAL PER SK FP-6L BATCH # 1 THICK TIME = 7 HRS 40 MIN INCLUDING I HOUR SURFACE TIME LAB APl F.L. = 76 ML @ 170°F (REQUESTED RANGE 70 TO 80 ML) FIELD APl F.L. = 76.6 ML FIELD APl FC = 1-1/16" LC FL = 54 LC FC = 1-7/8" BATCH # 2 (CEMENT WEIGHT WAS 15.2 PPG) THICK TIME = 7 HRS 40 MIN INCLUDING 1 HOUR SURFACE TIME LAB APl F.L. = 77.6 ML @ 170°F (REQUESTED RANGE 70 TO 80 ML) FIELD APl F.L. = 76 ML FIELD APl FC = 0.75" LC FL = 599LC FC = 2.75" RECEIVED MAY 20 ~994 Oil & Gas Oons. Commission Anchorage i ii i i ii i Endic°tt Production Engineering Depar, tmen, t, , , DATE: I 1-15-93 WELL N°-: 2-50/U-08 BP EXPLORATION REP: SERVICE COMPANY: Additional Perforations MCBRIDE/KIMMET AWS DATE/TIME OPERATIONS SUMMARY .... 073'0 MIRU" Post radio silence signs at the entrance to island and next to well site. Install SSV fusible cap. WHP = 250 psig. WHT = 40 deg F. lAP = 1450 . psig.,, CAP = 0psig. , Choke = 70 Beans, Pressure test lubricator to wellhead pressure. , . 081 5 ESTABLISH RADIO SILENCE ,&,ND ARM GUNS (Notify security). . . 0845 SI Well. ' ' , 0920 RIH with Gun #1 (14 feet), cci to top shot = 8'. 1105 New line thru flowtubes at 14300' and 14713'. Work thru OK. 1240 Tie in toSBT dated 7-18-93. Flag line at 15199' for next run. Log up t'hru jewel~ and locate ,TT at 14886' ELMD. '1403 Shoot gun #1 from 15108 - 15122' MDBKB No;:;hang;~ inWHP. Still360 psi~.-Log off and-POOH ........................................ .'.160'5 OOH. All shots fired. Pi~k'up Gun ¢2. cci to top shot = 9'. 1 700 RIH w/gun #2. SIP = 360, IA = 1450 CiA = 0 - 1815 Depth = 15000'. Open well to flow w/PBGL from ~'-52. 1 820 At flag. Correct counter to 15199'. Lo9 up to confirm depth control. 1 825 ' H'un9 up at 15120'. Sqz'd perf area. Drop back and try again. 1 830.. Hung again at 15128'. Pull thru w/400¢ overpull. 1 835 On depth. Position cci at 15081' FWHP = 290 FWHT = 30 IA = 1450 OA = 0. SHOOT 15090' - 15103' MD. Log off. 1 845 FWHP = 280 FWHT = 30. SHUT IN WELL AND 'POOH. 1 950 ... OOH. All shot~ fired. Rig down and release AWS. ' ' PERFORATION SUMMARY: Tied into SBT dated 18-jul-93. Tagged TD at 15190' ELMD Located T.T. at 14886' ELMD SHOT THE FOLLOWING INTERVALS: 15090' - 15103' (13') 3C5 RECEIVED M~Y 20 1994 h'~aska 0il & Gas Cons. Commission Anchorage DA TE: WELL TYPE O~ OPERATION: Additional Perforations 15108' . 15122, (14') Ail intervals Were shot using 3 3/8" 3C5 and RANDOM Orientat. Well Was left s'-.-~., ~on. Well ~;.~ guns at 6 spf, 60 ~ ,mul a temp. GL I'~ not react r~. . degree is rigged u;.~vorably durin~g RECEIVED ~tAY 20 1994 Oil & Gas Cons. Commission Anchorage Page ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 23 April 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~\~ 2-70/u-is C~.~ 3-17/~-3OA s~I , 3-27/~-33 ~-~rbq 2-0~/~-16 uPI DESCRIPTION 1 PFC/PERF FINAL BL 1 S~T/~/COL FINAL ~L 1 CN/GR FINAL BL 1 SSVD/CN/GR FINAL BL C,?/1SBT/GR/CCL RF SEPIA C~i CN/GR FINAL RF SEPIA ~ ~/~ SSVD/CN/GR RF SEPIA 1 GR/CCL JEWL.FINAL BL 1 PLS-PROF. FINAL BL GR/CCL JEWL.RF SEPIA PLS PROF. RF SEPIA 1/PLS FINAL BL ~ PLS FINAL RF SEPIA ~q~ 3-47/Q-35 SDI PFC/PERF 'FINAL BL PFC/PERF RF SEPIA 1 PLS PROF. FINAL BL 1 GR/CCL JEWL.FINAL BL ,,~.PLS PROF. RF SEPIa -"~1 GR/CCL JEWL.RF SEPIA ~'"~c'-'~O 3-35/L-36 SDI ~%~- 2-04/M-19 \ 2-04/M-19 ,_~i~LS PROF. RF sEPIA 1 PLS PROF. FINAL BL __J~PLS PROF. RF SEPIA PFC/PERF FINAL BL PFC/PERF RF SEPIA ECC No. Run # 1 6110.01 Run # 1 Run # Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run ~ 1 Run # Run # 1 Run # Run # 1 Run # 1 Run # 1 Run ~ 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run ~ 1 6185.00 6006.01 6175.00 5764.02 6034.03 5921.07 5985.04 5985.05 Cont/ 2-7o/u- 5 1PFC/PERF FINAL BL PFC/PERF RF SEPIA 1 PLS INJ. FINAL BL /~PLS INJ. RF SEPIA 1 PFC/PERF FINAL BL /1 PFC/PERF RF SEPIA · Please sign and return to: Atlas'~Wireline Services' 5600 B Street · Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: Please sign and return to: Sonya-Wallace (MB 3-3) Petrotechnical Data Center BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: Run # 1 Run # 1 6001.09 Run # 1 Run # 1 6110.02 Run # 1 Run # 1 6034.02 ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 8 April 1994 Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION /PLS INJ. FINAL BL PLS INJ. RF SEPIA ~/f PLS ~NJ. FINAL BL 1 PLS INJ. RF SEPIA /-5o/u-8 MPI 2-50/u-8 ~ -50/U-8 MPI '3-17/J-30 ~'1 PLS INJ. FINAL BL 1 PLS INJ. RF SEPIA ~CCL CEMENT FINAL BL C~"CCL CIRC. FINAL BL 1 CCL CEMENT RF SEPIA 1 CCL CIRC. RF SEPIA --w/1 GR/CCL FINAL BL 1 GR/CCL RF SEPIA ~1 SBT/GR FINAL BL 1 SBT/GR RF SEPIA d CCL TUB. FINAL BL 1 CCL TUB. RF SEPIA w~ CCL TUB. FINAL BL 1 CCL TUB. RF SEPIA ¢-43/P-26 -./1 PLS STP FINAL BL 1 PLS STP RF SEPIA Cont/ ECC No. Run ~ 1 Run ~ 1 5669.03 Run # 1 Run # 1 6145.01 Run # 1 Run ~ 1 6148.00 Run ~ 1 Run ~ 1 Run # 1 Run # 1 6001.06 Run # 1 Run # 1 6001.08 Run # 1 Run ~ 1 6001.07 Run # 1 Run # 1 6005.01 Run # 1 Run # 1 6005.02 Run # 1 Run # 1 6153.00 ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 16 March 1994 RE: Transmittal of Data ECC #: 6001.05 D at a: NONE Dear Sir/Madam, Reference: BP 2-50/U-8 MPI ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 CCL TUBING FINAL BL 1 CCL {TUBING RF_ SEPIA Sent by U.S. MAIL Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: STATE OF ALASKA ALAor~, OIL AND GAS CONSERVATION COMMIS$.,.,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing x Alter casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3218' NSL, 2317' WEL, SEC. 36, T12N, R16E At top of productive interval 4932' NSL, 2000' WEL, SEC. 34, T12N, R16E At effective depth 5039' NSL, 2235' WEL, SEC. 34, T12N, R16E At total depth 5064' NSL, 2305' WEL, SEC. 34, T12N, R16E Repair well x Other 5. Type of Well: Development .. Exploratory Stra~graphic Service 6. Datum elevation (DF or KB) KBE = 55.3' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-50/U-08 9. Permit number/approval number 93-67/94-012 10. APl number 50- 029-22367 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 15530 feet 10405' feet Plugs (measured) Effective depth: measured true vertical 15448' feet Junk (measured) 10349' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True ve~l depth BKB 94' 30" Drive 131' 131' 2829' 13-3/8" 1194 cu fl PF "E" & 2873' 2706' 460 cu ft Class "G" 15484' 9-5/8" 517 cu ft Class "G" 15528' 10404' measured true vertical 15072'- 15078', 15084'-15103', 15112'-15120', 15215'- 15245', 14798'- 14800' (squeezed) 15084'-15103', 15108'-15122' (open) 10039~10043~ 10047~10059~ 10065~10071~ 10132~10151~ 9868L9869'¢queeze~ 10031~10105~ 10109L10119'(open) Tubing (size, grade, and measured depth) 4-1/2", L-80 tubing to 14900' MD Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 9-5/8" Baker SABL-3 packer @ 14836'MD; Baker DB packer @ 14678' MD;4-1/2" Otis 9cr SVLN @ 1457' MD RECEIV U Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well ~perations x 17. I hereby certify th~r~is true/~_ nd Form 10-404 Rev 06/15/88 16. Status of well classification as: Oil x Gas Suspended correct to the best of my knowledge. Title Drilling Engineer Supervisor Service BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: 2-50/U-08 BOROUGH: NORTH SLOPE UNIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 02/02/94 01:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 15 WO/C RIG: DOYON 15 05/20/93 (1) TD: 1230' ( 0) 05/21/93 ( 2) TD: 2890' (1660) 05/22/93 ( 3) TD: 2890' ( 0) 05/23/93 ( 4) TD: 2890' ( 0) 05/24/93 (5) TD: 4750' (1860) 05/25/93 (6) TD: 6100'(1350) 05/26/93 (7) TD: 7240' (1140) 05/27/93 (8) TD: 8767' (1527) DRLG 16" HOLE MW: 8.7 VIS:165 RIG UP CUTTINGS WASHER & BAGGER UNIT. ACFEPT RIG @ 0600 HOURS 05/19/93. NIPPLE UP RISER. PICK UP-STRAP & ORIENT BHA. FUNCTION TEST DIVERTER SYSTEM. DRLG. 16" HOLE FROM 110 TO 380' POH INTO CONDUCTOR PIPE. WO SPERRY SUN TOOLS. RIH GYRO @ 380. DRLG & SURVEYS TO 1230' POH TO RUN 13 3/8" CSG MW: 9.4 VIS:108 WIPER TRIP @1230. DRLG & GYRO F/ 1230 - 2520. MOTOR QUIT. POH--CHANGE BHA--RUN. CUT DRLG LINE. FINISH RIH. DRLG & SURVEYS F/ 2520 TO 2890. 5 STAND WIPER TRIP. CBU. POH TO RUN 13 3/8" CSG. INSTALL WEAR BUSHING MW: 9.5 VIS: 78 POH, LD STABS. RU & RUN 13-3/8 CASG. HOOK UP CMT HEAD, CBU HOLE CLEAN. CMT CASG. B/O LNDG JT, RD CSG TOOLS. LD JT, ND, NU BOPE. TEST BOPE. INSTL WEAR BUSHING. DRLG CMT MW: 9.3 VIS: 56 RD DRAW-WORKS GUARDS & MISC. PULL INPUT SHAFT. PULL OUTER & INNER SPROCKETS. CHG INNER SPROCKET & INSTL SAME. RU EQUIP & GUARDS. PU BHA. RIH, TAG CMT. TEST CASG. DRLG CMT & PLUGS. DRLG 12.25" HOLE MW: 9.3 VIS: 51 DRLG CMT & SHOE. CIRC HOLE CLEAN. LO TEST. DRLG & SURV. CBU, WIPER TRIP TO SHOE & BACK TO BTTM. DRLG TO 4750. DRLG. MW: 9.5 VIS: 46 CBU. WIPER TRIP. DRLG TO 5027'. POOH. CHANGE BIT, BHA. RIH. DRLG TO 6100'. DRLG. MW: 9.7 VIS: 53 DRLG TO 6135'. CBU. SHORT TRIP TO 5027' DRLG TO 6685' CIRC. POOH. CHANGE BIT, BHA. RIH. DRLG TO 7240' CIRC. MW: 9.8 VIS: 49 DRLG TO 7622' SHORT TRIP 11 STDS. DRLG TO 8767' CIRC. 05/28/93 (9) TD: 9624' ( 857) DRLG. MW: 9.7 VIS: 44 CIRC. POOH. CHANGE BIT, BHA. RIH. DRLG TO 9624' RECEIVED WELL : 2-50/U-0 OPERATION: RIG : DOYON 15 PAGE: 2 05/29/93 (10) TD:10381' ( 757) 05/30/93 (11) TD:10760' ( 379) CIRC. MW: 9.7 VIS: 47 DRLG TO 9719' CIRC. SHORT TRIP TO 8767' DRLG TO 10381' CIRC. DRLG. MW: 9.8 VIS: 45 CIRC. POOH. TEST BOPE. RIH. DRLG TO 10760'. 05/31/93 (12) TD:lll60' ( 400) DRLG. MW: 9.8 VIS: 52 DRLG TO 11015'. POOH. CHANGE BHA. RIH. DRLG TO 11160' 06/01/93 (13) TD:12408' (1248) SHORT TRIP. DRLG TO 12408' CIRC. SHORT TRIP. MW:10.0 VIS: 49 06/02/93 (14) TD:12615' ( 207) 06/03/93 (15) TD:13120' ( 505) DRLG. MW: 9.9 VIS: 48 DRLG TO 12600' CBU. POOH. CHANGE BIT. RIH. DRLG TO 12615'. DRILLING DRILLING TO 13120' MW: 9.8 VIS: 52 06/04/93 (16) TD:13228' ( 108) 06/05/93 (17) TD:13750' ( 522) DRILLING MW:10.2 VIS: 52 DRILG TO 13123', POH, SERVICE WEAR BUSHING, CHG BHA, RIH TO CSG SHOE & TEST MWD, REPLACE GLYCOL HEAT EXCHANGER IN TOP DRIVE COOLING UNIT, RIH TO 2 STDS OFF BTM, REAM TO BTM, DRLG IN TUFFS, VERY HIGH TORQUE & DRAG DRLG. DRLG TO 13750'. MW:10.3 VIS: 52 06/06/93 (18) TD:13965' ( 215) 06/07/93 (19) TD:14008' ( 43) 06/08/93 (20) TD:14084' ( 76) STRING BLOCKS. MW:10.3 VIS: 51 DRLG TO 13965'. BACKREAM THRU HRZ. CIRC. POOH TO SHOE. RESTRING BLOCKS. DRLG. MW:10.3 VIS: 54 RESTRING BLOCKS. POOH. TEST BOPE. CHANGE BHA. RIH. REAM THRU HRS, TUFFS. DRLG TO 14008' RIH. DRLG TO 14098' MW:10.2 VIS: 56 POOH. CHANGE BIT. RIH. 06/09/93 (21) TD:14165' ( 81) TRIP OUT FOR PDC BIT MW:10.5 VIS: 53 TRIP IN TO 13744' (TIGHT), WASH & REAM 13744'-14084', DRLG TO 14125', SHORT TRIP TO 13345', TRIP IN, WASH & REAM 10' OF FILL, DRLG TO 14165', TRIP OUT FOR PDC BIT WELL : 2-50/U-0 OPERATION: RIG : DOYON 15 PAGE: 3 06/10/93 (22) TD:14216' ( 51) 06/11/93 (23) TD: 14216' ( 0) 06/12/93 (24) TD:14279'( 63) 06/13/93 (25) TD:14315'( 36) 06/14/93 (26) TD:14420' ( 105) TRIP OUT FOR BIT MW:10.5 VIS: 55 TRIP OUT, CHG BHA, SERVICE RIG, TRIP IN, TEST MWD, TRIP IN TO 14165', WASH & WORK PIPE @ BTM TO PICK UP BIT JUNK IN BASKET, DRLG TO 14216', TRIP OUT FOR PDC BIT TRIP OUT FOR BIT MW:10.5 VIS: 48. TRIP OUT, P/U PDC BIT, TRIP IN, TEST MWD, WASH & REAM TO BTM, P/U KELLY, DRILL & WORK BIT, DRLG TO 14228', CHG OUT SWAB #2 MUD PUMP, DRLG (MAKING NO HOLE), TRIP OUT FOR BIT F/14228' DRLG. MW:10.5 VIS: 47 POOH. CHANGE BIT. RIH. REAM TO BTM. DRLG F/ 14228'-14279'. DRLG. DRLG TO 14311' 14311'-14315'. MW:10.5 VIS: 66 POOH. CHANGE BIT, MWD. RIH. DRLG F/ DRLG. DRLG F/ 14315'-14420'. MW:10.4 VIS: 50 06/15/93 (27) TD:14480' ( 60) POOH. DRLG TO 14480'. POOH. MW:10.4 VIS: 52 06/16/93 (28) TD: 14529' ( 49) 06/17/93 (29) TD:14550' ( 21) 06/18/93 (30) TD:14686' ( 136) 06/19/93 (31) TD:14772' ( 86) DRLG. MW:10.4 VIS: 51 POOH. TEST BOPE. CHANGE BHA. RIH. WASH TO BTM. DRLG TO 14529'. TRIP FOR BIT MW:10.4 VIS: 47 DRLG 14529 - 14542' REPAIR BROKEN ROTARY CHAIN. DRLG 14542 - 14550'. DROP SURVEY. TRIP OUT FOR NEW BIT. RETRIEVE SURVEY. CHANGE OUT BIT & REPLACE SLEEVE ON NB STAB. DRLG 12-1/4" HOLE MW:10.4 VIS: 45 TRIP IN TO 14490', REAM TO BTM (NO FILL), DRLG F/14550'-14569', SERV RIG, DRLG F/14569'-14686' P/U BIT. MW:10.4 VIS: 50 DRLG TO 14772'. CIRC. POOH. P/U BIT. 06/20/93 (32) TD:14859' ( 87) DRLG. RIH. CIRC. DRLG F/ 14772'-14859'. MW:10.4 VIS: 49 06/21/93 (33) TD:14928' ( 69) CHANGE BHA. DRLG F/ 14859'-14928' MW:10.4 VIS: 50 CBU. POOH. CHANGE BHA. RECEIVED MAR 2 4 ]994 /~aska Uil & Gas Cons. Commission Anchorage WELL : 2-50/U-0 OPERATION: RIG : DOYON 15 PAGE: 4 06/22/93 (34) TD:15000' ( 72) DRILLING AHEAD MW:10.4 VIS: 58 PU LWD TOOL. TRIP IN, WASH & REAM. DRLG TO 15000. 06/23/93 (35) TD:15120' ( 120) CIRC BEFORE TRIPPING DRLG TO 15120' MW:10.4 VIS: 54 06/24/93 (36) TD:15123' ( 3) 06/25/93 (37) TD:15270' ( 147) 06/26/93 (38) TD: 15294' ( 24) 06/27/93 (39) TD:15440' ( 146) DRILLING MW:10.5 VIS: 72 DROP SINGLE SHOT SURVEY; SHOWS ARE DROPPING @ 1.3/100FT. POOH. RETRIEVE SURVEY, SERVICE RIG & CHANGE OUT KELLY HOSE. FINISH POOH & BREAK BIT. WORKED TO RETRIEVE DATA OUT OF SPERRY SUN LWD TOOL & CUT SLEEVE OFF OF NB STAB. PULL WEAR BUSHING, TEST BOP'S, PULL WEAR BUSHING. P/U BHA, RIH TO HWDP. INSTALL NEW KELLY HOSE & CUT DRILLING LINE. RIH TO 15000. LWD 15000 - 15114. DRILLING. POOH FOR NEW BIT MW:10.4 VIS: 51 DRILLING 15123 - 15187 IN SHALES WITH INTERMITTENT SANDS. HIGH TORQUE BROKE ROTARY CHAIN; REPAIRED. DRILLIN TO 15270. CIRC AND MIX PILL. DROP SINGLE SHOT SURVEY. POOH. DRLG. MW:10.4 VIS: 56 POOH. CHANGE BIT. RIH. MAD RUN F/ 15000'-15270' DRLG TO 15294' DRLG. DRLG F/ 15294'-15440' MW:10.3 VIS: 53 06/28/93 (40) TD:15450' ( 10) 06/29/93 (41) TD:15530' ( 80) 06/30/93 (42) TD:15530' ( 0) REAM TO BTM. DRLG F/ 15440'-15450' REAM TO BTM. MW:10.5 VIS: 80 CIRC. POOH. CHANGE BIT. RIH. SHORT TRIPPING FOR CASING MW:10.3 VIS: 47 REAM PREVIOUS BIT RUN TO 15450' DRILLING TO TD @15530'. MINOR COAL STREAKS IN MIDDLE OF SHALE SEQUENCE. CBU. SHORT TRIPPING PAST TOP OF TUFFS. JARRING STUCK PIPE MW:10.4 VIS: 57 SHORT TRIP TO 12700', CIRC & COND FLUID FOR CSG, POH FOR CSG, PULLED TIGHT ON STAND #48, CONNECTED TOP DRIVE & WORKED PIPE, COULD NOT WORK PAST TIGHT SPOT, TOP OF JARS @ 10950', WORKED UPWARDS ATTEMPTING TO BACKREAM, WORKED COMBINATION OF TORQUE & PUMP PRESS. THAT GOT JARS FIRING, NO MOVEMENT EITHER WAY, NO ROTATION POSSIBLE, SPOTTED 50 BBLS 10.3 SFT, JARRING STUCK PIPE, W/L TOOLS ARRIVING LOCATION RECEIVE[) ~ i! WELL ' 2-50/U-0 OPERATION: RIG : DOYON 15 PAGE: 5 07/01/93 (43) TD:15530' ( 0) 07/02/93 (44) TD:15530' ( 0) 07/03/93 (45) TD:15530' ( 0) 07/04/93 (46) TD:15530' ( 0) 07/05/93 (47) TD:15530' ( 0) 07/06/93 (48) TD:15530' ( 0) 07/07/93 (49) TD:15530' ( 0) 07/08/93 (50) TD:15530' ( 0) P/U FISHING TOOLS MW:10.3 VIS: 48 JARRING ON SP DOWNWARD ABOUT 65% OF THE TIME, COULD NOT ESTABLISH MOVEMENT, R/U TO RUN FREEPOINT AND BACKOFF TOOLS, RUN FREEPOINT - INCONSISTENT READINGS, CHG TOOL, STRING STUCK IN LOWER PART OF DRLG JARS, TOP OF JARS @ 10979', R/U STRINGSHOT & RIH, BACKED OFFF HWDP @ 10949', POH, FISH LEFT IN HOLE, P/U DC'S & SFJ W/REST OF FISHING TOOLS POH TO CHG ASSEMB. MW:10.3 VIS: 48 P/U FISHING ASSEMB & RIH, CUT 60' DRLG LINE, RIH TO TOF @ 10949', HAD TO REAM THRU TIGHT SPOT @ 8032', FISHING, RIH TO 11478' BACK REAM, CBU, RIH TO 15300' HOLE VERY TIGHT, CIRC & COND MUD, FISHING, WASHED DOWN TO 15420', POH TO L/D SOME DC'S, PLAN TO P/U OVERSHOT RUN FREEPOINT. MW:10.4 VIS: 53 POOH. L/D SCREW IN SUB. RIH W/ HOLE OPENER. TAG @ 11006'. POOH. R/U ATLAS. RIH W/ FREEPOINT. JAR FISH. MW:10.3 VIS: 56 RIH W/ FREEPOINT. FREE @ 7500'. RUN 3 STRING SHOTS @ 7498' 3RD OK. POOH. RIH W/ JAR ASS'Y. TAG FISH @ 7498' CIRC. ENGAGE FISH. JAR FISH. WASH OVER FISH. MW:10.3 VIS: 50 JAR FISH. NO MOVEMENT. SPOT 50 BBLS SFT. R/U ATLAS. RUN FREEPOINT. FISH ASS'Y STUCK AS WELL AS PIPE. RIH W/ STRING SHOT. FREE JARS. POOH. RIH W/ WASHPIPE. TAG TOF @ 7467' WASH OVER FISH. RIH. MW:10.6 VIS: 60 WASH OVER FISH. POOH. RIH. ATTEMPT TO WASH OVER FISH. APPEAR TO BE GOING BESIDE FISH. POOH. RIH W/ SCREW IN ASS'Y. CBU @ 10669' MW:10.6 VIS: 55 RIH W/PIN TAP J-JT ASSY TO 2000' CUT DRLG LINE, RIH TO , 7457', CIRC, POH, P/U WASH PIPE, RIH TO 7382', WASH OVER FISH (200') FISH FREE FELL TO BTM, RIH TO 10719' POH, L/D WASH PIPE, P/U OVERSHOT, RIH, CBU, COND HOLE @ 1~669' L/D FISHING TOOLS MW:10.6 VIS: 60' CIRC & COND MUD, WASH DOWN TO 10718', TRIP OUT W/OVERSHOT, RECOVERED J-JT, HWDP, PIN TAP, P/U NEW OVERSHOT, TRIP IN TO 10605', WASH DOWN TO FISH TAG @ 10882', LATCH ON TO FISH AND JAR ON FISH @ 400 K, PULL UP TO 550K, WORKED PAST FISH #1, TRIP OUT, L/D FISH %2, L/D WASH PIPE & FISHING TOOLS RECEIVED MAR 2 4. 1994 IJll & Gas Col'is. Commission Anchorage WELL : 2-50/U-0 OPERATION: RIG : DOYON 15 PAGE: 6 07/09/93 (51) TD:15530' ( 0) 07/10/93 (52) TD:15530' ( 0) 07/11/93 (53) TD:15530' ( 0) 07/12/93 (54) TD:15530' ( 0) 07/13/93 (55) TD:15530' ( 0) 07/14/93 (56) TD:15530' ( 0) 07/15/93 (57) TD:15530' ( 0) 07/16/93 (58) TD:15530' ( 0) 07/17/93 (59) TD:15530' ( 0) TRIP ON W/ WASH PIPE MW:10.6 VIS: 56 LAY DOWN AT TOOLS FROM DERRICK. CHANGE OUT DRLG LINE SPOOL. P/U 8 1/2" BIT & SLICK BHA, TRIP IN. WASH TO TOP OF FISH @10960' CIRC & COND HOLE FLUID. TRIP OUT. PULL WEAR RING. TEST BOPE. INSTALL WEAR RING. P/U WASH PIPE BHA. TRIP IN (SLM). WASHING SOWN TO FISH. POOH. MW:10.6 VIS: 63 JAR ON FISH @ 10960'. POOH. RIH W/ SCREW IN ASS'Y. LATCH FISH @ 10960' JAR. FISH FREE. POOH. RIH W/ OVERSHOT. CIRC OVER FISH. NO LATCH UP. POOH. POOH. MW:10.5 VIS: 58 POOH. RIH W/ OVERSHOT. LATCH FISH @ 10990'. JAR. FISH FREE. PULL TO 10900' JAR. BROKE GRAPPLE. FISH FELL DOWN HOLE. RIH TO 11~07'. POOH. RIH W/ HOLE OPENER. WASH & REAM F/ 10700'-11072' POOH. REAM. MW:10.6 VIS: 53 POOH. RIH W/ SCREW IN ASS'Y. LATCH FISH @ 11348' JAR & WORK TO 11060'. POOH. L/D FISH & FISH ASS'Y. RIH. WASH & REAM F/ 10700'-11164' TRIP OUT FOR HOLE OPERNER MW:10.5 VIS: 50 WASH & REAM 11164 TO 11353' SHORT TRIP TO 10700' WASH & REAM 11357 TO 12833' SHORT TRIP TO 11340'. WASH & REAM TO 14066'. TRIP OUT FOR HOLE OPENER. WASH & REAM MW:10.6 VIS: 55 TRIP OUT L/D HOLE OPENER. PULL WEAR RING, INSTALL TEST PLUG. CHANGE BLIND RAMS TO SHEAR RAMS. TEST BOPE. PULL TEST PLUG, INSTALL WEAR RING. CUT DRLG LINE. M/U BULL NOSE ON 12 1/4" HOLE OPENER. TRIP IN W/ H.O. (SLM). WASH & REAM TO 13963' WASH & REAM MW:10.6 VIS: 55 WASH & REAM 13963 TO 14365. SHORT TRIP 14365 TO 13963. WASH & REAM 14365 TO 14826. SHORT TRIP 14826 TO 14365. WASH & REAM 14365 - 15375. RUN 9 5/8" CASING MW:10.6 VIS: 57 WASH & REAM 15375 - 15530' = TD. SHORT TRIP TO 13905' CIRC VIS SWEEPS & CONDITION HOLE FLUID. TRIP OUT. L2D HOLE OPENER BHA. PULL WEAR RING. CHANGE RAMS. R/U TO RUN 9 5/8" CASING. TRIP IN W/ 9 5/8" CASONG. N/U BOPE MW:10.6 VIS: 58 CONT. TRIP IN W/9-5/8" CSG, WASH LAST JT TO TD @ 15530', PUMP 92 BBL CLASS G CMT, DISPLACE R/D CMT TOOLS, N/D BOPE, SET 9-5/8" EMERG. SLIPS, CUT CSG, INSTALL PACKOFF, L/D LNDG JT & CUT OFF STUB, N/U BOPE, TEST PACKOFF TO 3000 PSI Anchorage WELL : 2-50/U-0 OPERATION: RIG : DOYON 15 PAGE: 7 07/18/93 (60) TD:15530' ( 0) 07/19/93 (61) TD:15530' ( 0) 07/20/93 (62) TD:15530' ( 0) 07/21/93 (63) TD:15530' ( 0) 07/22/93 (64) TD:15530 PB: 0 07/23/93 (65) TD:15530 PB: 0 07/24/93 (66) TD:15530 PB: 0 MW:10.4 VIS: 50 N/U BOPE, CHG RAMS, TEST BOPE & INSTALL WEAR RING, CUT DRLG LINE, TRIP IN W/8-1/2" BIT, TAG CMT @ 15138', DRLG OUT CMT TO 15446', TEST CSG TO 3500 PSI, DRLG OUT FC + 40' CMT TO 15486', TEST CSG TO 3500 PSI, CIRC HI VIS SWEEP, TRIP OUT, R/U ATLAS W/L FOR CBL NOTE: EST. FINAL COST $4,650M CIRC, CHG OVER TO BRINE MW:10.4 VIS: 54 RAN CBL, TRIP IN W/8-1/2" BIT & 9-5/8" SCRAPER TO 15486', REV CIRC, HI VIS SWEEP SPACERS, 1100 BBLS BRINE NOTE: EST. FINAL COST $4,650M TRIP IN W/PERF GUNS MW:10.4 VIS: 0 CLEAN PITS, DISPLACE MUD W/BRINE, TRIP OUT L/D BHA, P/U PERF GUNS W/BAKER PKR, CUT DRILG LINE, TRIP IN W/PERF GUN ASSEMB. EFC AHS BEEN RAISED TO 4650M DUE TO STUCK PIPE INCIDENT. POH LDDP MW: 9.2 VIS: 0 RIH W/PERF GUNS, RUN GR/CCL TO POSITION PERF GUNS, R/U & SET RETRIEV-A-MATIC, DISPLACE BRIN, PRESS UP ANNULUS TO 1500 PSI & PERF WELL, KILL WELL BU REV. IN 3 DP VOL. OF 9.2 BRINE, CLEAR FLOOR, POH LDDP LANDED TUBING MW: 8.5 Seawater POH L/D DRILLPIPE. L/D PERF GUNS & RETRIEV-A-MATIC. ALL SHOTS FIRED ON GUNS. PULL WEAR BUSHING & R/U TO RUN TUBING. RUN 4-1/2" TBG. FILTER & INHIBIT 9.2 PPG-BRINE. R/D CIRC JOINT @ INSTALLED 2-WAY CHECK VALVE. M/U LANDING JOINT & LOWERED TBG HANGER INTO PLACE. RELEASED RIG MW: 8.5 Seawater LAND TUBING & RILDS. L/D LANDING JOINT & CLEAR RIG FLOOR. N/D BOP'S. N/U ADAPTER FLANGE, TREE & CONTROL LINES. TEST COMPONENTS TO 5000 PSI. COULD NOT GET TREE TO TEST INITIALLY; ACTUATOR VALVE WAS STUCK PARTIALLY OPEN. EVENTUALLY CLOSED & TESTED. R/U LUBRICATOR; PULL 2-WAY CHECK VALVE. R/D LUBRICATOR. PRESSURED UP DOWN TUBING TO SET PACKER. INSTALL BPV. SECURE WELLHEAD & CLEAN PITS OF DIRTY BRINE WHILE W.O. FUEL TRUCK TO PULL DIESEL OFF RIG TO LIGHTEN UP FOR RIG MOVE. RIG RELEASE @2200 HRS. 07/22/93 MW: 8.5 Seawater Oil & Gas Cons. Commissioc' Anchorage WELL : 2-50/U-0 OPERATION: RIG : DOYON 15 PAGE: 8 02/01/94 (67) TD:15530 PB:15448 02/02/94 (68) TD:15530' ( 02/03/94 (69) TD:15530' ( 02/04/94 (70) TD:15530 PB:15448 02/05/94 (71) TD:15530 PB:15448 02/06/94 (72) TD:15530 PB:15448 o) o) RIG ON STANDBY MW: 8.5 Seawater RIG IS ON STANDBY FROM 08:00 TO 06:00 HRS. WHILE COIL TUBING UNIT PREPARES THE WELL FOR WORKOVER. RIG CREW ON PREVENTATIVE MAINTENANCE - COMPLETE OVERHAUL OF MUD PUMP NO. 2 AND OVERHAUL OF TOP DRIVE. R/U TO KILL WELL PRESSURE MW: 0.0 VIS: 0 DOING PREVENTATIVE MAINTENANCE WORK WHILE ON STANDBY. APC DE-COMMISSIONED AND SAFED OUT WELL. MOVE RIG ON WELL. RIG OFF OF STANDY AND ACCEPTED AT 01:00 HOURS ON 2/2/94. COMMISSIONED EMERGENCY SHUT DOWN SYSTEM. FILL RIG PITS W/SEAWATER AND R/U CIRCULATING LINES TO TREE. TESTING THE BOP'S MW: 8.7 VIS: 0 R/U & CIRC SEAH20. PULL BPV. CHECK FLOW; ANNULUS FLOWING. CONTINUE TO KILL THE WELL. WELL STATIC FOR 30 MIN.; INSTALL TWC. N/D TREE AND ADAPTER FLANGE / NU RISER SECTIONS AND BOP STACK. TEST BOP AND SURF EQUIP. TEST WAIVED BY AOGCC REP: DOUG AMOS. GAS COLLECTING AT SURFACE ON ANNULUS SIDE - BLEEDING OFF PERIODICALLY. POOH W/ DP MW: 9.0 NaC1/Br INSTALL 4.5" PIPE RAMS AND TEST W/ LNDG JT TO 250/5000PSI. BLED DOWN ANNULUS AND PULLED TWC. MU LNDG JT AND PULL TBG HANGER TO FLOOR. CIRC BRINE. CIRC OUT RESIDUAL GAS AFTER WEIGHING UP BRINE TO 9 PPG. NORMAL LOSS TREND OBSERVED. LD HANGER AND PULL 4.5" TDS TBG TO SSSV. HOLE FILL NORMAL LOSS TREND ZERO. PU 5" DP AND RIG TO 8' ABOVE CUT. CIRC. POOH W/ DP AND RESUME PULLING AND LAYING DOWN 4.5"TBG. RIH W/ 5" DP MW: 9.3 NaCl/Br POOH W/5" DP. POOH W/4.5" PRODUCTION TUBING. TUBOSCOPE INSPECTOR SET ASIDE 6 OUT OF 367 TOTAL JTS AFTER DETECTING GALLING ON BOXES. MAX OD OF CUT JT = 5.25" INSTALL AND TEST 5" PIPE RAMS. INSTALL WEAR RING. P/U BHA AND RIH PICKING UP 5" DP. CBU MW: 9.3 NaCl/Br RIH W/ 5" DP TO 14796'. WORK OVER TOF. CBU - NO GAS. POOH W/FISH. RETRIEVED 1 CUTOFF JOINT, 1 PUP JT AND LATCH ASSBY. CHANGE BHA AND RIH TO MILL PACKER. CUT DL. MILLING ON PACKER BEGINNING AT 14821. MILL APPROX 2.5'. PACKER CUT LOOSE. PUSHED TO 15111. CBU -HIGH GAS RETURNS AT 05:00. CLOSED IN WELL AND CIRC THROUGH WIDE OPEN CHOKE. Anchorage WELL : 2-50/U-0 OPERATION: RIG : DOYON 15 PAGE: 9 02/07/94 (73) TD:15530 PB:15448 02/08/94 (74) TD:15530 PB:15448 02/09/94 (75) TD:15530 PB:15448 02/10/94 (76) TD:15530 PB:15448 02/11/94 (77) TD:15530 PB:15448 RIH W/ PACKER SPEAR MW: 9.3 NaC1/Br CBU WORK GAS OUT OF SYSTEM. POOH W/ MILL AND PU PACKER SPEAR BHA. CHANGE FLOWLINE RUBBERS AND RIH. FISH PACKER AND TAILPIPE ASSBY. POOH W/PACKER. DROP BAR AND SHEAR OUT PUMP-OUT SUB. POOH - NO FISH RECOVERED. CUT DL. CHANGE GRAPPLE, P/U SPEAR EXTENSION, RE-PIN PUMP OUT SUB AND RIH. RIGGING UP E-LINE MW: 9.3 NaC1/Br RIH T/15111. W/O FISH. POOH RECOVER ALL OF FISH. L/D FISH AND BHA. M/U C/O ASSBY AND RIH. TAG CMT @15115'. DRILL FIRM CMT T/15125. CBU UNTIL CLEAN. POOH R/U ATLAS TO RUN GAUGE RING AND SET EZ-DRILL RETAINER. TIH T/CMT RETAINER. MW: 9.3 NaC1/Br RUN CCL/GR/JB TO 12125'. POOH. WHILE ON TRIP, TOOLS P/O OF ROPE SOCKET. OVER SHOT ON E/LINE AND RECOVERED FISH. TIH W/EZSV ON E/LINE. SET AT 15040. TIH GUNS AND SHOOT SQZ PERFS F/14798 T/14800. NO CHANGE IN FLOW. ADJUST BRAKES AND SERV. RIG. TIH T/2000 W/EZSV STINGER ON 5" DP. SLIP AND CUT 60' DL. TIH T/14798. CIRC. AT PERFS. TIH TO EZSV AT 15040. CIRC. ACID F/HOLE MW: 9.3 NaCl/Br CBU ON TOP OF EZSV. PRESS TEST TO 750PSI. BLEED OFF. CIRC. POSSIBLE PLUGGED STINGER, ABORT ACID JOB. SLOW CIRC 10BPM @ 1300PSI. 70 BBLS SPOT ACID DOWN DP. PUMP THRU PERFS. CIRC. ACID OUT AT 2.5 BPM AT 1000PSI. SPOT 2500 GAL ACID DOWN DP. PUMP THRU PERFS. CIRC AT 5.5 BPM AT 1400PSI. STABLE CIRC AT 5.5 BPM AND 1250 PSI. LOSS AT .75 BPM. CONTINUE CIRCULATION AT STABLE RATE. TESTING THE BOP'S MW: 9.3 NaC1/Br CON'T CIRC THRU RETAINER. 5.5BPM @1200PSI INCREASING T/1500PSI. AVRG. FL. LOSS=30BPH. CIRC 20 BBLS XANVIS AT 5.5BPM @1625PSI. FL. LOSS=45BPH. CON'T W/SQUEEZE OPERATION. BUMPED PLUG CATCHER W/41 BBLS BELOW EZSV AND 34 BBL IN DP. POOH W. A SINGLE AND 15 STDS. CIRC AT 8 BPM AT 900PSI. HOLD 500PSI ON SQUEEZE. POOH, PULL WEAR BUSHING. RU AND TEST BOP'S RECEIVED .,.,.~,~(~ u~t & (las Cons, CommJggior~ Anchorage WELL ' 2-50/U-0 OPERATION: RIG : DOYON 15 PAGE: 10 02/12/94 (78) TD:15530 PB:15448 02/13/94 (79) TD:15530 PB:15448 02/14/94 (80) TD:15530 PB:15448 CBU. PREP. T/TEST SQZ PERFS MW: 9.3 NaC1/Br FINISH TESTING BOPE. INSTALL WEAR RING. MU 8.5" MILL AND BHA. TIH W/SAME. REPAIR RIG, REMOVE DRAWWORKS GUARDS. REPLACE BRAKE DRUM COOLING PLUMBING. CONT. TIH. TAG CMT AT 14670.8'. ARRANGE DP TO DRILL CMT. LD DP. DRIL CMT F/14670 T/15067. CBU. TESTING PERFS MW: 9.3 NaCl/Br TESTED SQZ PERFS AND CSNG TO 750 PSI. PUMPED HIGH VIS SWEEPS. COULD NOT DRILL EZSV. CIRC POH W/MILL. MILL HAD A 4" DIAMETER WEAR CIRCLE. LD MILL. SERVICE RIG. MU 8.5" BIT AND BOOT BASKETS. TIH T/4612. CUT DL. TIH TO 15070. DRILL UP EZSV AND CO TO PBD OF 15448. HARD CMT TO 15135, STRINGERS 14245 T/15286. CIRC HOLE CLEAN W/HIGH VIS SWEEP. MW: 9.3 NaCl/Br 02/14/94 (81) TD:15530 PB:15448 02/15/94 (82) TD:15530 PB:15448 02/16/94 (83) TD:15530 PB:15448 PREP. TO SWAP OUT FLUID MW: 9.3 NaCl/Br TESTED CSG AND SQZ'D PERFS. TO 750 PSI. OK. PUMP DRY JOB AND POOH. C/O JUNK BASKETS AND CLEAR FLOOR. RU ATLAS TIH W. CBL/SBT. T/13000. LOST SIGNAL POOH. RUN CBL/GR/SBT F/13445 T/14400. CLEAN GENERATOR FILTERS OF SNOW. TIH W/BIT AND SCRAPER. CIRC SWEEP TO CIN HOLE BEFORE CHANGING TO CLEAN BRINE TIH W/ PACKER ASSEMBLY MW: 8.5 Seawater CIRC HI-VIS SWEEP. CIRC HOLE CLEAN. SUCK DOWN PITS. RU TRUCKS FOR DISPLACEMENT W/9.3 PPF BRINE W/ SEAWATER. POOH W/5" DP. SERVICE RIG. LD BHA. CLEAR FLOOR. RU TBG TONGS. MU PACKER ASSEMBLY: TAIL PIPE ASMBLY, SABL-3 PKR., 3 JTS. TBG. DB PACKER AND RUNNING TOOL. RUN PACKER ASSEMBLY ON 5" DP. RU TO RUN TBG. MW: 8.5 Seawater TIH W/PCKR ASSY. RU ATLAS. RUN GR/CCL. MADE TIE-IN RUN. SET PKRS. TEST ANNULUS TO 3500PSI FOR 5MIN. RELEASE SETTING TOOL. POOH LD 5" DP. CUT DL. SERVICE RIG. POOH LD DP, SETTING TOOL. CHANGE RAMS, PULL WEAR BUSHINGS AND BONNET TEST THE STACK. RU TO RUN TBG. RECEIVED MAR 2 4. 1994 Uil & Gas Cons. Commission Anchorage WELL : 2-50/U-0 OPERATION: RIG : DOYON 15 PAGE: 11 02/17/94 (84) TD:15530 PB:15448 02/18/94 (85) TD:15530 PB:15448 CAMCO SLICK LINE WORK MW: 8.5 Seawater MU BAKER GBH-22S LOCATER AND SEAL ASSY. TIH ON 4.5" L-80 TDS TBG. MU BALL VALVE AND CONTROL LINE, TEST AT 5000PSI, CONTINUE TO RUN 4.5" TBG. SPACE OUT, MU HANGER AND CONTROL LINES, TEST TO 5000PSI. CIRC AROUND COREXIT AT 4 BPM. LAND TBG, RILDS, ATTEMPT TO PRESSURE TEST TBG TO 3500PSI. BLED TO 1500PSI. NO ANNULUS RETURNS. TEST BACKSIDE TO 3500PSI 30 MIN. TEST GOOD. RU CAMCO SLICL LINE UNIT AND LUBRICATOR TO PULL DUMMY. RIG MOVING MW: 8.5 Seawater PULL DUMMY SAFETY VALVE, RHC PRONG, SET PLUG IN "X" NIPPLE, REPLACE DUMMY VALVE AND RD CAMCO AND LUBRICATOR. MU LANDING JT AND TEST TBG TO 3500PSI OK. B/O LNDG. JT AND INSTALL 2-WAY CHECK. ND BOP'S NU TREE AND ADAPTER, TEST TREE AT 5000PSI. PULL BPV , SHEAR OUT, DISPLACE W/DIESEL AND U-TUBE, SET BPV, SECURE TREE AND WELL HOUSE, CLEAN PITS.AOGCC REP L. GRIMALDI WAIVED TEST. RIG RELEASED FROM 2-50/U-08 AT 05:00 HOURS ON 2/18/94. SIGNATURE: (drilling superintendent) DATE: RECEIVED MAtR .2_ 4. '1994 oil & Gas Cons. Commisslor: Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 11 January 1994 RE: Transmittal of Data ECC #: 6114.01 D at a: FMT Dear Sir/Madam, Reference: /BP ~ ~0-~ /2-24/M-12 MPI ~~ f ENDICOTT / NORTH SLOPE, AK 1 kF~T/GR FINAL BL / Sent by U.S. MAIL Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services Received by: Date: Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson / ~ 11 BP EXPLORATION Attn. PETROTECHNICAL DATA CENTER DAVID W. DOUGLAS: MB 3-3 900 EAST BENSON BOULEVARD ANCHORAGE AK, 99508. Date: 16 December 1993 RE: Transmittal of Data ECC ~: 6001.04 Data: PDK-PORO Dear Sir/Madam, Reference: BP 2-50/U-8 MPI 0~ ~ ENDICOTT [~' I NORTH SLOPE, AK Enclosed, please find the data as described ~elow: Prints/Films: 1 PDK/GR FINAL FILM Run ~ 1 2 PDK/G~ FINAL BL Run ~ 1 Sent by HAND-DELIVER Received by: Date: Please sign and return to: Atlas Wireline Services Petrophysical Services _ 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson /' U Wost~rn Atlas International ATLAS WIRELINE SERVICES Subject: Re-distribution of Final Prints for 2-50 / U-08 PDK-100/GR & PFC/CCL From: R. Paulson To: Endicott Log Distribution Recipients Date: 5 January 1994 It was determined after final prints had been distributed that the PDK-100 and PFC/CCL logs (dated 03- December-1993) for this well have incorrect API numbers on them. The changes are: Incorrect API Number: 50-029-22267-00 Correct API Number: 50-029-22367-00 The re-distributed logs can be recognized by having the correct AP1 number stated above. Please replace previously distributed final prints with those enclosed in this shipment. I apologize for the inconvenience this may have caused. Regards, Rodney D. Paulson Manager, Anchorage Log Analysis Center 5600 B Street, Suite 201, Anchorage AK 99518, (907) 563-3233, Fax (907) 561-4028 ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 4 January 1994 RE: Transmittal of Data ECC #: 6001.04 Data: PDK-PORO Dear Sir/Madam, Reference: l BP 2-50/U-8 MPI ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 Sent by U.S. MAIL PDK LDWG TAPE+LISTER Run # 1 Received by: Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown__ Alter casing Repair well x Plugging ~ Change approved program__ Pull tubing x Variance 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3218'NSL, 2317' WEL, SEC. 36, T12N, R16E At top of productive interval 4932' NSL, 2000' WEL, SEC. 34, T12N, R16E At effective depth 5039' NSL, 2235' WEL, SEC. 34, T12N, R16E At total depth 5064' NSL, 2305' WEL, SEC. 34, T12N, R16E 12. Present wall condition summary Total depth: measured - true vertical Re-enter suspended well ~ Time extension .__ Stimulate ~ Perforate ~ Other 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) KBE = 55.3' 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-50/U-08 9. Permit number 93-67 10. APl number 50- 029-22367 11. Field/Pool Endicott Oil Pool 15530 feet Plugs (measured) 10405' feet feet Effective depth' measured true vertical 15448' feet 10349' feet Junk (measured) Casing Length Structural Conductor 94' Sur[ace 2829' Intermediate Production 15484' Liner Perforation depth: Size Cemented Measured cl~;~ 131' 2873' 30" Drive 13-3/8" 1194 cuft PF "E" & 460 cu ft Class "G" 9-5/8" 517 cu ft Class "G" 15528' measured 15072'-15078', 15084'-15103', 15112'-15120', 15215'-15245' true vertical 10039~10043~ 10047~10059~ 10065~10071~ 10132~10151' Tubing (size, grade, and measured depth) 4-1/2", L-80 tubing to 14900' MD Tru~/~rtical depth 131' 2706' 104O4' Packers and SSSV (type and measured depth) 9-5/8" TIW HBBP 9chr packer @ 14810' MD; 4-1/2" Otis BBE SVL~/ ~'~1'~'~9' 13. Attachments Description summary of proposal x Detailed operations program ~ BOP sketch · ,. 14. Estimated date for commencing operation 1/20/94 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Suspended__ Service 17. I hereby certify tha~he foregoing is true and correct to the best of my knowledge. ~ /! 1 '~ :" Signed/u~,. /~' C L_Z~, '"-FOR COM,lSSloNTitle Drillin.c] Engineer Supervisor. USE ONLY Date Conditions of approval: Notify CommiSsion so representative may witness Plug integrity__ BOP Test~ Location clearance Mechanical Integrity Test~ Subsequent form required 10- ~ IApproval No. ~'~r ~ O /,~ Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY RUSSELL A. DOUGLASS A~proved Co~mmissi°ner Returned Date ///',.~? ~./ SUBMIT IN TRIPLICATE ENDICOTT MPI 2-50/U-.08 WORKOVER PLAN PURPOSE: The purpose of this rig workover is to shut off gas. The last production of the well was at a high GOR and a coil tubing squeeze was not successful in shutting off the gas. OBJECTIVES: A rig workover will be required on well 2-50/U-08 to squeeze off the 9-5/8" x 1 2- 1/4" annulus, cleanout and rerun the 4-1/2" completion assembly. The scope of the work will be as follows: 1. Pull the 4-1/2" tubing 2. Mill and recover the 9-5/8" packer 3. Squeeze off the 9-5/8" x 12-1/4" annulus 4. Clean out to PBTD 5. Make a bit & scraper run & displace to clean brine 6. Rerun the 4-1/2" L-80 completion assembly __ , , .J ._i 'l; TIMING' 1st Quarter 1994 10 days plus well to well move with rig Doyon 15 PRE-RIG OPERATIONS · RU slick line· dummy off gas lift mandrels· Pull the WL SSSV, if not already removed. . RUE line. RIH and cut the tubing 15' above the 9-5/8" packer latch. Circulate out the IA with kill weight brine. Check that the well is dead. Freeze protect the top 200' with diesel. Set BPV. Note' Maintain contact with Drilling. If rig move is delayed to more than three days after the well kill, a deeper freeze protect will need to be done · Dig out the cellar and level the pad. Inspect the wellhead and tree. Test the 9-5/8" packoff and function test the LDS's. RIG OPERATIONS · Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. 2. Pull the BPV. Check that the well is dead. Set the TWC. JLH Page 1 January 11, 1994 ENDICOTT MPi 2-50/U-08 WORKOVER PLAN o o . o . o , 10. 11. 12. 13. 14. ND the tree and NU the BOPE. Test the BOPE. (1/2 day) Screw in the landing joint. Pull and LD the tubing to cut directly above the packer. (1 day) GIH w/ovorshot and DP and RIH to the tubing cut directly above PBR. Recover the tubing stub and latch. (1 day) Mill up the packer. P/Id spear and recover the packer. (1-1/2 days) Run an 8-1/2" mill and 9-5/8" casing scraper and clean out to 15050' MD. (1 day) R/U E-line and perforate 9-5/8" casing at 15,000' MD & 14,900' MD. (1/2 day) P/U and run 9-5/8" retainer on 5" drill pipe. 'Set retainer @ 14950' MD. Attempt to circulate around retainer. Perform cement squeeze.(1 day) Run an 8-1/2" mill and 9-5/8" casing scraper and clean out to retainer. Test squeeze perforations to 2000 psi. Clean out to PBTD @15448' MD (1 day) Displace to clean inhibited brine. (1/2 day) Rerun 4-1/2" L-80 Completion with 9-5/8" straddle assembly. (1-1/2 days) N/D BOPE. N/U 4-1/2" tree. (1/2 day) Release rig and turn the well over to Production. JLH Page 2 January 11, 1994 ,. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 12/22/93 T# 85372 DUCK ISLAND/EArDICOTT DIRECTIONAL SURVEY Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. 2-50/U-08 GYRO 11/10/93 REF#AKii93G497 DIRECTIONAL SURVEY GYRODn= Information Services .......... _~_~A_ _~e..cq~_~s ..... . ._ -d%LASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. 'USA Date: 16 December 1993 RE: Transmittal of Data ECC #: 6001.04 Data: PDK-PORO Dear Sir/Madam, Reference: o BP 2-50/U-8 MPI ENDICOTT ~~7 NORTH SLOPE, AK Enclosed, please find th~ data as described b~low: Prints/Films: 1 PDK/GR FINAL BL Run # 1 1 PDK/GR FINAL RF Run # 1 Sent by U.S. MAIL Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson ~A , ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 23 November 1993 RE: Transmittal of Data ECC #: 6001.03 Data: NONE Dear sir/Madam, Reference: BP o 2-50/U-8 MPI ENDICOTT ~-~-~0~ NORTH SLOPE, AK Enclosed, please find the data as described below: · Prints/Films: 1 1 Sent by U.S. MAIL PFC/CCL FNL. BLUE PFC/CCL RF. SEPIA Run # 1 ~ il Run # 1 ; Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: This is to acknowledg~ ~eceipt of the following p. nts and negatives. COMPANY: STATE OF ALASKA-ALASKA OIL & GAS CONSERVATION COMMISSION ATTENTION: LARRY GRANT FIELD: PRUDHOE BAY & ENDICOTT WELL - LOG DESCRIPTION PRINTS NEGS. SEPIA /× OH - 32 SUB SEA TVD 14-Zu ~0L~--1 ~Q¢7 ~ I kx -32 ~-GR 2~ ~ 50--1 q~7 ~ 1 k R-34 BHC/AC-GR 2q5" ;~U~ ~ ~m5 ~% 1 , k R-34 S~ SEA T~ ~% 1 CH~.~72-50/U-08 SBT; (E~ICOTT ~,, 1 RFcrr , Please ret copy o sig ed transmittal to each of the following: Atlas Wireline Services Pouch 340013 Prudhoe Bay, AK 99734 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 FT/RTNCARD1 INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 93-067 CNL/GR/CCL 93-067 DGR/EWR-P4/FET 93-067 DGR/EWR-P4/FET 93-067 GR/CCL 93-067 SBT 93-067 407 93-067 DAILY WELL OP 93-067 SURVEY 93-067 5734 93-067 5759 93-067 5759 13500-15417 MWD 14928-15450 MWD 9898-10278 14737-14905 13500-15452 COMP DATE:07/22/93 05/20/93-07/23/93 ANADRILL CN/GR MWD 14885-15433 OH,MWD,14885-15433 Are well tests required? Yes~ Was well cored? Yes ~.. If yes, was the core analysis & description received? Are dry ditch samples required? Yes ~ COMMENTS: Yes 09/10/1993 PAGE · 1 WELL LOG TRANSMITTAL To: State of Alaska September 1, 1993 Alaska Oil and Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs - 2-50/U-08 AK-RB-930614 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of: Paul Radzinski, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG Formated LIS Tape with Verification Listing. Received: Date 5631 SilveradoWay, Suite G · Anchorage, Alaska99518 ° (907)563-3256 · Fax (907)563-7252 A Baroid Company ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 11 August 1993 RE: Transmittal of Data ECC #: 6001.00 Data: CN/GR Dear Sir/Madam, Reference: BP 2-50/U-8 MPI ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: Sent by U.S. MAIL CN/GR TAPE+LIST-AOGC Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: AUG 1 2 1993 INTERVALS LOG NAME RUN NO COMPANY NAME WELL NAME/~t~'DATE 1-15/P-25 {~)' (, 6/5/93 1-27/P-20 %q-~/26/93 2-04/M-19~'~,'~ 6/25/93 2-18/L-16 ~10''A~ 7/17/93 2-50/U-08 ~1~'~17/18/93 '~-7/18/93 3-21/L-34'~''~ '~'~6/19/937/20/93 3-25/M-27 qLY'r~'"6 / 27/93 3-49/J-40~q.,~O 6/28/937/9/93 12000'-12878' 10100'-10709' 10000'-.10695' 10700'~ 11334' 13500'-15452' 13500'-15417' 14737'-14905' 12300'-12830' 13600'-13957' 14350'-14856' 14700'-14870' PFC Gamma Ray CNL/GR PDK-100 Production Logging Services Segmented Bond Log Compensated N eutron/GR/CCL GR/CCL PDB-100/GR/CCL Production Logging (PITS) PFC/GR/CCL PFC/CCL 1 ATLAS 1 ATLAS 1 ATLAS 1 ATLAS 1 ATLAS 1 ATLAS 1 ATLAS I ATLAS I ATLAS 1 ATLAS 1 ATLAS ALASKA OIL AND GAS CONSERVATION COMMISSION May 19, 1993 Russ Strickland, Drilling Engineer Supervisor BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Re: Surface casing waive~-2-50~-0~'~ _ WALTER d. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Dear Mr. Strickland: This is in response t° your May 17, 1993 correspondence requesting a rule exception to set surface casing below 2700' TVD in the MPI 2-50/U-08 well. As you stated in your letter Conservation Order 202 sets the surface casing setting depth in Endicott wells to be "not below 2700 feet true vertical depth." Conservation Order202 does not allow administrative action on an exception of this nature and therefore the commission cannot administratively approve yOur request to deepen the setting depth of the surface casing in the MPI 2-50/U-08 well. Herewith we are returning your Application for Sundry Approvals dated May 18, 1993. If you anticipate future wells that would benefit from a more flexible surface casing setting depth the commission would consider an application from BPX to amend Conservation Order 202. The application should provide the basis for the change (e.g. operational experience gained during development of the Endicott Oil Pool) and the proposed change (i.e. establish new setting depth limitation or allow setting depth to be determined on a case by case basis). An application of this type would require a notice of possible hearing and a two week protest period in accordance with Title 20 Chapter 25.540 of the Alaska Administrative Code. If you would care to discuss this further please contact Russ or myself at 279-1433. David W.~ Chairman Attachments cc: JeffHupp r, !urinted on recycled paper b y .f'Ll'J STATE OF ALASKA ALASKA L)IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPEt",DF_D [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 93-67 3. Address B. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22367/~,~. _ 4. Location of well at surface 9. Unit or Lease Name t'"'~, 3218' NSL, 2317' WEL, SEC. 36, T12N, R16E t , ,~,;,.. ~-::.:: ....... ! LOC~I'~'[ Duck Island Unit/Endicott '~,~,"~ I ..... "' · ~;(')~..J ~ At T°P Pr°ducing Interval;' ',';":-' , _ .,.,~ I YLr'~["~' ,10' well Number~~ ,2-50/U-08 4932'NSL, 2000'WEL, SEC. 34, T12N, R'6~--~?~,~~I ~ ' 111. Field and poc, At Total Depth ,-,..,..J ~___.~ ~ ...... ' !Endicott Field/Endicott Pool 5064' NSL, 2305' WEL, SEC. 34, T12N, t~Tt~c ............... 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 55.3' I AOL 34634 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. ~ Aband. I15. Water Depth, il offshore 116. No. of Completions 5/19/93 6/27/93 7/22/93I 6'-12' MSL feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 15530' MD/10336' TVD 15528' MD/10335' TVD YES [] NO []I 1509' feet MD 1465' (Approx.) 22. Type Electric or Other Logs Run MWD 23. CASING, LINER AND CEMENTING RECORD SETI'~IG DEPTH MD CASING SIZE w'r. PER FT. GRADE TOP BOTI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Struct. Drive 37' 131' Drive 13-3/8" 681t L-80 44' 2873' 16" 1194 cuft PF "E"/460 cuft Class "G" 9-5/8" 4711 L-80/NT95HS 44' 15528' 12-1/4" 517cu ft Class "G" 24. Pedorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) Gun Diameter 4-1/2" 5 spf S~ZE DEPTH SET (MD} PACKER SET (MD} MD TVD 4-1/2" 14900' 14810' 15072'-15078' 10039'-10043' L-80 15084'-15103' 10047'-10059' 26. ACID, FRACTURE, CEMENT SQUEEZ~, ETC. 15112'-15120' 10065'-10071' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED 15215'-15245' 10132'-10151' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 8/5/93 I FIowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF ~ATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Briel description of lithology, porosily, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. &laska 0il & Gas Cons. (;ornmissiO;~ Anchorago Form 10-407 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. Top HRZ 13597' 9111' Top Itkilyariak 13996' 9350' Top Kekiktuk 15094' ~. 10076' 4!aska 0il & Gas Cons. ~,'omrnissio~-~ Anchorago 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true[ and correct to the best of my knowledge Signed.,, Title Drilling Engineer Supervisor Date ' v 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 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: 2-50/U-08 BOROUGH: NORTH SLOPE UNIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 05/19/93 06:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 15 WO/C RIG: DOYON 15 05/20/93 (1) TD: 1230' (1230) 05/21/93 (2) TD: 2890' (1660) 05/22/93 (3) TD: 2890' ( 0) 05/23/93 (4) TD: 2890' ( 0) 05/24/93 (5) TD: 4750'(1860) 05/25/93 (6) TD: 6100' (1350) 05/26/93 (7) TD: 7240' (1140) 05/27/93 ( 8) TD: 8767' (1527) DRLG 16" HOLE MW: 8.7 VIS:165 RIG UP CUTTINGS WASHER & BAGGER UNIT. ACFEPT RIG @ 0600 HOURS 05/19/93. NIPPLE UP RISER. PICK UP-STRAP & ORIENT BHA. FUNCTION TEST DIVERTER SYSTEM. DRLG. 16" HOLE FROM 110 TO 380' POH INTO CONDUCTOR PIPE. WO SPERRY SUN TOOLS. RIH GYRO @ 380. DRLG & SURVEYS TO 1230' POH TO RUN 13 3/8" CSG MW: 9.4 VIS:108 WIPER TRIP @1230. DRLG & GYRO F/ 1230 - 2520. MOTOR QUIT. POH--CHANGE BHA--RUN. CUT DRLG LINE. FINISH RIH. DRLG & SURVEYS F/ 2520 TO 2890. 5 STAND WIPER TRIP. CBU. POH TO RUN 13 3/8" CSG. INSTALL WEAR BUSHING MW: 9.5 VIS: 78 POH, LD STABS. RU & RUN 13-3/8 CASG. HOOK UP CMT HEAD, CBU HOLE CLEAN. CMT CASG. B/O LNDG JT, RD CSG TOOLS. LD JT, ND, NU BOPE. TEST BOPE. INSTL WEAR BUSHING. DRLG CMT MW: 9.3 VIS: 56 RD DRAWWORKS GUARDS & MISC. PULL INPUT SHAFT. PULL OUTER & INNER SPROCKETS. CHG INNER SPROCKET & INSTL SAME. RU EQUIP & GUARDS. PU BHA. RIH, TAG CMT. TEST CASG. DRLG CMT & PLUGS. DRLG 12.25" HOLE MW: 9.3 VIS: 51 DRLG CMT & SHOE. CIRC HOLE CLEAN. LO TEST. DRLG & SURV. CBU, WIPER TRIP TO SHOE & BACK TO BTTM. DRLG TO 4750. DRLG. CBU. WIPER TRIP. DRLG TO 5027' RIH. DRLG TO 6100' MW: 9.5 VIS: 46 POOH. CHANGE BIT, BHA. DRLG. MW: 9.7 VIS: 53 DRLG TO 6135'. CBU. SHORT TRIP TO 5027' DRLG TO 6685'. CIRC. POOH. CHANGE BIT, BHA. RIH. DRLG TO 7240' CIRC. DRLG TO 7622' MW: 9.8 VIS: 49 SHORT TRIP 11 STDS. DRLG TO 8767' CIRC. 05/28/93 (9) TD: 9624' ( 857) DRLG. MW: 9.7 VIS: 44 CIRC. POOH. CHANGE BIT, BHA. RIH. DRLG TO 9624' WELL : 2-50/U-0 OPERATION: RIG : DOYON 15 PAGE: 2 05/29/93 (10) TD:10381' ( 757) 05/30/93 (11) TD:10760' ( 379) CIRC. MW: 9.7 VIS: 47 DRLG TO 9719'. CIRC. SHORT TRIP TO 8767' DRLG TO 10381' CIRC. DRLG. MW: 9.8 VIS: 45 CIRC. POOH. TEST BOPE. RIH. DRLG TO 10760' 05/31/93 (12) TD:lll60' ( 400) DRLG. MW: 9.8 VIS: 52 DRLG TO 11015'. POOH. CHANGE BHA. RIH. DRLG TO 11160' 06/01/93 (13) TD:12408' (1248) SHORT TRIP. DRLG TO 12408' CIRC. SHORT TRIP. MW: 10.0 VIS: 49 06/02/93 (14) TD:12615' ( 207) 06/03/93 (15) TD: 13120' ( 505) DRLG. DRLG TO 12600' 12615'. MW: 9.9 VIS: 48 CBU. POOH. CHANGE BIT. RIH. DRLG TO DRILLING DRILLING TO 13120' MW: 9.8 VIS: 52 06/04/93 (16) TD:13228' ( 108) 06/05/93 (17) TD:13750' ( 522) DRILLING MW:10.2 VIS: 52 DRILG TO 13123', POH, SERVICE WEAR BUSHING, CHG BHA, RIH TO CSG SHOE & TEST MWD, REPLACE GLYCOL HEAT EXCHANGER IN TOP DRIVE COOLING UNIT, RIH TO 2 STDS OFF BTM, REAM TO BTM, DRLG IN TUFFS, VERY HIGH TORQUE & DRAG DRLG. DRLG TO 13750' MW:10.3 VIS: 52 06/06/93 (18) TD:13965' ( 215) 06/07/93 (19) TD:14008' ( 43) 06/08/93 (20) TD:14084' ( 76) STRING BLOCKS. DRLG TO 13965' RESTRING BLOCKS. MW:10.3 VIS: 51 BACKREAM THRU HRZ. CIRC. POOH TO SHOE. DRLG. MW:10.3 VIS: 54 RESTRING BLOCKS. POOH. TEST BOPE. CHANGE BHA. RIH. REAM THRU HRS, TUFFS. DRLG TO 14008'. RIH. DRLG TO 14098' MW:10.2 VIS: 56 POOH. CHANGE BIT. RIH. 06/09/93 (21) TD:14165' ( 81) TRIP OUT FOR PDC BIT MW:10.5 VIS: 53 TRIP IN TO 13744' (TIGHT), WASH & REAM 13744'-14084', DRLG TO 14125', SHORT TRIP TO 13345', TRIP IN, WASH & REAM 10' OF FILL, DRLG TO 14165', TRIP OUT FOR PDC BIT '~!a,.~k.~, Oii& (~as Cons. f.;or,qf'o~]ssk ,&nchorage WELL : 2-50/U-0 OPERATION: RIG : DOYON 15 PAGE: 3 06/10/93 (22) TD:14216' ( 51) 06/11/93 (23) TD: 14216' ( 0) 06/12/93 (24) TD: 14279' ( 63) 06/13/93 (25) TD:14315' ( 36) 06/14/93 (26) TD:14420' ( 105) TRIP OUT FOR BIT MW:10.5 VIS: 55 TRIP OUT, CHG BHA, SERVICE RIG, TRIP IN, TEST MWD, TRIP IN TO 14165', WASH & WORK PIPE @ BTM TO PICK UP BIT JUNK IN BASKET, DRLG TO 14216', TRIP OUT FOR PDC BIT TRIP OUT FOR BIT MW:10.5 VIS: 48 TRIP OUT, P/U PDC BIT, TRIP IN, TEST MWD, WASH & REAM TO BTM, P/U KELLY, DRILL & WORK BIT, DRLG TO 14228', CHG OUT SWAB #2 MUD PUMP, DRLG (MAKING NO HOLE), TRIP OUT FOR BIT F/14228' DRLG. MW:10.5 VIS: 47 POOH. CHANGE BIT. RIH. REAM TO BTM. DRLG F/ 14228'-14279'. DRLG. MW:10.5 VIS: 66 DRLG TO 14311'. POOH. CHANGE BIT, MWD. RIH. DRLG F/ 14311'-14315' DRLG. DRLG F/ 14315'-14420' MW:10.4 VIS: 50 06/15/93 (27) TD:14480' ( 60) POOH. DRLG TO 14480' POOH. MW:10.4 VIS: 52 06/16/93 (28) TD:14529' ( 49) 06/17/93 (29) TD:14550' ( 21) 06/18/93 (30) TD:14686' ( 136) 06/19/93 (31) TD:14772' ( 86) DRLG. MW:10.4 VIS: 51 POOH. TEST BOPE. CHANGE BHA. RIH. WASH TO BTM. DRLG TO 14529' TRIP FOR BIT MW:10.4 VIS: 47 DRLG 14529 - 14542' REPAIR BROKEN ROTARY CHAIN. DRLG 14542 - 14550'. DROP SURVEY. TRIP OUT FOR NEW BIT. RETRIEVE SURVEY. CHANGE OUT BIT & REPLACE SLEEVE ON NB STAB. DRLG 12-1/4" HOLE MW:10.4 VIS: 45 TRIP IN TO 14490', REAM TO BTM (NO FILL), DRLG F/14550'-14569', SERV RIG, DRLG F/14569'-14686' P/U BIT. DRLG TO 14772' MW:10.4 VIS: 50 CIRC. POOH. P/U BIT. 06/20/93 (32) TD:14859' ( 87) DRLG. RIH. CIRC. DRLG F/ 14772'-14859' MW:10.4 VIS: 49 06/21/93 (33) TD:14928' ( 69) CHANGE BHA. DRLG F/ 14859'-14928' MW:10.4 VIS: 50 CBU. POOH. CHANGE BHA. '~sk..?. ,U~i & ~s Cons, Commissio~ Anchorage WELL : 2-50/U-0 OPERATION: RIG : DOYON 15 PAGE: 4 06/22/93 (34) TD:15000' ( 72) DRILLING AHEAD MW:10.4 VIS: 58 PU LWD TOOL. TRIP IN, WASH & REAM. DRLG TO 15000. 06/23/93 (35) TD:15120' ( 120) CIRC BEFORE TRIPPING DRLG TO 15120' MW:10.4 VIS: 54 06/24/93 (36) TD:15123' ( 3) 06/25/93 (37) TD:15270' ( 147) 06/26/93 (38) TD:15294' ( 24) 06/27/93 (39) TD:15440' ( 146) DRILLING MW:10.5 VIS: 72 DROP SINGLE SHOT SURVEY; SHOWS ARE DROPPING @ 1.3/100FT. POOH. RETRIEVE SURVEY, SERVICE RIG & CHANGE OUT KELLY HOSE. FINISH POOH & BREAK BIT. WORKED TO RETRIEVE DATA OUT OF SPERRY SUN LWD TOOL & CUT SLEEVE OFF OF NB STAB. PULL WEAR BUSHING, TEST BOP'S, PULL WEAR BUSHING. P/U BHA, RIH TO HWDP. INSTALL NEW KELLY HOSE & CUT DRILLING LINE. RIH TO 15000. LWD 15000 - 15114. DRILLING. POOH FOR NEW BIT MW:10.4 VIS: 51 DRILLING 15123 - 15187 IN SHALES WITH INTERMITTENT SANDS. HIGH TORQUE BROKE ROTARY CHAIN; REPAIRED. DRILLIN TO 15270. CIRC AND MIX PILL. DROP SINGLE SHOT SURVEY. POOH. DRLG. MW:10.4 VIS: 56 POOH. CHANGE BIT. RIH. MAD RUN F/ 15000'-15270' DRLG TO 15294' DRLG. DRLG F/ 15294'-15440'. MW:10.3 VIS: 53 06/28/93 (40) TD:15450' ( 10) 06/29/93 (41) TD:15530' ( 80) 06/30/93 (42) TD:15530' ( 0) REAM TO BTM. DRLG F/ 15440'-15450' REAM TO BTM. MW:10.5 VIS: 80 CIRC. POOH. CHANGE BIT. RIH. SHORT TRIPPING FOR CASING MW:10.3 VIS: 47 REAM PREVIOUS BIT RUN TO 15450' DRILLING TO TD @15530' MINOR COAL STREAKS IN MIDDLE OF SHALE SEQUENCE. CBU. SHORT TRIPPING PAST TOP OF TUFFS. JARRING STUCK PIPE MW:10.4 VIS: 57 SHORT TRIP TO 12700', CIRC & COND FLUID FOR CSG, POH FOR CSG, PULLED TIGHT ON STAND #48, CONNECTED TOP DRIVE & WORKED PIPE, COULD NOT WORK PAST TIGHT SPOT, TOP OF JARS @ 10950', WORKED UPWARDS ATTEMPTING TO BACKREAM, WORKED COMBINATION OF TORQUE & PUMP PRESS. THAT GOT JARS FIRING, NO MOVEMENT EITHER WAY, NO ROTATION POSSIBLE, SPOTTED 50 BBLS 10.3 SFT, JARRING STUCK PIPE, W/L TOOLS ARRIVING LOCATION Anchorage WELL : 2-50/U-0 OPERATION: RIG : DOYON 15 PAGE: 5 07/01/93 (43) TD:15530' ( 0) 07/02/93 (44) TD:15530' ( 0) 07/03/93 (45) TD:15530' ( 0) 07/04/93 (46) TD:15530' ( 0) 07/05/93 (47) TD:15530' ( 0) 07/06/93 (48) TD:15530' ( 0) 07/07/93 (49) TD:15530' ( 0) 07/08/93 (50) TD:15530' ( 0) P/U FISHING TOOLS MW:10.3 VIS: 48 JARRING ON SP DOWNWARD ABOUT 65% OF THE TIME, COULD NOT ESTABLISH MOVEMENT, R/U TO RUN FREEPOINT AND BACKOFF TOOLS, RUN FREEPOINT - INCONSISTENT READINGS, CHG TOOL, STRING STUCK IN LOWER PART OF DRLG JARS, TOP OF JARS @ 10979', R/U STRINGSHOT & RIH, BACKED OFFF HWDP @ 10949', POH, FISH LEFT IN HOLE, P/U DC'S & SFJ W/REST OF FISHING TOOLS POH TO CHG ASSEMB. MW:10.3 VIS: 48 P/U FISHING ASSEMB & RIH, CUT 60' DRLG LINE, RIH TO TOF @ 10949', HAD TO REAM THRU TIGHT SPOT @ 8032', FISHING, RIH TO 11478', BACK REAM, CBU, RIH TO 15300', HOLE VERY TIGHT, CIRC & COND MUD, FISHING, WASHED DOWN TO 15420', POH TO L/D SOME DC'S, PLAN TO P/U OVERSHOT RUN FREEPOINT. MW:10.4 VIS: 53 POOH. L/D SCREW IN SUB. RIH W/ HOLE OPENER. TAG @ 11006' POOH. R/U ATLAS. RIH W/ FREEPOINT. JAR FISH. MW:10.3 VIS: 56 RIH W/ FREEPOINT. FREE @ 7500' RUN 3 STRING SHOTS @ 7498' 3RD OK. POOH. RIH W/ JAR ASS'Y. TAG FISH @ 7498' CIRC. ENGAGE FISH. JAR FISH. WASH OVER FISH. MW:10.3 VIS: 50 JAR FISH. NO MOVEMENT. SPOT 50 BBLS SFT. R/U ATLAS. RUN FREEPOINT. FISH ASS'Y STUCK AS WELL AS PIPE. RIH W/ STRING SHOT. FREE JARS. POOH. RIH W/ WASHPIPE. TAG TOF @ 7467' WASH OVER FISH. RIH. MW:10.6 VIS: 60 WASH OVER FISH. POOH. RIH. ATTEMPT TO WASH OVER FISH. APPEAR TO BE GOING BESIDE FISH. POOH. RIH W/ SCREW IN ASS'Y. CBU @ 10669' MW:10.6 VIS: 55 RIH W/PIN TAP J-JT ASSY TO 2000', CUT DRLG LINE, RIH TO 7457', CIRC, POH, P/U WASH PIPE, RIH TO 7382', WASH OVER FISH (200') FISH FREE FELL TO BTM, RIH TO 10719' POH, L/D WASH PIPE, P/U OVERSHOT, RIH, CBU, COND HOLE @ 1~669' L/D FISHING TOOLS MW:10.6 VIS: 60 CIRC & COND MUD, WASH DOWN TO 10718', TRIP OUT W/OVERSHOT, RECOVERED J-JT, HWDP, PIN TAP, P/U NEW OVERSHOT, TRIP IN TO 10605', WASH DOWN TO FISH TAG @ 10882', LATCH ON TO FISH AND JAR ON FISH @ 400 K, PULL UP TO 550K, WORKED PAST FISH #1, TRIP OUT, L/D FISH #2, L/D WASH PIPE & FISHING TOOLS WELL : 2-50/U-0 OPERATION: RIG : DOYON 15 PAGE: 6 07/09/93 (51) TD:15530' ( 0) 07/10/93 (52) TD:15530' ( 0) 07/11/93 (53) TD:15530' ( 0) 07/12/93 (54) TD:15530' ( 0) 07/13/93 (55) TD:15530' ( 0) 07/14/93 (56) TD:15530' ( 0) 07/15/93 (57) TD:15530' ( 0) 07/16/93 (58) TD:15530' ( 0) 07/17/93 (59) TD:15530' ( 0) TRIP ON W/ WASH PIPE MW:10.6 VIS: 56 LAY DOWN AT TOOLS FROM DERRICK. CHANGE OUT DRLG LINE SPOOL. P/U 8 1/2" BIT & SLICK BHA, TRIP IN. WASH TO TOP OF FISH 610960' CIRC & COND HOLE FLUID. TRIP OUT. PULL WEAR RING. TEST BOPE. INSTALL WEAR RING. P/U WASH PIPE BHA. TRIP IN (SLM). WASHING SOWN TO FISH. POOH. MW:10.6 VIS: 63 JAR ON FISH @ 10960' POOH. RIH W/ SCREW IN ASS'Y. LATCH FISH @ 10960'. JAR. FISH FREE. POOH. RIH W/ OVERSHOT. CIRC OVER FISH. NO LATCH UP. POOH. POOH. MW:10.5 VIS: 58 POOH. RIH W/ OVERSHOT. LATCH FISH @ 10990' JAR. FISH FREE. PULL TO 10900'_ JAR. BROKE GRAPPLE. FISH FELL DOWN HOLE. RIH TO 11307'. POOH. RIH W/ HOLE OPENER. WASH & REAM F/ 10700'-11072' POOH. REAM. MW:10.6 VIS: 53 POOH. RIH W/ SCREW IN ASS'Y. LATCH FISH @ 11348' JAR & WORK TO 11060'. POOH. L/D FISH & FISH ASS'Y. RIH. WASH & REAM F/ 10700'-11164' TRIP OUT FOR HOLE OPERNER MW:10.5 VIS: 50 WASH & REAM 11164 TO 11353'. SHORT TRIP TO 10700' WASH & REAM 11357 TO 12833'. SHORT TRIP TO 11340' WASH & REAM TO 14066' TRIP OUT FOR HOLE OPENER. WASH & REAM MW:10.6 VIS: 55 TRIP OUT L/D HOLE OPENER. PULL WEAR RING, INSTALL TEST PLUG. CHANGE BLIND RAMS TO SHEAR RAMS. TEST BOPE. PULL TEST PLUG, INSTALL WEAR RING. CUT DRLG LINE. M/U BULL NOSE ON 12 1/4" HOLE OPENER. TRIP IN W/ H.O. (SLM) . WASH & REAM TO 13963' WASH & REAM MW:10.6 VIS: 55 WASH & REAM 13963 TO 14365. SHORT TRIP 14365 TO 13963. WASH & REAM 14365 TO 14826. SHORT TRIP 14826 TO 14365. WASH & REAM 14365 - 15375. RUN 9 5/8" CASING MW:10.6 VIS: 57 WASH & REAM 15375 - 15530' = TD. SHORT TRIP TO 13905' CIRC VIS SWEEPS & CONDITION HOLE FLUID. TRIP OUT. L/D HOLE OPENER BHA. PULL WEAR RING. CHANGE RAMS. R/U TO RUN 9 5/8" CASING. TRIP IN W/ 9 5/8" CASONG. N/U BOPE MW:10.6 VIS: 58 CONT. TRIP IN W/9-5/8" CSG, WASH LAST JT TO TD @ 15530', PUMP 92 BBL CLASS G CMT, DISPLACE R/D CMT TOOLS, N/D BOPE, SET 9-5/8" EMERG. SLIPS, CUT CSG, INSTALL PACKOFF, L/D LNDG JT & CUT OFF STUB, N/U BOPE, TEST PACKOFF TO 3000 PSI Alaska Oil a Gas Cons. Anchorag~ WELL · 2-50/U-0 OPERATION: RIG : DOYON 15 PAGE: 7 07/18/93 (60) TD:15530' ( 0) 07/19/93 (61) TD:15530' ( 0) 07/20/93 (62) TD:15530' ( 0) 07/21/93 (63) TD:15530' ( 0) 07/22/93 (64) TD:15530 PB: 0 07/23/93 (65) TD:15530 PB: 0 MW:10.4 VIS: 50 N/U BOPE, CHG RAMS, TEST BOPE & INSTALL WEAR RING, CUT DRLG LINE, TRIP IN W/8-1/2" BIT, TAG CMT @ 15138', DRLG OUT CMT TO 15446', TEST CSG TO 3500 PSI, DRLG OUT FC + 40' CMT TO 15486', TEST CSG TO 3500 PSI, CIRC HI VIS SWEEP, TRIP OUT, R/U ATLAS W/L FOR CBL NOTE: EST. FINAL COST $4,650M CIRC, CHG OVER TO BRINE MW:10.4 VIS: 54 RAN CBL, TRIP IN W/8-1/2" BIT & 9-5/8" SCRAPER TO 15486', REV CIRC, HI VIS SWEEP SPACERS, 1100 BBLS BRINE NOTE: EST. FINAL COST $4,650M TRIP IN W/PERF GUNS MW:10.4 VIS: 0 CLEAN PITS, DISPLACE MUD W/BRINE, TRIP OUT L/D BHA, P/U PERF GUNS W/BAKER PKR, CUT DRILG LINE, TRIP IN W/PERF GUN ASSEMB. EFC AHS BEEN RAISED TO 4650M DUE TO STUCK PIPE INCIDENT. POH LDDP MW: 9.2 VIS: 0 RIH W/PERF GUNS, RUN GR/CCL TO POSITION PERF GUNS, R/U & SET RETRIEV-A-MATIC, DISPLACE BRIN, PRESS UP ANNULUS TO 1500 PSI & PERF WELL, KILL WELL BU REV. IN 3 DP VOL. OF 9.2 BRINE, CLEAR FLOOR, POH LDDP LANDED TUBING MW: 0.0 POH L/D DRILLPIPE. L/D PERF GUNS & RETRIEV-A-MATIC. ALL SHOTS FIRED ON GUNS. PULL WEAR BUSHING & R/U TO RUN TUBING. RUN 4-1/2" TBG. FILTER & INHIBIT 9.2 PPG-BRINE. R/D CIRC JOINT @ INSTALLED 2-WAY CHECK VALVE. M/U LANDING JOINT & LOWERED TBG HANGER INTO PLACE. RELEASED RIG MW: 0.0 LAND TUBING & RILDS. L/D LANDING JOINT & CLEAR RIG FLOOR. N/D BOP'S. N/U ADAPTER FLANGE, TREE & CONTROL LINES. TEST COMPONENTS TO 5000 PSI. COULD NOT GET TREE TO TEST INITIALLY; ACTUATOR VALVE WAS STUCK PARTIALLY OPEN. EVENTUALLY CLOSED & TESTED. R/U LUBRICATOR; PULL 2-WAY CHECK VALVE. R/D LUBRICATOR. PRESSURED UP DOWN TUBING TO SET PACKER. INSTALL BPV. SECURE WELLHEAD & CLEAN PITS OF DIRTY BRINE WHILE W.O. FUEL TRUCK TO PULL DIESEL OFF RIG TO LIGHTEN UP FOR RIG MOVE. RIG RELEASE @2200 HRS. 07/22/93 SIGNATURE: (drilling superintendent) DATE: Alaska Oil & Gas Gons, ~on~'ms~%'-' ' Ancho.m!~]e, D~(E/-W) 277,6~ 41C OFILMED Date ~a//'/Oq~ ' I S i: ? -- 2 i,99;5 4~aska 0i~ & 6as Cons. Commission Anchorage D~'TH ft ft ft Z::6,(K: !.9c',~0 507,00 103,0 507,CK, 60~,1_-- 97,2 TARGET E~ATIC~. AZIMbT, H ~TiTUD~ cTf'tlrff-J :'-'' ......... IN~_.:.N, ~t deg deo O,OO O,OO O,~J -0,43 0,~ 9,-.',,{<) -0,04 -o,r¢: v,5C ?_7~,, ¢X:, 0,!5 ! ,20 1,03 ~.,E:.~', .'.-.70,49 DEF'ARTUF. 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Z~ ,53 835, i7 72~ 2.48 57,6,.z 276. ~,_~ - ---~ ~:.' .'~ ~.'~ L-;': ~VJ- ..'~ , 1_..~ ,,'u 55,n~.,~ 250,00 ~,:= ,~' -71.t'.2,57 7211,5~. 27..:,, 6.5 - 7 ;'47, .5:'L7??2 ,? 276.6? -7- :': ,&:.._ . 744~ ,,..~.~s' -7477,1}~ 752.;.',3.: *'- -~- 1,04 L. ~L'O ,5~'LLZ ~L'LL~ Lt'8~96 LI'L~6 6L',C_2,S5 z: * · :-~,,-o,'o '~':'~,OL~' ~,/¢Tf :~'5'~g L6'SL6~ ~9'?LL9 7~ S~"gL?L ~L''~' n'?A ~:,7.-,~t SURVEY REPORT B.P. EXPLORATION MPI UNIT WELL NUMBER 2-50 ENDICOTT NORTH SLOPE DECEMBER 10, 1993 eouexe~e~ Ie~Uoz/~oH IeOOq ~o~ pe~elnOleD se~eu!pzooo Ie~U°zl2°H ue!~eseq peeH IIeH mo~ pe~elnSleO e2nselO esue~e~e~ Ie~Uoz!~eH IeSOq mo~ pe~InsleD uo!~ses '~ 9S :esue~e~eH IeSl~eA mo~ uol~seZ2eD ees-qns ~ -Bep 000£S£'0A :epn~laeq XeA~ns ~Hg~AH~D HgHIMIH :poqaeN uol~elnsleO GH~GGO~S HOg :~eJeA~ns 00:00:~I ~6-AO~-0I :e~ ~R~ £6~©£6IIM~ :~eqmn~ qop 0~-~ HZ~M ~IM~ IdH :qqZM ~OIL~OqdXZ 'd'~ .zos 80'69£ M 96'~[ 86'6IC M 8£'9I ~ ~6'961 M S0'8 ~ 9~'~91 M 80'9 M 00'6£T ~ 5£'9 M 89'911 M £0'£ ~ ~I'£6 M 66'I M S£'6£ M 89' H C6'[9 S 99' ~ S0'A9 S [8' M I~'C£ M 6I' ~ ~9'~ M 96' M 98'CI M SI'I M CS'£ M 0T'1 M A6'£ k{ 88' M TS'I M M 8~' M 9~' L0' M 8£' S0' M 0g' 80' M A0' £0' M T0' 00'0 M 00'0 q V ~ H 0 Z I H 0 H £'~£~ 9'I~ 9'££~ 8'69£ 6'~A~ 9'~£~ £'~L~ L'96I T'~L~ L'SgT 8'TL~ 1'6£1 S'TL~ S'gTT ~'IL~ ~'L6 S'OL[ 8'6L 9'695 6'~9 0'69~ l'L9 £'OL~ 9'~A~ L'~l~ A' 9A~ 6 ' CI £'8A[ 9'A S'~8~ I'~ 9'£8~ 6'1 A'CTC A' T'0S£ e' 9'60£ l' L'gSg 0' 0'0 0'0 ~'S~C~ ££' ~'£ST~ £6'I S'990~ 6£'C £'C£6I ~S'08~ ~9'I£ 0'009{ 8~'6L~ 0~'I£ 0'00£~ £8'SL~ £~'8~ 0'00~ 09'£L~ 6S'9~ 0'00I~ 9I'££~ 08'~ 0'000~ 9'088I [9'~ 9'SSLI 99'[ 0'6891 91'[ 9'T6SI [9'T S'£69I £9' ~9'£LE 6£'61 0'006I 98'£LE LL'9I 0'0081 09'£LE TI'gl O'OOtI SS'~L~ 96'II 0'0091 09'££~ S£'OI O'OOSI 0'S6£I 6I' S'96~I SS'I £'£6II ££'I A'860I ~9'I £'666 80'I O0'S£~ ££'6 0'0091 II'9£~ 99'6 0'00£I 99'99~ 99'8 0'00~I 6S'99~ S6'9 0'00II S9'£9~ £S'S 0'000I L'668 LL'I 6'66L 0~'I 0'00£ ~' 0'009 SA' O'OOS SC' £I'0£~ IS'9 0'006 06'0£[ 9£'~ 0'008 89'8£~ 9£'I 0'00£ C9'££~ 9I'I 0'009 L9'99~ 09' O'OOS 0 ' 009 EI ' 0'00£ 80' 0'00~ 90' 0 ' 00I 90 ' 0'0 00'0 L9'9[£ £I' 0'009 80'ti II' 0'00£ 99'99£ 90' 0'00[ SL'~SE bO' 0'00I 00'0 00'0 0'0 Bep ~K ~ OOI/'8ep Bep Bep ~} Z H ~ S 0 q D q~DI~H~A ©Zq-~OG HL~HIZ~ q O M I GZH~$~ZH YZS~q~ ZdOqS HLHOH £69©£6IIM~ :2eqmnM qof GqZIg LLODIGMZ 'HZAOMHOM :MOI~VDOq OS-~'HZ~HOM ~IM~ IdH :qqZM N IC'~STU ~ ~0'~9C N 60'90I~ M 9E'ISC ~ ~0'8~0~ ~ E~'LCC M L9'6~6I ~ 0S'C~C M 59'I£8I ~ C9'60C ~ SI'96Ll ~ 9L'965 ~ 89'9ILI ~ 68'S85 ~ 98'099I ~ LL'SLE M 88'gTgT ~ AT'T95 ~ CS'8CCT ~ ~T'855 M S6'C95T ~ 80'ST5 ~ £8'68II ~ I9'E05 M TT'9ITI ~ 85'06T ~ 8T'CgOT M ~9'9LI ~ 8C'5A6 M LS'T9I M 8I'906 M TS'99T ~ ~T'8C8 ~ ~E'TCI ~ IL'EAt ~ I9'~II M TS'60L M OS'L6 M 95'9~9 M OE'T8 M L9'PSS N S9'99 M S9'95S N SP'gS S'6L5 9'9155 S'6LE E'SCTE 9'6LE 6'SS05 9'6L5 c'gL6T 9'6LE I't68I 9'6LE S'STST S'6L5 C'09LT S'6AE 6'C99I 9'6LE 9'88ST 9'6L5 S'EISI L'6L5 C'SCgT L'6LE T'SSCT t'6L5 I'585I t'6L5 O'LOET L'6LE E'E£TI 9'6LE 0'SSOI f'6L5 L'S86 5'6L5 6'ST6 6'8LE 9'858 8'ALE S'9TL 5'AA5 C'IS9 S'9LE S'88S 6'SL5 C'6~S 9'9909 ST'T 9'C86C S'556C 06' 6'T98C O'T08C OT'T 6S'8L5 95'ES 0'0069 S6'6LE C9'59 0'0089 SI'08E SE'ES O'OOL9 00'085 LI'CS 0'0099 9I'08E EL'TS 0'00S9 T'6CLC 5C'I 8'9L9C T9'E 9'ET9C 89' 9'99SC 8~'T 8'189C 56' 9L'SLE LL'TS 0'0099 SE'ALE 6T'TS 0'00C9 00'8L5 S9'89 0'0059 IS'SAC 96'89 O'OOTV 8S'8LE CE'OS 0'0009 E'SIgC I6' 9'5SCC 8E'T £'685C C9' 9'C55C SC' C'LSTC 8S'T 59'6L5 68'0S 0'006C CO'08E II'OS 0'008C SL'6L~ S8'89 O'OOLC SC'6LE ~S'89 0'009C 99'6LE 95'8~ O'OOSC E'060C L9'5 SS'TSE 9S'L9 0'009C C'TEOC SI'5 86'585 EC'S9 0'00CC 8'6965 ES'T 06'I85 TC'C9 0'00~C E'9L85 CI'T 0L'C85 96'I~ 0'00TC 9'I085 9C' C5'S85 L9'I9 0'000£ 9'9CAE 88' I'TS9E 98'5 9'C69~ TO'£ E'OTgE 8S'T 9L'985 LC'T9 0'0065 50'98[ C9'09 0'0085 CS'[85 C6'AC 0'00L5 0I'I85 OI'S£ 0'0095 6I'CSE ~C'EC O'OOS~ ~ee~ 6ap ~ J~ 00l/'SeP 6ep 8ep ~ SZLVMIGHOOD HI~HIZ~ LSIG HIdZG XLIHZAZS HLdZG q ~ L M 0 Z I ~ 0 H Z ~ ~ S 0 q O q~OILHZA ©Zq-©OG HL~NIZ~ q O M I ~ZH~S~ZH VMS~TV ZdO~S HLHOM A690C6TIM~ :~qmnM qo£ GTZI~ LLODIG~Z 'HZAOMHOM :NOIL~OO~ A Gyro da t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: MPI UNIT NUMBER 2-50 LOCATION: WORKOVER, ENDICOTT FIELD Job Number: AKl193G497 NORTH SLOPE ALASKA MEASURED I N C L AZIMUTH DOG-LEG VERTICAL DEPTH SEVERITY DEPTH ft deg deg deg./100 ft 5000.0 50.92 277.53 5100.0 51.63 276.48 5200.0 51.85 277.92 5300.0 52.36 274.13 5400.0 55.34 274.14 1.56 4106.5 1.08 4169.1 1.15 4231.0 3.04 4292.4 2.98 4351.4 5500.0 55.86 278.75 5600.0 56.80 273.95 5700.0 55.45 276.97 5800.0 56.15 276.14 5900.0 56.70 276.22 3.84 4407.9 4.10 4463.3 2.84 4519.1 .98 4575.3 .55 4630.6 6000.0 57.42 276.70 6100.0 56.23 275.91 6200.0 55.90 273.71 6300.0 56.26 278.37 6400.0 55.35 275.19 .82 4685.0 1.36 4739.7 1.86 4795.5 3.89 4851.3 2.78 4907.5 6500.0 55.73 273.64 6600.0 56.34 274.97 6700.0 56.83 277.04 6800.0 56.45 273.91 6900.0 56.36 277.06 1.33 4964.1 1.26 5020.0 1.79 5075.0 2.64 5130.0 2.63 5185.3 7000.0 55.96 274.67 7100.0 55.80 274.71 7200.0 56.47 274.62 7300.0 55.64 276.01 7400.0 54.73 274.56 2.02 5241.0 .16 5297.1 · 68 5352.8 1.43 5408.7 1.50 5465.8 C L 0 S U R E DIST AZIMUTH ft deg 2292.8 279.4 2370.7 279.3 2449.2 279.3 2527.9 279.2 2608.3 279.0 2690.7 278.9 2773.8 278.9 2856.6 278.8 2939.2 278.7 3022.5 278.6 3106.3 278.6 3190.0 278.5 3272.8 278.4 3355.6 278.4 3438.3 278.3 3520.5 278.2 3603.3 278.1 3686.7 278.1 3770.1 278.0 3853.2 278.0 3936.2 277.9 4018.9 277.9 4101.8 277.8 4184.7 277.7 4266.7 277.7 Page 3 H 0 R I Z O N T A L COORDINATES feet 375.03 N 2261.87 W 384.55 N 2339.30 W 394.39 N 2417.20 W 402.66 N 2495.63 W 408.48 N 2576.14 W 417.75 N 426.93 N 434.81 N 444.25 N 453.22 N 2658.06 W 2740.70 W 2823.32 W 2905.48 W 2988.31 W 462.66 N 471.85 N 478.80 N 487.53 N 497.30 N 3071.70 W 3154.89 W 3237.55 W 3320.00 W 3402.10 W 503.65 N 509.87 N 518.61 N 526.58 N 534.54 N 3484.30 W 3567.00 W 3649.99 W 3733.10 W 3815.99 W 543.03 N 549.80 N 556.56 N 564.23 N 571.80 N 3898.59 W 3981.10 W 4063.86 W 4146.46 W 4228.20 W M 00'SLI9 N 50'LLL M C9'5609 N S£'LSL M 65'0109 N US'LSL M Ic'sgLs N ~8'0CL M EI'P89S N LC'5[L M 5T'C09S N 6C'~TL M 89'59US N 09'869 M 8U'E9CS N UC'069 M 8C'E85S N 80'589 M L5'505S M C9'Ct9 M T6'IEIS N 9V'S99 M 0U'IP0S N 8P'LS9 M 96'096~ N IL'8U9 M C5'0889 M 86'6C9 M C0'66L~ N 0C'IC9 M 09'LILP ~ SL'IE9 M 9I'9C9U M gI'gI9 M 86'I6C~ M IE'98S M 06'60C~ N 99'8LS SZL~NIGHOOD q V i M 0 Z I H 0 H ~'L£5 £'90C9 5'£LE 8'0~I9 5'LA5 6'LS09 5'££5 5'SL6S 5'LA5 0'C68S ~'ttE C'ITSS ~'LL5 6'65LS C'LL5 C'L8US C'LL5 L'90PS U'LL5 L'SPCS U'LLE 0'S9IS U'LL~ I'USOS U'LLE 5'C00S S'LL~ u'gL9u S'LL5 8'U6SP 9'LAg I'CISP 9'LAg 6'0CUP 9'LL5 9'SPCU ~ep q~ HL~HIZV LSIG Z H D $ 0 q O S'6069 AL' £'CS89 15' 6't6L9 S5' 0'5~£9 SC' L'S899 69' 0S'££E 95'9S 0'0066 99'9LE 56'~S 0'0086 ut'gL5 CI'9S 0'00£6 IL'9L5 88'SS 0'0096 IU'9L5 C9'SS 0'00S6 8'8E99 I'I£S9 I'CIS9 96' I'SSU9 86' 1'96C9 SI' 90'9£~ 00'SS 0'00U6 8A'SL~ 6U'US 0'0056 SI'9L5 lA'US 0'0056 0I'SL5 65'US 0'0016 8L'SL5 BP'CS 0'0006 L'9CC9 [~' S'LLE9 6C' 5'8159 CS' 0'6SI9 09' I'0019 AP' C8'SL5 [9'CS 0'0068 C6'SL[ C8'CS 0'0088 S8'~L5 UU'CS O'OOt8 8I'9L5 06'C5 0'0098 ~P'SL~ SS'CS 0'00S8 C'IP09 I9' S'~86S 90'I 5'~569 IS' S'9989 ~'608S 99' 88'SL5 SI'US 0'00~8 9S'9L5 88'CS 0'00C8 6L'SL5 Ct'US 0'0058 lU'9L5 LA'US 0'0018 96'9L5 LC'SS 0'0008 5'U69S SC' 9'9C9S C8' 9'6ASS OP' 0'CCSS 08' £S'9L~ IS'US 0'006L 90'9L5 C9'PS 0'00SA 5I'9L5 86'PS O'OOLL 9U'SL~ T9'SS 0'009L PO'SL5 5P'~S O'OOSL q~: 00I/'6ep HLdZ~ XLIHZAZ$ q~O I L%/ZA OZq- DOG Dap Sap q~ HLdZJ YMS~q~ ZdOqS HLHOM L6P©C6IIM~ :2eqmnM qok QqZIZ LLODIG~Z 'HZAOMHOM :MOILVDOq 0S-5 HZ~H~H LIM~ IdH :qqZM MOIL~HOqdXZ 'd'~ A Gyr oda t a D i r e c t i o na i Survey B.P. EXPLORATION WELL: MPI UNIT NUMBER 2-50 LOCATION: WORKOVER, ENDICOTT FIELD Job Number: AKl193G497 NORTH SLOPE ALASKA MEASURED I N C L AZIMUTH DEPTH ft deg deg DOG-LEG VERTICAL C L O S U R E SEVERITY DEPTH DIST AZIMUTH deg./100 ft ft deg 10000.0 56.21 277.38 10100.0 55.28 277.58 10200.0 56.05 277.24 10300.0 54.74 277.64 10400.0 55.48 276.74 .11 6965.1 .94 7021.4 .82 7077.8 1.35 7134.6 1.04 7191.8 10500.0 55.86 276.80 10600.0 56.06 276.57 10700.0 56.83 276.35 10800.0 56.60 275.94 10900.0 56.36 276.60 .38 7248.2 .27 7304.2 .79 7359.4 .41 7414.3 .60 7469.5 11000.0 57.22 277.53 11100.0 57.02 278.66 11200.0 55.77 279.66 11300.0 55.07 280.41 11400.0 54.67 280.44 1.16 7524.3 .97 7578.6 1.50 7633.9 .93 7690.7 .40 7748.2 11500.0 54.69 280.73 11600.0 54.40 280.32 11700.0 53.67 279.86 11800.0 53.26 280.76 11900.0 52.46 280.66 .24 7806.0 .44 7864.0 .82 7922.8 .83 7982.3 .80 8042.7 12000.0 52.48 280.65 12100.0 52.15 281.02 12200.0 51.58 281.30 12300.0 51.61 280.85 12400.0 50.86 281.77 .02 8103.6 .44 8164.7 .61 8226.5 .35 8288.6 1.04 8351.2 6389.8 277.2 6472.5 277.2 6555.0 277.2 6637.3 277.2 6719.4 277.2 6801.9 277.2 6884.8 277.2 6968.1 277.2 7051.7 277.2 7135.1 277.1 7218.7 277.1 7302.7 277.2 7385.9 277.2 7468.2 277.2 7549.8 277.2 7631.3 277.3 7712.6 277.3 7793.4 277.3 7873.7 277.4 7953.3 277.4 8032.4 277.4 8111.4 277.5 8189.9 277.5 8268.1 277.5 8345.9 277.6 Page H O R I Z O N T A L COORDINATES feet 798.01 N 808.77 N 819.41 N 830.06 N 840.32 N 6339.79 W 6421.74 W 6503.62 W 6585.23 W 6666.61 W 850.06 N 859.70 N 869.08 N 878.02 N 887.13 N 6748.61 W 6830.92 W 6913.72 W 6996.83 W 7079.70 W 897.42 N 909.24 N 922.50 N 936.84 N 951.64 N 7162.73 W 7245.87 W 7328.09 W 7409.16 W 7489.59 W 966.63 N 981.51 N 995.70 N 1010.07 N 1024.89 N 7569.80 W 7649.88 W 7729.57 W 7808.62 W 7886.94 W 1039.56 N 1054.43 N 1069.66 N 1084.71 N 1099.99 N 7964.88 W 8042.60 W 8119.77 W 8196.67 W 8273.13 W [S'0800I M I£'£0£I £9'~I00I M S6'089I ~'~66 M 00'~S9I ST'9£~6 M £~'9~9I 66'9086 M 58'66ST M 0t'9£t6 M 58'[LSI M 89'£6S6 ~ LL'LISI ~ I9'0[S6 N LT'06TI M £0'9TT6 N £9'59TI M IL'0L£6 N TI' M 9L'S656 ~I t6'S09I M 59'I556 N 0S'St£I M ~0'8~I6 N S9'IS£T M 6S'~006 N SA'00£I M 59'0C68 M M 99'6~88 M 69'£~5I M TS'68£8 N 66'T£5I M 5£'8TA8 ~ £6'015T M ~£'9998 N E~'06II M SA'ELS8 N £9'0tII M 00'86T8 N 0£'T~TI M 8I'£5~8 N 0£'££TT M 9~'8T£8 N 85'9TIT SZ,z~fHI CI'~OOD q ~f ,I, M 0 Z I H O H 9'6L5 I'T550I S'6LE L'SSIOI T'6L5 I'IS00I 9'6L5 E'6000I £'6£5 9'9£66 5'6L5 6'5986 I'6L5 £'88£6 0'6LE 0'£IL6 6'8L5 9'9£96 8'8L5 9'8S56 L'8£5 8'6£T6 9'8£E S'IOT6 S'8£5 £'8£5 5'8£E I'9606 I'8£5 T'IS06 1'8£5 6'£T68 0'8£E T'~A88 6'££E T'E088 8'££~ 6'L~£8 £'L£~ 9'SAS8 £'££[ I'66T8 9'££5 6'55T8 £'E966 69' T'9E86 9'8S£6 66' 9'1696 88' ££'I6E 9S'99 0'0069I 65'I6E £I'£T 0'0089I S8'I65 TI'AT 0'00£91 £S'16~ £9'L~ 0'00991 ST'T65 59'89 0'00S~T 8'S596 00'I I'19S6 8£' £'£6T6 ~9'I 5'9L£6 19' 88'065 8~'69 0'00~9I £9'I6~ 6I'0S 0'00£91 AT'065 TV'OS 0'005TI 0S'06[ 60'~ 0'0019I ST'06~ CT'CS 0'00091 6'~I£6 TT'T 0'SS56 99' 8'C616 00'T 9'T£T6 £8' T'8906 69' 66'065 58'£~ 0'006£1 6I'06~ 9S'5S 0'008£1 £T'065 T6'IS 0'00££I £9'685 SI'TS 0'009£T 0C'68E SC'OS O'OOS£T 5'T006 £8' I'6£68 TL'T S'~A88 9~' 9'T088 85'I E't££8 l£'I 06'885 C£'6T 0'009£1 I£'88~ £0'69 0'00££I 9£'£85 Tg'£T 0'005CI I0'A85 90'AT O'OOICI £1'985 Al'89 0'000£1 £'IA98 9'9098 0I'I 0'£TS8 6£'1 5'6£~8 8'TI~8 IS'S85 6£'6T 0'00651 58'T85 SO'OS 0'00851 96'£85 £6'0S 0'00£51 60'£85 I£'69 0'00951 09'[8~ 9I'0S 0'00S[I Sap j~ ~g 00I/'5ep 5ep 5ep ~g HI~HIZV ISIG Hid~G X6IH~A~S Hid~G H ~ S 0 q O q~DI~H~A ©~q-DO~ H~HIZ~ q O N I G~H~S~H kQtS~q~ ~dOqS HIHOM A6TD£6IIM~ :2eqmnH qop GqZI~ ILODIGMZ 'HZAOMHOM :NOIi~DOq 0S-~ HZ8H~H IIM~ IdH :qqZM MOIL~OqdXZ ~ £~'8£~0I ~ 6£'~T~0I ~ ~T'£~IOT M 6['88AT M ~S'Tg£T M SC'~££T S,W,T,~M I GHOOD q ~g ,T, M 0 Z I H 0 H · 6ep A8'6£~ 6'6£5 9'~£90I 8'6LE E'£9£0I £'6£~ £'96~0I H,T,flNI Z~g ,T, SI(I :zv Jg ~9'E£90I :esueJs!G 9'£tIOI £6'I I'£0IOI t0'I e'~£00I ~e'I :e~nsolD UOlq~qS IeUlS oo~/'Sep 88'06[ 69'S9 0'00~SI 9C'C6~ I6'99 0'00ISI £8'I6~ II'S9 0'000SI ~S~q~ ~dOqS H~HO~ 8ep Bep A6~©£6IIM~ :~eqmnH qof e j e p o ~ AD V SON 8.P, EXPLORATION WELL: IV[PI UNIT NUMBER 2-50 LOCATION' W0RKOVER, ENDICOTT FIELD NORTH SLOPE ALASKA AKl198G497 Definitive Z .q- r--t z ~000,0 1500,0 100N 500,0 500,0 N x, Botton hole ' /oca-~ed ' %~, ~,, .~s~o.o,oo .... . ........................... . ............... 18000,0 11000,0 10000,0 9000,0 8000,0 7000,0 6000,0 5000,0 4000,0 3000,0 8000,0 1000,0 0,0 EASTINO 1000,0 ~500,0 B .P. EXP 1..,0 RATI. O N W.l!.', L'I_,: MP 1 UiNI"[' iN U i 1} E 1!~, ~---50° LOCATION" 'WOI<t{OVEi-~ ~ ENDICOTT FIELD NORTH SLOPE ALASKA AKl193G497 Definitive ~000,0 500,0 1000,0 -500,0 0,0 1000,0 SO00,O 3000,0 4000,0 5000,0 6000,0 7000,0 8000,0 9000,0 10000,0 11000,0 1~000,0 13000,0 14000,0 15000,0 16000,0 17000,0 HEASURE3 DEPTH 0'00~ l~_I O'O00~I O'O00C;'[ 0'000~7'[ O'O00~I O'O00~I 0'000'['[ O'O000I 0'000~ 0'000~ 0'000/ 0'000~ 0'000~ 0'000~? 0'000~ 0'000~ O'O00'~,.~.,~..._~!'OU.0 0'0~ 0'0~ 0'0~ O'O.C, 0'08 0'0/_ 0'09 300,0 ?95,0 ~!90,0 285,0 aSO,O B.P. EXPLORATION WELL: MPI UNIT N'UMBER 2-50 LOCATION' WORKOVER, ENDICOTT FIELD NORTH SLOPE ALASKA AKl19SG497 Preliminary . .... .' ' ' : , .... ~"%%~.' Bo. o~'n0~ . ' . 275,0 ~70,0 ......... 265,0 260,0 255,0 250,0 500,0 1500,0 2500.0 3500,0 4500,0 5500,0 6500,0 7500,0 8500,0 9500,0 10500,0 11500,0 1$500,0 13500,0 14500,0 1%00,0 HEASURED DEPTH (Ftc) 16500,0 B.P. EXPLORATION WELL: MPI UNIT NUMBER 2-50 7.0 LOCATION: WORI(0VER, ENDICOTT FIELD NORTH SLOPE ALASKA AKi193G497 Definitive L~J __1 0,0 1000,0 2000,0 3000,04000,0 SO00,O 6000,07000,0 8000,0 9000,0 10000,0 11000,0 12000,0 13000,0 14000,0 15000,0 16000,0 17000,0 MEASURED DEPTH (Ct) ~su~g~H I~UozT~oH IeOOq mo~g p~eInoI~O se~uTp~ooo Ie~UOZ~OH uoT~soq P~H II~ mo~g p~InuI~0 ~nsoIO Mq~oM ~n~z oq ~Tq~I~H e~ ZH~LVAH~O MI1MIMIM :poq~M uoI~InoI~O GH~GGO~S WO~ :~oAa~ns 00:00:~I £6-~oM-0I :aqeG unH SS~£69©£6IIMV :~qmnM qof ~S~q~ ZdOqS HLHON GqZI~ L&ODIGNZ 'HZAOXHOM :NOILVOOq OS-~ HZ~MOM LINll IdH :qqZM MOILVHOTdXZ 'd'~ .zo~ XeA~ns ieuol ~oe~!C e~epo~X© ~f M £9'8££ M ~ SS'T[£ M 6S'9T M £['OL[ M S£'[T ~ AS'88T M SS'£ M 9~'AST M SS'S ~ ££'T£T M T6'£ · M 8~'60T M 89'E M ~S'06 ~ 6~'T ~ 60'££ ~ £9' ~ E5'9S ~ M 9C'T9 ~ SS' M 98'8E M M ES'ST M 50'T N 60'TT M ET'T M L6'S iii O0'T M EO'£ ~ fL' M £E'T N ES' M 0£' M Elz' M 90' bi 0£' M 9O M 9O N ~70' O'OOTE O'O00E O'O06T 0'008I o O' O' O' O' O'OOLT O'O09T O'OOST O'OOfT O'O0£T . O' O' O' O' O'OOET O'OOTl O'O00T 0'006 0'008 9STE 9SOE 9S6T 9S8T 0'00£ 0'009 O'OOS 0'00~ 0'00£ O'OOE O'OOT Sq~A~ZLNI 9SLT 9S9T 9SST 9SfT 9S£T 0'gsEI 0'9SIT 0'gsoT 0'9S6 0'9S8 0'gSA 0'9S9 0'9SS 0' 9Sfz 0'9SC 0'9SE 0'gST '~Z 00T £6'E IS'6AE 86'T ~6'SLE 9L'£ 9S'CLE 9E'C OE'£LE C9'~ SS'CAE TS'E 8L'£LE L6'T SC'CAE 9E'T ET'CAE 9~' £L' sg'~LE Eg'T 90'TLE 09'T 6L'sgE LE'T 06'S9~ 8£'T SL'89~ Ig'I 6~'0LE 88' ~£'~£E 8S' T8'ELE SE' L0'£6~ 0I' S8'~6T £0' 69'£9T SO' ~S'STC i~ 8E'IC L'SICE ~E'9E L'060E ST'EE T'T86T EL'SI £'9L8I 96'ST S'69LT 8£'£I T'999T 8£'TT L'£9ST £I'0I 6'I99I £L'6 ~'09CI SE'6 0'6SET ~6't 6'LSTT 9£'9 I'LSOT II'S S'9S6 ~£'£ E'9S8 £T'E T'9S£ 9E'T 0'9S9 TS' 0'9SS 85' 0'9S~ ET' 0'9S£ 60' 0'gsE SO' 0'9ST SZL~NIJ~OOD ~ ~ i N 0 Z I H 0 H q/ q~ q~DI&HZA 00l/'Sep Sap Sap q~ XLIHZAZS HLdZG ~Q{S~q~ ZdOqS HLHOM SSLL6~D£6ITM~ :2eqmnN qo£ GqZIS IiOOIGNZ 'HZAOMHOM :NOILVDOq 0S-~ HZ~H~N IIN~ IdH :qqZM A Gy r o da t ~ D i r ec t i o n a i Survey B.P. EXPLORATION WELL: MPI UNIT NUMBER 2-50 LOCATION: WORKOVER, ENDICOTT FIELD Job Number: AKl193G497TSS NORTH SLOPE ALASKA Page MEASURED INCL AZIMUTH DOG-LEG VERTICAL DEPTH SEVERITY DEPTH ft deg deg deg./100 ft 2436.1 31.87 281.48 2555.0 33.85 282.04 2677.9 37.31 282.21 2806.5 40.68 284.07 2939.2 41.41 284.93 SUB-SEA DEPTH ft 1.06 2356.0 2300.0 2.37 2456.0 2400.0 2.97 2556.0 2500.0 2.73 2656.0 2600.0' .67 2756.0 2700.0 HORIZONTAL COORDINATES feet 35.85 N 439.10 W 49.21 N 502.06 W 63.95 N 571.82 W 82.26 N 650.37 W 104.21 N 734.87 W 3072.9 41.83 284.11 3208.7 43.48 281.99 3350.3 46.45 282.26 3498.1 48.25 279.68 3649.0 48.69 279.55 .92 2856.0 2800.0 1.85 2956.0 2900.0 2.31 3056.0 3000.0 1.60 3156.0 3100.0 .39 3256.0 3200.0 126.72 N 820.68 W 147.52 N 910.10 W 169.01 N 1008.01 W 190.02 N 1114.75 W 208.72 N 1226.18 W 3802.2 50.13 280.02 3959.5 50.50 278.92 4114.3 48.92 278.70 4267.7 50.37 277.48 4427.3 51.76 279.12 1.27 3356.0 3300.0 .92 3456.0 3400.0 1.20 3556.0 3500.0 1.99 3656.0 3600.0 1.26 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Bop ~ZS-~S ~OILHZA ©Zq-©OG H~NIZ~ SSL£6UOC6TTM~ :~aqmnN qof G~ZIg LLODIGMZ 'HZAOMHOM :MOILED07 0S-5 ~Z~HDM ~IN~ IdH :7~ZM TS'££86 66'89£6 9£'6996 9~'S~96 06'~6 M 08'S~9I M ~'SSST M 90'£~ST N S£'66~I M 88'£S~T M A6'96~6 M A8'9AI6 M ~0'I906 ~ 9£'6f68 ~ fg'~f88 M £f'90fT M £I'~9£T M 66'0~£I M £8'~8~T ~ f6'8198 ~ T£'96£8 M T8'8L[8 N IS'gT~T M 0L'98IT M T~'99TT M AT'Alii M ~['TOTT [C'9918 09'I£08 86'£06L 69'CL£L 8£'8£9£ M IS'gt0I N I£'~90I M 0I'8[0I M [L'£00I 8£'009L [9'69C£ 8['II[t 0T'690L 69'8069 99'£96 80'816 06'T88 09'898 q ~ L M 0 Z I H 0 H 0'00£6 0'0096 0'0096 0'00T6 0'00£6 0'00~6 0'0016 0'0006 0'0068 0'0088 0'00£8 0'0098 0'0098 0'00TS 0'00£8 0'00~8 0'0018 0'0008 0'006£ 0'008£ O'OOLL 0'009£ 0'009£ O'OOT£ O'O0£L 0'99£6 66' 0'9996 96' 0'9996 98' 0'99T6 9T'T 0'99£6 98' ~S'T6~ TS'AT ['969~T 00'T6E 88'8f 6'SfffT S£'T6E T~'0S 6'T6~I 6~'06~ £9'I9 0'T£I~I ~9'06~ 99'C9 C'696CI 0'9916 Ag' 0'9916 ~6' 0'9906 0'9968 0'9988 99' 0~'06[ 89'[S 9'T08£I 96'68~ ST'TS ~'6£9£I [~'68~ £['09 £'08f£l 99'88[ 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88'06[ 69'S~ 0'00[SI 69'I6[ 0S'S9 ['SLISI 69'I6~ [9'9~ I'068~I I9'I6~ SI'L9 9'£9L9I q_,z ooY/'S~p H,T,dZQ X,I, IHZAZS ~I~fD I,T,~ZA ©Z~I - DO(:]: 6ep 8ep q~ HLdZ~ HL~HIZ~ qDMI GZH~SVZM ~MSV~V ZdOqS HLHOM SSLL6~D£6IIMV :~qmnM qof Q~ZI~ LLO~IQMZ 'HZAOMHOM :~OI~V00~ 0S-~ ~Z~M~M ~IMD IdM :~ZM MOI~VHOTdXZ X a ~ ~ n S i e,u o Y ~ ~ a ~ T C e q e p o ~ X D ~f WELL LOG TRANSMITTAL To: State of Alaska July 13, 1993 Alaska Oil and Gas Conservation Commission Attn: Larry Grant 3001 Porcupine Drive - 0~.~'~ Anchorage, Alaska 99501 MWD Formation Evaluation Logs - 2-50/U-08 RE: AK-RB-930614 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of: Paul Radzinski, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs / / 1 Blueline 1 Folded Sepia ~5 iq qz.~ 2" SSTVD Resistivity and Gamma Ray Logs: 1 Blueline 1 Folded Sepia Received: Date 5631 Silverado Way, Suite G · Anchorage', Alaska 99518 ° (907) 563-3256 · Fax (907) 563-7252 A Baroid Company MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: David W Job .~ date: Chairmar~.-~-' file: thru: Blair E Wondzell ~/.~o/~)_~ subject: Petr Insp Supervisor Petr Inspector June 29, 1993 061593.doc BOP Test- Doyon 15 BPX-DIU - 2-50/U-08 Endicott Field PTD 93-67 Tuesday, June 15, 1993: I traveled this date to BPX's 2-50/U-08 and witnessed the BOP test. As the attached BOP test report shows, there was 1 failure. This was repaired and tested OK. Summary: Tested BOP on Doyon 15; test time 3 hours - 1 failure. attachments STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: // Workover:~ DATE: Drlg Contractor: '~,._,~-,~// Rig No. /,,~ PTD # ~'~- Operator: ~-) ~/~' Rep.: Well Name: ~"~ / ~"-~ ~ Rig Rep.: ~.. Casing Size: / ~ -~//r~ ' Set (~ ~5~ 7,~' Location: Sec. c....~ (o T. /~_./~ R. /~,~/_~ Meridian Test: Initial Weekly Other MISC. INSPECTIONS: Location Gen.: Housekeeping: ~ (Gen) Reserve Pit ~_.. BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. ! '/ / / ! /, Visual t/ Well Sign' Drl. Rig /... Test Pressure VIUD SYSTEM: Alarm Tdp Tank ~/ · Pit Level Indicators ~ Flow Indicator ~ Gas Detectors ~ Test FLOOR SAFETY VALVES: Quan. Pressure P/F Upper Kelly I IBOP / , ,..~,'~)J J~ Lower Kelly/IBOP j J ,~:? Ball Type J ,~'~.~ Inside BOP / I - Test CHOKE MANIFOLD: Pressure P_,/F No. Valves /? I IY No. Flanges ~,~. J ~_.~ Manual Chokes ~ J - Hydraulic Chokes / ! ACCUMULATOR SYSTEM: System Pressure ~,~ ~,'~ J Pressure After Closure ~1 c~0 0 J ~' 200 psi Attained After Closure --> . minutes ~sec. System Pressure Attained ; ;~ minutes ~_~/ sec. Blind Switch Covers: Master: ~ Remote: · Nitgn. atl's: / ~ ~.~2~.. 5"o ~r~(.~ ,'~ 0 Psig. .- :. : . ....... .:-: .... Number of Failures '/ Test Time -.-:~ Hours Number of valves tested ~5" Repair or Replacement of Failed Equipment will be made within- ~ days""-':'. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 Distribution: odg-Well File c - OperJRig c - Database c - Tdp Rpt File c - Inspector STATE WITNESS REQUIRED? YES NO ~./ 24 HOUR N~OTICE GIVEN YES · ~ NO Waived By: ~..~ .._~ W~essed By: /~i. ,~.)., : F!-021L (Rev. 2/93) Boptst3 MEMORA ND UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION TO: David J~ Chairma~ THRU: Blair Wondzell 61:~o['~ P.I. Supervisor FROM: L~u Grimaidi Petroleum Inspector DA TE: JUNE 27 1993 FILE ]VO: QKHJF 1 AB.doc PHONE NO: 279-1433 SUBJECT: Rig~OPE inspection Doyon #15 BPX well#2-50\U-08 Endicott field PTD 93-67 SUN, PAY JUNE 27 1993 I made a Rig~OPE inspection of Doyon rig #15 drilling BPX well #2- 50\U-08 in the Endicott field. I found the rig to be in very good shape with all BOPE equipment to be in place and in apparent good operating condition. The hammer union's between the choke manifold and the pit skid are still in place and are due to be replaced during the next rig move. The rig was situated quite well considering the tight quarters afforded it on the Main Production Island. The area surrounding the rig was kept clean and orderly with adequate access provided for emergency equipment. I spoke with Steve Walls (BPX rep.) about notifying the inspector's of upcoming BOP tests which they have not been very consistent on, I was assured that this problem would be taken care of. SUMMARY; I made a Rig~OPE inspection on Doyon rig #15 in the Endicott field Atf, achmeni:: QKHJFiAB.XLS STATE OF ALASKA - ALASKA .LAND GAS CONSERVATION CO,, .~ISSION RIG / BPS INSPECTION REPORT OPERATION: Drilling X Workover ~Compl. UIC DATE: # Well Name 2-50\U-08 PTD# 93-67 Drig Contractor DOYON Rig# 15 Rep. LATCH Operator: BPX Rep. STEVE WALLS Rig Ph.# 659-6510 Location: Section 36 T. 12N R. 16-E M. U (A.) B.O.P. STACK YES NO N/A (C.) MUD SYSTEM YES NO N/A 1 Wellhead fig wkg press X 29 Pit level floats installed X 2 Stack wkg press X 30 Flow rate sensor X 3 Annular preventer X 31 Mud gas separator X 4 Pipe rams X 32 Degasser X 5 Blind rams X 33 Separator bypass X 6 Stack anchored X 34 Gas sensors X 7 Chke/kill line size X 35 Choke line connections X 8 All turns targeted ( chke & kill Ln.) X 36 Trip tank X 9 HCR valves (chke & kill bn.) X ii!i~:?i!!::iii'.iiiiiii:.'.~:.!': ;? INSPECTI0N ITEMS, . IN COMPLIANCE 10 Manual valves (chke & kill Ln.) X (D.) RIG FLOOR YES NO N/A 11 Connections (Flgd, Whd, Clamped X 37 Kelly cocks (upper, lower, iBOP) X 12 Drilling spool X 38 Floor valves (dart, ball, ect.) X 13 Flow Nipple X 39 Kelly & floor valve wrenches X 14 Flow monitor X 40 Drillers console (flow monitor, X 15 Control lines fire protected X flow rate indicator, pit level X ?:':!!!il ;:: iili! ?.; i! !! INSPE~ION:~ ~E~ iii!~,~:ii!:- i!iiiii i ;! ii! ?,i :: ::!i tN i COMPEIANCE?, i nd icato rs g a u g e s) X (B.) CLOSING UNIT YES NO N/A 41 Kill sheet up-to-date X 16 Working pressure X 42 Gas detection monitors X 17 :Fluid level X (H2S & methane) X 18 Operating pressure X 43 Hydraulic choke panel~ X 19 Pressure gauges X 44 Choke manifold X 20 Sufficient valves X ITEMS..:; ..... IN COMPLIANCE: 21 Regulator bypass X (E.) MISC. EQUIPMENT YES NO N/A 22 4-way valves (actuators) X 45 Flare/vent line X 23 Blind rams handle cover X 46 All turns targeted X 24 Driller control panel X (downstream choke lines) X 25 Remote control panel X 47 Reserve pit tankage X 26 Firewall X 48 Personnel protective equip, avail. X 27 Nitrogen power source (backup) X 49 All Drillsite Supervisors Trained X 28 Condition (leaks, hoses, ect.) X For Procedures X 50 H2S probes X 51 Rig housekeeping X REMARKS: Hammer unions stillsent in lines between choke manifold and pit skid RECORDS: Date of Last Rig / BPS Inspection Date of Last BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Properly Entered On Daily Record? YES 6/23/93 Kill Sheet Current? YES Distribution: orig - Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector AOGCC REP Louis R. Grimaldi OPERATOR REP: QKHJF1AB.XLS (Rev. 12/92) ,.. MEMORANDUM TO: David Johns~aff" Chairman THRU: Blair Wondzell P.I. Supervisor FROM: Lou Grimaldi ,~ gJ~ Petroleum Inspector S TA TE Or ALASKA ~s~ o~ ~uvz~ a]s co~vsg~ ~ rzo~ co~zsszo~ DATE: JUNE 27 1993 FILE NO: QKHJF1AB.doc PHONE NO: 279-1433 SUBJECT: Rig\BOPE inspection Doyon #15 BPX well#2-50\U-08 Endicott field PTD 93-67 SUNDAY JUNE 27' 1993 I made a Rig\BOPE inspection of Doyon rig #15 drilling BPX well #2- 50\U-08 in the Endicott field. I found the rig to be in very good shape with all BOPE equipment to be in place and in apparent good operating condition. The hammer union's between the choke manifold and the pit skid are still in place and are due to be replaced during the next rig move. The rig was situated quite well considering the tight quarters afforded it on the Main Production Island. The area surrounding the rig was kept clean and orderly with adequate access provided for emergency equipment. I spoke with Steve Walls (BPX rep.) about notifying the inspector's of upcoming BOP tests which they have not been very consistent on, I was assured that this problem would be taken care of. SUMMARY; I made a Rig\BOPE inspection on Doyon rig #15 in the Endicott field Attachment: QKHJF1AB.XLS ....... STATE OF ALASKA ALAS. . OIL AND GAS CONSERVATION COl~, RIG / BPS INSPECTION REPORT .JSION OPERATION: Drilling X Workover Compl. UIC DATE: # Well Name: 2-50\U-08 PTD# 93-67 Drig Contractor: DOYON Rig# 15 Rep. LATCH Operator: BPX Rep. STEVE WALLS Rig Ph.# 659-6510 Location: Section 36 T. 12 N R. 16-E M. U (A.) B.O.P. STACK YES NO N/A (C.) MUD SYSTEM YES NO N/A 1 Wellhead fig wkg press X 29 Pit level floats installed X 2 Stack wkg press X 30 Flow rate sensor X 3 Annular preventer X 31 Mud gas separator X 4 Pipe rams X 32 Degasser X 5 Blind rams X 33 Separator bypass X 6 Stack anchored X 34 Gas sensors X 7 Chke/kill line size X 35 Choke line connections X 8 All turns targeted ( chke & kill Ln.) X 36 Trip tank X 9 HCR valves (chke & kill Ln.) X ............ `~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~;~~~~~;~;~~~~~~~~~~~~~~~~~~~~~~~~~.~~~'~~~~~~~~~~~~~ ....,.....................;.~.;.,.......................;..?..;.;.;...........;........ ,?;..............................:.:.:.: ...... ....................... 10 Manual valves (chke & kill Ln.) X (D.) RIG FLOOR YES NO N/A 11 Connections (Flgd, Whd, Clamped X 37 Kelly cocks (upper, lower, IBOP) X 12 Drilling spool X 38 Floor valves (dart, ball, ect.) X 13 Flow Nipple X 39 Kelly & floor valve wrenches X '14 Flow monitor X 40 Drillers console (flow monitor, X 15 Control lines fire protected X flow rate indicator, pit level X (B.) CLOSING UNIT YES NO N/A 41 Kill sheet up-to-date X 16 Working pressure X 42 Gas detection monitors X 17 Fluid level X (H2S & methane) X 18 Operating pressure X 43 Hydraulic choke panel I X 19 Pressure gauges X 44 Choke manifold X 21 Regulator bypass X (E.) MISC. EQUIPMENT YES NO N/A 22 4-way valves (actuators) X 45 Flare/vent line X 23 Blind rams handle cover X 46 All turns targeted X 24 Driller control panel X (downstream choke lines) X 25 Remote control panel X 47 Reserve pit tankage X 26 Firewall X 48 Personnel protective equip, avail. X 27 Nitrogen power source (backup) X 49 All Drillsite Supervisors Trained X 28 Condition (leaks, hoses, ect.) X For Procedures X 50 H2S probes X 51 Rig housekeeping X REMARKS: Hammer unions stillsent in lines between choke manifold and pit skid RECORDS: Date of Last Rig / BPS Inspection Date of Last BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Properly Entered On Daily Record? YES 6/23/93 Kill Sheet Current? YES Distribution: orig - Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector AOGCCREP: LouisR. Grimaldi OPERATOR REP: QKHJF1AB.XLS (Rev. 12/92) .... STATE OF ALASKA - ALA~,,~ OIL AND GAS CONSERVATION COMMISS, APPLICATION FOR SUNDRY APPROVALS ., 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well__ Plugging __ Time extension __ Stimulate __ Change approved program x Pull tubing ~ Variance ~ Perforate ~ Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3218' NSL, 2317' WEL, SEC. 36, T12N, R16E, UM At top of productive interval 4930' NSL, 1810' WEL, SEC. 34, T12N, R16E, UM At effective depth N/A At total depth 5029' NSL, 2392' WEL, SEC. 34, T12N, R16E, UM 5. Type of Well: Development Exploratery Stratigraphic Service 6. Datum elevation (DF or KB) KBE - 56' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-50/U-08 9. Permit number 93-67 10. APl number 50- 029-22367 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Size Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal ~ 14. Estimated date for commencing operation 5/19/93 16. If proposal was verbally approved Name of approver feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth RECEIVF Alaska Oil & Gas Cons. Corr~rnissior', Anchorage Date approved Detailed operations program ~ BOP sketch 15. Status of well classification as: Oil Gas Service Water Injector Suspended. . 17. I hereby certify that the foreg/oing is true and correct to the best of my knowledge. Signed ' Title Drilling Engineer Supervisor ,[ Date ' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ~ Oog"J I Approval No ..... Plug integrity__ BOP Test Location clearance ,-m~ :'~ -~ I c~..~_ Mechanical Integrity Test~ Su"~equent form required 10- Approved by order of the Co-mmission David W. Johnston ~'"~Co"~missioner Date,.~"-'c~,/~--~_-~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MPI 2-50/U-08 9-$/8" Production Casing Contingency Back~round _ The MPI 2-50/U-08 well was originally approved with the 9-5/8" 47#/ft NT-80 & NT-95H casing set at 14529' MD/9816' TVD and a 7" 29#/ft NT-80 liner set at TD (15864' MD/ 10506' TVD). If hole conditions are favorable after drilling the 12-1/4" hole to 14529' MD/ 9816' TVD, approval is requested to allow drilling to TD (15864' MD/ 10506' TVD) and open hole logging prior to running 9-5/8" casing. Shown below are the revised casing design specifications for the deeper 9-5/8" setting depth. Production Casing 9-5/8", 47#,NT-80S and NT-95HS,NSCC Casing GRADE BURST COLLAPSE NT-80S 6870 4750 NT-95HS 8150 5080 PBYS (#) TJYS (#) 1086000 1161000 1289000 1273000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SITP 3900 Burst S.F. Burst S,F, 1.76 (NT-80S) 2.09 (NT-95HS) Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Mud Wt. (ppg) 10.2 Collapse S.F. Collapse S.F. Gas Grad. Collapse press TVD (FT) (psi/fi) at 8500' TVD 10506 0.1 3658 1.30 (NT-80S @ 8500' TVD) 1.12 (NT-95HS @ TD) Collapse press at TD 4522 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 47 15684 PBYS Tension S.F. 1.75 Tension S.F. 2.07 Mud Wt. String Wt. (#) 10.2 622227 TJYS 1.87 (NT-80S) 2.05 (NT-95HS) M,~¥ 2- -4 1993 Alaska Oil & Gas Cons, Commission Anchorage DOYON 15 13 5/8" 5,000 psi Stack 9.00 4.65 3.00 2.00 2.00 1.85 13.95 i/ RKB 1 KR TO BF R IFLO t, HYDRIL 5" PIPE RAM 11.32 14.32 BLIND RAM 4" Choke MUD CROSS 4 1/2" X 7" VARIABLE PIPE RAM R 16.32 20.17 39.05 4 FEET ABOVE GROUND LEVEL TO: M~Y 0~ '95 13:S~ BP D~ILLIMG BP EXPLORATION BP Exploration (Naska) inc. P.O. Box 196612 Anchorage, Alaska 99519-661 TELECOPY SATELLITE UNIT Name: Mike Minder Company: AOGCC Location: .......... An, ahoracj? ,, RECEIVED MAY 0 6 1993 Alaska 0ii & Gas Cons. Commission Anchorage Fax # 276-7542 FROM: Name & Ext.' Marian $1oan Department' Drilling NOTES: Let me know if you need any further detail! PAGES TO FOLLOW ..... 1 .... (Do not include cover sheet) SECURITY CLASSIFICATION PRIVATE ......... SECRET .... _ II .,. -- I .. 1 I IL . il ...... j J~ CONFIDENTIAL ;SATELLITE FAX MACHINE FAX# CONFIRM# -- _LI ....,. --: ' L __. ~ I~ --:- :-- ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 May 17, 1993 Russ Strickland Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Duck Island Unit/Endicott 2-50/U-08 BP Exploration (Alaska), Inc. Permit No. 93-67 Sur. Loc 3218'NSL, 2317'WEL, Sec. 36, T12N, R16E, UM Btmhole Loc. 5029'NSL, 2392'WEL, Sec. 34, T12N, R16E, UM Dear Mr. Strickland: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] RedrillFlllb. Type of well. Exploratory l-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 feet Endicott Field/Endicott Pool 3. Address 16. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 34893' Z ~z~ 3 ¢ 4. Location of well at surface !7. Unit or property Name 11. Type Bond(se, 20 AAC 25.o25) 3218'NSL, 2317' WEL, SEC. 36, T12N, R16E, UM Duck Island Unit/Endicott At top of productive interval 8. Well number Number 4930' NSL, 1810' WEL, SEC. 34, T12N, R16E, UM 2-50/U-08 2S100302630.277 At total depth 9. Approximate spud date Amount 5029'NSL, 2392' WEL, SEC. 34, T12N, R16E, UM 5/20/93 $200,000.00 12. Distance to nearest 13. Distance to nearest welt 14. Number of acres in property15. Proposed depth (MO and 'rvD) property line ADL 34636-5029' fe et 8' @ 680' MDfeet 2560 15684' MD/10506' TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (,,)(2)) Kickoff depth 500'feet Maximum hole angle ~.a4~ Maximum sudace 3900 psig At total depth (TVD) 10000774890 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Struct. Drive Pipe 94' 37 37' 131' 131' Drive 16" 13-3/8" 68# N~p4_i . BTC 2838' 37 37' 2875' 2756' 550 sx "E"/400 sx 'G"/250 sx 12-1/4" 9-5/8" 47# NT80S NSCC 12289' 36 36' 12325' 8497' 12-1/4" 9-5/8' 47# NT95H NSCC 2204: 12325 8497' 14529' 9816' 1400 sx Class G 8-1/2" 7' 29# NT-80 NSCC 1405i 14279 9667' 15684' 10506'. 350 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural --~ Conductor R~tEIVEL; Surface Intermediate i~f, A V - ~ Production ~:'~: Liner ..~iaska. 0il & Gas Cons, Perforation deptt~ measured ;Anchorage true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed reportF1 20 AAC 25.050 requirements[] 21. I hereby/~I,,~ ~~ ce~'fY that the'~f~r~is true}and correct to the best of my knowledge~--/?~ Si~)ned Title Drilling7 EnClineer Supervisor Date , ~Commission Use Only Permit Number APl number IApproval date See cover letter .~..:~-~'~ 50- CZ_~'- .?~.2-.¢~..~' J ~-*---/'-~_ ~__~ for other requirements Conditions of approval Samples required [] Yes ~] No Mud Io~-required [] Yes I~J No Hydrogen sulfide measures [] Yes ~ No Directional survey required [] Yes [] No Required working pressure for BOPE 1-12M' i~3M' ~5M; I-I10M; []15M; Other: Origina! q~r~ed By ,-,,.¢ by order of Approved by David VV. johnstoPt Commissioner me commlssitn Date,,.~'-/ Form 10-401 Rev. 12-1-85 Submit in triplicaf PROPOSED DRILLING AND COMPLETION PROGRAM ENDICOTT MPI 2-50/U-08 PROCEDURE 1) MIRU Doyon 15 Drilling Rig. N/U diverter and function test same. 2) Drill 16" hole to surface casing point. Run and cement surface casing. Nipple up BOPE and test to 250 psi (low test) and 5000 psi (high test). 3) P/U 12-1/4" BHA and RIH. Test casing to 3500 psi for 30 minutes. Drill 10' of new hole and perform leak off test. 4) Drill 12-1/4" hole to casing point. 5) MU and run 9-5/8" casing and cement as per well plan. 6) RIH w/8-1/2" BHA and drill through reservoir to TD. 7) RU and run E-line logs. 8) MU 7" liner on 5" DP. RIH to TD. Cement same. Set liner hanger and packer. Circulate excess cement from well bore. POH. 9) MU casing scraper and clean out 7" liner. 10) Run 4-1/2" L-80 tubing and packer assembly with SSSV. Freeze protect with diesel. Test tubing and casing to 4000 psi. 11) NU and tree and test to 5000 psi. Release drilling rig. Anticipated BHP: Maximum Anticipated Surface Pressure: Planned Completion Fluid: 3700 psi @ 10010' TVD SS 4100 psi @ 10270' TVD SS 4900 psi @ 10350' TVD SS 3865 psi 8.6 ppg Filtered Sea water Notes: a. The drilling program and surface system will conform to the regulations set forth in 20ACC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). c. Based on Endicott previous logs, no potential productive zones are anticipated above the Kekiktuk formation. d. No potential hazardous levels of H2S are anticipated in thi{~ Oil & Gas gons. gomrp.:sstoa- ' Anchorago MUD PROGRAM: MPI 2-50/U-08 MUD SPECIFICATIONS - SURFACE HOLE Mud Properties Mud Wt (ppg) Funnel Viscosity YP (lbs/lO0 ft2) 10 sec Gel (lbs/100 ft2) 10 min Gel (lbs/1 O0 ft2) PH APl Fluid Loss (cc/30 min) Hardness (mg/1) Spud to 2000' TVD At Csg Point 8.5-9.5 ppg 8.5-9.5 ppg +/- 300 sec/qt < 100 sec/qt 40-60 20-40 30-60 15-20 60-80 20-30 8.5-10.0 8.5-10.0 15-25 15-25 < 200 < 200 MUD SPECIFICATIONS - INTERMEDIATE HOLE Surface casing shoe to top of the Kekiktuk Formation: LSND Gel/Water System Mud Properties Mud Wt (ppg) YP (lbs/lO0 ft2) 10 sec Gel (lbs/1 O0 ft2) 10 min Gel (lbs/1 O0 ft2) PH APl Fluid Loss (cc/30 min) TO LCU At Csg Point 9.5-9.8 ppg 9.8-10.3 ppg 10-15 10-15 5-10 5-10 20-30 20-30 8.5-10.0 8.5-10.0 15-10 8-10 MUD SPECIFICATIONS - PRODUCTION HOLE Watered back LSND Gel/Water System from the intermediate hole Mud Properties Mud Wt (ppg) YP (lbs/1 O0 ft2) 10 sec Gel (lbs/100 ft2) 10 min Gel (lbs/1 O0 ft2) PH APl Fluid Loss (cc/30 min) 9.0-9.8 ppg 8-13 5-10 7-15 8.5-10.0 6-8 ~. ~99a MAY_5. ~,. Aias~a Oil .& Gas Cons. Commission ~nchorago SPUD mUD PROPERTIES Weight M~r~h Vi~. ..Yield Pt. _1 0 sec gel 1 0 min gel p_I_I_H Spud 8.7 300 40-60 30-60 60-80 9-10 Csg Pt. 9.5 1 O0 2_0-40 15-20 2_0-30 9-10 INTERMEDIATE HOLE MUD PROPERTIES APl F.L, 15-25 15-25 Depth Weight Y._~P 1 0 sec Gel 1 0 rain Gel APl F,L, p_F[ TUFFS 9.5 - 9.8 15 - 25 12- 15 25 - 30 <12 9.5 - 10.0 to Csg Pt. 9.8 - 10.5 20 - 30 12 - 15 25 - 30 6.0 - 8.0 9.5 - 10.0 At the top of the Tuffs, the fluid loss should be controled by the addition of Drispac SL, Resinex, and/or lignite. Polymer sweeps utilizing Biozan should be incorporated into the mud system to improve Iow shear rate rheology. PRODUCTION HOLE MUD PROPERTIES Depth Weight Y__~P 10 sec Gel 1 0 rain Gel APl F.L, p_l_F[ to TD '-- 9.2-9.4 15 - 25 12 - 15 ?_5 - 30 <8 9.5 - 10.0 The intermediate hole mud should be watered back to build the production hole mud. The fluid loss should be controlled with Drispac. Polymer sweeps utilizing Biozan should be incorporated into the mud system to improve Iow shear rate rheology. Alaska Oil & Ga:; r,,.,.,,.,,,~,,o, f.;orl~r:~issioi', 2-50/U-08 (MPI) Casing Design Specifications SURFACE CASING 13-3/8" 68#/FT NT-80CYHE BTC CASING BURST COLLAPSE PBYS (#) NT-S0CYHE-' ,.5'0'2-0' ~.L>ff-e 1556000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. TJYS (#) 15~5000 LOT (ppg) TVD (FT) SI PRESSURE 1 4 2756 20O6 Burst S.F. 2.50 Collapse Calculation Collapse rating based on losing retUrns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 2756 1361 Collapse S.F. I. 66 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 68 2875 PBYS Tension S.F. 9.31 Mud Wt. 9.5 ppg TJYS 9.48 String Wt. (#) 167113 , 2-50/U-08 (MPI) Casing Design Specifications Production Casing 9-5/8", 47#,NT-80S and NT-95HS,NSCC Casing GRADE BURST COLLAPSE NT-80S 6870 4750 NT-95HS 81 50 5080 PBYS (#) 1086000 1289000 TJYS (#) 1161000 1273000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SFTP 3900 Burst S.F. Burst S.F. I .76 (NT-80S) 2.09 (NT-95HS) Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Mud Wt. (ppg) 10.2 Collapse S.F. Collapse S.F. Gas Grad. Collapse press TVD (FT) (psi/ft) at 8500' TVD 9816 0.1 3658 I .30 (NT-80S @ 8500' TVD) 1.20 (NT-95HS @ TD) Collapse press at TD 4225 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) Mud Wt. 47 12394 10.2 PBYS TJYS Tension S.F. 2.21 2.36 Tension S.F. 2.62 2.59 String Wt. (#) 4917O3' (NT-80S) (NT-95HS) 2-50/U-08 (MPi) Casing Design Specifications PRODUCTION LINER 7", 29#,NT-80,NSCC Casing GRADE BURST NT-80 8160 COLLAPSE PBYS (#) TJYS (#) 7020 676000 746000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid SITP Fluid wt (ppg) back up (ppg) Burst Pressure 3900 9.5 9.7 3808 Burst S.F. 2.1 4 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 9.7 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse Press 9.7 9645 0.1 3900 Collapse S.F. I. 80 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 29 1134 Mud Wt. String Wt. (#) 9.7 27759 Tension S.F. PBYS TJYS 24.35 26.87 ' LF DIVERTEFI S¥$TF_M SUI-,.:"SCE .., ...... Two lines venting 90 deg. apart in directions that ensure sate down wind venting, and ex- tending to a point at least 100' Irom any potential source of ignition. _10' Full Opening Valves 35' or as required ' Dresser Sleeve I0" Diverter Une 1. All pipe connections 150¢ ANSI Flanges or welded c~nnedions and secured to prevent movemenL 2. Manual 10' full opening valves mechanically connected to ensure that one valve is fail-sate open at ali limes. ,.t. All tums are g0 deg. and t;~rgeted. Actuator10' Full opening ball valve w/Hydraulic .~ [;'~"? ~'"'-~¢ ~E "~1 ~'';¥t' ~ r't!,~,, ce I r MA'¥- ,5 199; Alaska 0il & Gas 00ns. 20' Divefler S~ol w/10' Side Oudet Anchorage MEM 1FJF20 MPI 2-50/U-08 CEMENT PROGRAM HALLIBURTON 13 3/8" SURFACE CASING CASING SIZE: 13 3/8", 68# CIRC. TEMP: 40°F LEAD CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx APPROX #SACKS: 550 THICKENING TIME: 5+ hfs MIX WATER: 11.63 gps TAIL CEMENT TYPE: Premium ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD: 1.16 ft3/sx APPROX #SACKS: 400 THICKENING TIME: 4 hrs MIX WATER: 5.00 gps TOP JOB CEMENT TYPE: Type 'C' Permafrost ADDITIVES: retarder WEIGHT: 15.6 ppg YIELD:0.94 ft3/sx MIX WATER: 3.5 gps APPROX #SACKS: 250 SPACER; 1 O0 bbls fresh water ahead of lead slurry. The mixing temperature should be as cold as possible to prevent acceleration-approximately 35-40F. CEMENT VOLUME 1. Lead slurry + 400 sx Tail slurry w/40% excess over gauge hole. 2. Top job volume 250 sx. 9 5/ 1" INTERMEDIATE CASING CASING SIZE: 9 5/8", 47# CIRC. TEMP 135°F LEAD CEMENT TYPE: Premium ADDITIVES: 0.5% CFR-3 (Dispersant) + 3% Econolite (Extender) + 0.4% Halad-344 (Fluid Loss) WEIGHT: 11.0 ppg YIELD:3.24 ft3/sx MIX WATER: 20.4 gps APPROX #SACKS: 1000 PUMP TIME: 5+hrs TAIL CEMENT TYPE: Premium ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.2% Halad-344 (Fluid Loss) + HR-5 (Retarder) WEIGHT: 15.8 ppg YIELD:I .15 ft3/sx MIX WATER: 5.0 gps APPROX #SACKS: 400 PUMP TIME: 4 hrs Retarder (HR-5) concentration will be based on actual lab tests. SPACERS: Pump 20 bbls ARCO Preflush; 50 bbls ARCO spacer @ 11 ppg. OTHER CONSIDERATIONS: Continuously mix lead and tail slurries. Displace at 12-1 5 bpm with rig pumps. CEMENT VOLUME 1. Lead Slurry based 90% of hole volume from top of tail slurry to surface casing shoe. 2. Tail Slurry to 1000' above shoe w/50% excess. 7" LINER CASING SIZE: 7", 29# CR-13 CIRC. TEMP: 140° F CEMENT TYPE: Premium . ADDITIVES: 0.2% CFR-3 (Dispersant) + 2% KCL (clay control) + 0.9% LAP-1 (Powdered Latex) + 0.3% Econolite (Extender)+ 0.4% Halad-344 (Fluid Loss) + 0.01gps Stabilizer 434B (Surfactant) + 0.01 gps D-AIR 3 (Defoamer) + HR-5 (Retarder) Retarder (HR-5) concentration to be based on actual lab tests. WEIGHT: 15.7 ppg YIELD:1.19 ft3/sx MIX WATER: 5.12 gps APPROX #SACKS: 350 THICKENING TIME: 3 hrs +45 min @surface PREFLmJSH: 20 bb!s ARCO pref!ush SPACER: 50 bbls ARCO spacer, weighted 1ppg above MW. OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 40cc or less. Displace @ 8-10 bpm. LINER CEMENT VOLUME 1. Open hole (8 1/2" X 7") annulus + 75% excess. 2. 7" 26# casing capacity below landing collar (80 feet). 3. 250' liner lap (9 5/8" x 7" liner) 4. 200' of cement on top of the liner in the 9 5/8" casing (without DP in .hole). Gas Cons, Oomm. isslot~ Anchorag~ SU::lddOH (3FI~ U::INIM::IOIS 008-9 Hq:]NOld-g HqS$¥©:IQ AO~] HOOd OO::IHQ-I. ::I5)F'I-IIHIN::IO II ~IH¥1,,N H::I::INOld -I. I:I::iSSVD::IO OOqlH(3 - [ H::INV::IqO (]FIN :qNOO ,,t, - 9 I- MO-I-IIHJ_- !. · . H::IQNVSqQ ::INOO ,,gl. - 800lAI::IQ - I- SH::]>tVHS ::i"lVHS MO-I-I -'IVlO.L J_QNVEIB =10 SJ_3S g :(3::lZiqlln IN::llAidl FI©::] HO,&::::IANO0 SDNII J OllVI/~aHO$ lid orliAI ~;1.# 911::1 NOAOO DOYON 15 13 5/8" 5,000 psi Stack 9.00 4.65 3.00 2.00 2.O0 1 85 13.95 r" RKB h KB TO RF RI(~ FLO HYDRIL 5-PIPE RAM ,J 11.32 ,. I 14.32 BLIND RAM MUD CROSS 4 1/2" x 7" VARIABLE PIPE RAM R 16.32 20.17 39.05 4 FEET ABOVE GROUND LEVEL AJask~ OJJ & Gas Cons. Comrnis.~ Anchorage I." KE PRUBHO. , BAY DRILLING Gas ,5'o,,-~s fJomm ' ~ncho,'aga ' 2-50/u-os VERTTCAL SECTZON VTEX ~6~ion at: N 80.34 W VO Scale · 1 inch = 2000 feet Oep Scale · 1 inch = 2000 feet OPawn · 09/24/92 Sreat Land flJ£actiona! ~£jl]_ing Marker Identification A) K8 8) KOP BUILD ~/~00 C) ~UILD ~.§/~00 D) BUILD ~/~00 E) ~3-3/8' CASING PT F) END 2/~00 ~UILD G) 9-5/8 CASING POINT i4529 9816 9863 53 H) TARGET ~4947 i0066 10199 53 I) TB 15684 ~0506 10790 53 ~300 1297 56 8 2100 2072 249 20 2875 2756 609 35 3767 339! ~230 53 MD BKB SECTN INCLN 0 0 0 0.00 5OO 50O 0 0 O0 O0 O0 50 34 34 34 3J 800O lO000 I I I I i I I i I I I i I I i I I I 0 lO00 iGLDD 1c192 250U08 8~,.25 8:53 AN 2) 2000 3000 4oo0 ,5000 6000 7o0o 8000 9000 ~ooso :l jooo ~2000 13000 " Section Departure , PRUDHOE BAY DR I L!_ I NG Narker Identification NO N/S A) KB 0 0 N B) KOP BUILD 1/100 500 0 N C) BUILD 1.5/100 1300 g N D) BUILD 2/100 2100 42 N E) 13-3/8' CASING PT 2875 102 N F) END 2/100 BUILD 3767 207 N GJ 9-5/8 CASING POINT 14529 1656 N H) TARGET 14947 1712 N I] TO 15684 1811 N E/W .55 245 6O0 1213 9723 10055 ]0637 2-5o/u-o8 PLAN VZE~ CLOSURE ..... : ~0790 ft at N 80.34 W DECLINATION.: 30.00 E SCALE ....... : 1 inch = 2000 feet DRAWN ....... :09/24/92 ,, Srea2 Land DJrectYona] OrY]]Jng 1000 0 1000 ~ t2000 11000 10000 9000 8000 7000 6000 5000 4000 3000 2000 {GLDD (c)92 ~OU08 B1.35 8:55 AM 2) lO00 0 lO00 <- WEST ' EAST -> TO: BP EXPLORATION bP Exploration (Alaska) Inc. P.O. Box 19661~ Anchorage, Alaska 99519-661 TELECOPY RECEIVED MAY ! v D93 &/as~ fli~ & 6as Cons. Commission SATELLITE UNIT Name:_ Mike Minder,_ · Company: AOGOC Location: ,,_ ~ A~ch°ra~e Fax Ct 276-7542 ~-~1 ,~,,.~.,.~.~.~.¢,~ - - FROM: Name & Ext.' Marian $toan Department: Drilling . __' i ----. NOTES: Let me know if you need any further detai!l PAGES TO FOLLOW __ II I . f · ~,ECU R I'1'Y CLASSIFICATION PRIVATE ~_- .... I I I T~ ' --' I1 . I (DO not include cover sheo. t) · I' 7 '"= I . I I " -- SECRET · CONFIDENTIAL =. ...... I ! SATELLITE FAX MACHINE · ~HiqqiH.(] d,~ OT :Ol E:6, OT HAY 10 '93 10:0~ B? DRiLLIHG 009 ~ ~0'~ M ~'08 N 609 00£g 9~£Z 0S*~ SA~ 009 N ~OI ~ ~.f'08 ~ 609 OOA~ 9~4~ O~'SE g~O~ 0 ~ ~ ~05 ~Z 9~ M ~C'00 ~ TT~ SS~Z TTg~ O0'~C 00£~ 0'~ ~ 90~ N 69 M ~'05 M gT~ TOC~ £~ 00'8~ 00~ 0'~ M Tg~ N T9 M ~'08 X 99~ ~6~ ~f~ 8~°9~ , O'Z M TgZ ~ 89 M ~E'08 N SDg OTIg 9~T~ O0'~g OOgZ ~'T M ~T~ ~ 9Z M ?f'08 M 9I~ ~GT 866T 0~'ST 000~ S'T M ~ST N TE M ~C'08 M ~RT L~gT. CggT 00'£T 00GT ~-'l M SST M 9~ M ~'08 N 8~I ~Ai £~£T OS"ST 00~T ooz/~ ~zns S'I a 88 M ST ~ ~£'08 N 68 6f~I S6~T 00'TI 00~I ~'I M OA R ~I M Df'OB ~ I£ O~Y 9G~I 0~'6 009I O'I M SS H 6 M 9C'08 M 99 Tt~I &6SI 00'~ 0DST 0'I M I~ ~ ~ ~ ~'0B H I~ ~0T ~60T 00'g 00TI o'I ~ T~ ~ ~ ~ ~'08 ~ ~ ~ 66~ O0'g O001 0'T M ~I N ~ M ~'08 R ~I ' ~ 00~ 00'~ 006 · 00t/S'T ~TIn~ 0'T M 8 M T M ~T'08 N B 99£ 00g 00'C 008 0'T M Z N 0 M ~'0g M I ~S 009 00'Z 009 O'O ~ 0 ~ 0 ~ l'¢'0S a 0 ~ 00S 00'0 00~ 00I/I ~Ia~ ~O~ 0'0 ~ 0 ~ 0 3 00'0 N 0 9~- 0 00'0 0 ~ 00'009~86S ~/gI/OT : ..... _ · Great Land Directional Drillinq, Co!ii.ion Avoidance knaly~is Existing Well min ft 151V20 170 2t2Q16 11~P25 262 266SAG~W 80 101J~gG 316 1050~0G ~97 109JiSG 285 lliSN4G ~7~ I17SN2G 255 l~lK25G !~7~20~ 218 129M~G 214 135025G 137P24G 165 l~gP17G I77 i41025G 175 143P26G 173 145Q25G 17i 147Q21G 170 149P21G 169' 155R25G 173 l~TRZ3G 1~ 153T22G 184 167T20G 19~ 169V19G 197 204M19G 250 ~0SJ22G 2~0 208K1~G 240 214016G' 208 216M16G ZOO 218L16G 190 2~0Li~G 222LI4G 170 228P19G 140 ~3OOQgG 130 232SN3G 120 234P14G I09 236014G 70 ~3~$N1~ 60 242P13G 246Q15G 17 2525i4G 8 254QI2G 13 258S09G 38 262QlTG 56 264U10G 62 268S17G 84 270U15G 27UU£~G 92 5015GTG Planne~ Woll: ~0UO8 Ctose~t ADDroach Sep Depth TVD ft 0 0 0 5o0 534 63 1 509 1 721 1 0 45~ 1 0 1 1 i97 564 1 29 1 0 5'66 i. i 0 1223 6~0 1047 1042 1126 0 11~5 2056 ~ad: MPI Field: NSLOPE 11:17: 51 warning band MD ft Start End 1354 1 i 11~4 0 143~ 1 1635 1 1960 21 15S5 0 1790 ! 1598 1 i691 I 14'$~ 0 24S 1419 0 0 0 50O 534 63. 499 1 508 509 ~$3 1 316 1 0 1 1 727 ! 89O 1 1 0 1 0 197 564 1 1 5~ 1 0 0 566 1 I 0 1 964 1043 0 ~052 25ft serious Start 21 0 End 1499 1049 1391 MAY 1~ ~=' I~:09 BR DRILLIHG R S 2-50_CI4T,,','XLS State: Well: Field: State Permit 2-50 / Endicott 9.-'.-'~67 Work Sheet: Date: Cemen! V~,¢ne £a/ctY~ion,~ 5,/'¢,/'35 Casing T Casing Size -lnche~ C~ing Length - Feet Hole Diamete[-Inches Cement- Sacks111 Cement-Yield 111 Cement- Cubic ft. 111 Cement- Cubic lt. 111 Cement-Sacks'112 Cement- Yield112 Cerrb~ - Cubic fl 112 Cement.- Cubic lt. 112 Cement-Sacks 113 Cement-Yield 113 Cement- Cubic It. 113 Cement- Cubic lt. 113 Cerr~mt - Cubic It. / Vol Cement- Fill Factor Conduct.or 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 tI:DIV/O! Sudace 13.375 2,838.000 16.000 550.000 .2.170 1,193.500 1,193.500 400.000 1.160 464.000 464.000 0.000 0.000 0.000 0.000 1,657.500 1.389 Liner 7.000 1,405.000 8.500 350.000 1.190 418.500 418.500 0.000 0.000 0.000 0.000 416;.500 2.338 C.~ing T..vpe Casing Size -Inches Casing Depth- Feet Hole Diameter -Inches Cement- Sacks 111 Cement-Yieldti1 Cement- Cubic ft. 111 Cement- Cul:4c fl 111 Cement- Sacks 112 Cement-Y'b=,ld 112 Cement.- Cubic ft. 112 Cement- Cubic it. 112 Cement- Sacks ti3 Cement-Yield113 Cement- Cubic It. 113 Cement-Cut~ ft. 113 Cement- Cubic It / Vol Cement-inte~¥al fl Top of Cement- Feet Intermediate 111 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIW~ tIDIV/O! Intemediate :1:12 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/O! tIDIV/O! Production 9.6;25 14,529.000 12.250 1,000.00 3.24 3,240.00 3,240.00 400.00 1.15 46600 480.00 0.00 0.00 0.00 0.00 3,700.00 11,814.23 2,714.8 Measured Depth Rinted 5/6/93 State: Alaska Borough: We~l: 2-50 / U-8 Field: Endicott St. Perm # 93-67 Date 5/6/93 Engr: M. Minder Casing Interval Interval Size Bottom Top Length 13,375 2756 37 2838 9.625 9816 36 14493 7 10506 9667 1405 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Description Descdption Description Tension Lbs Grade Thread Lbs 68 FSOCYHE BTC 0 47 NTSO-S NSCC 0 29 NTB0 NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 , A~ Mud Hydraulic Collapse Maximum Minimum Weight Gradient Gradient Pressure ppg psi/ft psi,fit psi 9.5 0.494 0.394 3900 10.3 0.536 0.436 3900 9.8 0.510 0,410 3900 0.0 0,000 -0,100 0 0.0 0.000 -0.100 0 0,0 0,000 -0.100 0 0.0 0.000 -0.100 0 0.0 0.000 .43.100 0 0,0 0.000 -0,100 0 0.0 0,000 -0.100 0 Yield psi BDF 493O 1.3 6870 1.8 8160 ;~.1 0 #DIV/0! 0 #DIVI0! 0 #DIV/0! 0 #DIVI0! 0 #DIV,'0! 0 #DIV/0! 0 #DNIOI Tension Strength K/Lbs K/Lbs TDF 192.984 1545 8.01 681.171 1086 1 40.745 676 16.59 0 0 #DIVKI.I 0 0 #DIV,,'0! 0 0 #DIV/0.1 0 0 #DIV~0! 0 0 #DIV/0! 0 0 #DIV/O~. 0 0 #DIV/0! Collapse Collapse Pr-Bot-Psi Resist. CDF 1086 2850 2.5'25 4276 4750 1.111 4303 7020 1.631 0 0 #DIV,'0! 0 0 #DIV/0! 0 0 #DN/0! 0 0 #DIV/0! 0 0 #DiViO! 0 0 #DIViO! 0 0 #DlViO! Page 1 ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE ( 2 ) _Loc ~2~/e~f ~f/~/,/~] [2 thru ['9 thru 13] ['10 & 13] L14 thru 22] (5) BOPE [23 thru 28] Company .4 P Lease _ . 2. 3. 4. 5. 6. 7. 8. . 10. 11. 12. 13. 14. 15. 16. 17. 18. !.9. 20. 21. 22. 23. 24. 25. 26 27. 28. YES NO Is permit fee attached ............................................... _~ Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... ~ Is well located proper distance from other wells ..................... . Is sufficient undedicated acreage available in this pool ............. ~ Is well to be deviated $ is wellbore plat included ................... · , Is operator the only affected party .................................. .~. Can permit be approved before 15-day wait ............................ ~, Does operator have a bond in force ................................... ~ ~ Is a conservation order needed ....................................... £ Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... '~ ..... Does well have a unique name & ngrnber ................................ /~ I s conductor st r i ng prov i ded ......................................... ~L Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. ~ Is Wil Wil Wil Is Is Is Is enough cement used to circulate on conductor & surface..'. ......... 1 cement tie in surface & intermediate or production strings ...... 1 cement cover al 1 known product ive horizons ..................... 1 all casing give adequate safety in collapse, tension, and burst. well to be kicked off from an existing wellbore ................... old wellbore abandonment procedure included on 10-403 ............. Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE~at%ached .... to ~ ~ ' Does BOPE have sufficient pressure rating -- test ~ps~g. Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... adequate wellbore separation proposed ............................. ~ a diverter system required ........................................ REMARKS (6) Other .,/pC .:'/:_:/~? ['29 thru 3i] (:7) Contact [32] (8) Addl geology' engineerinq' DWc ~~~ MTM,/~ RAD ~ .~'-_ I'~ RP . _ BEW JDH. Jq ~'~/1"~ LG ( rev 12/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLOP~TORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone n~rnber of contact to supply weekly progress data ...... Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ux X MERIDIAN' ~ TYPE' SM Red ri 1 I Inj ~ Rev 0 -rz u~--I Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simpiify finding information, informati;3n of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Tape. Subfile 2 is t. ype:. LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 2-50 / u-o8 500292236700 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 04-JAN-94 6001.04 HARPER/KOENN G. MCBRIDE 36 12N 16E 3218 2317 56.00 10.00 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 14719.5 14729.0 14741.5 14806.0 14808.0 14809.0 14840.0 14856.5 14875.0 14880.0 14932.5 14933.0 14934.0 2435 GRCH 1 7 18-JUL-93 ATLAS WIRELINE SERVICES LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: GRCH 14720.0 14729.5 14742.5 14807.0 14809.5 14810.5 14840.5 14857.0 14876.0 14881.0 14934.5 14935.0 14935.5 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 9.625 15528.0 47.00 PRODUCTION STRING 4.500 14900.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS 14937.0 14943.0 14943.5 14996.5 14999.5 15002.5 15015.0 15015.5 15016.0 $ REMARKS: 14938.5 14944.0 14944.5 14997.0 15000.0 15003.5 15016.0 15017.0 15017.5 PDK-100/GR Log. LOG TIED INTO CNL RUN 18-JUL-1993. WELL SHUT-IN PRIOR TO LOGGING. LOGGING PROGRAM ORGANIZATION: 1. LOGGED BASE SEAWATER PASS 1 - 60 BBLS BEHIND PIPE. 2. LOGGED BASE SEAWATER PASS 2 - 50 BBLS BEHIND PIPE. 3. LOGGED BORAX PASS 1 - 50 BBLS BEHIND PIPE. 4. LOGGED BORAX PASS 2 - 100 BBLS BEHIND PIPE. 5. LOGGED FLUSH PASS 1 - 140 BBLS BEHIND PIPE. 6. LOGGED FLUSH PASS 2 - 40 BBLS BEHIND PIPE. A DIFFUSION CORRECTED SGMA CURVE IS INCLUDED FOR BOTH BASE SEAWATER PASSES. THE CURVE IS NAMED SGNT AND WAS CORRECTED WITH THE FOLLOWING PARAMETERS: BOREHOLE SIZE = 8" CASING SIZE = 7" SALINITY = 25,000 PPM CASED HOLE GAMMA RAY FOR DEPTH MATCHING DOWNLOADED FROM BP EXPLORATION UPS/CSS ON 03-JAN-94. THE CASED HOLE GAMMA RAY IS FROM A CN/GR LOGGED 18-JUL-93 ON MARKED LINE. THIS GAMMA RAY IS THE DEPTH REFERENCE FOR THIS WELL. SHIFT PROCEDURE AS FOLLOWS: 1. FIRST PASS GAMMA RAY DEPTH MATCHED TO PREVIOUS CASED HOLE REFERENCE GAMMA RAY. 2. FIRST PASS SGMA DEPTH MATCHED TO "SHIFTED" FIRST GAMMA RAY. 3. ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4. ALL SUBSEQUENT SGMA (PDK) PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS SGMA. / ? ?MATCH1A. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 1 DEPTH INCREMENT: 0. 5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 14738.0 PDK 14750.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH SGMA 14759.5 14760.5 14765.5 14766.0 14770.0 14771.5 14803.5 14805.0 14805.5 14807.5 14809.0 14811.5 14815.0 14817.0 14826.5 14827.0 14837.0 14838.5 14840.0 14840.5 14856.5 14857.0 14872.5 14872.0 14875.0 14876.0 14880.0 14881.0 14893.5 14894.5 14899.0 14899.0 14903.5 14904.5 14932.5 14934.0 14937.5 14938.5 14948.5 14949.5 14967.5 14969.0 14996.5 14997.0 14999.5 15000.0 15002.5 15003.5 15011.5 15012.5 15023.0 15024.0 15045.0 15046.5 15050.5 15052.0 15071.0 15072.0 $ REMARKS: for each pass in separate files. STOP DEPTH 15050.0 15062.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASE SEAWATER PASS 1. ALL PDK CURVES WERE SHIFTED WITH SGMA. GRCH WAS DEPTH MATCHED TO CASED HOLE REFERENCE GAMMA RAY. / ??MATCH1B. OUT $ CN : BP EXPLORATION WN : 2-50 / U-08 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS 15 SGNT PDK 68 1 CU 16 PHI PDK 68 1 PU-S 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 55 Tape File Start Depth = 15080.000000 Tape File End Depth = 14700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12938 datums Tape Subfile: 2 233 records... Minimum record length: 62 bytes Maximum record length: 958 bytes ~Tape Subfile 3 is ~ype: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 14738.0 14750.0 BASELINE DEPTH GRCH 14700.0 14700.0 14720.0 14729.5 14743.5 14744.5 14744.0 14748.5 14750.5 14749.0 14755.5 14760.0 14759.5 14769.5 14770.5 14776.0 14776.0 14777.5 14778.5 14779.5 14780.0 14780.5 14782.0 14783.0 14791.5 14791.5 14792.5 14792.5 14793.5 14793.0 14798.0 14798.5 14803.5 14803.0 14806.0 14805.5 14810.0 14810.0 14811.0 14811.5 14813.5 14814.5 14819.0 14820.0 14827.0 14826.5 14837.0 14837.0 14838.5 14839.5 files. STOP DEPTH 15050.0 15062.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 14719.5 14729.0 14745.5 14750.5 14755.5 14769.5 14770.0 14778.0 14779.0 14779.5 14780.0 14781.0 14782.5 14783.0 14798.0 14799.0 14811.5 14812.5 14814.5 14815.0 14819.5 14820.0 14838.5 14839.0 14840.0 14841.0 14842.0 14843.0 14846.5 14847.5 14852.0 14856.5 14860.0 14860.5 14874.5 14875.0 14875.5 14881.5 14882.5 14890.0 14891.0 14895.5 14904.5 14918.0 14921.0 14922.0 14922.5 14924.0 14925.0 14925.5 14926.0 14927.0 14928.0 14933.0 14935.5 14936.0 14936.5 14937.0 14939.5 14940.5 14942.0 14943.0 14943.5 14944.5 14948.0 14953.5 14962.5 14968.0 14973.0 14975.5 14982.5 14993.5 15000.0 15001.0 15001.5 15003.0 15003.5 15007.0 15011.0 15011.5 15012 · 0 15012.5 15014.0 15015.0 14846.5 14847.0 14852.0 14856.0 14875.5 14882.5 14883.0 14896.0 14934.0 14937.0 14948.0 14962.5 14968.0 15000.0 15001.5 15007.5 15011.5 15012.5 15016.0 14840.0 14841.0 14841.5 14842.0 14859.0 14860.5 14875.0 14876.0 14890.5 14891.0 14904.5 14919.0 14922.0 14922.5 14923.5 14925.0 14925.5 14926.0 14927.0 14928.0 14928.5 14936.0 14936.5 14937.5 14940.0 14940.5 14942.0 14942.5 14943.5 14944.5 14954.0 14973.5 14975.5 14982.5 14993.0 15000.5 15001.5 15003.0 15004.0 15012.0 15012.5 15013.0 15014.5 15015.0 po~ SlO dKA dAA q$6uaq aZTS S-~6 I 89 HG~ IH~ ~O I 89 HG~ ~NDS S~D I 89 HG~ SS nD t 89 HG~ ~O I 89 H~ ¥~4DS I 89 HG~ NIH I 89 HG~ SDIH I 89 H~ HO~F~t I 89 H~ 0~ ~O I '89 H~ ~S~ S~D I 89 HG~ Sq ~O I 89 H~ S~SD S~D I 89 HG~ S~D I 89 H~ I 89 HG~ ~I~ I~D I 89 HG~ HDH9 ssTu~ saldm~s apoo IOOA s=eN 9I II OI 6 8 9 I :S~AInD 9I · ~ :GI gsdap H~nfH~ HH~ HAdHG HNO ( ~79 #HcIX,T,) (]HOOHH ,T.k~q~O~I HdOqS H,~,HON : N/IOD ,~J, ODIGNH : N~ 80-fl / 0~-Z : NM NOIA%C~OqdXH dM : ND &no- ~ZHOAkndZZ/ 'k~49S H~IM GH~IHS HHHM SHAHaD HG~ 'g SS~d HHI~MYHS 0'080SI g'££0~I 0'Ct0gI 0'g£0gI ~'890gI 0'9~0~I ~'0~0gI 0 '0~0~I g'£C0gI ~ '~C0~I 0 'gC0gI 0'~C0~I g'IC0§I 0'610gI 0'SI0§I g'910~I :S~H 0'080SI g'0£O~I 0'0L0gI 0'690~I 0'890~I 0'9~0~I g'6~0~I 0'6C0~I 0'tZ0~I 0'~£0~I 0'~C0~I 0'CCO~I 0'IC0~I ~'SI0~I 0'SI0~I 0'gI0~I * DATA RECORD (TYPE# 0) Total Data Records: 55 958 BYTES * Tape File Start Depth = 15080.000000 Tape File End Depth = 14700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12938 datums Tape Subfile: 3 202 records... Minimum record length: 62 bytes Maximum record length: 958 bytes 64 Tape Subfile 4 is ~ype: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 14740.0 14752.0 STOP DEPTH 15050.0 15062.0 (MEASURED DEPTH) BASELINE DEPTH 14700.0 14720.0 14748.0 14760.0 14765.5 14766.0 14767.0 14768.0 14770.0 14775.0 14775.5 14780.0 14780.5 14781.5 14782.5 14790.0 14800.5 14801.0 14803.5 14805.5 14810.0 14813.5 14815.5 14817.5 14819.0 14819.5 14820.5 14840.0 14840.5 14841.0 14842.0 14843.0 14846.5 14851.0 14851.5 14857.5 14861.5 GRCH 14700.0 14748.0 14759.5 14776.0 14790.0 14803.5 14805.5 14810.5 14813.0 14815.0 14847.0 14852.0 in separate files. EQUIVALENT UNSHIFTED DEPTH SGMA 14720.0 14765.5 14766.5 14767.5 14768.0 14770.0 14775.5 14780.5 14781.5 14782.5 14783.0 14801.0 14802.0 14818.5 14819.5 14820.0 14820.5 14840.0 14841.0 14841.5 14842.0 14843.0 14851.5 14858.0 14862.5 14862.0 14868.5 14872.5 14873.0 14873.5 14890.0 14891.0 14894.5 14895.5 14896.0 14898.5 14899.5 14903.5 14904.0 14913.0 14913.5 14918.5 14926.0 14926.5 14927.5 14928.5 14932.0 14935.5 14936.5 14937.0 14937.5 14938.5 14939.5 14940.5 14942.5 14943.5 14952.5 14953.5 14955.5 14959.5 14962.5 14968.0 14971.0 14971.5 14972.0 14973.0 14973.5 14976.0 14996.0 14999.5 15002.5 15003.5 15007.5 15010.0 15010.5 15012.5 15014.0 15014.5 15018.5 15023.5 15036.5 15041.5 15045.5 15046.0 15046.5 14873.5 14899.5 14904.0 14933.5 14937.5 14938.0 14939.0 14959.5 14962.5 14968.0 14996.0 14999.5 15008.5 15014.0 15015.0 15023.5 15046.5 14863.0 14869.0 14873.5 14874.5 14891.0 14891.5 14895.0 14895.5 14896.5 14899.5 14903.5 14914.5 14915.0 14919.0 14926.5 14927.5 14928.5 14929.0 14936.0 14936.5 14937.0 14938.0 14940.0 14940.5 14942.5 14943.0 14952.5 14953.5 14956.0 14971.5 14972.5 14973.0 14973.5 14974.0 14976.0 15002.5 15004.0 15010.5 15011.5 15013.5 15019.0 15037.0 15042.5 15046.5 15047.0 15047.5 15056.0 15060.0 15069.0 15070.0 15070.5 $ REMARKS: 15061.0 15057.0 15072.5 15073.5 15074.0 BORAX PASS 1; 50 BBLS BEHIND PIPE. ALL PDK CURVES WERE SHIFTED WITH SGMA. / ??MATCH3A. OUT /??MATCH3B. OUT $ CN : BP EXPLORATION WN : 2-5O / U-08 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 MSD PDK 68 1 CU 4 8 RATO PDK 68 1 4 9 RBOR PDK 68 1 4 10 RICS PDK 68 1 4 11 RIN PDK 68 1 4 12 SGMAPDK 68 1 CU 4 13 SGMB PDK 68 1 CU 4 14 SS PDK 68 1 CPS 4 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 48 Tape File Start Depth = 15080.000000 Tape File End Depth = 14700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet SagKq 996 :gSBUaI paooaa m-nm~x~ sa~Xq E9 :g~BuaI paooaa mnm~u~ · --spaooaa ~8I ~ :aI~qns s~n~p ~~ 89 :apoo daH :Xa~m~ns 6u~pooap apoD uo~guasaadaa SIq Tape Subfile 5 is ~ype: LIS FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 14722.0 14734.0 STOP DEPTH 15050.0 15062.0 (MEASURED DEPTH) BASELINE DEPTH 14700.0 14741.5 14747.5 14754.0 14756.0 14757.0 14758.0 14771.5 14775.5 14778.5 14782.0 14783.0 14783.5 14790.0 14797.5 14801.0 14802.0 14803.0 14803.5 14804.0 14808.0 14809.5 14810.5 14811.5 14812.5 14813.0 14813.5 14818.5 14819.5 14820.0 14821.0 14821.5 14825.0 14832.0 14835.0 14836.0 14837.0 GRCH 14700.0 14742.0 14747.0 14758.0 14775.5 14784.0 14791.5 14797.5 14803.0 14804.0 14809.0 14811.0 14813.0 14825.0 14837.0 in separate files. EQUIVALENT UNSHIFTED DEPTH SGMA 14754.0 14756.0 14757.5 14772.0 14779.5 14783.0 14783.5 14801.5 14803.0 14804.5 14805.5 14811.0 14811.5 14812.5 14814.0 14814.5 14819.5 14820.0 14820.5 14821.0 14821.5 14832.5 14835.5 14836.0 14838.0 14846.5 14847.0 14848.0 14850.5 14854.0 14869.5 14872.5 14875.5 14876.0 14876.5 14877.0 14889.5 14890.0 14891.0 14893.0 14893.5 14894.0 14894.5 14895.5 14896.0 14899.5 14900.5 14901.0 14912.5 14919.0 14919.5 14920.0 14924.0 14925.0 14925.5 14927.5 14928.5 14932.5 14941.5 14942.5 14943.5 14944.0 14947.5 14962.5 14968.0 14970.5 14971.0 14973.5 14975.5 14978.0 14978.5 14980.5 14986.0 14993.5 14998.0 14998.5 15002.5 15003.5 15012.5 15013.5 15014.0 15023.5 15028.5 15029.0 14846.5 14847.5 14848.5 14877.0 14878.5 14890.0 14893.5 14895.0 14895.5 14901.5 14913.0 14933.5 14947.5 14962.5 14968.0 14970.0 14970.5 14978.0 14986.5 14993.5 14998.0 14999.0 15013.0 15013.5 15014.0 15023.5 14838.0 14851.0 14854.5 14869.5 14872.0 14876.5 14877.5 14891.0 14891.5 14894.0 14894.5 14895.5 14896.5 14900.0 14900.5 14901.0 14919.5 14920.0 14921.0 14925.0 14925.5 14926.5 14928.5 14929.0 14942.0 14942.5 14943.5 14944.5 14974.0 14975.5 14978.0 14979.0 14981.0 14993.5 15002.5 15004.0 15029.0 15030.0 15045.5 15055.0 15056.5 15069.5 15070.5 15071.0 15071.5 15080.0 $ REMARKS: 15~45.5 15056.0 15057.0 15080.0 15070.5 15071.0 15071.5 15072.0 BORAX PASS 2; 100 BBLS BEHIND PIPE. ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH4A. OUT / ? ?MATCH4 B. OUT $ CN : BP EXPLORATION WN : 2-50 / U-08 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 48 Tape File Start Depth Tape File End Depth = 15080.000000 = 14700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 24354 datums Tape Subfile: 5 187 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 14740.0 14752.0 BASELINE DEPTH GRCH 14719.5 14720.0 14720.0 14729.5 14756.5 14765.5 14766.0 14766.5 14767.5 14768.0 14768.5 14791.0 14791.5 14801.0 14801.5 14804.5 14805.5 14813.0 14814.0 14819.5 14820.5 14841.5 14842.5 14854.5 14855.5 14855.0 14856.5 14857.5 14858.0 14859.0 14860.0 14861.0 14861.5 14862.5 14870.0 14872.5 14873.0 14875.0 14875.0 14877.0 14876.0 14877.5 14878.5 14880.0 14879.0 STOP DEPTH 15050.0 15062.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 14720.0 14729.5 14757.0 14766.0 14767.0 14767.5 14768.0 14768.5 14769.5 14802.0 14803.0 14814.5 14815.0 14820.5 14821.0 14842.0 14842.5 14855.0 14855.5 14856.5 14857.5 14858.5 14859.5 14860.0 14860.5 14861.0 14863.0 14870.0 14872.5 14880.0 14889.0 14890.0 14890.5 14891.5 14893.0 14898.5 14899.0 14900.0 14904.0 14919.5 14920.0 14925.0 14925.5 14927.0 14928.0 14929.0 14932.5 14933.5 14937.0 14943.5 14944.5 14948.5 14953.0 14957.0 14959.0 14962.0 14970.5 14971.0 14972.5 14973.5 14984.5 14985.5 14988.0 14993.0 14996.0 14997.0 14997.5 15003.0 15003.5 15005.5 15006.0 15012.0 15012.5 15013.5 15014.0 15014.5 15019.5 15020.0 15020.5 15033.5 15039.5 15049.5 15051.5 15056.0 15065.5 15068.0 15069.5 15071.0 15071.5 $ 14890.0 14895.5 14900.5 14904.0 14935.0 14935.5 14939.0 14996.0 14997.0 14998.0 15006.0 15007.0 15013.0 15014.0 15015.5 15056.5 15066.0 15072.0 14891.5 14892.0 14892.5 14900.0 14900.5 14920.0 14921.0 14926.0 14927.0 14928.5 14929.0 14929.5 14944.0 14944.5 14948.5 14953.5 14958.0 14960.0 14962.5 14971.0 14972.0 14973.5 14974.0 14985.0 14985.5 14988.0 14993.5 15003.5 15004.5 15014.5 15015.0 15020.0 15020.5 15021.0 15034.0 15040.5 15050.5 15053.0 15057.5 15069.0 15070.0 15071.5 15072.0 REMARKS: FLUSH PASS 1; 140 BBLS BEHIND PIPE. ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH5A. OUT / ? ?MATCH5B. OUT $ CN : BP EXPLORATION WN : 2-50 / U-08 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 MSD PDK 68 1 CU 4 8 RATO PDK 68 1 4 9 RBOR PDK 68 1 4 10 RICS PDK 68 1 4 11 RIN PDK 68 1 4 12 SGMA PDK 68 1 CU 4 13 SGMB PDK 68 1 CU 4 14 SS PDK 68 1 CPS 4 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 56 * DATA RECORD (TYPE# 0) Total Data Records: 48 966 BYTES * Tape File Start Depth = 15080.000000 Tape File End Depth = 14700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35770 datums Tape Subfile: 6 Minimum record length: Maximum record length: 178 records... 62 bytes 966 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 14740.0 14752.0 STOP DEPTH 15050.0 15062.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 14719.5 14720.0 14720.0 14765.0 14765.5 14775.5 14777.5 14784.0 14785.0 14794.5 14795.0 14796.0 14797.0 14797.5 14803.5 14804.0 14806.0 14807.0 14818.5 14820.0 14827.0 14827.0 14838.5 14842.0 14843.0 14843.5 14851.5 14854.5 14855.0 14855.5 14855.5 14856.5 14861.5 14862.0 14869.5 14872.5 14873.0 14873.0 14874.5 14875.0 14876.0 14891.5 14893.5 in separate files. EQUIVALENT UNSHIFTED DEPTH ......... SGMA 14720.0 14765.0 14766.0 14776.0 14778.5 14785.0 14785.5 14795.0 14796.0 14797.0 14797.5 14798.5 14804.5 14805.5 14807.5 14808.0 14819.5 14820.0 14838.5 14841.5 14842.0 14842.5 14851.5 14854.5 14855.0 14856.0 14862.0 14862.5 14869.5 14872.0 14875.0 14876.0 14893.5 14894.5 14895.5 14900.0 14903.5 14904.0 14913.0 14913.5 14914.0 14915.0 14932.0 14933.0 14940.0 14973.5 14975.5 14977.5 14978.5 14995.5 15005.0 15009.0 15009.5 15012.5 15013.5 15014.0 15014.5 15015.0 15016.5 15037.0 15039.0 15056.0 15056.5 15065.5 15068.0 15069.0 15071.0 15071.5 $ REMARKS: 14895.5 14896.0 14895.5 14897.0 14896.0 14900.0 14904.0 14904.0 14914.0 14915.0 14915.5 14916.0 14934.0 14933.0 14933.5 14940.0 14974.0 14976.5 14978.5 14979.0 14996.0 15005.5 15009.5 15010.5 15013.5 15014.5 15015.0 15015.5 15015.5 15017.5 15038.0 15040.5 15057.5 15057.0 15066.0 15069.0 15069.5 15071.5 15072.0 15072.0 FLUSH PASS 2; 40 BBLS BEHIND PIPE. ALL PDK CURVES WERE SHIFTED WITH SGMA. /??MATCH6A.OUT /??MATCH6B. OUT $ CN : BP EXPLORATION WN : 2-50 / U-08 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 56 * DATA RECORD (TYPE# 0) Total Data Records: 48 966 BYTES * Tape File Start Depth = 15080.000000 Tape File End Depth = 14700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35770 datums Tape Subfile: 7 155 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile $ is type: LIS FILE HEADER FILE NUMBER: 7 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.2500 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS GRCH PDK $ REMARKS: 1 1, 2 AVERAGED PASS. BASE SEAWATER PASSES 1 & 2 WERE AVERAGED. $ CN : BP EXPLORATION WN : 2-50 / U-08 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PNAV 68 1 GAPI 4 2 BKL PNAV 68 1 CPS 4 3 BKS PNAV 68 1 CPS 4 4 BIF PNAV 68 1 CPS 4 5 CSLS PNAV 68 1 CU 4 6 LS PNAV 68 1 CPS 4 7 MSD PNAV 68 1 CU 4 8 RATO PNAV 68 1 4 9 RBOR PNAV 68 1 4 10 RICS PNAV 68 1 4 11 RIN PNAV 68 1 4 12 SGMA PNAV 68 1 CU 4 13 SGMB PNAV 68 1 CU 4 14 SS PNAV 68 1 CPS 4 15 SGNT PNAV 68 1 CU 4 16 PHI PNAV 68 1 PU-S 4 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 64 * DATA RECORD (TYPE# 0) 958 BYTES * Sa~Kq 8~6 :q~6uaI paosaa mn~x~H saSKq E9 :q~BuaI paosaa ~n~u~N · --spaooaa I£I 8 :aI~qns ad~A s~n$~p 8E919 89 :apoD da~ :Xa~un~ns 6u~pooap apos uo~$~$uasaadaa SI~ 0000~E'0 = 6u~o~ds IaA~ ~I~ ~d~A 000000'00L~I = g~d~o pu~ sI~ ad~A 000000'080~I = g~d~G ~a~S si3& ad~& 60I :sploDSM ~$~0 I~gO~ Tape Subfile 9 is {ype: LIS FILE HEADER FILE NUMBER: 8 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 14737.5 PDK 14749.5 $ LOG HEADER DATA STOP DEPTH 15062.0 15074.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ 03-DEC-93 FSYS REV. J001 VER. 1.1 2013 03-DEC-93 15448.0 15077.0 14750.0 15076.0 900.0 YES TOOL NUMBER 2725XA 2324NA 2120XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 15528.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): P.F./SEA H20/BORAX 0.00 0.0 171.1 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: BASE SEAWATER PASS 1. THE NEAR COUNT RATE HIGH SCALE VALUE IS 120,000. $ CN : BP EXPLORATION WN : 2-50 / U-08 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SPD PDK 68 1 F/MN 4 20 SS PDK 68 1 CPS 4 21 SGNT PDK 68 1 CU 4 22 PHI PDK 68 1 PU-S 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 00 201 24 1 4 71 162 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 05 626 89 6 4 00 201 24 1 4 00 201 24 1 88 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 123 Tape File Start Depth = 15074.000000 Tape File End Depth = 14737.500000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 66752 datums Tape Subfile: 9 201 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 10 is 'type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 14738.0 PDK 14750.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 15061.5 15073.5 03-DEC-93 FSYS REV. J001 VER. 1.1 2053 03-DEC-93 15448.0 15077.0 14750.0 15076.0 900.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ TOOL NUMBER 2725XA 2324NA 2120XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.O00 15528.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): P.F./SEA H20/BORAX 0.00 0.0 171.1 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE ~ SH~A8 8IOI (0 #H~A~) GHODHH ~ · 88 9 9 0 0 0 0 9 9 9 9 0 ~ I0~ O0 ~ ~ I0~ O0 ~ 68 9~9 GO ~ ~ I0~ O0 ~ ~9 ~9£ 96 ~ O~ 09~ C~ ~ O~ 09~ ~ ~ O~ 09~ ~ ~ 0~ 09E g~ ~ ~g I0g 00 9 68 g9I IL 9 ~g I0g 00 ~ ~ IC9 9C ~ 96 gL6 gC ~ ~E I0E 00 ~ ~g I0E 00 ~ 6A 0~9 E6 9 I9 69I 9£ 9 I9 fi0L 6C ~ ~g I0g 00 ~ 60 II§ 90 ~ 9 S-~ I 89 HG~ IHd 9 ~D I 89 HGd ~NDS 9 SdO I 89 HG~ SS ~ ~D I 89 HO~ ~4DS BI ~ ~O I 89 ~G~ ¥I4DS ~ I 89 ~G~ NIH 9I ~ I 89 HG~ SDIH ~ I 89 ~ HOSH ~ I 89 HGd o~krH ~ ~O I 89 ~ GS~ ~ SdO I 89 HG~ Sq ~ SdD I 89 HGd SSI 0I ~ SdO I 89 HGd gO 6 ~ S~D I 89 HG~ SSD ~ ~O I 89 HG~ SqSD 9 ~ SdO I 89 M~ SH~ ~ SdO I 89 ~Q~ qH~ 9 Id~D I 89 HG~ HO pon sID dAA dXA q~Bua~ az!s AaD AaO BOq s$!uQ saId~s apoo IOOA :S~AInD gE ~ :GI qsdap adeA '000'0EI SI Hflq~fA HqYDS HDIH H,I,¥H J,N/IOD H~HN HH3, 'g SS~d HHA~M%fHS HS~ :SHHk~AHH 0'0 : (NI) aaOGN~f&S 700& 0'0 0'0 : (&.~) MOGNIM DNIZIqk~RION : (.L~) MOGNIM DNIZI~ON Total Data Records: 123 Tape File Start Depth = 15073.500000 Tape File End Depth = 14738.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 92518 datums Tape Subfile: 10 201 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 11 is type: LIS FILE HEADER FILE NUMBER: 10 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 14740.0 PDK 14752.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 15062.0 15074.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 03-DEC-93 FSYS REV. J001 VER. 1.1 2127 03-DEC-93 15448.0 15077.0 14750.0 15076.0 900.0 YES TOOL NUMBER 2725XA 2324NA 2120XA 0.000 15528.0 0.0 P.F./SEA H20/BORAX 0.00 0.0 171.1 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMkRKS: BORAX PASS 1; 50 BBLS BEHIND PIPE. THE NEAR COUNT RATE HIGH SCALE VALUE IS 120,000. $ CN : BP EXPLORATION WN : 2-50 / U-08 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SPD PDK 68 1 F/MN 4 20 SS PDK 68 1 CPS 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 00 201 24 1 4 71 162 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 05 626 89 6 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 112 Tape File Start Depth = 15074.000000 Tape File End Depth = 14740.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 94830 datums Tape Subfile: 11 190 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 12 is type: LIS FILE HEADER FILE NUMBER: 11 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 14721.0 PDK 14733.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 15062.0 15074.0 03-DEC-93 FSYS REV. J001 VER. 1.1 2154 03-DEC-93 15448.0 15077.0 14750.0 15076.0 900.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ TOOL NUMBER 2725XA 2324NA 2120XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 15528.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): P.F./SEA H20/BORAX 0.00 0.0 171.1 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 5000 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: BORAX PASS 2; 100 BBLS BEHIND PIPE. THE NEA~R COUNT RATE HIGH SCALE VALUE IS 120,000. $ CN : BP EXPLORATION WN : 2-50 / U-08 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SPD PDK 68 1 F/MN 4 20 SS PDK 68 1 CPS 4 4 06 511 09 4 00 201 24 4 39 705 61 4 74 169 61 4 92 630 79 4 00 201 24 4 00 201 24 4 35 975 96 4 36 631 32 4 00 201 24 4 71 162 89 4 00 201 24 4 23 260 40 4 23 260 40 4 23 260 40 4 23 260 40 4 96 761 61 4 00 201 24 4 52 386 28 4 05 626 89 0 1 6 6 6 1 1 1 1 1 6 1 0 0 0 0 6 1 5 6 80 * DATA RECORD (TYPE# 0) Total Data Records: 118 1014 BYTES * sasKq ~IOI :g$6uaI paoDaa m-nm~x~ · '-spaooal 96I EI :aI~qns ad~ smn~p E6IEEI 89 :apoo daH :Aa~unans 6u~poo~p apoo uo~u~saadaa SI~ 0000~'0 = ~u~o~dS I~A~ ~I~ 000000'IELgI = g~daG puH aI:~ Tape Subfile 13 is type: LIS FILE HEADER FILE NUMBER: 12 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 5 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 14740.0 PDK 14752.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 15062.0 15074.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 03-DEC-93 FSYS REV. J001 VER. 1.1 2223 03-DEC-93 15448.0 15077.0 14750.0 15076.0 900.0 YES TOOL NUMBER 2725XA 2324NA 2120XA 0.000 15528.0 0.0 P.F./SEA H20/BORAX 0.00 0.0 171.1 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): 0.0 REMAR/(S: FLUSH PASS 1; 140 BBLS BEHIND PIPE. THE NEAR COUNT RATE HIGH SCALE VALUE IS 120,000. $ CN : BP EXPLORATION WN : 2-50 / U-OS FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SPD PDK 68 1 F/MN 4 20 SS PDK 68 1 CPS 4 4 06 511 09 4 00 201 24 4 39 705 61 4 74 169 61 4 92 630 79 4 00 201 24 4 00 201 24 4 35 975 96 4 36 631 32 4 00 201 24 4 71 162 89 4 00 201 24 4 23 260 40 4 23 260 40 4 23 260 40 4 23 260 40 4 96 761 61 4 00 201 24 4 52 386 28 4 05 626 89 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 112 Tape File Start Depth = 15074.000000 Tape File End Depth = 14740.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 122908 datums Tape Subfile: 13 190 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes HNOZ TIO NI NOIKYZIqkn.4HON HKk~H KN/IOD HNIqHDq~ 000'0 00'0 0'0 000 '0 000 '0 000 '0 0'0 0 I 'ILI 0'0 00 '0 x~os/ozH :(ssa) : OIKk~H TIO/S~fD : (J,D~) S,~,flD HH,IAfM : (Nde) ~HHqqHM A~ HA~ GI~q~ : (~) AAINIq~S SNOIAIGNOD HqOHHHO~ 0'0 O' 8E:ggI 000 '0 :(Kd) HKaHG ONIS~D S,HHDDOT :(Kd) HK~HG DNISVD S,HHqqIHG :(NI)HZIS KI~ HqOH NH~O VK~G DNIS~D GN~f HqOHHHO~ k~XOEIE TOOK 'DOT H%~IqOO DNIS~D TOD H~f~ HHHNIS H~SS H~AK qOOK HGOD TOOK HO~NHA (~OKKO~ OK 4OK) 9NIHKS TOOK 0'006 0'9£0gi 0'0g£~I 0'£t0gI 0'8~gI E6-DHQ-E0 00gE I'I 'HHA I00£ 'AIH SAS~ E6-DHa-C0 0'~£0~I 0'g90gI HKdHG ~OKS :(oN/sax) ~asn TO~KNO0 HK~a~ :(HH~) aHH~S DNIDDOT : (Kd) q~AHHKNI DOT aOK :NOKKO~ NO HHDDOq HNIK :NOISHHA HH%fMK~OS YK~G HHGVHH DOT O'ggt~I HG~ 0'0~LgI HD HK~HG KH%fKS HGOD qooK HOQNHA 00~E'0 :KNHk~HHDNI HK~HG 9 :HH~LQN SS~ '~I~ ~s~I u~ ss~d punoa6Mowq awa ~saI~ a~wawd~s u~ una gowa ao~ wSwp aapw~g 6oi puw SaAlnD SHAHflD Mk~H HHG~fHH ~qI~ sIq :~dA$ s! ~I ~I!~qns sdgK TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: FLUSH PASS 2; 40 BBLS BEHIND PIPE. THE NEAR COUNT RATE HIGH SCALE VALUE IS 120,000. $ CN : BP EXPLORATION WN : 2-50 / U-08 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SPD PDK 68 1 F/MN 4 20 SS PDK 68 1 CPS 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 00 201 24 1 4 71 162 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 05 626 89 6 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 112 Tape File Start Depth = 15074.000000 Tape File End Depth = 14740.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 150270 datums Tape Subfile: 14 190 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes 0 = ~GOO Ngf~A~ · spuoDas 6E'E~ = am~ uo~$nDaxa pasd~I~ ~9E:II ~6 N~f£ ~ an~ :uo~nDaxa ~o pu~ sa~Xq E~I :g~6uaI p~oDa~ ~n~x~ · -'spaooaa E ~I :aI~qns IO · ~ HHqlk~H~ qHHH ~ IO sIq :adA$ s~ GI aI~qns ad~A -£ape S~bfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 2-50/U-08 500292236700 BP EXPLORATION (ALASKA) INC SPERRY-SUN DRILLING SERVICES 30-AUG-93 BIT RUN1 BIT RUN2 BIT RUN3 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD HANIK/KRELL S. WALLS 36 12N 16E HANIK/KRELL S. WALLS 3218 2317 58.00 56.00 10.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 12.250 REMARKS: 13.375 2872.0 15450.0 MWD - DGR/EWR4 ALL DEPTHS ARE MEASURED BIT DEPTHS. CRITICAL VELOCITY CALCULATED USING "POWER LAW" HYDRAULICS MODEL. EWR-P4 CALIBRATION FOR POST RUN 1 COULD NOT BE PERFORMED. NO DATA RECOVERED ON MWD RUN #2. RUN ~3 INCLUDED A MAD PASS FROM 15000' - 15270'. RPX - EXTRA SHALLOW PHASE 4 RESISTIVITY. RPS - IS SHALLOW PHASE 4 RESISTIVITY. PRM - IS MEDIUM PHASE 4 RESISITIVTY. RPD - IS DEEP PHASE 4 RESISITIVTY. $ / / FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 14885.0 EWR4 14895.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 14880.0 14900.0 14900.0 14920.0 14932.2 14953.3 14937.0 14957.0 14996.3 15015.6 15000.0 15018.5 15007.5 15026.4 15022.3 15040.6 15032.3 15050.2 15045.1 15062.2 15064.3 15088.2 15071.0 15094.3 .15075.0 15097.0 15080.2 15102.0 15105.0 15127.5 15135.8 15157.2 15218.0 15240.0 15240.5 15261.0 15291.0 15310.0 15301.5 15321.0 15324.0 15343.0 15359.8 15379.1 15377.0 15396.0 15405.0 15422.2 15482.8 15500.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MAD MWD $ REMARKS: all bit runs merged. CN WN FN COUN STAT STOP DEPTH 15411.0 15420.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 14928.0 15114.0 3 15000.0 15270.0 3 15270.0 15450.0 ALL CURVES WERE SHIFTED WITH GR. $ : BP EXPLORATION : 2-50/U-08 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 2 ROP MWD 68 1 3 FET MWD 68 1 4 RPX MWD 68 1 5 RPS MWD 68 1 6 RPM MWD 68 1 7 RPD MWD 68 1 API API API API Log Crv Crv Size Length Typ Typ Cls Mod * DATA RECORD (TYPE# 0) Total Data Records: 46 AAPI 4 FPHR 4 HR 4 OHMM 4 OHMM 4 OHMM 4 OHMM 4 998 BYTES * 4 91 948 38 6 4 99 789 97 5 4 62 202 97 6 4 54 501 47 1 4 54 501 47 1 4 54 501 47 1 4 54 501 47 1 28 Tape File Start Depth = 15500.000000 Tape File End Depth = 14800.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11209 datums Tape Subfile: 2 153 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 14905.0 EWR4 14915.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP. LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 15090.0 15100.0 23-JUN-93 MWD 1.70 3.65 MEMORY 15114.0 14928.0 15114.0 0 43.8 43.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0138CRG8 P0138CRG8 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID 'LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 12.250 2872.0 LSND 10.30 54.0 9.7 3200 7.2 0.900 0.460 0.820 1.450 76.0 154.0 74.0 79.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): 0.0 2 REMARKS: MWD RUN 1. $ CN : BP EXPLORATION WN : 2-50/U-08 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 3 FET MWD 68 1 HR 4 4 RPX MWD 68 1 OHMM 4 5 RPS MWD 68 1 OHMM 4 6 RPM MWD 68 1 OHMM 4 7 RPD MWD 68 1 OHMM 4 4 91 948 38 6 4 99 789 97 5 4 62 202 97 6 4 54 501 47 1 4 54 501 47 1 4 54 501 47 1 4 54 501 47 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 14 Tape File Start Depth = 15115.000000 Tape File End Depth = 14905.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 3369 datums Tape Subfile: 3 79 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 14976.0 EWR4 14986.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 15428.0 15438.0 27-JUN-93 MWD 1.70 3.65 MEMORY 15450.0 15000.0 15450.0 0 42.5 43.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): TOOL NUMBER P0139CRG8 P0139CRG8 12.250 2872.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 10.30 53.0 10.1 3600 7.2 0.870 0.410 0.780 1.550 76.0 171.0 75.0 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 2 REMARKS: MWD RUN 3. NO DATA WAS RECOVERED ON MWD RUN 2. MWD RUN 3 INCLUDED A MAD PASS FROM 15000' - 15270'. $ CN : BP EXPLORATION WN : 2-50/U-08 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 FPHR 3 FET MWD 68 1 HR 4 RPX MWD 68 1 OHMM 5 RPS MWD 68 1 OHMM 6 RPM MWD 68 1 OHMM 7 RPD MWD 68 1 OHMM 4 91 948 38 6 4 99 789 97 5 4 62 202 97 6 4 54 501 47 1 4 54 501 47 1 4 54 501 47 1 4 54 501 47 1 28 * DATA RECORD (TYPE# 0) Total Data Records: 32 998 BYTES * Tape File Start Depth = 15460.000000 Tape File End Depth = 14970.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 19058 datums Tape Subfile: 4 99 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 5 is type: LIS 93/ 8/3'0 01 **** REEL TRAILER **** 93/ 8/31 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 31 AUG 93 8:27a Elapsed execution time = 12.85 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 2-50/U-8 MPI 500292236700 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 11 -AUG- 93 6001.00 BRAD ESARY SEE REMARKS 36 12N 16E 3218 2317 56.00 10.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) lST STRING 2ND STRING 3RD STRING 13.375 2873.0 PRODUCTION STRING 9.625 15530.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: GR PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: UNKNOWN BASELINE DEPTH $ REMARKS: CN/GR CASED HOLE. EQUIVALENT UNSHIFTED DEPTH 68.00 47.00 LOGS WITNESSED BY: C. BALLARD, B. LUEDKE THE MAIN PASS GAMMA RAY FROM THIS LOGGING SUITE IS THE DEPTH REFERENCE FOR THIS WELL. LOG TIED TO WIRELINE MARKS. LOGGING PARAMETERS: CHISM FILTERING ACTIVE 12.25" CALIPER CORRECTION CASING CORRECTIONS APPLIED CASING THICKNESS = 0.472" CEMENT THICKNESS = 1.313" SANDSTONE MATRIX. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 7 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2435 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 7 START DEPTH 13497.0 13497.0 BASELINE DEPTH NPHI 13495.0 13495.0 13506.0 13506.0 13585.0 13584.5 13592.5 13592.0 13598.0 13598.5 13601.5 13601.5 13620.5 13621.0 13626.5 13626.0 13632.0 13631.5 13635.0 13635.0 13760.5 13760.5 13776.5 13776.0 13833.5 13833.5 13882.5 13882.5 13918.5 13917.5 13921.0 13920.5 13934.0 13934.0 13977.5 13978.0 13989.0 13990.0 14030.0 14030.0 14051.5 14051.5 14069.5 14069.5 14080.5 14080.5 14102.5 14102.5 14231.5 14231.5 14263.5 14264.0 14339.5 14339.5 14362.5 14362.5 14424.0 14424.0 14458.0 14458.0 14570.0 14569.5 14594.0 14594.5 14630.0 14630.0 14650.0 14650.0 14688.5 14688.5 14703.0 14702.5 14749.0 14749.0 14792.0 14792.0 14803.5 14803.5 STOP DEPTH 15410.0 15417.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH 14809.0 14836.5 14866.0 14878.0 14903.0 14948.0 14968.0 15022.5 15074.0 15135.5 15150.5 15211.5 15272.5 15301.5 15339.0 15352.0 15404.5 15495.0 $ REMARKS: CN WN FN COUN STAT 14810.0 14836.5 14866.0 14877.0 14903.0 14948.0 14967.5 15022.5 15074.0 15135.5 15150.5 15212.0 15272.5 15302.0 15339.5 15352.0 15404.5 15495.0 MAIN PASS. FUCT & NUCT WERE SHIFTED WITH NPHI. GRCH FROM THIS PASS IS THE DEPTH REFERENCE FOR THIS WELL. $ : BP EXPLORATION (ALASKA) : 2-50/U-8 MPI : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2435 68 1 GAPI 4 2 NPHI 2435 68 1 PU-S 4 3 FUCT 2435 68 1 CPS 4 4 NUCT 2435 68 1 CPS 4 4 08 501 10 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 81 Tape File Start Depth = 15495.000000 Tape File End Depth = 13495.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20006 datums Tape Subfile: 2 231 records... Minimum record length: 26 bytes Maximum record length: 1006 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 7 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13497.0 2435 13497.0 $ LOG HEADER DATA STOP DEPTH 15445.0 15452.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR CN KNJT KNJT ACOM SBT VDL CENT $ CASING COLLAR LOC. GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT KNUCKLE JOINT ACOUSTILOG COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER WTS BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): 18-JUL-93 FSYS REV. J001 VER. 1.1 1203 18-JUL-93 15486.0 15460.0 13500.0 15417.0 1500.0 YES TOOL NUMBER 2330XA 1309XA 2435XA 3921XA 3921XA 1633XA 1424XA 1424PA 0.000 15530.0 0.0 MUD 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 0.00 12.250 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 1000 TOOL STANDOFF (IN): 0.0 REMARKS: MAIN PASS. LOGGING PARAMETERS: CHISM FILTERING ACTIVE CASING CORRECTIONS APPLIED CASING THICKNESS = 0.472" CEMENT THICKNESS = 1.313" CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 2-50/U-8 MPI : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 4 2 CNC 2435 68 1 PU-S 4 3 CN 2435 68 1 PU-L 4 4 LSN 2435 68 1 CPS 4 5 SSN 2435 68 1 CPS 4 6 SPD 2435 68 1 F/MN 4 7 CCL 2435 68 1 4 8 TEN 2435 68 1 LB 4 4 08 501 10 0 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 54 376 29 5 4 90 640 78 6 4 19 912 29 5 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 286 Tape File Start Depth = 15495.000000 Tape File End Depth = 13495.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 72010 datums Tape Subfile: 3 370 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 5 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 15193.0 2435 15193.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR CN KNJT KNJT ACOM SBT VDL CENT $ STOP DEPTH 15445.0 15452.0 CASING COLLAR LOC. GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT KNUCKLE JOINT ACOUSTILOG COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER WTS 18-JUL-93 FSYS REV. J001 VER. 1.1 1133 18-JUL-93 15486.0 15460.0 13500.0 15417.0 1500.0 YES TOOL NUMBER 2330XA 1309XA 2435XA 3921XA 3921XA 1633XA 1424XA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 15530.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): MUD 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 0.00 12.250 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 1000 TOOL STANDOFF (IN): 0.0 REMARKS: REPEAT PASS. LOGGING PARAMETERS: CHISM FILTERING ACTIVE CASING CORRECTIONS APPLIED CASING THICKNESS = 0.472" CEMENT THICKNESS = 1.313" CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 2-50/U-8 MPI : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size 1 GR 2435 68 1 GAPI 4 2 CNC 2435 68 1 PU-S 4 3 CN 2435 68 1 PU-L 4 4 LSN 2435 68 1 CPS 4 5 SSN 2435 68 1 CPS 4 6 SPD 2435 68 1 F/MN 4 7 CCL 2435 68 1 4 8 TEN 2435 68 1 LB 4 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 08 501 10 0 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 54 376 29 5 4 90 640 78 6 4 19 912 29 5 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 44 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = 15495.000000 15191.000000 0.250000 Tape Fife Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 30960 datums Tape Subfile: 4 128 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS 93/ 8/11 01 **** REEL TRAILER **** 93/ 8/11 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 11 AUG 93 11:38a Elapsed execution time = 26.53 seconds. SYSTEM RETURN CODE = 0
