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Home My WebLink About193-014Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:193-014 6.50-029-22337-00-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10315 10165 9083 9645 None None 8610 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 76 20" 36 - 112 36 - 112 1490 470 Surface 3025 10-3/4" 36 - 3061 36 - 3059 5210 2480 Intermediate 9823 7-5/8" 34 - 9857 34 - 8802 8180 5120 Production Perforation Depth: Measured depth: 9880 - 10122 feet True vertical depth:8823 - 9044 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 32 - 9697 32 - 8657 9645 8610Packers and SSSV (type, measured and true vertical depth) 4-1/2" TIW HBBP Packer Liner 624 5-1/2" 9691 - 10315 8652 - 9221 7740 6280 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 19912551713120 150 1010 Shut-In 20 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Semmens, Travis travis.semmens@bp.com Authorized Name:Semmens, Travis Authorized Title: Authorized Signature with Date:Contact Phone:+1 9072979672 Treatment descriptions including volumes used and final pressure: 13. Intervention & Integrity Engineer Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9221 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Set Patch Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028286 PBU A-40 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations Repair Well 5 By Samantha Carlisle at 2:25 pm, May 28, 2020 Travis Semmens Digitally signed by Travis Semmens Date: 2020.05.28 13:13:48 -08'00' DSR-5/28/2020MGR29MAY20 RBDMS HEW 5/29/2020 ACTIVITYDATE SUMMARY 4/29/2020 ***JOB RESUMED FROM 29-APR-2020***(ELINE SET TUBING PATCH) INTIAL T/I/0=200/0/0 SET ONE TRIP 45 KB PATCH WITH 18.85' 3.5" 9.3# PUP WITH MIDDLE OF PUP AT 9600' PATCH SPECS: RUN IN HOLE LEGNTH=26.77', LEFT IN HOLE LENGTH=25.411', OAW=430#, MAX OD=3.70" CCL TO TOP OF ELEMENT=8.0', TOP OF ELEMENT TO BOTTOM OF ELEMENT=4.5", CCL TO MIDDLE OF PUP JOINT=17.8' CORRELATE TO READ CASED HOLE LDL LOG DATED 17-NOV-2019 CCL STOP DEPTH=9582.2', MIDDLE OF PUP SET AT 9600' FINAL T/I/0=150/0/0 ***JOB COMPLETE*** 5/8/2020 ***WELL S/I ON ARRIVAL*** (Patch Tubing Liner) SET 4-1/2" WHIDDON CATCHER @ 9546' SLM PULL BK-DGLV FROM STA #2(9245' MD), STA #7(3418' MD), STA #4(8139' MD) & STA #6(5544' MD) ****CONT WSR ON 5-9-20**** 5/9/2020 ****CONT WSR FROM 5-8-20****(patch/liner) SET BK-LGLV IN STA #7(3418' MD), STA #6(5544' MD) & STA #4(8139' MD) SET BK-OGLV IN STA #2(9245' MD) PULL 4-1/2" CATCHER OFF PATCH @ 9,546' SLM PULL 2-7/8" XX-PLUG FROM NIPPLE REDUCER @ 9,669' MD ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** Daily Report of Well Operations PBU A-40 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMA. )N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well I71 Re-enter Susp Well 0 Other:Packer Squeeze WI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5 Permit to Drill Number 193-014 3 Address: P.O.Box 196612 Anchorage, Development l Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6 API Number: 50-029-22337-00-00 7 Property Designation(Lease Number). ADL 0028286 8. Well Name and Number PBU A-40 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools' PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary' RECEIVED Total Depth: measured 10315 feet Plugs measured None feet I 1 true vertical 9221 feet Junk measured 9848 feet U L 1 4 2.015 Effective Depth: measured 9848 feet Packer measured See Attachment feet {�' `,+-�, true vertical 8794 feet Packer true vertical See Attachment feet 4,0(3 C C Casing: Length: Size' MD' TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 36-116 36-116 1490 470 Surface 3025 10-3/4"45.5#NT-8 36-3061 36-3059 4560 1730 Intermediate 9826 7-5/8"29.7#NT-95 31 -9857 31 -8802 8180 5120 Production Liner 624 5-1/2"17#13Cr80 9691 -10315 8652-9221 7740 6280 Perforation Depth: Measured depth' 9880-9898 feet 9980-10020 feet 10106-10122 feet True vertical depth: 8823-8840 feet 8914-8951 feet 9030-9044 feet5CANWED Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr8 30-96977 30-8657 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) — - - 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9416'-9645' Treatment descriptions including volumes used and final pressure: 11 BBLS 15.8PPG CLASS G CEMENT 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation. 117 791 1767 1373 236 Subsequent to operation: 0 0 0 0 0 14.Attachments.(required per 20 AAC 25 070 25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations H Exploratory 0 Development m Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16 Well Status after work' Oil Il Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ SUSP 0 SPLUG 0 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-664 Contact Summerhays,Nita M IPRO Technologies) Email Nita.Summerhays@bp com Printed Name Sum erhay Nita (WIPRO Technolo/1) Title Petrotechnical Data Manager i Si.•- //�j ' 41 / .0"��,i Phone +1 907 564-4035 Date 07/13/2015 Form 10-404 Revised 5/2015 VTL qtZ/1\d/ f/ � RBDMS bmd On mal Only c JILL 1 7 2015 Daily Report of Well Operations PBU A-40 ACTIVITYDATE SUMMARY ***WELL S/I ON ARRIVAL***(Surface csg excavation) PULL P-PRONG FROM 4-1/2" PX PLUG BODY AT 9,669' MD. CURRENTLY RIH W/4-1/2"GS TO PULL 4-1/2" PX PLUG BODY. 2/1/2015 ***JOB IN PROGRESS, CONTINUED ON 2/2/15 WSR*** T/I/O=7/0/VAC. Temp=Sl. Assist W/cellar watch(Pre SC excavation). No AL or FL. Cellar has spray in liner installed (not noticable under gravel in cellar). Assist SLB & FB w/cellar watch during pumpnig operations. No leaks at surface noted at any time during pumpnig. Final W H Ps=1000/500/0. 2/2/2015 SLB in control of valve positions upon departure. (1530 hrs) ****CONTINUED FROM 2/1/2015 WSR**** PULL 4-1/2" PX PLUG BODY FROM 9.633' SLM/9,669' MD. TAG STICKY BOTTOM AT 9,971' ELM W/3.70"CENT, TEL, 2.50"S-BLR (Sample of rubber/ silt). PERF INTERVAL FROM 9,880'TO 10,122' ELM (91'Open- 151'Covered). SET 4-1/2" PX PLUG BODY(Oal =26"-4 x 3/16" ports) & P-PRONG AT 9,599'SLM/9,636' MD. LRS PERFORMED SUCCESSFUL MIT-T TO 2500 PSI. LRS ACHIEVED A LIQUID LEAK RATE OF .163 BPM @ 1140 PSI. PULL P-PRONG &4-1/2" PX PLUG BODY FROM 9,599' SLM/9,636' MD. 2/2/2015 ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** T/I/O=7/0/0 Temp=Sl Assist Slickline, MIT-T PASSED to 2500 psi, Established an LLR of.164 bpm (6.846 gpm) measured by tank volume (Surface Excavation) Pressured up Tbg with 4 bbls crude. Tbg lost 118 psi in 1st 15 mins and 36 psi in 2nd 15 mins for a total loss of 154 psi in 30 min test. Ble pressure back to 1200 psi. Pumped 47 bbls crude down IA to establish LLR thru packer leak. Established an LLR of .164 bpm (6.846 gpm) measured by tank volume. Bled—3 bbls crude back. Final WHPs 1000/500/4 Slickline still on well at time of departure,AFE sign hung on master 2/2/2015 ***WELL SI UPON ARRIVAL***(E-LINE PLUG SET AND TUBING PUNCH) INITIAL T/I/O =450/100/0 ARRIVE ON LOCATION AND GET PERMIT SIGNED. JOB CONTINUED ON 07-FEB-2015. 2/6/2015 ***JOB CONTINUED ON 07-FEB-2015*** 2/6/2015 Road to location, Stby for E-Line T/I/O=450/100/0. Temp= SI. Assist Eline w/cellar watch. AL& Flowine removed. Cellar has spray in liner. IA has integral installed =inspection not current. Installed secondary containment. 2/6/2015 ***WSR continued on 02/07/15***. ***JOB CONTINUED FROM 06-FEB-2015***(E-LINE: PLUG AND TUBING PUNCH) SET 4.5" HALLIBURTON COMPOSITE BRIDGE PLUG ME= 9618', CCL TO ME =7.88', CCL STOP DEPTH = 9610.12', OAL LEFT IN HOLE=2.41', LRS MIT GOOD. (9616.8' MD) TUBING PUNCH W/MEDIUM PUNCHES OVER INTERVAL 9600'TO 9601'. CCL TO TS= 9.67' CCL STOP DEPTH = 9590.33'. POOH. RIG DOWN. FINAL T/I/O= 500/400/0 2/7/2015 ***JOB COMPLETE. WELL SHUT-IN UPON DEPARTURE*** ***WSR continued from 02/06/15***. Assist E-line w/cellar watch. Assisted E-line w/cellar watch during pumping operations. No leaks @ surface noticed during the duration of the job. 2/7/2015 SLB in control of valves upon departure. 14:20. T/I/0=330/11/0 Assist E-Line w/Load and Test. MIT T PASSED to 2500 psi. Loaded Tbg.w/50 bbls crude. SD. due to fluid packed well. E-Line set CIBP .( MIT T) Pumped 2.5 bbls of 40*F crude to reach test pressure .Tbg lost 131 psi. in the first 15 min. and 32 psi. in the 2nd 15 min for a total loss of 163 psi. in a 30 min. test .Bled back to Final WHP-600/300/1 E-Line on well at 2/7/2015 departure Daily Report of Well Operations PBU A-40 CTU#6- 1.75"CT(CTV= 31.2 bbls)Job Scope: Packer Squeeze Perform Circ-out. Pump 292 bbls KCL&529 bbls of diesel pumping down the IA taking tubing returns to A-43 flowline. No Ch2 or Peak vac trucks available. Standby to do cementing until trucks are available. 2/8/2015 ***Job in Progress*** CTU#6- 1.75"CT(CTV= 31.4 bbls) Job Scope: Packer Squeeze Standby to do cementing until vac trucks arrive. MU 2.5" BDN and RIH while taking diesel returns. Lightly tag CBP at 9593'at up weight. Shift depth to 9618'. Pump 10 bbls 60/40 down backside taking IA returns, good 1:1 returns. Lay in 11 bbls of 15.8ppg Class G Cement above plug. Puh to safety. Down coil push 6.0 bbls into IA while taking IA returns, shut in IA. Pump 1 bbl down backside to sqz cement through packer, did not see any bump in pressure. Estimated TOC in IA at 9371'. Drop ball &contaminate cement to plug. Leave clean powervis gel from plug at 9618'to 8700'. Chase ooh at 80%. Wash jewelry on way out. Lay in 60/40 freeze protect from 2500'tvd. Jet tree& BOP's. Wait for 500psi compressive strength.Attempt MIT-IA, but the tubing was tracking the IA. Performed a CMIT-TxIA to 980psi, T/IA lost 23/30psi in 1st 15min, 26/25psi in 2nd 15min and 13/16psi in 3rd 15min. CMIT-TxIA Passed to 980psi. Slowly bleed down the tubing pressure and confirm the IAP is tracking. SI well 200psi overbalance. RDMO. 2/9/2015 ***Job in Progress*** CTU#6- 1.75"CT Job Scope: Packer Squeeze RDMO. 2/10/2015 ***Job Complete*** T/I/O=0/522/5 MIT-IAQ to 2500 PASSED lost 108 and 41 psi bled IA back to 0 rig down (swab closed wssv closed master open annulus valves open to gauges tags hung on IA and wing flui 2/12/2015 packed annulus sign hung on master) FWHP=0/0/3 T/I/O=0/522/5. Temp= SI. Assist Fullbore (Surface Excavation). No AL. Initial OA FL @ surface. Maintained an open bleed on the OA while LRS performed a MIT x IA. No visible returns 2/12/2015 to the bleed tank during job. Job continues on AWRGS dated 2-13-15. Job continued from AWGRS dated 2-12-15. Maintained an open bleed on the OA while LRS performed a passing MIT x IA. No visible returns to the bleed tank during the job. FWP's= 0/0/4. 2/13/2015 LRS in control of wellhead valves upon departure. 0115 hrs. CTU-6 1.75" CT Objective: Mill out cement stringers and CBP MIRU. Perform Weekly BOP Test. RIH with 2-7/8" motor&3.70"5-bladed junk mill. Tag cement at 9462'. Mill down to 9595', stacking wt and seeing 100-200psi motor work. PUH to 9585'and circ BU before milling up plug. RIH and mill CBP up, push plug out tubing tail at 9699' into 5-1/2" liner down to 9739'. PUH and wait on water trucking. 2/13/2015 ***In Progress*** CTU-6 1.75" CT Objective: Mill out cement stringers and CBP RIH and mill CBP up, push plug out tubing tail at 9699' into 5-1/2"liner down to 9739'. PUH and wait on water trucking. RIH and confirm tag at 9736'. Continue milling down to 9848'. POOH and determine plan forward. FP well w/38bbls of 60/40 methanol. 2/14/2015 ***Job Complete*** T/I/O = 0/410/0. Temp= SI. Bleed IAP to 0 psi (Pre LDD). Flowline removed, temporary scaffolding set in well house. Secondary containment installed around conductor. Integral installed on IA=inspection not current. IA FL @ surface. Bled IAP to 0 psi in 30 min (1 bbl). Removed a section of well house floor to reach conductor. Flutes are completely frozen. Placed heater in wellhouse to thaw conductor. Monitored WHPs for 30 min, WHPs unchanged. Job complete. Final WHPs= 0/0/0. 2/15/2015 SV, WV, SSV= C. MV=O. IA, OA= OTG. 16:30 hrs. Daily Report of Well Operations PBU A-40 T/I/O=SSV/150/0, Temp=SI. PPPOT-T(PASS), PPPOT-IC (PASS), pre surface casing excavation. PPPOT-T: Stung into test port(200 psi), bled to 0 psi. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port(0 psi). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 2/15/2015 psi. T/I/O= SSV/440/0. Temp= SI. OA LDD. (Pre SC repair). No flowline or AL line. Temporary scaffolding erected in wellhouse. Secondary containment in cellar. IAP increased 440 psi overnight. OA FL near surface. Vacced fluid from conductor. Pumped 1.56 bbls diesel into OA, response©surface in conductor. Vacced fluid from conductor for—5-10 min until stabilized (no outflow). Leak point appears to be between flute openings @ 9 o'clock& 11 o'clock position & under flute spoke. Pushed N2 into OA for< 1 min with almost immediate response. LEL level increased to 10% &02 decreased to 16.4%. Leak point visible under flute spoke, measured from leak point to bottom of OA casing valve body= 33". N2 caution tags hung. Re-installed grating before departure. See log for details. Job complete. Final WHPs= .VAC/440/0. 2/16/2015 SV, WV, SSV= C. MV= 0. IA, OA=OTG. 2200 hrs. ***WELL SHUT IN ON ARRIVAL***(Pre surface csg excavation/repair) SWCP DC#5 RIG UP 3/5/2015 ***CONT ON WSR 3/6/15*** ***CONT FROM WSR 3/5/15***(surface csg excavation) BRUSHED X-NIPLLE @9636' MD SET PX PRONG AND PLUG BODY @9636' MD PERFOMED FAILING MIT-T AND C-MIT PULLED PRONG FROM PLUG BODY @9636' MD 3/6/2015 ***CONT ON WSR 3/7/15*** T/I/0=540/900/0. Temp=SI. Assist Slickline with cellar watch. Held open bleed on OA. Had fluid come up in conductor @ 9 O'clock position (— 10 gallons of fluid). Slickline bled TP to 500 psi and IAP to 0 psi. 3/6/2015 Slickline in control of well upon departure. 1945 . ***CONT FROM WSR 3/6/15*** SET PX PRONG AND PLUG @9636' MD PERFORMED FAILING MIT-T PULLED PX PRONG AND PLUG FROM 9636' MD SET 4-1/2" EVO-TRIEV @9594' SLM PERFORMED FAILING MIT-T 3/7/2015 ***CONT ON WSR 3/8/15*** T/I/0=384/384/0. Temp=SI. Assist slickline (Cellar watch). Maintained open bleed on OA& monitored conductor during SL activities. No response in conductor throughout job. Job complete. 3/8/2015 SL in control of well on departure. 0120 hrs(3/9/15). ***CONT FROM WSR 3/7/15*** SET 4 1/2"WCS @ 9588' SLM PULLED STA#2 BK-DGLV FROM 9223' SLM (9245' MD) SET STA#2 BK-FLOW SLEEVE 9223'SLM (9245' MD) PERFORM PASSING C-MIT(SEE DATA TAB) 3/8/2015 ***CONT ON WSR 3/9/15*** ***CONT FROM WSR 3/8/15*** PULLED 4 1/2"WCS FROM 9588' SLM SET 4 1/2" DUMMY SSSV(2standard packing stacks, 36"oal) @ 2072' SLM (2096' MD) 3/9/2015 ***WELL LEFT S/I PAD OP NOTIFIED ON DEPARTURE*** Daily Report of Well Operations PBU A-40 T/I/O= 0/0/0 Temp= S/I Circ-Out Through TBG Taking returns out IA to A-43 FL(SURFACE 3/12/2015 CASING EXCAVATION) Riged up, Standby do to Cold Temp. ***Continued on 3/13/15 WSR*** T/I/O = 0/0/0. Temp= SI. Hold open bleed on OA for Circ-out (Assist FB). OA FL near surface. Job postponed due to weather. See log for details. Final WHPs=0/0/0. 3/12/2015 LRS in control of well on departure. T/I/O = 106/105/vac.Circ-Well and CMIT TxIA to 2500 psi (PASSED) SB for weather, Pumped 10 BBL Neat Spear followed by 50 bbl DSL, 360 bbl KCL down TBG up IA taking returns down A-43 flowline.Then Pumped 124 bbl DSL for U-Tube FP, FP Surface Hardline w/5 bbl Neat. Pumped 3.84 bbls DSL down TBG up IA to reach test pressure. 15 min. TBG/IA lost 22/21 psi 30 min. lost TBG/IA 19/19 psi for total loss of 41/40 psi. bleed back—4 bbls DSL. Tags hung on IANW. 3/13/2015 SV/WV/SSV=closed MV/IA/OA=open DSO notified of FWHP 270/270/0 T/I/O = 0/0/0. Temp= SI. Hold open bleed on OA for Circ-out (Assist FB). OA FL near surface. Hold Open bleed on OA to slop tank during circ-out&CMIT for 8.25 hrs. —.5 bbls fluid evacuated from conductor throughout job. Minimal returns to slop tank during open bleed. Job complete. 3/13/2015 LRS in control of well on departure. 2310 hrs. T/I/O= SSVNacNac. Temp=SI. WHPs. 4/16/2015 SV, WV, SSV= C. MV= O. IA&OA=OTG. 16:00 T/I/O=VacNac/0. Temp= SI. Bleed WHP's to 0 psi, Purge& Install N2 Cap. (SC Repair). Well House, Flow line, Production riser&well head scaffold removed. Drilling scaffold installed. TBG & 4/16/2015 IA FL's @ Surface, OA FL= Near surface. Continued on WSR 4/17/15. Continued from WSR 4/16/15. T/I/0=75/75/0. Temp= SI. Bleed WHP's to 0 psi, Purge& Install N2 Cap. (SC Repair). Well House, Flow line, Production riser&well head scaffold removed. Drilling scaffold installed. TBG& IA FL's @ Surface, OA FL= Near surface. Removed 4.1 bbl of fluid from TBG/IA, Hooked up jumper hose&U-tubed FL's. TBG FL @ 102'& IA FL @ 120', left TP& IAP @ 205 psi for PT after BPV install. Final WHP's=205/205/0. 4/17/2015 SV&WV= C. MV& SSV= O. IA&OA= OTG. NOVP. 02:00 T/I/0=150/150/0 Set 4"CIW"H" BPV#152. Removed upper tree, installed dry hole tree. FWP's 4/21/2015 BPV/150/0 see log for details. T/I/O= BPV/150/0. Surface casing excavation and repair. Initiated Ground Disturbance Permit. Removed drilling scaffolding. Dewatered well cellar. Excavated around well cellar to allow room for 4/22/2015 installation of OA Companion Valve. Site prep for drilling. T/I/O=BPV/150/0. Installed 2"Temp#72 as OA Companion valve, Pulled 2"VR plug. Final WHP's 4/23/2015 BPV/150/0. ***Job Complete***See log. T/I/O= BPV/150/0. Surface casing excavation and repair. Begin drilling around cellar. Site prep for water washing cellar and CMP instlation. Final WHP's= BPV/100/0 4/24/2015 SV&WV= C. MV&SSV= 0. IA&OA= OTG. 1800 Hr T/I/O= BPV/150/0. Surface casing excavation and repair. Completed drilling around cellar. Site prep for water washing cellar to expose float. L2RA excavation. See log for L2RA controls. Begin to water wash cellar and excavate to expose float. Float exposed at 48". Cover cellar and drill holes W/herculite . Install heaters to thaw ground. Final WHP's= BPV/150/0 4/25/2015 SV&WV= C. MV&SSV= 0. IA&OA= OTG. 1700 Hr T/1/0= BPV/150/0. Surface casing excavation and repair. L2RA excavation. L2RA HWOF. L2RA hazardous confined space. See log for L2RA controls. N2 Purge. Cut cement float off. Bell Survey. Final WHP's= BPV/150/0 4/26/2015 SV = C. MV= O. IA&OA= OTG. 1800 Hr T/I/O= BPV/150/0. Surface casing excavation and repair. L2TRA Excavation. L2TRA HWOF. See log for L2TRA controls. Excavate down to wellhouse I-Beam foundation. Cut and remove (- Beam foundation. Continued with excavation reaching 7 feet. Final WHP's= BPV/150/0 4/27/2015 SV = C. MV=0. IA&OA= OTG. 1800 Hr Daily Report of Well Operations PBU A-40 T/I/O= BPV/150/0. Surface casing excavation and repair. **DELAY** Continue L2RA excavation. See log for DELAY and L2RA controls. Excavated to 8.5 feet and removed cement from cellar. Final WHP's= BPV/150/0 4/28/2015 SV = C. MV=O. IA& OA= OTG. 1800 Hr T/I/O= BPV/150/0. Surface casing excavation and repair. L2RA excavation. See log for L2RA controls. Excavation complete with a finished depth of 9'6". CMP installed. Final WHP's= BPV/150/0 SV = C. MV=O. IA& OA= OTG. 1800 Hr 4/29/2015 Surface casing repair-Arrived to A-40 with WSS, crane, and other SCE&R equipment. Staged 5/4/2015 WSS and equipment, unloaded crane from trailer and spotted on EOP. 1800hrs. 5/5/2015 Surface casing excavation repair. Critical lift. Lifted WSS off trailer onto rigmats. 1200Hrs. 5/6/2015 Surface casing excavation repair. Delivered and staged remaining equipment and tools. T/I/O= BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Bell Survey for reference points. Air drill 5 holes in rear and 3 holes in front around well cellar and install casing. Unloaded template. Electricians installed generator for Ops and WSL trailers. Delivered 8-80ft H - Pile to location. Final WHP's= BPV/150/0 5/7/2015 SV = C. MV= 0. IA& OA= OTG. 1800 Hr T/I/0 = BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Bell Survey finish reference points. Drill to expose cable that was discovered in pad. Drilled through cable. Continue drilling H-Pile holes and install casing. Ran into a bundle of nested cable on the back side of well approx. 3' below grade. Water washed to extract cable. Then ran into large timbers in hole. Continue water washing to remove. Installed steam probes to front 6 H-Pile holes. Steaming operations through the night. Final WHP's= BPV/150/0 5/8/2015 SV = C. MV= 0. IA&OA= OTG. 1800 Hr T/I/0= BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Continue steaming front 6 H-Pile holes. Drilled#4 H-pile hole. Transfered stream probes to rear H-Pile holes. Continue steaming through the night. Final WHP's= BPV/150/0 5/9/2015 SV =C. MV= 0. IA& OA=OTG. 1800 Hr T/I/0 = BPV/150/0. Temp = SI. No flowline. Surface casing excavation and repair. Removed casing from front H-Pile holes. Back fill front holes. Continue steaming rear H-Pile holes through the night. Final WHP's= BPV/150/0 5/10/2015 SV = C. MV=0. IA&OA= OTG. 1800 Hr T/I/0 = BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Finished steaming. Rig down steam probes and steamer unit. Pull casing from H-Pile holes. Level ground for template. Bell Survey to shoot points. Set template. Final WHP's= BPV/150/0 5/11/2015 SV = C. MV= O. IA&OA=OTG. T/I/0= BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Drive 2-60' spud piles and weld to templete. L2RA HWOF see log for controls. Final WHP's= BPV/150/0 1800 Hr. 5/12/2015 SV = C. MV= O. IA& OA=OTG. T/I/0 = BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Drove spud piles, P3 and P4 60' into the ground at template height. L2RA HWOF see log for controls. Final WHP's= BPV/150/0 1800 Hr. 5/13/2015 SV = C. MV= 0. IA&OA=OTG. T/I/0 = BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Shutdown lifting operations due to 40-45 mph winds. Level and prep front surface location for placement of template. Final WHP's= BPV/150/0 1800 Hr. 5/14/2015 SV = C. MV= 0. IA&OA= OTG. Daily Report of Well Operations PBU A-40 T/I/O = BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Shutdown lifting operations due to 35-40 mph winds. Final WHP's= BPV/150/0 1800 Hr. 5/15/2015 SV = C. MV=O. IA&OA= OTG. T/I/O= BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Drove spud piles, P1 and P2 60'into the ground at template height. Removed spuds and template. Set and ,surveyed template for front location. L2RA HWOF see log for controls. Final WHP's = BPV/150/0 1800 Hr. 5/16/2015 SV = C. MV= 0. IA&OA=OTG. T/I/0 = BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Drove rear piles P1, P2 and P3, 75' into the ground. Shutdown due to jaw failure on vibratory hammer. 1L2RA HWOF see log for controls. Final WHP's= BPV/150/0 1800 Hr. 5/17/2015 SV = C. MV= O. IA&OA=OTG. T/I/O = BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Fresh head spuds and pile 4. Install new jaws on vibratory hammer and drive pile 4 to a final depth of 75'. L2RA HWOF see log for controls. Final WHP's= BPV/150/0 1800 Hr. 5/18/2015 SV = C. MV= 0. IA&OA=OTG. T/I/O = BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Set, surveyed and tack welded rear pile caps. Standby for power pack parts. L2RA HWOF see log for controls. Final WHP's= BPV/150/0 1800 Hr. 5/19/2015 SV = C. MV=0. IA&OA=OTG. T/I/0 = BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Replaced checkvalve on power pack. Standby for parker valve arrival and replacement on power pack. Final WHP's = BPV/150/0 1800 Hr. 5/20/2015 SV = C. MV= 0. IA&OA=OTG. Surface casing excavation and repair. Moved equipment to allow slickline to operate on A-6. 5/21/2015 Shutdown due to flooding in GPB. Surface Casing Excavation and Repair. Completed repairs on vibratory hammer. Shutdown pile 5/22/2015 driving operations to allow slickline to complete work on A-6. T/I/0 = BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Pile driving standby wind 35-40 mph. Final WHP's= BPV/150/0. 5/23/2015 SV = C. MV= 0. IA&OA=OTG. T/I/0 = BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Completed welding P1 pile cap and 50%complete on P2. Pile driving standby wind 30-35 mph. L2RA HWOF see log for controls. Final WHP's= BPV/150/0. 5/24/2015 SV = C. MV= 0. IA&OA= OTG. T/I/0 = BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Drove and welded spud piles. Drove P5, P7 and P8, 60'into the ground at template height. L2RA HWOF see log for controls. Final WHP's= BPV/150/0 1800 Hr. 5/25/2015 SV = C. MV= 0. IA&OA=OTG. Surface casing repair, L2TRA for HWOF. (See log for controls)Complete driving front 4 foundation pile. Remove spud pile and template. Backfill and level grade for install of WSS.Prep for weld pile 5/26/2015 caps and Bell &Assoc survey Surface casing excavation and repair, L2TRA HWOF-See log for controls. T/I/0= BPV/150/0. 5/27/2015 Finish welding out rear foundation pilecaps. Cut front pile. Surface casing excavation and repair, L2TRA HWOF-See log for controls. T/110= BPV/150/0. -Completed welding out front foundation piles. Set Tiger Tank for de-watering and loaded out 5/28/2015 vibratory hammer. Location is ready for WSS Critical Lift. Daily Report of Well Operations PBU A-40 5/29/2015 Surface casing excavation and repair- Delayed waiting on E-Line on A-6 Surface casing excavation and repair. T/I/O= BPV/150/0. Conducted Critical Lift-set WSS onto H- 5/30/2015 Piles and began bolting into place. T/I/O = BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. Bolt up of WSS to foundation piles. Removal of travel hardware from WSS. Completed hook up of electrical, encoders, thermocouplers, loadcells. Raised WSS 6"and conducted a weight TARE. Dirt work for worksite prep. Final WHP's= BPV/150/0 5/31/2015 SV = C. MV=O. IA&OA= OTG. 1800 hrs. T/I/O = BPV/0/0. Evacuated fluid from dryhole tree. Removed Dryhole tree and THA. Installed Surface CSG Knuckle and torqued to API specs. ***Job Complete*** Final WHP's BPV/0/0. 6/1/2015 RDMO. T/I/O= BPV/150/0. Temp= SI. No flowline. Surface casing excavation and repair. L2RA for(see log for details&controls). Bled IAP to 0 psi in 3 min. DRILL 0951 (See log for details). TRP and FMC removed dry hole tree and THA. Installed WSS adapter and vertical support. Raised WSS to ZERO. (see log for final readings). Final WHP's= BPV/0/0 6/1/2015 WSS, no tree valves. IA&OA=OTG. 1800 hrs. T/I/O = BPV/0/0. Temp= SI. No flowline. Surface casing excavation and repair. De-water confined space, install sump pump for continuous de-watering. Final WHP's= BPV/0/0 6/2/2015 WSS, no tree valves. IA&OA= OTG. 1800 hrs. T/I/O = BPV/0/0. Temp= SI. No flowline. Surface casing excavation and repair. WSS attached to Well head. L2RA confined space(See log for controls). Scaffold in cellar and above ground completed. 50 psi of N2 was established on IA. OA purge was started, then discontinued due to lack of time to finish work when 0% LEL was reached. Final WHP's= BPV/50/0 6/3/2015 WSS, no tree valves. IA&OA= OTG. 1800 hrs. T/I/O= BPV/50/0. Temp= SI. No flowline. Surface casing excavation and repair. WSS attached to Well head. L2RA confined space(See log for controls). Thawed the frozen hardline from the sump to the tank. drill holes in conductor to find good cement. Cut 51"of conductor and removed cement away from casing and out of cellar. Buffed surface casing. Final WHP's= BPV/50/0 6/4/2015 WSS, no tree valves. IA& OA=OTG. 1800 hrs. T/I/O = BPV/50/0. Temp= SI. No flowline. Surface casing excavation and repair. WSS attached to Well head. L2RA HWOF, Haz confined space. (See log for controls). Strapped FL on OA. Was determined that the FL was determined to be>9ft. Mistras attempted UT on surface casing. Casing needed additional prep work. Welder grinded surface casing. Final WHP's= BPV/50/0 6/5/2015 WSS, no tree valves. IA&OA= OTG. 1800 hrs. T/I/O= BPV/50/0. Temp= SI. No flowline. Surface casing excavation and repair. WSS attached to Well head. AOGCC (John Crisp)witness of corrosion damage declined. Mistras completed UT inspection of surface casing. Final WHP's= BPV/50/0 6/6/2015 WSS, no tree valves. IA&OA= OTG. 1900 hrs T/I/O= BPV/50/0. Temp= SI. No flowline. Surface casing excavation and repair. WSS attached to Well head. FMC inspected mandrel hanger. Welders conducted pre weld inspection. Final WHP's= BPV/50/0 6/7/2015 WSS, no tree valves. IA&OA= OTG. 1900 hrs T/I/O= BPV/50/0. Temp= SI. No flowline. Surface casing excavation and repair. WSS attached to Well head. L2RA HWOF, Haz Confined space(See log for controls). Welders cut and removed fluted mandrel, and tacked on thermo couplers. Electrician installing heating blankets. Final WHPs = BPV/50/0. 6/8/2015 WSS, no tree valves. IA&OA=OTG. 16:45 Daily Report of Well Operations PBU A-40 T/I/O= BPV/50/0. Temp= SI. No flowline. Surface casing excavation and repair. WSS attached to Well head. L2RA HWOF, Haz confined space. (See log for controls). Cut/removed Fluted Mandrel Hanger from SC. Welded Thermocouples onto SC Pup and Starting head for Cooper Heat Machine. RU Cooper Heat Machine in preparation for welding tomorrow. Final WHP's= BPV/50/0 6/8/2015 WSS, no tree valves. IA&OA= OTG. 1800 hrs. T/l/O=BPV/50/0,Temp=Sl. Assist SC excavation crew. Stung into IC test void (0+ psi), bled to 0 psi. Maintained open bleed through out WH bake off an 6/9/2015 heat soak. Returned little to no fluid. T/I/O= BPV/50/0. Temp= SI. No flowline. Surface casing excavation and repair. WSS attached to Well head. L2RA HWOF, Haz Confined space(See log for controls). Maintain N2 purge during preheat and untill wellhead temp cools down to 180 degrees. Cameron bleed PPPOT-IC. Electrician pre heat weld area to 550 degrees and bake for 4 hr. Welders begin butter bead and filiet weld. Electrician 2 hr cool down to 450 degrees . Made change out W/DHD night crew, continue N2 purge. Well head temps between 156* F & 166* F, SI N2, bleed, rig off lines, Plug & cap fittings. Final WHPs= BPV/50/0 6/9/2015 WSS, no tree valves. IA&OA= OTG. 00:30 T/I/O= BPV/50/0. Temp= SI. No flowline. Surface casing excavation and repair. WSS attached to Well head. L2RA HWOF, Haz Confined space(See log for controls). Maintain N2 purge during welding. Electrician pre heat weld area to 250* F Welders fit and splice upper sleeve. SI N2, bleed, rig off lines, Plug&cap fittings. Final WHPs= BPV/50/0 6/10/2015 WSS, no tree valves. IA&OA= OTG. 1800 T/I/O = BPV/50/0. Temp= SI. No flowline. Surface casing excavation and repair. WSS attached to Well head. L2RA HWOF, Haz Confined space(See log for controls). Maintain N2 purge during welding. Welders fit and splice lower sieve. Welders fit and splice collar sleeve. Weld on lugs for heat heat machine and wrap w/heat blanket. SI N2, bleed, rig off lines, Plug&cap fittings. Final WHPs= BPV/50/0 6/11/2015 WSS, no tree valves. IA&OA=OTG. 1800 T/I/O= BPV/50/0. Temp= SI. No flowline. Surface casing excavation and repair. WSS attached to Well head. L2RA HWOF, Haz Confined space(See log for controls). Maintain N2 purge during welding and cooling of wellhead to 180*F. Electrician RU heat pads and wrap lower sleeve to bake @ 550*F for 4 hr. Weld upper collar and lower sleeve to OA casing. (Note: Total sleeve length installed is 63" measured from bottom of startinghead tie in point) Electrician bake out lower weld @ 450*F for 2 hr. Made change out W/DHD night crew, continue N2 purge till temp reaches< 180*F. SI N2, bleed, rig off lines, Plug&cap fittings. Final WHPs= BPV/50/0 6/12/2015 WSS, no tree valves. IA&OA= OTG. NOVP. 22:15 T/I/O = BPV/50/0. Temp= SI. No flowline. Surface casing excavation and repair. WSS attached to Well head. L2RA Haz Confined space(See log for controls). Clean work area in cellar and prep for RG 2401 (blue goo treatment). Final WHPs= BPV/50/0 6/13/2015 WSS, no tree valves. IA&OA= OTG. 1800 T/I/O = BPV/50/0. Temp=SI. No flowline. Surface casing excavation and repair. WSS attached to Well head. MIT-OA PASS to 1200 PSI w/diesel. OA FL near surface. Used 2.25 bbls of Diesel to pressure OAP from 0 to 1200 psi. OAP decreased 21 psi in 1st 15 min and 11 psi in 2nd 15 min for a total loss of 32 psi in 30 min. Bled OAP from 1168 to 0 psi in 30 min to slop tank(1 bbls). State (Jeff Jones)declined to witness MIT-OA and Sleeve repair. Denso tape exposed Surface casing. install RG 2401 (blue goo) in conductor. Scaffolding crew dismantel scaffolding in cellar. Final WHPs = BPV/45/0 6/14/2015 WSS, no tree valves. IA&OA= OTG. 1900 T/I/O= BPV/50/0. Temp= SI. No flowline. Surface casing excavation and repair. WSS attached to Well head. Begin to back fill excavation and compact. Final WHPs= BPV/45/0 6/15/2015 WSS, no tree valves, IA&OA =OTG. 1800 Daily Report of Well Operations PBU A-40 T/I/O= BPV/50/35. Temp= SI. No flowline. Surface casing excavation and repair. WSS attached to Well head. L2RA haz confined space see log for controls. Continue to back fill excavation and compact. Cut off 10'x 10'CMP 18" bellow top of 8'x 5'cellar. Final cellar depth 40" Final WHPs = BPV/50/35 6/16/2015 WSS, no tree valves, IA&OA = OTG. 1800 T/I/O=BPV/0/0. Surface Casing Repair. Install dryhole tree and THA. Did not perform PPPOT-T on 6/17/2015 hanger void. Final WHP's BPV/0/0. ***Job Complete***See log. T/I/O = BPV/0/0. Temp= SI. No flowline. Surface casing excavation and repair. WSS attached to Well head. Finsh compacting around excavation. R/D bonnet cap assembly on WSS. Bleed IAP to 0 psi in 20 min (all gas). Bleed OAP to 0 psi in 10 min (fluid .25 bbl).API valve shop and FMC install THA and Dry hole tree. lower WSS to install travling bolts. Final WHPs= BPV/0/0. 6/17/2015 WSS, no tree valves, IA&OA =OTG. 1800 T/I/O= BPV/0/0. Temp= SI. No flowline. Surface casing excavation and repair. Install traveling bolts on WSS. R/D electrical cables and move job site trailers. Remove WSS bolts from H pile and prep to move. Final WHPs= BPV/0/0. 6/18/2015 Dry hole tree, SV=C. MV=O. IA&OA = OTG. 1630 T/I/O= BPV/0/0. Temp= SI. No flowline. Surface casing excavation and repair. Remove WSS and spot on edge of pad. Begin removing fill to pad grade. Excavate around rear H piles and cut off 5' below pad grade. L2RA HWOF& Excavation see log for controls. Final WHPs= BPV/0/0. 6/19/2015 Dry hole tree, SV= C. MV= O. IA&OA = OTG. 1900 T/I/O = BPV/0/0. Temp= SI. No flowline. Surface casing excavation and repair. L2RA HWOF& Excavation see log for controls. Excavate around front H piles and cut below pad grade. P1=5' 10", P2=5'7", P3=5'7.5", P4=5'4", P5=6'4", P6=6' 9", P7=6' 10", P8=6'9", also the thermistor on the left side of the well is cut off 6' below pad grade and the thermistor located in front of the well was removed altogether. Fill in excavation and compact to pad grade. Final WHPs= BPV/0/0. 6/20/2015 Dry hole tree, SV= C. MV= O. IA&OA = OTG. 1600 6/21/2015 Surface casing excavation and repair complete. T/I/O= Dry hole tree/0/0,Temp: SI, PPPOT-T(PASS) Post Surface Casing Repair PPPOT-T: Stung into test void, (0+ psi) bled void to 0 psi. Monitored for 10 minutes, void stayed at 0 psi. Pumped through void, good returns. Pressured test void to 5,000 psi for 30 minute test. Lost 6/22/2015 200 psi in 15 minutes, lost 50 psi in second 15 minutes. (PASS) Bled void to 0 psi. T/I/O=0/0/0. Set VR plug in Comp. OA. Removed OA Temp#72 . Installed blind flange. Torqued 6/27/2015 and PT'd to API specs. (PASSED). RDMO. ***Job Complete*** Final WHP's=0/0/0. T/I/O= BPV/0/0. N/D Dyhole tree. N/U new 4-1/8"x 4-1/16"CIW tree w/Baker actuator. Torqed MV x THA to API spec.. Pull BPV#152 @ 120". Set 4"CIW"H"TWC#294 @ 120", set rough. Test tree thru lubricator. Pulled TWC#284 @ 120", pulled rough. See log for details. ***Job 6/27/2015 incomplete*** ***WELL S/I ON ARRIVAL***(Post SCER) STANDBY FOR SCAFFOLDING 6/29/2015 ***JOB CONTINUED ON 6/30/15*** Daily Report of Well Operations PBU A-40 ***JOB CONTINUED FROM 6/29/15***(post scer) PULLED 4-1/2" DSSSV FROM 2096' MD SET 4-1/2"WHIDDON @ 9574' SLM PULLED ST#2 BK- FS FROM 9,208'SLM, 9,245' MD PULLED ST#6 BK-DGLV FROM 5,509'SLM, 5,544' MD PULLED ST#7 BK-DGLV FROM 3,383'SLM, 3,418' MD SET ST#7 BK-LDGLV @ 3,383' SLM, 3,418' MD SET ST#6 BK-OGLV @ 5,509' SLM, 5,544' MD SET ST#2 BK-DGLV @ 9,208'SLM, 9,245' MD PULLED 4-1/2"WHIDDON FROM @ 9574' SLM PULLED 4-1/2" EVO TRIEVE FROM 9580' SLM DRIFT W/3.70" CENTRALIZER , 4-1/2 TEL, 2-1/2"SAMPLE BAILER, TAG BOTTOM @ 9827' SLM, 9850' ELMD 6/30/2015 ***JOB COMPLETE WELL TURNED OVER TO PAD OP*** Fluids Summary Bbls Type 713.09 DIESEL 100.5 CRUDE 24 METH 201 60/40 METH 652 1% KCL 789 SLICK 1% KCL W/SAFELUBE _ 34 POWERVIS 52 FESHWATER 11 15.8PPG CLASS G CEMENT 2576.59 Total Packers and SSV's Attachment PBU A-40 _SW Name Type MD TVD Depscription A-40 PACKER 9644.67 8609.97 4-1/2"TIW HBBP Packer A-40 PACKER 9698.83 8658.31 5-1/2" H Isolation Packer .„- .,.. 0 . 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"*.,t s 3 ,,, Viiiiiiiiikb P._ TREE= 4-1/16"5MG NOTES:WARNING:RA(1O TRANSMITTER IN 1AELLhEAT FMC A-40 MONITORING SHACK MUST BE TURNED OFF ACTUATOR= BAKER i BEFORE ANY WELL WORK INVOLVING NON RADIO SAFE DIB.RIV= 80 EXPLOSIVE CAN BEGIN.CONTACT PAD OPERATOR"' BF.ELEV= 4T CHROME TBG'"' KOP= 3614' 20'CONDUCTOR109' Mu Angle= Eki _ ' 3, 94#,NT60L�5329' 2096' —14-1/2'OTIS 1-0(0 SSSV NP,0=3.813" tum RADll Datum TVD= 8800'SS D=19.124" 2096' —14-1/2"DSSSV w/2 SETS PKNG,D=2.62"(3/09/15) GAS LFT MANDRELS 10-3/4'CSG,45.5#,NT-80LHE BUTT,D=9.953' ,-j 3061' 1 ST MD TVD DEV TY FE VLV LATCH FORT BATE 7 3418 3416 5 CAMEO DMY BK 0 09/21/12 Minimum ID = 3.725"@ 9685' 6 5544 5296 37 CAMEO DMY BK 0 09/21/12 PARKER SWN NIPPLE 5 7095 6532 37 CAMEO DMY BK 0 09/21/12 4 8139 7363 36 CAMEO DM1 BK 0 09/21/12 3 8790 7895 34 CAMEO DMY BK 0 09/21/12 TOP OF CEMENT N IA (02/09/15) -{ 9416' k'.f' 2 9245 8272 34 CAMEO FS 'BK-P - 03/08/15 kV' . 1 9543 8521 31 CAMEO DMY BK 0 01/02/95 TN UBG PUNCH(02/07/15) 9600'-9601' 'ti 1 ' `STA#2=FS HAS A POR!LD LATCH 9621' H4-1/2"EVO TREY E PLUG(03107/15) II !+ 9636' H4-1/2"PARKER SWS NP,D=3.813" At. IP '4 4P 4 9645'J-1 7"x 4-1/2"TIW HBBP PCR,D=4.0" I 9669' —14-1/2'PARKER SWS NP,D= 3.813" ' SW NN H4-112"PARKER SN FesID, =3.725" TOP OF 5-1/2"LNR 9691' R,D 9391' —7-5/8"X 5-41/2"BKR TK,H FSOLAON PCR &FLEX LOCK HG = " 4-1/2"TBG, 12.6#, 13CR, .0152 bpf, =3.958" —I 9697' ISTi 969T H4-1/2"WLEG,0=3.958" D 9684' H ELMD LOGGED ON 06/28/93 9848'CTMD H FISH-CBP MILLED TO BTM (02/14/15) 9848'-10228' --1FLL(COL MLLED- 02/14/15) 7-5/8"CSG,29.7#,NT-95-HS NSCC,D=6.875' — 985T , PERFORATION SUMMARY REF LOG: TE N LOG,SONIC/GR 06/14/93 ANGLE AT TOP PEF F: 24'@ 9880' Note:Refer to Production DB for historical perf data SEE SPF INTERVAL Opn/Sgz SHOT SO2 3-3/8" 6 9880-9898 C 02/02/96 3-3/8" 6 9980-10020 C 07/28/93 3-3/8" 4 10106-10122 C 06/28/93 FBTD -- 10228' w s,w ♦t ' �.I1� 5-1/2"LNR, 17#,13CR-80 NSCC, H 10315' .0232 bpf,D=4.892" DATE REV BY COMMENTS DATE REV BY COPD NTS PRUDHOE BAY UNR- 06/18/93 N-28E ORIGINAL COMPLETION 03/08/15 JTG/PJC PILL DGLV&SET FS N STA#2 WELL: A-40 02/09/15 DHS/PJd OBSIDIAN PLUG CORRECTION 03/09/15 JTG/PJC SET DSSSV w/2 SETS PACKING PERMIT No:'1930140 02/09/15 TFA/PJC CEMENT SQZ IA 03/11/15 PJC STA#2 FS HAS PORT®LATCH API No: 50-029-22337-00 02/14/15 -1-TRI PJC TAG FLU MILL&PUSH CBT TO BTM04/27/15 AR/PJC CSG/LW UPDATES Sec.35,T11N,R 13E, 1862'FPL&921'FEL 02/16/15 PJC CONDUCTOR SFECS ADDED 03/07/15 JTG/PJC SET EVO TREVE PLUG BP Exploration(Alaska) 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. [ ~ ~. O /~ 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 n Diskettes, No. [] Other, No/Type OVERSIZED -[] Logs 'of various kinds. n Other COMMENTS: Scanned by: ~, Dianna Vincent Nathan Lowell :] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20` Post Office Box 196612 Anchorage, Alaska 99519 -6612 -" May 18, 2012 S . N D AUG 7 ‘ 401 Mr. Jim Regg , 613 0 t Alaska Oil and Gas Conservation Commission , i 333 West 7th Avenue 0 Anchorage, Alaska 99501 ct Subject: Corrosion Inhibitor Treatments of GPB A -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad A that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) A -Pad Date: 04/15/2012 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal A -01A 2012420 50029201080100 1.3 NA 1.3 NA 11.10 7/21/2009 A-02 1710310 50029201090000 1.9 NA 1.9 NA 13.60 7/22/2009 A-03 1710380 50029201130000 0.5 NA 0.5 NA 5.10 7/21/2009 A-04 1720060 50029201150000 0.0 NA NA NA NA NA A-05A 2061280 50029201160100 0.0 NA NA NA NA NA A -06 1720180 50029201180000 0.8 NA 0.8 NA 6.80 7/21/2009 A -07 1730410 50029201310000 0.8 NA 0.8 NA 5.10 8/12/2009 A -08 1740040 50029201320000 No conductor NA NA NA NA NA A -09A 2001740 50029205520100 0.5 NA 0.5 NA 3.40 7/21/2009 A -10 1810300 50029205680000 14.0 NA 14.0 NA 103.70 7/22/2009 A -11 1810380 50029205750000 5.0 NA 5.0 NA 17.00 7/22/2009 A -12A 2071300 50029205150200 0.5 NA 0.5 NA 3.40 7/22/2009 A -13 1811590 50029206720000 0.3 NA 0.3 NA 2.55 4/15/2012 A -14 1810770 50029206050000 3.3 NA 3.3 NA 17.00 7/19/2009 A -15 1810780 50029206060000 0.5 NA 0.5 NA 3.40 7/19/2009 A -16A 1960980 50029205210100 0.3 NA 0.3 NA 1.70 7/19/2009 A -17A 2061250 50029205200100 0.3 NA 0.3 NA 2.60 7/19/2009 A -18 1921070 50029206300100 SC leak NA NA NA NA NA A -19 1811270 50029206480000 0.8 NA 0.8 NA 3.40 7/19/2009 A -20 1820130 50029207090000 0.8 NA 0.8 NA 5.10 7/20/2009 A -21 1820140 50029207100000 2.0 NA 2.0 NA 16.15 7/20/2009 A -22 1820180 50029207120000 Sealed conductor NA NA NA N/A NA A -23 1820240 50029207160000 0.3 NA 0.3 NA 3.40 7/20/2009 A -24 1820700 50029207430000 29.0 5.8 0.1 11/27/2009 1.70 3/18/2010 A -25A 2011480 50029207640100 0.3 NA 0.3 NA 1.70 8/13/2009 A -26L1 1971060 50029207946000 0.3 NA 0.3 NA 1.70 7/21/2009 A -27A 1982350 50029208090100 7.5 NA 7.5 NA 71.40 7/20/2009 A -28 1821500 50029208250000 2.5 NA 2.5 NA 20.40 7/20/2009 A -29 1821670 50029208410000 9.0 NA _ 9.0 NA 62.90 7/21/2009 A -30A 2040780 50029213720100 0.3 NA 0.3 NA 1.70 7/19/2009 A -31A 1990560 50029213830100 0.8 NA 0.8 NA 4.30 7/19/2009 A -32A 1990580 50029213950100 2.0 NA 2.0 NA 17.00 4/11/2012 A -33 1851830 50029214100000 0.8 NA 0.8 NA 3.40 8/12/2009 A -34A 1851050 50029213390100 4.4 NA 4.4 NA 28.90 7/22/2009 A -35 1850510 50029213130000 1.3 NA 1.3 NA 10.20 7/22/2009 A -37 1930070 50029223310000 0.0 NA NA NA N/A No treat A -38 1930320 500292234700 0.1 NA 0.1 NA 0.85 4/15/2012 A -39 1930280 50029223440000 0.5 NA 0.5 NA 3.40 7/21/2009 . --=j A -40 1930140 50029223370000 0.5 NA 0.5 NA 3.40 7/22/2009 A -41 1941580 50029225300000 SC leak NA NA NA NA NA A -42A 2061300 50029225420100 0.6 NA 0.6 NA 5.10 7/20/2009 A -43 1960860 50029226770000 0.3 NA 0.3 NA 1.70 8/12/2009 A -44 2090410 50029234120000 1.5 NA 1.5 - NA 8.50 6/24/2009 OPERABLE: A-40 (PTD #1930140)Tubing Integrity Restored • Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, July 17, 2008 7:30 PM ~-~~ff ~~~~(~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC3 Wellpad Lead; GPB,~~C3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Kimmet, Megan; GPB, Gas Lift Engr; NSU, ADW Well Integrity Engineer; Winslow, Jack L. Subject: OPERABLE: A-40 (PTD #1930140)Tubing Integrity Restored AI#, Well A-40 (PTD #1930140} passed a TIFL post-gas lift valve chance out an 07/17!08. The passing test verifies that tubing integrity has been restored. The well has been reclassified as Operable and may be put on production :.i when convenient. Please call with any questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~f~N~~3 S~~ :~ 2008 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, July O8, 2008 8:11 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, GC3 Wellpad Lead; GPB, GC3 OTL; GPB, Area Mgr Central (GCl/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Kimmet, Megan; GPB, Gas Lift Engr Subject: UNDER EVALUATION: A-40 (PTD #1930140) for Sustained casing pressure due to TxIA Comm Hi all, Well A-40 (PTD #1930140) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to SSV/2040/0 psi on 07/01/08. Due to the constraint of not being able to bleed pressure down to the production system due to the shut-down, the diagnostic work took more days to complete. On 07/08/08, a TIFL failed confirming TxIA communication. ,The well has been reclassified as Under Evaluation and placed on a 28-day clock. Operations may allow the IA pressure to continue to build pressure. The plan forward for the well is as follows: 1. DHD: TIFL -FAILED 2. Well Integrity Engineer: Evaluate for gas lift valve change out 3. Slickline: Change out gas lift valves 4. DHD: re-TIFL A TIO plot and wellbore schematic have been included for reference. Please call with any questions. 8/29/2008 OPERABLE: A-40 (PTD #1930140)Tubing Integrity Restored • Page 2 of 2 • Thank you, Anna ~?u6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 Pager: {907) 659-5100 x1154 8/29/2008 PBU A-40 PTD 193-014 a,ooo ................................................R-0II'TT~T'1t3t............... -~- Tbg 3,000 -f- IA • 2,000 1,000 f OA OOA • 0 418!2008 af23C2008 SISE2008 5{23F2008 6(7!2008 6C12C1008 7!812008 7r13l2008 TREE= 4-1/16" 5M CM1 WELLHEAD= FMC ACTUATOR= BAKER KB. ELEV = 81' BF. ELEV = 47' KOP = 3614' Max Angle = 38.50 @ 5329' Datum MD= 9943' DatumTVD= 8800'SS 10-3/4" CSG, 45.5#, J-55 BUTT, ID = 9.953" H 3061' Minimum ID = 3.725"@ 9685' PARKER SWN NIPPLE ITOPOF5-1/2"LNRH 9691' 4-1/2" TBG, 12.6#, 13CR 0.0152 bpf, ID = 3.958" 969T 7-5/8" CSG, 29.7#, NT-95-HS NSCC, ID= 6.875^ H 9857' PERFORATION S UMMA RY REF LOG: T1E IN LOG, SONIC/GR 06/14/93 ANGLE AT TOP PERF: 24 @ 9880' Note: Refer to Roduction DB for historical oerf data SQE SFF NTBZVAL Opn/Sqz DATE 3-38" 6 9880-9898 O 02/02/96 3-3/8" 6 9980-10020 O 07/28/93 3-3/8" 4 10106-10122 O 06/28/93 I PBTD r-j 10228' 5-1/2"LNR, 17#, 13-CRNSCC, 0.0232 bpf, ID= 4.892" 10315' SAFEfY NOTES: WARNING: RADIO TRANSMITfERIN A 40 WEATHER MDNffORING SHACK MUST BE TURNED _ OFF BEFORE ANY W~L WORK INVOLV ING DCPLOSN E5 CA N BEGIN. C ONTACT PAD OPERATOR 13 CHROMIUM TBG N WELL 2096' 4-1/2" OTIS SSSV NIP, ID= 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH SIZE DATE 7 3418 3335 4 CAMCO BK 1" 6 5544 5215 37 CAMCO BK 1" 5 7095 6451 37 CAMCO BK 1" 4 8139 7282 36 CAMCO BK 1" 3 8790 7815 34 CAMCO BK 1" 2 9245 8191 34 CA MCO BK 1 " 1 9543 8441 30 CA MCO BK 1 " 9636' 4-1/2" PARKER SWS NIP, ID= 3.813" ~ 9645' H7" x 4-1 /2" TNV HBBPPKR, ID=4.0" 9669' 4-1/2" PARKER SWS NIP, ID= 3.813" 9685' 4-1/2"PARKER SWN NIP, ID=3.725" 969T 4-1/2" WL~ 9699' WLEG ELMD LOGGED 06/28/93 DOTE REV BY COMMENTS DATE REV BY COMMENTS 06/18FJ3 ORIGINAL COMPLETION 02A~6i01 SIS-MH CONVB~T® TO CANVAS 03ro5A~1 SIS-LG FlNAL 05/20/01 RPYKAK CORRECTIONS PRUDHOE BAY UNIT WELL: A-40 PERMIT No: 93-0140 API fib: 50-029-22337-00 Sec. 35, T11N, R 13E BP Expbration (Alaska) THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE DECEMBER 01, 2000 E PL W El lA L U N D ER M A T C:LO~ILM.DOC TH IS M ARK ER 12/12/96 To: Blair WondzeU P! Supervisor Ref: Water & Gas to Surface @ BPX PBU A-Pad ('-'~- ~ ..../-¢2) We got the gas sample analogous back from the lab and it was confirmed that the sample was Lift Gas and not MI. _.-- Lift gas was shut off in the five wells one at a time, when the LG in well A- 7 was shut-in and the IA bled off, the gas bubbling and water in all cellars subsided. It took about 3 hours for the water to evacuate the cellar in A-5. ! went back to the Pad at about 6:00 PM, there was no water in any of the cellars however there was gas still bubbling up in A-5 & 40 cellars. The injection rate on well A-Si had been brought back up to 3350 psi, and all annuli were bled to 100 +t- psi. The gravel inside and outside of the cellars of A-.__.5,.4~0 & 4~3 had subsided about 24' this subsidence extended about two foot around the outside of the weiihouses. Tomorrow 12/13/96 we will simulate the same conditions that existed wt3en the flow to surface commenced, if A-7 will continue to flow all night wit/lout LG. This should confirm or deny that AJT~'~ the fault of this flow. I wilt write a real report to you and David after we have the final results of tomorrow's simulation. This is just a FYI to keep you up to speed on the issue. tf you have any other questions you need answered please call me at 448-1227 or page me and I will do my best to answer them for you. Doug Amos RECEIVED DEC 1 5 1996 Alaska Oil & Gas Cons. Commission i~P EXIt. ORaN Memorandum ~-o: Production Supt. o,..: 12/11/96 Ken Smith, N.S.P.E s.~t.:,: A-Pad__Fresh Water/Gas Production in Cellars The following is a chronological break down of events on A-Pad involving wells A-5, A-7, A-8i, A-40 and A-43. Date: i1 ¢-6-96 1~8-96 1~--9-96 Daily events GC-3 produced water system was shut down for 18 hours for repairs in skid 301. Subsidence was reported in well house of Well A-43. Well A-08i was converted from produced water(PW) to miscible injection (MI). This is the first time A-08i has been ~ on miscible injection. The following readings were on produced water. FWHP:1050psig, FWRT: 140deg F, IA: 100psig, CA: 560psig A-pad & X-pad went down due to logic problems, all wells were down for 5 hours. A-08i well readings on MI; WHP:3350 psig, WriT: 130 deg F, IA: zero, CA: zero The night Pad Operator found standing water in the cellar in well A-7. The day Pad Operator found flooding with gas bubbling in well houses A-43, A-40, and A-5 cellars. LEL readings are found to be as high as 30% in cellar but only a traCe inches above cellar, Twenty four hour man watch initiated by Production Engineers. Samples of w~ter taken by BPX lab and found to be fresh at 1000 ppm chlorides. Area has been roped off and access restricted. Peak vac truck brought on location and sucking down cellars as needed. ur_L, Oil & 6~s Cons. Miscible Injection was shut in on well A-8i. No effect was found on offset wells. Well was brought back on at half rate to monitor ',veil integrity. A-8i casing pressures remain at zero. 10-11-96 Night pad operator reported major subsidence plus watedgas in Well A-43 well house. Well A-5 has major gas/water production. Gas samples taken from Well A-5 cellar by BPX lab. Vac Truck recovered 1000 bbls of water from cellars. Watedgas production has ceased in Well A-7. Wells A-43 and A-40 have subsided by 30%. Well A-5 water/gas production continues unchanged. Waiting on gas analysis. Vac truck ceases liquid recovery but remains on location with man watch. Subsidence of wells in question since September 1996: A-07' None A-05: 4 yards of gravel A-40: 10 yards of gravel A-43: 62 yards of gravel Note: Previous records could not be found by subsidence crew. Night Pad Operator reports conditions are improving, Area remains restricted and man watch continues. Please find attaChed the pad map, Pad Operator's daily readings and comments. Course of action and Interpretation. Continue to monitor wells and sample liquid and gas production for possible well integrity failure, At this time a suspected failure of well Integrity is not warranted. The source of the fresh water is assumed to be from known underground streams which were documented prior to pad construction in the early 1970's. The suspected cause of the problem is continued melting of the permafrost by each wells proximity and the migration of gases known to exist in and under the permafrost. p,r- -, Alaska 0il & G~s Cons. FLARE PIT SEWAGE 29" SUMP 21 =-- 20',~'- SUMP 13~, 3~ = 12"- 34A~- 11-- 10--- SUMP TO D PAD ... 14 15 31 16 17 ["] WELL AND 6' PRODUCTION LINE ~ WELL, 6' PRODUCTION LINE, AND 3" GLT LINE · WELL, 6" WSW LINE, AND 4' MI LINE O WELL, 4' PRODUCTION LINE, AND 3' GLTLINE * SUBSIDENCE WELL -3- GLT TWINS:WELLS A-41 & ^-34A A-23 & A-24 A-9 & A-,39 A-2 & A-4 MI TRUNK & LATERAL: WELLS A-3 & A-$ / A-11 & A-3~ / A-16 & A-31 / A-21 & A-27 O CELLAR ONLY I~ PRODUCTION & GLT TWIN: A-22 & A-42 '~- WSW TWIN R:t WELLHEAD AND CELLAR AI;~sK~ 0il & 6~.s Gons. ~. n~,.kr, rg[ln STATE OF ALASKA ,-~LASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing . . Alter casing __ Repair well__ Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1862'SNL, 921'WEL, SEC. 35, T11N, R13E At top of productive interval 454 'NSL,2748'WEL, SEC. 35, T11 N, R 13E At effective depth 4884 'SNL,2833'WEL, SEC. 35, T11N, R 13E At total depth 371 'NSL,2857'WEL, SEC. 35, T11N, R 13E 5. Type of Well: Development X Exploratory ..... Stratigraphic ... Service ~ 6. Datum elevation (DF or KB) KBE=80.58 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-40(24-35-11-13) 9. Permit number/approval number 93-14 / 10. APl number 50- 029-22337 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Structural -- Conductor 110 20 S u trace 3025 10 3/4 Intermediate 9826 7 5/8 Production -o Liner 624 5 1/2 Perforation depth: measured 10106'- 10122' 10315 feet 9220 feet 10228 feet 9141 feet Plugs (measured) Junk (measured) Cemented 11 yds Arcticset 1862 c.f CS 11/408 c.f G 305 c.f. Class "G" 152 c.f. Class "G" Measured depth True vertical depth BKB 3061 9857 9691-10315 3061 88O3 8652-9221 true vertical subsea9029'-9044' Tubing (size, grade, and measured depth) 4-1/2"13CR @9697' Packers and SSSV (type and measured depth) Packerset @9645'& SSSV2096' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 917 1486 1495 2480 838 1124 1505 2510 Tubing Pressure 228 233 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operation~ Oil _X. Gas Suspended 17. I hereb~/~ertif~that ~he/foreg~'m~(is true an~l co.~rrect to the best of my knowledge. Signed'''~,~/,~/~,~ ?~/////,-, ~"~,,/~--.,-z..~.<~ Title Technical Assistant III Form 10-404 Rev~06/1-5/8§ - - " Service Date /~..~/~ l SUBMIT IN DUPLICATE WELL A-40 (24-35-11-13) Addperf 2/02/96 The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 9880'-9898' MD PERMIT 9 3 .... 0 i a. 9 3 --' 0 1 9 3 '-' 0 I a. 9 3 ...... 0 1 a. 93 .... 0 , ! A06CC Ind'¥v'¥dua'l We'i'i Geolog'¥caJ Ma't:er'"ial s :lT. isventor'.y D A T A T D ,,-', ~ A _..~P t... I S 569'3 ~025 ..... i0367 hO7 ~Of','lP DATE ~ 6,,. :28 ..... 93 ,"4. 07 ~ E V I S E D .E)AZt..Y ~,,,tEL.!... C,P ,....-'~6/0~/93 TO 6/'18/'93 DAZLY WELL ,'DP,, u.~"~: 6--0/.,--93 TO 6--18.-.-93 SURVEY ~ SPERRY S!Ji'..t BHC(SONIC TOOL.) ~ 9050 .... 10300 o .. D S 0 ..:,3 .... 01,4 ..TI.. PHA R 93 ..... 0 t/.,,. PERF C'~ ~ ..:,3 ...... 0la PF'C PROD 9 3 ~- 0 1/.~. 8 B T ~4:1. 9050 ..... 10300 ~'~.. 'noOO~r,~. ..... 101.9k. ~9850 ..... 10100 ~,-E/~ R'i ~5~1,~9800 .... '10196 ~9720 .... 10189 Ape ..r"y a'itch samp'/es Was '.l::.he v,,'e1'l cor'ed° we1'1 tests r'equ'¥r'ed?~],.yes (~ Rec:e'~_ 'i' s '¥ n c o trip 1 ~ a n (:: e ....... Z n" t: ".-i '~. 'i' a '1 C 0 M bi E N 7' S \,,l e '1 1 r'equ'~ r"ed? yes ~__~~ct r'ece'i,v'~d°,, i::' a ,;jj e ' D a 't: e; y e S r"e c e 'i' v e d '? tq o i 04.,/1 '1/'95 DA, TE ..... F:ECVD 07/.'/06/' 'l ,993 os/o2/1993 10/20/1993 10/'20/'1993 08/02// 1993 0,9 / 02 / 1 q 93 '), ,.., '.., 07/06/ 1993 o7/o6/.199; 07/I 2/" '199:!:; [.) 8/" 0 9/" I 9 9 3 t O/'Oh/' 1993 0 '? / .'f) 0 / 1993 y .*? 3 i"~ 0 INDIVIDUA~d, ELL GEOLOGICAL INVENTORY REPORT 11/18/1993 PAGE: PERMIT DATA DETAIL 93-014 BHC(SONIC TOOL) 9050-10300 93-014 DIL PHASOR 9050-10300 93-014 PERF 9200-10194 93-014 PFC 9850-10100 93-014 PROD 93-014 SBT R1,5",9800-10196 9720-10189 93-014 407 COMP DATE:6-28-93 93-014 407 REVISED 93-014 93-014 DAILY WELL OP DAILY WELL OP. 6/04/93 TO 6/18/93 6-04-93 TO 6-18-93 93-014 SURVEY SPERRY SUN 93-014 5693 9025-10367 SUMMARY Are well tests required? Yes No Was well cored? Yes No If yes, was the core analysis & description received? Are dry ditch samples required? Yes No Yes No WELL IS IN COMPLIANCE. INITIAL COMMENTS: STATE OF ALASKA AL.. (A OIL AND GAS CONSERVATION COMMIS 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 1862'SNL, 921'WEL, SEC. 35, T11N, R13E At top of productive interval 454'NSL,2 748'WEL, SEC. 35, T11 N, R 13E At effective depth 4884 'SNL, 2833'WEL, SEC. 35, T11 N, R 13E At total depth 3 71 'NSL,2857'WEL, SEC. 35, T11N, R 13E 12. Present well condition summary Total depth: measured true vertical 10315 feet 9220 feet 5. Type of Well: Development Exploratory Stratigraphic Service Plugs (measured) 6. Datum elevation (DF or KB) KBE=80.58 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-40(24-35-11-13) 9. Permit number/approval number 93-14 / 10. APl number 50- 029-22337 11. Field/Pool Prudhoe Oil Pool Effective depth: measured true vertical 10228 feet 9141 feet Junk (measured) Casing Length Size Structural -- Conductor 110 20 Surface 3025 10 3/4 Intermediate 9826 7 5/8 Production -- Liner 624 5 1/2 Perforation depth: measured 10106'- 10122' Cemented 11 yds Arcticset 1862 c.f CS 11/408 c.f G 305 c.f. Class "G" 152 c.f. Class "G" Measured depth 3061 9857 9691-10315 True vertical depth BKB 3061 8803 8652-9221 true vertical subsea902959044' Tubing (size, grade, and measured depth) 4-1/2"13CR @9697' Packers and SSSV (type and measured depth) Packer set @9645'& SSSV2096' NOV 8 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure AJaska Oil & Gas Cons. Anchora.(~e 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 860 961 320 2070 1910 1006 2915 1410 Tubing Pressure 245 264 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 Ce,L'tify that ?e foregoin, g~ true an, d correct to the best of my knowledge. Signed ~7~/,~_~_~ (///-/ [A.,~: Title Senior Technical Assistant, Form 10-404 ~R~v 06/15/88 ~ ' ' Date SUBMIT IN DUP'LICATE WELL A-40 ( 24- 35-11 - 13 ) Hydraulic Fracturing 7/28/93 The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 120° phasing. 9980' - 10020' MD 9/25/93 A Hydraulic Fracture (Ivishak) was performed using the following fluids FLUIDS PUMPED DOWNHOLE 20 Bbls 40# Gel Prepad To Establish Rate 19,7 Bbls 40# X-Link Gel Pad 8.7 Dirty I Ppg 4 2 Ppg 2 3 Ppg 3.3 4 Ppg 4 5 Ppg 6 6 Ppg 3.3 7 Ppg 37.1 8 Ppg 144 20# Linear Gel Flush LOAD VOLUME:1061 (TOTAL FLUIDS PUMPED DOWN HOLE) 50 Total diesel pumped downhole 0 Diesel Recovered 50 Total Diesel 1111 TOTAL FLUID 10/01/93 A Hydraulic Refracture (Ivishak) was performed using the following fluids: FLUIDS PUMPED DOWNHOLE 20 Bbls 40# Gel Prepad To Establish Rate 18 Bbls 40# X-Link Gel Pad w/no ESL 8 Dirty I Ppg I 2 Ppg I 3 Ppg 3 4 Ppg 4 5 Ppg 6 6 Ppg 7 7 Ppg 133 8 Ppg 79 20# Linear Gel Flush LOAD VOLUME:480 (TOTAL FLUIDS PUMPED DOWN HOLE) 15 so 70 Total diesel pumped downhole Diesel Recovered Total Diesel ~nchor'a.r.~e fjh 11/02/93 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOUP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SLISPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 93-14 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50-029-22337 4. Location of well at surface 9. Unit or Lease Name 1862'SNL, 921' WEL, SEC. 35, T11N, R13E ~~~-~__ ~ !' ~- '/~ A-40Prudh°e Bay Unit(24-35-11-13) ; ...... , " 10. Well Number At Top Producing Interval i ~'4'T~ ' !,,~"~'~I 454' NSL, 2748' WEL, SEC. 35, T11N, R13El --!.L~-~-.-~-~i i ¥~F!ED I 11. Field and Pool At Total Depth iXT~'~C.~_._~ ~~ ~.. ~ Prudhoe Bay Field/Prudhoe Bay Pool 371' NSL, 2857' WEL, SEC. 35, T11N, R13E~-~.~--~"~ '/ ' ~ .:i.;:- 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. KBE = 80.58' I ADL 28286 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. o~ Aband. 115. Water Depth, if offsho re 116. No. of Completions 6/4/93 6/14/93 6/28/93I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDI 19. Directional Survey ~0. Depth where SSSV set ~21. Thickness of Permafrost 10315' MD/9220' TVD 10228' MD/9141' TVD YES [] NO []! 2096' feet MD ! 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/BHC/GR 123. CASING, LINER AND CEMENTING RECOFID SE'I-riNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 31' 110' 30" 11 yds Arcticset 10-3/4" 45.5# NT-8OLHE 36' 3061' 13-1/2" 1862 cuft CS 11/408 cu ft Class "G" 7-5/8" 29.7# NT-95 31' 9857' 9-7/8" 305 cu fl Class "G" 5-1/2" 17# 13CR80 9691' 10315' 6-3/4" 152 cu fl Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter 3-3/8" 4 spf 4-1/2", 13CR 9697' 9645' MD TVD 10106'-10122' 9029'-9044' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 6/30/93 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description o! lithology, porosity, lractures, apparent dips, and presence of oil, gas or water. Submit core chips. * Completion notice revised to reflect the correct liner grade 10/19/93 ~as~a Oit & Gas Cons, Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ; ( 30. GEOLOGIC MARKERS r-(.~MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 9874' 8817' Shublik 9897' 8838' Sadlerochit 9979' 8913' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed " T it lo Senior Drilling Eno_ineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. R E C E!'~~ ~ Item 28: If no cores taken, indicate "none". Form 10-407 OCT 2 0 1993 Oil & Gas Cons. Cornmi~.' BP/AAI SHARED SERVICE WELL: A-40 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: APl: 50- PERMIT: APPROVAL: DALLY 'OPERATIONS PAGE: 1 ACCEPT: 06/04/93 03:00 SPUD: 06/04/93 09:30 RELEASE: OPERATION: DRLG RIG: NABORS 28E WO/C RIG: NABORS 28E 06/04/93 (1) TD: 0 PB: 0 NU DIVERTER RISER MW:10.1 KCI TURNKEY WELL TO WELL RIG MOVE. NU DIVERTER & RISER. TAKE ON WATER IN MUD PITS. .~ 06/05/93 ( 2) DRILLING MW: 9.1 VIS:248 TD: 1900'( 0) NU DIVERTER/RISER & MIX SPUD MUD. FUNCTION TEST DIVERTER. STRAP & MAKE UP BHA. ORIENT. DRILL FROM 109'TO 1711'. SHORT TRIP 10 STDS TO 750'. NO DRAG & NO FILL ON BOTTOM. DRILL FROM 1711' TO 1900'. 06/06/93 ( 3) NIPPLE DOWN MW: 9.5 VIS: 46 TD: 3080'(1180) DRILL FROM 1900 TO 3080. CIR BOTTOM UP. SHORT TRIP TO HWDP. WORKED THROUGH TIGHT HOLE @ 2178' WHILE POH. HOLE CLEAN WHILE TIH. CIRCULATE. TRIP OUT OF HOLE TO RU 10 3/4" CASING, TIGHT HOLE @ 2100'. RIG UP & WASH & WORK CASING THROUGH TIGHT HOLE FROM 2100 TO 2140. RUN 10 3.4 CASING MAKE UP CEMENT HEAD. CIRCULATE@ 10 BTM. TEST CEMENT LINES & CEMENT 10 3/4" CASING AS PER WELL PLAN. BUMPED PLUG. RIG UP & PERORM 250 SACK TOP JOB. LD LANDING JOINT & NIPPLE DOWN RISER & FLOW LINE. 06/07/93 ( 4) SHORT TRIP MW: 9.1 VIS: 40 TD: 4100'(1020) NIPPLE DOWN DIVERTER & NIPPLE UP BOPE. TEST BOPE. PULL TEST PLUG & INSTALL BOWL PROTECTOR. PICK UP, STRAP & ORIENT BHA fl~2. TRIP IN HOLE WITH BHA #2. TAG UP @ 2969. PRESSURE TEST 10 3/4" CASING. DRILL CEMENT, FLOAT EQUIPMENT & 10' NEW HOLE TO 3090'. PERFORN L.O.T.. 16.1 PPG EMW. DRILL 9 7/8" HOLE & KICK OFF FROM 3090 TO 4100. SHORT TRIP 10 STDS. 06/08/93 ( 5) DRILLING MW: 9.7 VIS: 44 TD: 5925'(1825) 10 STAND WIPER TRIP. SOME SWABBING. NO FILL ON BOTTOM. DRILL FROM 4100 TO 5023. 15 STAND WIPER TRIP. SOME TIGHT SPOTS. NO SWABBING. NO FILL ON BTM. DRILL FROM 5023 TO 5690. CIRC SWEEP. TRIP OUT OF HOLE & CHANGE BIT. SERVICE WEAR BUSHING. TRIP IN HOLE. REAM 3 JOINTS TO BOTTOM. DRILL FROM 5690 TO 5925. 06/09/93 ( 6) DRILLING @ 6860' MW: 9.9 VIS: 40 TD: 6860'( 935) DRILL FROM 5925 TO 6739'. CBU W/HV SWEEP & PUMP PILL. POH. SWR. RIHTOSHOE. CUT & SLIP DRILLING LINE. RIHT(~ ~ ,~.. ~ 6639'. NO FILL. DRILLING F/6739 TO 6860'. ~, L I ~,/ ~L.~; OCT 2 0 995 0il & Gas Cons. Commissio~ WELL : A-40 OPERATION: RIG : NABORS 28E PAGE: 2 06/10/93 ( 7) DRILLING @8405 MW: 9.8 ViS: 41 TD: 8405'(1545) DRILLING F/6860 TO 7694'. SHORT TRIP TO 6634'. NO FILL. DRILLING F/7694 TO 8405'. 06/11/93 ( 8) DRILLING @ 9499 MW: 9.9 VIS: 44 TD: 9499'(1094) DRILLING F/8405 TO 8767'. SHORT TRIP TO 7767'. DRILLING F/8767 TO 9459'. CBU W/HV SWEEP. DROP SURVEY & PUMP PILL. POH & CHANGE BHA. SWR. RIH TO 9367'. DRILLING F/ 9459 TO 9499'. 06/12/93 ( TD: 9869'( 9) POH L/D 5" DP MW: 9.9 VIS: 44 370) DRILLING F/9499 - 9869. CBU. SHORT TRIP 16 STDS TIGHT F/ 9362- 9110 & RIH F/9551 - 9646. NO FILL. CBU W/HV SWEEP. SHORT TRIP 11 STDS. WORK TIGHT SPOTS CLEAN. NO FILL. CBU W/HV SWEEP & DROP SURVEY. POH L/D 5" DP. 06/13/93 ( 1 TD: 9869'( 0) RU TO TEST BOPE MW: 9.2 VIS: 32 0) POH L/D 5" DP, L/D BHA & BREAK KELLY. CHANGE RAMS TO 7 5/8 & BODY TEST TO 5000 PSI. RU & RUN 7 5/8 CSG TO 3060. CBU. RUN 7 5/8 CSG TO 6680'. CBU. RUN 7 5/8 CSG & CIRC LAST JT TO BOTOOM. CIRC & CONDITION CUDD. TEST CMT LINES. L/D CH & LJ. INSTALL & TEST PACK OFF. CHANGE RAMS TO 3 1/2. CHANGE OUT KELLY. R/U TO TEST BOPE. 06/14/93 ( 1 TD :10238'( 1) DRILLING @ 10238 MW: 9.0 VIS: 46 369) TEST BOPE. INSTALL WR, MU BHA & PU HWDP. SLIP & CUT DRILLING LINE. RIH P/U 3 1/2 DP. WASH F/9670 TO 9773. CBU TAG FC @ 9775. TEST CSG. DRILL OUT PLUGS & FC TO 9777 & CMT TO 9847. RETEST CSG. DRILL OUT CMT F/9847 TO FC @9857 & CMT TO 9869. DRILLING F/9869 TO 10232. 06/15/93 ( 1 TD:10315'( 2) RIH W/5 1/2 LINER ON 3 1/2 DP MW: 9.0 VIS: 46 77) DRILLING F/10238 TO 10315'. SHORT TRIP TPO 9857'. CBU W/ SWEEP, DROP SURVEY, RABBI'Ir' & PUMP PILL. POH. RU SCHLUMBERGER & RUN #1 DIL/BHC/GR. & RD. RIH. CBU W/HV SWEEP. POH & L/D BHA. RU & RUN 5.5 LINER, CIRC CASG VOL. RIH W/5 1/2 LINER ON 3 1/2 DP. 06/16/93 (13) CBU MW: 8.7 VIS: 37 TD:10315'( 0) RIH W/5-1/2" LINER, CIRC & RECI., PUMP 25 BBLS CMT, POH & L/D RUNNING TOOL, PU 6-3/4" BHA & RIH TO 9350', WASH GREEN CMT F/9350' TO LINER TOP @ 9691', CBU, POH, RU 4-3/4" & RIH TO LNR TOP @ 9691°, DRLG MED HARD CMT F/9691'-9734', RIH F/9734' TO LC TOP @ 10228', CBU 06/17/93 (14) TD:10315'(0) RUN 4 1/2" TUBING MW: 8.7 VIS: 0 TEST 7 5/8, LAP & 5 1/2 LINER. DISPLACED WELL W/30 BBL SWEEP, 250 BBL FRESH H20, 1060 BBL SEA H20. TEST 7 5/8, LAP & 5 1/2 LINER. POH LAYING DOWN 3.5 DP. TIGHTEN GRAYLOCK CLAMP BETWEEN BLIND RAMS & UPPER PIPE RAMS. RU AND RUN 4 1/2" 12.6~ 13 CR NSCT TUBING. RECEIVED OCT 2 0 199; Alaska 0il & Gas Cons. uurnmissio¢ Anchorage WELL · A-40 OPERATION: RIG · NABORS 28E PAGE: 3 06/18/93 (15) RELEASED RIG @ 0100 HRS. MW:10.1 KCl TD:10315 RUN 4 1/2 12.6# 13 CR NSCT TBG. INSTALL SSSV, CONNECT & PB:10228 TEST CONTROL LINES. PRESS. UP PKR. LD LJ, SET 2 WAY CHECK & CLEARED FLOOR. ND BOPE. NU CONTROL LINES, ADAPTOR FLANGE & XMAS TREE. INSTALL BULL PLUGS, NEEDLE VALVES & SECURE WELL & RELEASE RIG @01:00 HRS 06/18/93. RECEIVED OCT 2 0 t993 Aiaska 0il & Gas 0ohs. uur~miss~°~ Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard Re. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 09/22/93 T# 85045 BPX/PBU~LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. BRIDGE PLUG 09/15/93 a-24 ~70 CNn ~ ~lcO%- 09/18/93 A-40q~-i~ PRODUCTION LOG~ 09/17/93 C-03 ~~ PRODUCTION LOG ~ 09/15/93 D-09~-~5 ~PE~)~/~ 09/16/93 D-27 ~-~ ~PE~) ~ ¢C~ 09/16/93 G-~07~¥~ PRODUCTION LOG ~ 09/14/93 P-02 9~ ~E~ ~~ 09/13/93 P-2~ SBL~ ~ 09/16/93 P-23~%%% ~E~)~I~CC~ 09/16/93 P-23/ ~k/CCL {~% 09/16/93 R-01~9 ~E~') ~~~u 09/18/93 S-05 ~-%~ CCL (~ ~=~) 09/17/93 U-11~ ~ SBLI~I~U 09/13/93 U-1 lB ]~-~~ (~ 09/13/93 U-11BI (PE~) ~IG~ 09/14/93 X-02 ~-~ ~PE~)~/~ 09/15/93 X-27 ~ CNA/6~[cC% 09/18/93 . Information Control Well Records 9250.00- 9700.00 ATLAS 5 " 10600.00-11052.00 ATLAS 5 " 9800.00-10196.00 ATLAS 5 " 9800.00-10188.00 ATLAS 5 " 10230.00-10494.00 ATLAS 5 " 9100.00- 9634.00 ATLAS 5 " 11000.00-11356.00 ATLAS 5 " 12480.00-12736.00 ATLAS 5 " 11488.00-12175.00 ATLAS 5 " 11833.00-12100.00 ATLAS 5 " 11488.00-12175.00 ATLAS 5 " 8740.00- 9130.00 ATLAS 5 " 9340.00- 9552.00 ATLAS 5 " 10100.00-11013.00 ATLAS 5 " 10100.00-11013.00 ATLAS 5 " 10200.00-10850.00 ATLAS 5 " 9630.00- 9914.00 ATLAS 5 " 11150.00-11719.00 ATLAS 5 " OCT 0 4 199,] Alaska Oil & Gas Cons. C°~rnis~io~7 Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 08/04/93 T# 84842 BPX/PBU~LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-18A~ , PDK-100 A-40 ~%~t~% PFC G-08~% ~ CNL PORO H-15 ~%~% CNL PORO H-30~~ PFC~ P-04~%'q~ PRODUCTION LOG 07/24/93 07/29/93 #1 07/28/93 #1 07/28/93 #1 07/27/93 #1 07/26/93 #1 9600.00- 9911.00 ATLAS 5 " 9850.00-10100.00 ATLAS 5 " 11300.00-12351.00 ATLAS 5 " 10850.00-11388.00 ATLAS 5 " 10870.00-11100.00 ATLAS 5 " 11350.00-11850.00 ATLAS 2/5" 9250.00- 9550.00 ATLAS 5 " Information Control Well Records STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION wr::! ! COMPI TION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS r-I SUSPENDED r-! ABANDONED n SERVICE [] 2. Name of Operator ~"'~,~'~'~/~ . 7.93.14Permil Number BP Exploration 3. Address ', O~/'jJ~. 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 ~'~ Il s0-029-22337 4. Location of well at surface ~ , 9. Unit or Lease Name Prudhoe Bay Unit 1862' SNI~ 921' WEl~ SEC. 35, T11N, R13E ~;~ ,,., --i1~ ' 10. Well Number At Top Producing Interval J=~! I !.~ ~~.~ A-40(24-35-11-13) 454' NSL, 2748' WEL, SEC. 35, T11N, R13E ] ~,.,~?!~ 11. Field and Pool At Total Depth ~i ~ Prudhoe Bay Field/Prudhoe Bay Pool 371' NSL, 2857' WEL, SEC. 35, T11N, R13E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE-- 80.58' IADL 28286 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. o! Completions 6/4/93 6/14/93 6/28/93 I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD119. Directional Survey ~20. Depth where SSSV set Fl. Thickness of Permafrost 10315' MD/9220' TVD 10228' MD/9141' TVD YES r~ N~ [] ! 2096' feet MD ! 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/BHC/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 31' 110' 30" 11 yds Arcticset 10-3/4" 45.5# NT-8OLHE 36' 3061' 13-1/2" 1862 cu ft CS 11/408 cufl Class "G" 7-5/8" 29. 7# NT-95 31' 9857' 9-7/8" 305 cu ft Class "G" 5-1/2" 17# L-80 9691' 10315' 6-3/4" 152 cuft Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD! PACKER SET (MDI Gun Diameter 3-3/8" 4 spf 4-1/2", 13CR 9697' 9645' MD TVD 10106'-10122' 9029'-9044' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 6/30/93 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZ. E IGAS-OIL RATIO n--sT p~,~D ~ I Flow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF ~/ATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Briel description of lithology, porosity, lractures, apparent dips, and presence of oil, gas or water. Submit core chips, RECEIVED AU G - 2 199~ .... Alaska 0il A~chorag,~ \ \ Form 10-407 ~ Submit in duplicale Rev. 7-1-80 CONT'INUED 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. Sag River 9874' 8817' Shublik 9897' 8838' Sadlerochit 99 79' 8913' RECE VFD A U 6 - 2 31. LIST OF ^~rACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~~~~'~JTitleSeniorOrillinclEnoineer Date ~'/~/~"~C~ / 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 DALLY OPERATIONS PAGE: 1 WELL: A-40 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: APl: 50- PERMIT: APPROVAL: ACCEPT: 06/04/93 03:00 SPUD: 06/04/93 09:30 RELEASE: OPERATION: DRLG RIG: NABORS 28E WO/C RIG: NABORS 28E 06/04/93(1) TD: 0 PB: 0 NU DIVERTER RISER MW:10.1 KCI TURNKEY WELL TO WELL RIG MOVE. NU DIVERTER & RISER. TAKE ON WATER IN MUD PITS. 06/05/93 ( 2) DRILLING MW: 9.1 VLS:248 TD: 1900'( 0) NU DIVERTER/RISER & MIX SPUD MUD. FUNCTION TEST DIVERTER. STRAP & MAKE UP BHA. ORIENT. DRILL FROM 109' TO 1711'. SHORT TRIP 10 STDS TO 750'. NO DRAG & NO FILL ON BOTTOM. DRILL FROM 1711' TO 1900'. 06/06/93(3) TD: 3080'(1180) NIPPLE DOWN MW: 9.5 ViS: 46 DRILL FROM 1900 TO 3080. CIR BOTTOM UP. SHORT TRIP TO HWDP. WORKED THROUGH TIGHT HOLE @ 2178' WHILE POH. HOLE CLEAN WHILE TIH. CIRCULATE. TRIP OUT OF HOLE TO RU 10 3/4" CASING, TIGHT HOLE @ 2100'. RIG UP & WASH & WORK CASING THROUGH TIGHT HOLE FROM 2100 TO 2140. RUN 10 3.4 CASING MAKE UP CEMENT HEAD. CIRCULATE @ 10 BTM. TEST CEMENT LINES & CEMENT 10 3/4" CASING AS PER WELL PLAN. BUMPED PLUG. RIG UP & PERORM 250 SACK TOP JOB. LD LANDING JOINT & NIPPLE DOWN RISER & FLOW LINE. 06/07/93 (4) SHORT TRIP MW: 9.1 VIS: 40 TD: 4100'(1020) NIPPLE DOWN DIVERTER & NIPPLE UP BOPE. TEST BOPE. PULL TEST PLUG & INSTALL BOWL PROTECTOR. PICK UP, STRAP & ORIENT BHA .92. TRIP IN HOLE WITH BHA .92. TAG UP @ 2969. PRESSURE TEST 10 3/4" CASING. DRILL CEMENT, FLOAT EQUIPMENT & 10' NEW HOLE TO 3090'. PERFORN L.O.T. 16.1 PPG EMW. DRILL 9 7/8" HOLE & KICK OFF FROM 3090 TO 4100. SHORT TRIP 10 STDS. 06/08/93 (5) DRILLING MW: 9.7 VIS: 44 TD: 5925'(1825) 10 STAND WIPER TRIP. SOME SWABBING. NO FILL ON BOTTOM. DRILL FROM 4100 TO 5023. 15 STAND WIPER TRIP. SOME TIGHT SPOTS. NO SWABBING. NO FILL ON BTM. DRILL FROM 5023 TO 5690. CIRC SWEEP. TRIP OUT OF HOLE & CHANGE BIT. SERVICE WEAR BUSHING. TRIP IN HOLE. REAM 3 JOINTS TO BOTTOM. DRILL FROM 5690 TO 5925. 06/09/93 (6) DRILLING @ 6860' MW: 9.9 VIS: 40 TD: 6860'(935) DRILL FROM 5925 TO 6739'. CBU W/HV SWEEP & PUMP PILL. POH. SWR. RIH TO SHOE. CUT & SLIP DRILLING LINE. RIH TO 6639'. NO FILL. DRILLING F/673g TO 6860'. WELL : A-40 OPERATION: RIG : NABORS 28E PAGE: 2 06/10/93 ( 7) DRILLING @8405 MW: 9.8 ViS: 41 TD: 8405'(1545) DRILLING F/6860 TO 7694'. SHORT TRIP TO 6634'. NO FILL. DRILLING F/7694 TO 8405'. 06/11/93 ( 8) DRILLING @ 9499 MW: 9.9 VIS: 44 TD: 9499'(1094) DRILLING F/8405 TO 8767'. SHORT TRIP TO 7767'. DRILLING F/8767 TO 9459'. CBU W/HV SWEEP. DROP SURVEY & PUMP PILL. POH & CHANGE BHA. SWR. RIH TO 9367'. DRILLING F/ 9459 TO 9499'. 06/12/93 ( 9) POH L/D 5" DP MW: 9.9 VIS: 44 TD: 9869'( 370) DRILLING F/9499 - 9869. CBU. SHORT TRIP 16 STDS TIGHT F/ 9362 - 9110 & RIH F/9551 - 9646. NO FILL. CBU W/HV SWEEP. SHORT TRIP 11 STDS. WORK TIGHT SPOTS CLEAN. NO FILL. CBU W/HV SWEEP & DROP SURVEY. POH L/D 5" DP. 06/13/93 (10) RU TO TEST BOPE MW: 9.2 ViS: 32 TD: 9869'( 0) POH L/D 5" DP, L/D BHA & BREAK KELLY. CHANGE RAMS TO 7 5/8 & BODY TEST TO 5000 PSI. RU & RUN 7 5/8 CSG TO 3060. CBU. RUN 7 5/8 CSG TO 6680'. CBU. RUN 7 5/8 CSG & CIRC LAST JT TO BOTOOM. CIRC & CONDITION CUDD. TEST CMT LINES. L/D CH & LJ. INSTALL & TEST PACK OFF. CHANGE RAMS TO 3 1/2. CHANGE OUT KELLY. R/U TO TEST BOPE. 06/14/93 ( 1 TD :1 O238'( 1) DRILLING @ 10238 MW: 9.0 VIS: 46 369) TEST BOPE. INSTALL WR, MU BHA & PU HWDP. SLIP & CUT DRILLING LINE. RIH P/U 3 1/2 DP. WASH F/9670 TO 9773. CBU TAG FC @ 9775. TEST CSG. DRILL OUT PLUGS & FC TO 9777 & CMT TO 9847. RETEST CSG. DRILL OUT CMT F/9847 TO FC @9857 & CMT TO 9869. DRILLING F/9869 TO 10232. 06/15/93 (12) RIH W/5 1/2 LINER ON 3 1/2 DP MW: 9.0 VIS: 46 TD:10315'( 77) DRILLING F/10238 TO 10315'. SHORT TRIP TPO 9857'. CBU W/ SWEEP, DROP SURVEY, RABBITT & PUMP PILL. POH. RU SCHLUMBERGER & RUN//1 DIL/BHC/GR. & RD. RIH. CBU W/HV SWEEP. POH & L/D BHA. RU & RUN 5.5 LINER, CIRC CASG VOL. RIH W/5 1/2 LINER ON 3 1/2 DP. 06/16/93 (13) CBU MW: 8.7 VIS: 37 TD:10315'( 0) RIH W/5-1/2" LINER, CIRC & RECI., PUMP 25 BBLS CMT, POH & L/D RUNNING TOOL, PU 6-3/4" BHA & RIH TO 9350', WASH GREEN CMT F/9350' TO LINER TOP @ 9691', CBU, POH, RU 4-3/4" & RIH TO LNR TOP @ 9691', DRLG MED HARD CMT F/9691'-9734', RIH F/9734' TO LC TOP @ 10228', CBU 06/17/93 (14) TD:10315'(0) RUN 4 1/2" TUBING MW: 8.7 VIS: 0 TEST 7 5/8, LAP & 5 1/2 LINER. DISPLACED WELL W/30 BBL SWEEP, 250 BBL FRESH H20, 1060 BBL SEA H20. TEST 7 5/8, LAP & 5 1/2 LINER. POH LAYING DOWN 3.5 DP. TIGHTEN GRAYLOCK CLAMP BETWEEN BLIND RAMS & UPPER PIPE RAMS. RU AND RUN 4 1/2" 12.6# 13 CR NSCT TUBING. Alaska Oil & Gas Co~s. ^nchora~, / . WELL 'A-40 OPERATION: RIG · NABORS 28E PAGE: 3 06/18/93 (15) RELEASED RIG @ 0100 HRS. MW:10.1 KCI TD:10315 RUN 4 1/2 12.6~ 13 CR NSCT TBG. INSTALL SSSV, CONNECT & PB:10228 TEST CONTROL LINES. PRESS. UP PKR. LD LJ, SET 2 WAY CHECK & CLEARED FLOOR. ND BOPE. NU CONTROL LINES, ADAPTOR FLANGE & XMAS TREE. INSTALL BULL PLUGS, NEEDLE VALVES & SECURE WELL & RELEASE RIG @01:00 HRS 06/18/93. SPk,,RY-SUN DRZLLZNG SERVZCES ANCHORAGE ALASKA PRUDHOE BAY DRTLLTNG 500292233700 NORTH SLOPE CONPUTAT'[ON DATE' 6/18/9 TRUE SUB-SEA COURS HEASD VERTZCAL VERTZCAL ZNCLN DEPTH DEPTH DEPTH DG MN L COURSE D DTRECTTON DEGREES DG/ DATE OF SURVEY: 06/11/93 NWD SURVEY JOB NUHBER: AK-HW-30035 KELLY BUSHZNG ELEV. = 81.00 FT. OPERATOR: BP EXPLORATZON LS TOTAL RECTANGULAR COORD'[ 100 NORTH/SOUTH EAST/ NATES VERT. WEST SECT. 0 .00 -81.00 0 0 141 141.00 60.00 0 12 243' 243.00 162.00 0 18 333 333.00 252.00 0 12 424 424.00 343.00 0 24 N .00 E .00 .OON S 68.10 E .14 .098 S 10.40 E .25 .428 S 29.30 E .14 .798 S 42.90 E .23 1.168 .OOE .23E .44E .56E .86E .00 -.05 .12 .37 .52 543 542.98 461.98 1 17 632 631 .94 550.94 2 12 722. 721 .84 640.84 3 5 81'0 809.69 728.69 3 35 906 905.47 824.47 4 0 S 84.70 W 1.32 1.598 .21W N 89.50 W 1.03 1.678 2.92W S 88.20 W 1.01 1.738 7.08W S 88,20 W .57 1.898 12.22W N 89.40 W .45 1.958 18.58W 1 .45 2.97 5.26 8.15 11.61 1001 1000.24 919.24 4 5 1096 1095.03 1014.03 3 30 1192 1190.84 1109.84 3 35 1288 1286.69 1205.69 2 54 1383 1381.60 1300.60 1 42 N 88.50 W .12 1,838 25,29W S 85.00 W .78 1.99S 31,57W S 83.40 W .15 2.598 37,48W S 82.10 W .73 3.278 42,88W S 77,70 W 1.28 3.908 46,64W 15.11 18.61 22.29 25.76 28.31 1478 1476.58 1395.58 1574 1572.56 1491.56 1669 1667.56 1586.56 1764 1762.55 1681.55 1860 1858.55 1777.55 1 0 S 59.80 W ,85 4.628 48,73W 0 42 S 56.80 W .32 5.368 49,95W 0 42 S 59.80 W .04 5.978 50.94W 0 36 S 84.90 W .31 6.318 51.93W 0 36 N 35.70 W .62 5.958 52.73W 30.04 31.32 32.36 33.18 33.30 1955 1953.53 1872.53 2051 2049.52 1968.52 2147 2145.51 2064.51 2242 2240.50 2159.50 2337 2335.48 2254.48 1 6 N 22.00 E .98 4.708 52.68W 0 48 N 68.20 E .83 3.598 51.71W 0 54 S 86.00 E .41 3.408 50.33W 1 0 S 75.80 E ..21 3.658 48.79W 1 6 S 85.80 E .22 3.928 47.07W 32.22 30.77 29.86 29.25 28.56 2433 2431.46 2350.46 2528 2526.44 2445.44 2623 2621.42 2540.42 2719 2717.40 2636.40 2846 2844.37 2763.37 1 12 S 80.90 E .15 4.t58 45.16W 1 6 S 76.30 E .14 4.528 43.29W 1 12 S 73.70 E .12 5.028 41.45W 1 17 S 72.40 E .11 5.638 39.45W 1 6 S 74.50 E .16 6.398 36.90W 27.72 27.04 26.47 25.91 25.19 2910 2908.36 2827.36 3006 3004.34 2923.34 3t36 3134.31 3053.31 3232 3230.28 3149.28 3328 3326.19 3245.19 I 12 S 74.20 E .16 6.748 35.67W 1 17 S 73.00 E .11 7.338 33.66W I 0 S 74.80 E .23 8.068 31.15W 1 36 S 23.60 E 1.30 9.508 29.81W 3 12 S 1.20 W 1.95 13.418 29.33W RECEIV D 24.82 24.24 23.51 24.01 27 .O5 ,'Rt'-SdN DRiL iNG SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY PBU/A-40 500292233700 NORTH SLOPE COMPUTATION DRILLING DATE' 6/18/93 TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA VERTICAL DEPTH COURS COURSE D INCLN DIRECTION DG MN DEGREES DO/ DATE OF SURVEY' 06/11/93 MWD SURVEY JOB NUMBER: AK-MW-30035 KELLY BUSHING ELEV. = 81,00 OPERATOR: BP EXPLORATION FT, LS TOTAL RECTANGULAR COORDINATES 100 NORTH/SOUTH EAST/WEST VERT, SECT, 3423 3420.95 3339 3519 3516.41 3435 3614 3610.45 3529 3710 3705,00 3624 3806 3798.90 3717 ,95 ,41 ,45 ,00 ,90 4 48 S 17,80 W 2,06 7 5 S 27,30 W 2.60 9 6 S 27.90 W 2,11 10 48 S 30,80 W 1,85 13 6 S 32.30 W 2.42 19,853 30,60W 33,16 28.94S 34,55W 42.96 40.80S 40,75W 56.29 55,233 48.91W 72,85 72.163 59.33W 92,72 3902 3891.95 3996 3982,11 4092 4073.05 4187 4162,11 4282 4250,34 3810,95 3901,11 3992,05 4081,11 4169,34 t5 18 S 32.70 W 2.29 17 30 S 33.40 W 2.35 19 47 S 30.90 W 2.54 20 53 S 30.70 W 1.16 22 36 S 27.10 W 2.27 92.01S 71.99W 116.27 114.25S 86.47W 142.80 140.25S 102.76W 173.49 168.62S 119.68W 206.51 199.44S 136.64W 241.62 4376 4336.50 4255 4473 4424.26 4343 4569 4509.69 442'8 4663 4591,09 4510 4758 4670.89 4589 ,50 ,26 ,69 ,09 ,89 24 30 S.29,30 W 2,23 25 53 S 30,00 W 1,48 28 23 S 35,50 W 3,69 31 36 S 33.90 W 3,51 34 5 S 31.80 W 2,89 232,523 154,41W 279,06 268,41S 174.84W 320,31 305,163 !98,59W 364,07 343.813 225,32W 411.03 387,113 253.24W 462.55 4854 4749.77 4668 4948 4825.41 4744 5045 4902.16 4821 5140 4977.07 4896 5233 5050,26 4969 .77 .41 .16 .07 .26 35 24 S 32,30 W 1,39 37 24 S 30,70 W 2,36 38 0 S 29,90 W ,80 37 54 S 30,90 W ,66 38 17 S 28.30 W 1,78 433.49S 282.28W 517.26 481,05S 311.40W 573.02 532.26S 341,32W 632,29 582.65S 370,88W 690.68 632,53S 399,22W 747.98 5329 5125,49 5424 5200,40 5519 5275.97 5615 5352.34 5710 5427.65 5044.49 5119.40 5194.97 5271.34 5346.65 38 30 S 29.50 W .80 37 24 S 32.70 W 2,37 37 12 S 30.00 W 1.74 37 24 S 31.60 W 1,03 37 42 S 32.30 W .'55 684,73S 428.03W 807,49 734.75S 458.18W 865,87 783.903 488,13W 923,41 833,863 517,91W 981.56 882.993 548,55W 1039,45 5805 5502.67 5900 5577,48 5996 5652.8? 6091 5727.68 6186 5803,20 5421.67 5496.48 5571.87 5646.68 5722.20 38 0 S 29.70 W 1.71 38 5 S 30.70 W .66 38 24 S 30.00 W .55 37 42 S 30.40 W ,78 37 0 S 29,70 W ,86 932.94S 578.56W 1097,71 983.55S 608.02W 1156.22 1034.83S 638,04W 1215,61 1085.44S 667.50W 1274,12 1135.32S 696,36W 1331.70 6282 5880.02 6378 5957.09 6473 6033.45 6568 6109,72 6664' 6186,79 5799.02 5876.09 5952.45 6028.72 6105.79 36 42 S 31,60 W 1,23 36 30 S 32,30 W ,48 36 30 S 30.20 W 1,31 36 42 S 30,40 W ,24 36 30 S 30,40 W ,21 1184.85S 725.70W 1389.24 1233.41S 755.99W 1446.47 1281.72S 785.30W 1502.96 1330,62S 813,88W 1559,56 1379,99S 842.84W 1616.76 SF ~RY-SUN DRTLL]-NG SERVICES ANCHORAGE ALASKA PAGE ,, PRUDHOE BAY DRZLLZNG PBU/A-40 500292233700 NORTH SLOPE COMPUTATZON DATE: 6/18/9 DATE OF SURVEY: 06/11/93 MWD SURVEY JOB NUMBER: AK-MW-30035 KELLY BUSHZNG ELEV. = 81.00 FT. OPERATOR: BP EXPLORATZON TRUE SUB-SEA COURS COURSE DLS NEASD VERTZCAL VERTZCAL ZNCLN DZRECTZON DEPTH DEPTH DEPTH DG MN DEGREES DG/IO0 TOTAL RECTANGULAR COORDZNATES VERT. NORTH/SOUTH EAST/WEST SECT. 6761 6264,81 6183,81 36 24 S 30,20 W ,16 6856 6341,18 6260,18 36 35 S 31,40 W ,78 6951. 6417.30 6336,30 36 54 S 29,50 W 1,24 7047 6493,97 6412,97 37 5 S 30,20 W ,49 7141 6568,74 6487,74 37 30 S 30,00 W ,44 1429,74S 871,92W 1674,35 1478,28S 900.85W 1730.83 1527.28S 929,65W 1787,63 1577,38S 958,41W 1845,34 1626,66S 986,97W 1902,26 7237 6644,85 6563,85 37 35 S 28.10 W 1,21 7333 6720,8.6 6639,86 37 42 S 30,70 W 1.66 7429 6796.82 6715,82 37 42 S 30,40 W ,19 7555 6896,38 6815,38 37 54 S 29,50 W .47 7619 6946,85 6865.85 38 0 S 30,90 W 1,35 1677.81S 1015,38W 1960,66 1728,88S 1044,16W 2019,20 1779,44S 1074,00W 2077.87 1846,35S 1112,55W 2155.02 1880,36S 1132.35W 2194,35 7714 7021,60 6940,60 38 12 S'30,00 W ,62 7810 7096.94 7015.94 38 24 S 30,00 W ,21 7905 7172.60 709'1,60 36 0 S 30,90 W 2,59 7999 7248,60 7167,60 36 5 S 29,50 W ,88 8095 7326,26 7245,26 35 54 S 31,60 W 1,30 1930,89S 1162,05W 2252,93 1982,42S 1191,80W 2312,38 2031,93S 1220,89W 2369,76 2079,74S 1248,72W 2425,04 2128,32S 1277,39W 2481,42 8191 7404,07 7323,07 35 47 S 30,20 W ,86 8286 7481,22 7400,22 35 35 S 31,60 W ,89 8381 7558,61 7477,61 35 17 S 30,60 W .69 8472 7632,97 7551,97 35 5 S 29,50 W ,73 8567 7710.93 7629,93 34 35 S 29.70 W ,54 2176.56S 1306.26W 2537.62 2224.13S 1334,73W 2593,03 2271.31S 1363.19W 2648.12 2316,71S 1389,45W 2700,52 2363,91S 1416,27W 2754.74 8661 7788.45 7707.45 34 17 S 30.70 W .68 8754 7865.36 7784.36 34 5 S 29.00 W 1.05 8848 7943.16 7862,16 34 12 S 29,50 W .32 8943 8021.73 7940.73 34 12 S 29.30 W ,12 9038 8100.30 8019.30 34 12 S 30.00 W .'41 2409,87S 1443,01W 2807,87 2455,20S 1469,03W 2860.09 2501.24S 1494,81W 2912,77 2547,76S 1521,03W 2966,10 2594,16S 1547.44W 3019.43 9132 8178,05 8097,05 34 12 S 30,20 W ,12 9226 8255,88 8t74,88 34 0 S 30,90 W ,47 9322 8335,57 8254,57 33 47 S 29,90 W ,62 9384 8387,09 8306,09 33 47 S 29,50 W ,36 9516 8497,90 8416.90 32 0 S 32,30 W 1,78 2639,87S 1573,94W 3072,22 2685,26S 1600,73W 3124,89 2731.44S 1627,82W 3178.40 2761.40S 1644,91W 3212.85 2822,92S 1681,68W 3284,49 9611 8579,99 8498,99 28 30 S 39,90 W 5,45 9706 8664,49 8583,49 25 53 S 46,60 W 4.23 9798 8747,95 8'666,95 23 53 S 52,00 W 3,29 9822 8769,88 8688,88 24 0 S 52,70 W 1,26 10315 9220,26 9139,26 24 0 S 52,70 W .00 2861.61S 1709.69W 3332.17 2893.26S 1739.31W 3374.78 2918.55S 1768,60W 3411,83 2924.50S 1776,32W 3420.99 3046.01S 1935.83W 3609,10 THE CALCULATZON PROCEDURES ARE BASED ON THE USE OF THREE-DZMENSZON MZNZMUM CURVATURE METHOD, HORZZONTAL DZSPLACEMENT = 3609,10 FEET AT SOUTH 32 DEG, 26 MZN, WEST AT MD = 10315 VERTZCAL SECTZON RELATZVE TO WELL HEAD VERTZCAL SECTZON COMPUTED ALONG 212,44 DEG, Sk_,~R'¥-SUN DRZLL.T. NG SERV-f""ES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRZLLZNG PBU/A-40 500292233700 NORTH SLOPE CONPUTATZON DATE: 6/18 /93 DATE OF SURVEY: 06/11/93 JOB NUMBER: AK-MW-30035 KELLY BUSHZNG ELEV, = 81,00 OPERATOR: BP EXPLORATZON FT, ZNTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL NEASD VERTZCAL VERTZCAL RECTANGULAR COORDZNATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTZCAL DZFFERENCE CORRECTZON O. .00 -81.00 .00 N .00 E 1000 999.24 918.24 1.83 S 25.22 W 2000 1998.53 1917.53 3.89 S 52.35 W 3000 2998.34 2917.34 7.29 S 33.79 W 4000 3985.92 3904.92 115.25 S 87.13 W ,00 ,76 ,76 1,47 ,71 1,66 ,19 14,08 12,42 50.00 4866,70 4785,70 508,24 S 327,51 6000' 5656,00 5575,00 1036,98 S 639,29 7000 6456,48 6375,48 1552,88 S 944,14 8000 7249,40 7168,40 2080,25 S 1249,01 9000 8068,87 7987,87 2575,67 S 1536,76 133,30 119,22 344,00 210,70 543,52 199,52 750,60 207,08 931,13 180,53 10000 8932.49 885'1.49 2968.37 S 1833.91 10315 9220.26 9139.26 3046.01 S 1935.83 1067,51 136,38 1094,74 27,23 THE CALCULATZON PROCEDURES ARE BASED ON THE USE OF THREE-DZMENSZON MZNZNUN ~URVATURE METHOD. S¢~-,-~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE · PRUDHOE BAY DRILLING PBU/A-40 500292233700 NORTH SLOPE COMPUTATION DATE: 6/18 /93 DATE OF SURVEY' 06/11/93 JOB NUMBER' AK-MW-30035 KELLY BUSHING ELEV. = 81.00 OPERATOR' BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TR MEASD VERTIC DEPTH DEP UE SUB-SEA TOTAL AL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL TH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 81 181 281 381 8 18 28 38 .00 -81.00 .00 N .00 E .00 1.00 .00 .01 S .03 E .00 .00 1.00 100.00 .15 S .36 E ,00 .00 1,00 200.00 ,61 S .48 E .00 .00 1.00 300.00 .94 S .65 E .00 .00 481 581 681 781 881 481.00 400.00 1.45 S 1.10 E .01 .00 581.00 500,00 1,67 S 1.08 W .03 .03 681.00 600,00 1.66 S 4.87 W .10 .07 781.00 700.00 1.83 S 10.42 W .26 .15 881.00 800.00 1.97 S 16.87 W .47 .21 981 981.00 900.00 1.86 S 23.91 W .71 .25 1081 1081.00 1000.00 1.92 S 30.72 W .95 .23 t182 1181.00 1100.00 2.52 S 36.87 W 1.14 .19 1282 1281.00 1200.00 3.23 S 42.60 W 1.31 .17 1382 1381.00 1300.00 3.90 S 46.62 W 1.40 .09 1482 1582 1682 1782 1882 1481 1581 1681 1781 1881 .00 1400.00 4.66 S 48.80 W 1.43 .03 .00 1500.00 5.42 S 50.04 W 1.44 .01 .00 1600.00 6.06 S 51.08 W 1.44 .01 .00 1700.00 6.33 S 52.13 W 1.45 .01 .00 1800.00 5.75 S 52,86 W 1.46 .01 1982 2082 2182 2282 2382 198 208 218 228 238 1.00 1900.00 4.21 S 52.48 W 1.47 .02 1.00 2000.00 3.43 S 51.30 W 1.48 .01 1.00 2100.00 3,44 S 49,'78 W 1.49 .01 1.00 2200.00 3.82 S 48.10 W 1.51 .02 1.00 2300.00 3.99 S 46.20 W 1.53 .02 2482 2582 2682 2782 2882 248 258 268 278 288 1.00 2400.00 4.32 S 44.14 W 1.55 .02 1.00 2500.00 4.78 S 42.27 W 1.57 .02 1.00 2600.00 5.38 S 40.24 W 1.59 .02 1.00 2700.00 6.06 S 38.08 W 1.62 .03 1.00 2800.00 6.58 S 36.22 W 1.63 .02 2982 3082 3182 3282 3382 298 3O8 318 328 338 1.00 2900.00 7.17 S 34.16 W 1.66 .02 1.00 3000.00 7.81 S 32.05 W 1.68 .02 1.00 3100.00 8.32 S 30.38 W 1.70 .02 1.00 3200.00 10.89 S 29.27 W 1.74 .04 1.00 3300.00 16.65 S 29.57 W 1.91 .17 SP'L..,~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRZLLZNG PBU/A-40 500292233700 NORTH SLOPE CONPUTATZON DATE: 6/18 /93 DATE OF SURVEY: 06/11/93 JOB NUHBER: AK-MW-30035 KELLY BUSHZNG ELEV, = 81,00 FT, OPERATOR: BP EXPLORATZON ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL NEASD VERTZCAL VERTZCAL RECTANGULAR COORDZNATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTZCAL DZFFERENCE CORRECTZON 3483. 3481,00 3400,00 25,02 S 32 3584 3581.00 3500,00 36,63 S 38 3685 3681,00 3600,00 51,30 S 46 3787 3781.00 3?00.00 68,64 S 57 3890 3881,00 3800.00 89,49 S 70 ,52 W 2,31 ,40 ,55 W 3.17 ,86 ,57 W 4.57 1,40 ,11 W 6.62 2,05 ,37 W 9.65 3,03 3994 3981,00 3900,00 113,95 S 86 4t00 4081,00 4000,00 142.70 S 104 4207 4181,00 4100,00 174,83 S 123 4315 4281.00 4200,00 210.81 S 142 4424 4381.00 4300,00 250.29 S 164 ,27 W 13,84 4,19 ,23 W 19,45 5,61 ,36 W 26,22 6,76 ,46 W 34,21 7,99 ,40 W 43,95 9,74 4536 4481.00 4400.00 292.64 S 189 4651 4581.00 4500.00 338,74 S 221 4770 4681,00 4600,00 392.93 S 256 4892 4781,00 4700.00 452.25 S 294 5018 4881,00 4800,00 517.93 S 333 ,96 W 55.52 11,58 ,89 W 70.20 14,68 .84 W 89,21 19,01 ,14 W 111,32 22,11 ,08 W 137.14 25,83 5144 4981,00 4900.00 585,27 S 5272 5081,00 5000,00 653,91 S 5399 5181,00 5100,00 722.27 S 5525 5281,00 5200,00 787.20 S 5651 5381,00 5300,00 852,53 S 372,45 W 163,98 26,83 410,73 W 191,17 27.20 450,17 W 218.58 27.41 490.04 W 244.31 25,74 529,40 W 270,08 25,77 5777 5481,00 5400.00 918.24 S 5904 5581,00 5500.00 985,92 S 6031 5681,00 5600,00 1054,14 S 6!58 5781,00 5700,00 1120,80 S 6283 5881.00 5800.00 1185.47 S 570.18 W 296.50 26,42 609.43 W 323.47 26.97 649.19 W 350.90 27,42 688.07 W 377.21 26,31 726.09 W 402.23 25,02 6407 5981.00 5900,00 1248,37 S 6532 6081.00 6000,00 1312,16 S 6656 6181,00 6100,00 1376,29 S 6781 6281,00 6200,00 1440,06 S 6905 6381,00 6300,00 1503,59 S 765.44 W 426,75 24,52 803,04 W 451.18 24.43 840,67 W 475,80 24.62 877,92 W 500,11 24.31 916,19 W 524.62 24,51 7030 6481,00 6400,00 1568,91 S 7156 6581,00 6500,00 1634,81 S 7282 6681,00 6600,00 1702,34 S 7409 6781.00 6700,00 1768,89 S 7535 6881,00 6800,00 1835,93 S 953,47 W 549,74 25,12 991.68 W 575.45 25.71 1028,54 W 601,63 26,18 1067,81 W 628,01 26,38 1106,66 W 654,51 26,50 'sP~.,t~Y-SUN DRTLLTNG SERVZCES ANCHORAGE ALASKA PAGE pRUDHOE BAY DRTLLZNG PBU/A-40 500292233700 NORTH SLOPE COMPUTATTON DATE: 6/18 /93 ZNTERPOLATED VALUES FOR EVEN 100 DATE OF SURVEY: 06/11/93 JOB NUMBER: AK-MW-30035 KELLY BUSHZNG ELEV. = 81.00 OPERATOR: BP EXPLORATZON FEET OF SUB-SEA DEPTH FT. TRUE SUB-SEA TOTAL MEASD VERTZCAL VERTZCAL RECTANGULAR COORDZNATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTZCAL DZFFERENCE CORRECTZON 7662. 6981,00 6900,00 1903,27 S 1146,04 W 681,35 7789 7081,00 7000,00 1971,48 S 1185,48 W 708.66 7915 7181,00 7100,00 2037,17 S 1224,03 W 734,39 8039 7281,00 7200,00 2100,30 S 1260,35 W 758.10 8162 7381,00 7300,00 2162,18 S 1297,89 W 781,55 26,84 27,31 25.73 23.72 23,45 8285 7481.00 7400.00 2223.99 S 1334.64 W 804,73 8408 7581.00 7500.00 2284.95 S 1371.26 W 827.43 8530 7681.00 7600.00 2345.97 S 1406.04 W 849.64 8651 7781,00 7700.00 2405,50 S 1440.42 W 870,99 8772 7881.00 7800.00 2464.46 S 1474.16 W 891.88 8893 7981,00 7900,00 2523,62 S 1507.47 W 912,76 9014 8081,00 8000,00 2582,80 S 1540,88 W 933,66 9135 8181,00 8100,00 2641,61 S 1574,95 W 954,57 9256 8281,00 8200,00 2699,79 S 1609,43 W 975,29 9376 8381,00 8300,00 2757,85 S 1642,90 W 995,68 23.18 22,71 22.20 21 .35 20.90 20.87 20,91 20,91 20.72 20,38 9496 ' 8481.00 8400.00 2813.99 S 1676.03 W 1015.07 9612 8581.00 8500,00 2861.99 S 1710.04 W 1031.14 9724 8681.00 8600.00 2898.65 S 1745,13 W 1043.31 9834 8781,00 8700.00 2927.50 S 1780.25 W 1053.17 9943 8881.00 8800.00 2954.48 S 1815.67 W 1062.63 19.39 16.07 12,17 9,86 9.46 10053 8981.00 '8900.00 2981.46 S 1851.09 W 1072.10 10162 9081.00 9000,00 3008.44 S 1886.50 W 1081.56 10272 9181.00 9100.00 3035.42 S 1921.'92 W 1091,03 1031.5 9220.26 9139.26 3046.01 S 1935.82 W 1094.74 9,46 9.46 9,46 3,71 THE CALCULATZON PROCEDURES USE A LZNEAR ZNTERPOLATZON BETWEEN THE NEAREST 20 FOOT MD (FROM MZNZMUM CURVATURE) POZNTS BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/13/93 T# 84761 BPX/PBU CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-40 SBL S-23 q§'\~ PERF X-13A PERF 07/09/93 #1 07/07/93 #1 07/09/93 #1 07/06/93 #1 07/07/93 #1 Z-06~,%4/ PRODUCTION LOG 06/07/93 Information Control Well Records 8900.00- 9496.00 ATLAS 5 " 9720.00-10189.00 ATLAS 5 " 10850.00-11130.00 ATLAS 5 " 10220.00-10716.00 ATLAS 5 " 7800.00-10650.00 ATLAS 5 " 9850.00-10350.00 ATLAS 5 " BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/07/93 T# 84739 BPX/PBUOLOGS Enclosed is your copy of the materials listed questions, please contact BP Well Records at A-40qS'lq PS~ 06/28/93 #1 F-i~ ,I-IIq PRODUCTION LOG 06/26/93 #1 F-1~ PRODUCTION LOG 06/26/93 #1 N-2 ~'~ PERF 07/01/93 #1 S-2490-~5 PERF 07/01/93 #1 s-2590-10~ PERF 07/01/93 #1 S-33~-~0L PERF 07/03/93 #1 S-34~w~ PERF 06/30/93 #1 S-35q~-Iq~ PERF 06/30/9~ #1 S-36 ~%-IJ~ PERF 06/28/93 #1 S-38~%,t~N pERF 07/01/93 #1 z-19qZ~Z% PERF 06/30/93 #1 below. If you have any (907) 564-4004. 9200.00-10194.00 ATLAS 5 " 10980.00-12361.00 ATLAS 5 " 10980.00-12361.00 ATLAS 5 " 9915.00-10056.00 ATLAS 5 " 9700.00- 9950.00 ATLAS 5 " 9058.00- 9253.00 ATLAS 5 " 900Q.00- 9200.00 ATLAS 5 " 10100.00-10259.00 ATLAS 5 " 9500.00- 9702.00 ATLAS 5 " 9765.00- 9986.00 ATLAS 5 " 9200.00- 9350.00 ATLAS 5 " 13940.00-14224.00 ATLAS 5 " Information Control Well Records RECEIVED ,. JUL 12 199,3 Alaska 0Il & Sas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 BPX/PBU~OGS DATE: 06/25/93 T# 84690 Enclosed is your copy of the' materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-40 BHC 06/14/93 #1 9050.00-10300.00 SCH A-40 DIL PHASOR 06/14/93 ~1 9050.00-10300.00 SCH 2/5" 2/5" Information Control Well Records BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/01/93 T# 84721 BPX/PBUOMAGNETIC TAPE W/LISTING Enclosed is your copy of the materials listed below. questions, please contact BP Well Records at (907) A-4U OH/BHC FIN 06/14/93 #1 9025.00-10367.50 1600BPI API#500292233700 9402->TP# If you have any 564-4004. SCH REF#93268 Information Control Well Records MEMORANDUM S TA TE A LA SKA ALASKA OIL AND GAS CONSER VA TiON COMMISSION TO: David Johnsto~.~. Chairman THRU: BlairWon~ ~a[,~.x P.I. Supervisor FROM: Doug Amos ']~' Petroleum Inspector DA TE: June 6,1993 FILE NO: DA-6693. DOC PHONE NO.: 279-1433 SUBJECT: BOPE Test Nabors 28E BPX PBU A-40 Prudhoe Oil Pool PTD# 93-14 Sunday. June 6, 1993: I traveled this date to BPX PBU A-40 well to witness the BOPE test on Nabors Rig No. 28E. As the attached AOGCC BOPE Test form indicates, the one failure encountered during this test was the gate valve upstream of the outboard manual choke. This valve was repaired and retested before drilling out the casing shoe. The location was clean and all equipment and supplies were arranged in a manner that would allow room for additional equipment in case of a well control situation. The driller and his crew were knowledgeable about the BOP equipment and the test procedure. The rig house keeping was adequate considering that the rig had just been moved and all personnel were busy with the many task required of them during rig up on a new location · ' I did pick up some note worthy information in a discussion with Nabors toolpusher Mike . Downey, he expressed his concerns about the age and condition of the Choke Manifold and (5~_~~ ~,,. that during the past 4 BOPE test they have had at least one of the choke manifold valve fail. He stated that they grease the valves during the test and they pass but after one actuation they will -- again fail. Mike feels that the choke manifold valves are just worn out and in need of replacement but Nabors is reluctant to spend the money. I feel the inspectors should target ~"~,,~ this rig and catch as many BOPE test as possible so that we can substantiate the validity of this /7 condition. IN SUMMARY, witnessed BOPE Test on Nabors 28E, 28 valves tested, I failure, at BPX PBU A-40 well. T'e, rf ~e ..1 Attachment DA-6693.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Nabors Drilling Co. Operator: BPX Well Name: PBU A-40 Casing Size: 10 3/4" Set ~ Test: Initial X Weekly Rig No. 28E PTD# Rep.: Rig Rep.: 3,025' Location: Sec. Other g3-14 35 T. DATE: 6/6/93 Rig Ph.# 659-4863 James Carlile Mike Downey 11N R. 13E Meridian Umiat MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gan) Reserve Pit 'N/A Well Sign Drl. Rig BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. 1 f 1 Test Pressure 25O/5,000 250/5,000 250/5,000 I 250/5,000 2 250/5,000 2 250/5,000 2 250/5,000 0 0 TEST DATA YES OK P/F P P P P P P P N/A FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP .......... Te~t" Quan. Pressure I 250/5,000 I 250/5,000 I 250/5,000 I 250/5,000 P/F P P P P MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators '" OK oK Flow Indicator OK OK , Gas Detectors OK OK CHOKE MANIFOLD: No. Valves 18 No. Flanges 39 Manual Chokes 2 Hydraulic Chokes I Test Pressure 250/5,000 PIF ISee Note , , ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2,0oo 3,000 I P 1,500 P minutes 22 sec. minutes 32 sec. YES Remote: YES Psig. TEST RESULTS Num'ber'0f'Failures: ........... f Test Time': 3.00 HoUrs.'' NUmber of ~alve~'iested 2~'" i~'~p~i~:'or'~ePiace'ment 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 I REMARKS: NOTE: the choke manifold valve upstream of the outboard manual choke failed. After greasing the valve ...two times it would no pass the test. The valve was repaired and retested b~, Nabors toolpusher Mike Downey before drillin~l out As per my instruction before departing the rig, I was contacted I was contacted by Mike this date and informed of the retest. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector FI-021L (Rev. 2/93) STATE WITNESS REQUIRED? YES ~/es NO 24 HOUR NOTICE GIVEN YES yes NO Waived By: W~nessed By: DA-6693.XLS Si ned: Doug Amos ALASKA OIL AND GAS CONSERVATION COMMISSION January 25, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Jeff Hall Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit A-40 BP Exploration (Alaska), Inc. Permit No: 93~14 Sur. Loc. 1861'SNL, 923'WEL, Sec. 35, TllN, R13E, UM Btmhole Loc. 5152'SNL, 2994'WEL, Sec. 35, TllN, R13E, UM Dear Mr Hall: 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) 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 test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · David W.~ohnston~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC.' Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ printed on recycled paper b y C. ~'.~. STATE OF ALASKA ALASKA L~IL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill Flll b. Type of well. Exploratory l-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen!-!I Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration AMSL = 47'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL ~ ~-~' 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 ^^c 25.025) 1861' SNL, 923' WEL, SEC. 35, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well, umber Number 5000' SNL, 2899' WEL, SEC. 35, T11N, R13E A-40 (~-35-11-13) 2S100302630-277 At total depth 9. Approximate spud date Amount 5152' SNL, 2994' WEL, SEC.35, T11N, R13E 1/25/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) !property line , ' ADL 28327-126 feet A-05-35'@ 50' feet 2560 10429' MD/9202' TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (s~e 20 AAc 25.035 (e)(2)) Kickoff depth 3~Tfeet Maximum ho!e ancjle 3;, o Maximum sudace 3330pslg At total depth (TVD) 8800'/4390Pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" - 20" 91.5# H-40 Weld 80' 31' 31' 110' 110' 11 yds Arcticset 13-1/2" 10-3/4" 45.5# NTSOLHE BTC 3020' 31' 31' 3051' 3050' 970 sx CS 111/685sx CS il 9-7/8" 7-5/8" l.~ NT~HS NSCC 9894' 30' 30' 9924' 8798' 265 sx Class "G" 6-3/4" 5-1/2" 17# 13CR80 FL4S 655' 9774' 8678' 10429' 9202' 120 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 .~CEIv~D Surface Intermediate Production '.!0:'.~?,l '~ ,r~ Liner /-~,,:,o:(a Oil & Gas Oo~s. Perforation depth: measured true vertical A~ch0r,:~ga 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program ITl Drilling fluid pro~ram [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify ~:hat th~ ~{orecl~ing is true and correct to the best of my knowledge .~'"-"~ I1 I! II II ~,~_~~.._ Title Drilling Engineer Supervisor Signed Date (-'~' Commission Use Only Permit Number"'" IAPI number IApproval d._ate ISee cover letter ~-/~' 150- ~ z.? - 2.2_ ~_9 ? I /-,:~Z.~'"- ~'~ Ifor other requirements Conditions of approval Samples required [] Yes .E~ No Mud Icg required []Yes [] No Hydrogen sulfide measures [] Yes ~ No Directional survey required i~ Yes [] No Required working pressure for BOPE [] 2M' []3M; '¢i~5M; [-J1OM; []15M; Other: Origina! Sicned By by order of Approved by David W. Johnston Commissioner tne commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate WELL PLAN Well' LOCATION: A-40 Surface' Target: T.D.: [4 3-35-1 I -1 3] PBU 1861' FNL 923' FEL S35 T11N R13E (Proposed) 5000' FNL 2899' FEL S35 T11N R13E 5152' FNL 2994' FEL S35 T11N R13E ESTIMATED START: Jan 25, 1993 OPR. DAYS TO COMPLETE: 19 (15 days drilling, 4 days completion) Nabors 28E MAX ANGLE/SECT COURSE/KOP/BUILD/MAX DEP' 37/S31.6W/3117'/2.0/3887' Estimated Ground level elevation is 47' AMSL. KB to ground level elevation is 32.5'. Item TVD(BKB) MD(BKB) Mud Wt. 20" CONDUCTOR' 11 0 110 8.5 10-3/4" SHOE 3050 3051 9.1 TOP UGNU SANDS . 421 9 4250 9.1 SEABEE 5949 6356 9.5 IKRU/LCU 7779 8648 9.8-1 0.0 7-5/8" SHOE 8798 9924 SAG RIVER SANDSTONE 8 7 9 8 9 9 24 8.8 - 9.0 SHUBLIK 8820 9951 8.8-9.0 TOP SADLEROCHIT 8893 1 0043 8.8-9.0 TARGET 8966 10134 8.8-9.0 TOTAL DEPTH 9 2 02 1 0 429 8.8 - 9.0 CASING PROGRAM: ,Hole Csq Wt Grade Ccnn Lenath Too 30" 20" 91.5# H-40 WELD 80 32 1 3- 1/2" I 0-3/4" 45.5# NTSOLHE BTC 3020 3 1 9-7/8" 7-5/8" 29.7# NT95HS NSOC 9894 30 6-3/4" 5- 1/2" I 7# 13Cr-80 FL4S 655 9774 COMPLETION: Btm 110 3051 9924 10429 Tubing' GLMs: Packer: 4-1/2" 12.6# 13Cr-80 NSCT 10187 29 10216 4-1/2" x 1" - est 6 required, all dummies except RP shear in shallowest GLM Permanent-latched. 7-5/8" x 4-1/2" set at 9724' or +/- 50' above TOL LOC-~ING PFtO~RAM: Open Hole- Cased Hole 9-7/8" Hole: Possible RFT in Cretaceous. 6-3/4" Hole: DIL/BHCS/CNL/GR/SP LDToptional. No cased hole logs '~ ~'~ l V ~ P PROPOSED DRILLING AND COMPLETION A-40 Procedure PROGRAM o ° . a . 0 . ° . 10. 12. MIRU drilling rig. N/U diverter and function test same. Drill 13 1/2" hole to surface casing point. Run and cement surface casing. Nipple up BOPE and function test same to 5000 psi. PU 9 7/8" BHA and RIH. Test casing to 3500 psi for 30 minutes. Drill 10' of new hole and perform leak off test. Drill intermediate hole to intermediate casing point. Run E-line logs if required. MU and run 7-5/8 casing string and cement as per well plan. Bump cementing plug with mud. RIH and drill 6-3/4" hole through reservoir to TD. RU and run E-line logs. MU 5 1/2" liner on 3 1/2" DP. RIH to TD. Cement same. Set liner hanger and packer. Circulate excess cement from wellbore. POOH. MU casing scraper & clean out 5 1/2" liner. Run 4-1/2", 13Cr-80 tubing and packer assembly with SSSV. Freeze protect with diesel. Test tubing and casing to 3500 psi. NU tree and test to 5000 psi. Release drilling rig. ° Anticipated BHP: ° Maximum Anticipated Surface Pressure: o Planned Completion Fluid: 3500 psi @ 8814' TVD SS 2619 psi 8.6 ppg filtered sea water Notes: a. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi). c. No potential hazardous levels of H2S are anticipated in this well. d. There are 2 close approaches requiring shut-in. Note well proximities on close approach sheets. A gyro will be required. MUD PROGRAM: Well A-40 The mud program for this well shall follow the new Mud Policy. The following are the recommended mud parameters. MUD SPECIFICATIONS- SURFACE HOLE Surface: Casino point: Mud Weight: ppg 8.5 - 9.5 8.5 - 9.1 Funnel Viscosity sec/qt ~300 < 1 00 YP Ibs/100ft2 40 - 60 20 - 40 10 sec Gel Ibs/100ft2 30 - 60 15 - 20 10 min Gel Ibs/100ft2 60 - 80 20 - 30 pH - 9 - 10 9 - 10 APl Fluid loss mi/30 min 15-25 15-25 Hardness mg/I < 200 <200 .,MUD SPECIFICATIONS- INTERMEDIATE HOLE Surface casing shoe to Top of Sag River Sandstone: LSND Gel/Water System Mud Weight ppg 9.0- 9.8 (To to the LCU) 10.0 to Casing Point Yield Point Ibs/100ft2 10 - 15 10 sec Gel Ibs/100ft2 5 - 10 10 min Gel Ibs/100ft2 10 - 20 APl Fluid Loss mi/30 min <15 pH -- 9.5 - 10.0 Hardness m g/I NC-no control MUD SPECIFICATIONS-PRODUCTION INTERVAL: Watered back mud system used in intermediate hole. Mud Weight ppg Yield Point lbs/1 00ft2 10 sec Gel lbs/1 00ft2 10 min Gel Ibs/100ft2 APl Fluid loss mi/30 min pH -- Hardness m g/I t r 8.8-9.0 8-13 5-10 7- 15 6.0 - 8.0 (fluid loss lowered to below 6 cc prior to entering K-shales 8.0 - 9.0 < 4000 The mud salinity should be compatible with the Reservoir logging program. The mud should be run at < 3500 ppm chlorides. Over Balance in the production Hole Design Mud Wt. (6-3/4" Hole): 9.0 ppg. Formation pressure at top Sag River: Formation pressure at Sadlerochit: 3000 psi. 3500 psi at 8800' TVDSS. Over Balance Sag River: 1080 psi Over Balance Top Sadlerochit: 620 psi. Current GOC: At top Sad. For more detailed information refer to the Prudhoe Bay Drilling Mud Policy that resides in DRILLING VOLUME #1(file server) under the MUD POLICY folder. 10-3/4" SURFACE CASING CEMENT PROGRAM - BJ SERVICES CASING SIZE: 10-3/4" CIRC. TEMP 38°F SPACER: 75 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE: ColdSet III ADDITIVES: retarder WEIGHT: 12.2 ppg APPROX #SACKS: 970 YIELD:1.92 ft3/sx THICKENING TIME: 4:30 hrs MIX WATER: 10.5 gps TAIL CEMENT TYPE: ColdSet II ADDITIVES: As Required WEIGHT: 14.9 ppg APPROX #SACKS: 435 YIELD:0.96 ft3/sx THICKENING TIME: 4 hrs MIX WATER: 3.89 gps TOP JOB CEMENT TYPE: Coldset II ADDITIVES: retarder WEIGHT: 14.9 ppg APPROX #SACKS: 250 YIELD:0.96 ft3/sx MIX WATER: 3.89 gps CENTRALIZER PLACEMENT: 1. Run one(l) bow type centralizer per joint for the first 20 joints. 2. Place the centralizers in the middle of each joint with a stop collar. 3. Run two cement baskets inside the conductor pipe on stop collars. CEMENT VOLUME: 1. Lead slurry to surface w/100% excess. 2. Tail slurry volume 435 sx 3. Top job volume 250 sx. ECEIVED JAN 1 9 A~ask~ Oil & Gas Cons, Cornm Anchorage 7-5/8" INTERMEDIATE CASING CEMENT PROGRAM- BJ SERVICES CIRC. TEMP: 140° F SPACER: 50 bbls Arco preflush+1%S-400, weighted 1 ppg above current mud weight. TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.3% F L-52+0.5%C D-32+ 1%A-2+ 1GHS thickening time WEIGHT: 15.8ppg YIELD: 1.15ft3/sx APPROX #SACKS: 265 THICKENING TIME: 3-4 hrs FP-6L for 3-4 hrs MIX WATER: 5.0 gps CENTRALIZER PLACEMENT: 1 Turbulator centralizer per joint on the bottom 500' of 7-5/8" casing ( 12 required ). One solid body 7-3/4" x 9-1/4" centralizer or turbolator just inside 10-3/4" surface casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 10-12 bpm. Batch mix tail cement - perform fluid loss test. Fluid loss should be 40 cc or less. CEMENT VOLUME: .1 Tail G slurry to 1000' md above casing point with 30% excess. 2. 80' md 7-5/8", 29.7# capacity for float joints. NOTE: No hydrocarbon bearing zones are identified in the Cretaceous interval. RECEIVED JAN ! .9 ~ ~ AJaska Oil & Gas Cons~ OOFnIf~isSiOD Anchorage 5-1/2" PRODUCTION LINER CEMENT PROGRAM - BJ SERVICES CIRC. TEMP 140° F BHST 226 deg F at 8800' TVDSS. SPACER: 50 bbls fresh water w/3 ppb ARCO preflush and 1% S-400. CEMENT TYPE: CLASS G 6L WEIGHT: 15.7 ppg ADDITIVES- 0.8%BA-10+0.6%FL-32+0.2%CD-30+0.3%A-2+0.35%R-1+1GHS FP- YIELD:1.18 ft3/sx MIX WATER- 5.03 gps APPROX #SACKS: 120 THICKENING TIME' 4.5 hrs total Note: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencys ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/cementer. CENTRALIZER PLACEMENT: Run 2 turbolators per joint in open hole, 1 per joint in lap, and none opposite intermediate casing shoe.. OTHER CONSIDERATIONS' Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 40cc or less. Displace @ 6-8 bpm. LINER CEMENT VOLUME- I . . Open hole (6-3/4" X 5-1/2") + 30% excess (adjust if a caliper log is run and it indicates severe washouts). 5-1/2", 17# casing capacity below landing collar. 150' liner lap (6.750" x 5-1/2") 200' of cement on top of the liner in the 7-5/8" casing. ,JAN 1 AJaska Oil & Gas Cons. Comm"~ssio~ Anchorage A-40 Casing Design Specificatio; SURFACE CASING 10-3/4", 45.5# NT-80LHE BTC CASING BURST COLLAPSE NT-80LHE 521 0 31 30 PBYS (#) 1040000 TJYS (#) 1097000 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. LOT (ppg) TVD (FT) SIPRESSURE 14 3050 2220 Burst S.F. 2.35 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 3050 1507 Collapse S.F. 2.08 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 45.5 3051 PBYS Tension S.F. 8.7 6 Mud Wt. 9.5 ppg TJYS 9.24 String Wt. (#) 118664 ,ECEiV D ~ J~ ~, Oil & Gas Cons, Anchorage A-40 Casing Design Specificatio; Intermediate Casing 7-5/8", 29.7#,NT-95HS,NSCC Casing GRADE BURST COLLAPSE NT-95HS 81 80 7150 PBYS (#) 811000 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. sm= 3330 Burst S.F. 2.46 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse press 1 0 8798 0.1 3695 Collapse S.F. 1.93 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 29.7 9924 PBYS Tension S.F. 3.2 6 Mud Wt. 10.0 TJYS 3.38 String Wt. (#) 248792 TJYS (#) 841000 Gas Cons. Corn .Anchorage A-40 Casing Design Specificatio~ PRODUCTION LINER 5-1/2", 17#,L-80, 13Cr, FL4S Casing GRADE BURST COLLAPSE L-80 7740 6280 PBYS (#) 397000 TJYS (#) 248000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.6 ppg fluid SITP Fluid wt (ppg) 3500 9.6 Burst S.F. 2.1 0 back up (ppg) Burst Pressure 9.2 3683 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 9.6 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse Press 9.6 8800 0.1 3513 Collapse S.F. 1.79 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) Mud Wt. String Wt. (#) 17 655 9.6 9399 Tension S.F. PBYS TJYS 42.24 26.39 RECEIVED JAN ] 9 t99~ ,A, lask~ L)it & Gas Cons. Anchor;~ge A-40 Casing Design Specificatio PRODUCTION LINER 5-1/2", 17#,L-80, 13Cr, FL4S Casing GRADE BURST COLLAPSE L-80 7740 6280 PBYS (#) 397000 TJYS (#) 248000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.6 ppg fluid SlTP Fluid wt (ppg) 3500 9.6 Burst S.F. 2.1 0 back up (ppg) Burst Pressure 9.2 3683 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 9.6 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse Press 9.6 8800 0.1 3513 Collapse S.F. 1.79 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) Mud Wt. String Wt. (#) 1 7 655 9.6 9399 Tension S.F. PBYS TJYS 42.24 26.39 Smith International, Inc. Proposal Report Calculated using the Minimum Curvature Method Computed by the Sii Win-CADDS System Vertical Section Plane: 212.14 deg. Survey Reference: WELLHEAD Reference World Coordinates: Lat. 70.15.59.16 N - Long. 148.45.03.65 Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (feet): 5948586.20 N 654460.30 E Vertical Section Reference: WELLHEAD Closure Reference: WELLHEAD North Aligned To: TRUE NORTH Prudhoe Bay Drilling Prudhoe Bay A-PAD A-40 A-4OWP Gas Coas, CommissJo~ Page 1 Date: 1/15/93 WeLLpath ID: A-4OWP Program No: 1120-005 Last Revision: 1/15/93 Measured Inc[ Drift Depth Dir. (ft) (deg.) (deg.) TVD (ft) Subsea Depth (ft) R.K.B. ELEVATION 79.5' SS 0.00 0.00 0.00 0.00 '79.50 100.00 0.00 0.00 100.00 20.50 200.00 0.00 0.00 200.00 120.50 300.00 0.00 0.00 300.00 220.50 400.00 0.00 0.00 400.00 320.50 START NUDGE 500.00 0.00 0.00 500.00 420.50 TOTAL Rectangular Offsets (ft) (ft) 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 600.00 1.00 270.00 599.99 520.49 0.00 S 0.87 700.00 2.00 270.00 699.96 620.46 0.00 S 3.49 800.00 3.00 270.00 799.86 720.36 0.00 S 7.85 900.00 4.00 270.00 899.68 820.18 DROP TO VERTICAL 1000.00 5.00 270.00 999.37 919.87 1100.00 4.00 270.00 1099.06 1019.56 Geographic Coordinates Latitude / Longitude 70.15.59.1559 N 148.45.03.6461 70.15.59.1559 N 148.45.03.6461 70.15.59.1559 N 148.45.03.6461 70.15.59.1559 N 148.45.03.6461 70.15.59.1559 N 148.45.03.6461 70.15.59.1559 N 148.45.03.6461 70.15.59.1559 N 148.45.03.6715 70.15.59.1559 N 148.45.03.7477 70.15.59.1559 N 148.45.03.8746 0.00 S 13.96 W 70.15.59.1559 N 148.45.04.0523 W 0.00 S 21.80 W 70.15.59.1559 N 148.45.04.2807 0.00 S 29.65 W 70.15.59.1559 N 148.45.04.5091 1200.00 3.00 270.00 1198.87 1119.37 0.00 S 35.75 1300.00 2.00 270.00 1298.77 1219.27 0.00 S 40.12 1400.00 1.00 270.00 1398.74 1319.24 0.00 S 42.7'5 END DROP 1500.00 0.00 0.00 1600.00 0.00 0.00 1700.00 0.00 0.00 1800.00 0.00 0.00 BASE PERMA 1880.77 0.00 0.00 1900.00 0.00 0.00 1498.73 1419.23 0.00 S 43.61 1598.73 1519.23 0.00 S 43.61 1698.73 1619.23 0.00 S 43.61 1798.73 1719.23 0.00 S 43.61 1879.50 1800.00 0.00 S 43.61 1898.73 1819.23 0.00 S 43.61 1998.73 1919.23 0.00 S 43.61 2098.73 2019.23 0.00 S 43.61 2198.73 2119.23 0.00 S 43.61 2298.73 2219.23 0.00 S 43.61 W 2398.73 2319.23 0.00 S 43.61 W 2000.00 0.00 0.00 2100.00 0.00 0.00 2200.00 0.00 0.00 2300.00 0.00 0.00 2400.00 0.00 0.00 70.15.59.1559 N 148.45.04.6868 70.15.59.1559 N 148.45.04.8137 70.15.59.1559 N 148.45.04.8899W 70.15.59.1559 N 148.45.04.9153 70.15.59.1559 N 148.45.04.9153 70.15.59.1559 N 148.45.04.9153 70.15.59.1559 N 148.45.04.9153 70.15.59.1559 N 148.45.04.9153 70.15.59.1559 N 148.45.04.9153 70.15.59.1559 N 148.45.04.9153 70.15.59.1559 N 148.45.04.9153 70.15.59.1559 N 148.45.04.9153 70.15.59.1559 N 148.45.04.9153 W 70.15.59.1559 N 148.45.04.9153 W GRID Coordinates Northing Easting (ft) (ft) 5948586.21 654460.30 5948586.21 654460.30 5948586.21 654460.30 5948586.21 654460.30 5948586.21 654460.30 5948586.21 654460.30 5948586.19 654459.43 5948586.13 654456.81 5948586.04 654452.45 5948585.92 654446.35 5948585.76 654438.50 5948585.60 654430.66 5948585.47 654424.55 5948585.38 654420.19 5948585.33 654417.58 5948585.31 654416.70 5948585.31 654416.70 5948585.31 654416.70 5948585.31 654416.70 5948585.31 654416.70 5948585.31 654416.70 5948585.31 654416.70 5948585.31 654416.70 5948585.31 654416.70 5948585.31 654416.70 5948585.31 654416.70 Closure Dist. Dir. (ft) deg. 0.00 @ 0.00 0.00 a 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 Vertical ] Section (ft) (dg/lOOft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 43.61 @ 270.00 23.20 1.00 43.61 @ 270.00 23.20 0.00 43.61 @ 270.00 23.20 0.00 43.61 @ 270.00 23.20 0.00 43.61 @ 270.00 23.20 0.00 43.61 @ 270.00 23.20 0.00 43.61 @ 270.00 23.20 0.00 43.61 @ 270.00 23.20 0.00 43.61 @ 270.00 23.20 0.00 43.61 @ 270.00 23.20 0.00 43.61 @ 270.00 23.20 0.00 21.80 @ 270.00 11.60 1.00 29.65 @ 270.00 15.77 ~ n~ 35.75 @ 270.00 19.02 1.~0 40.12 @ 270.00 21.34 1.00 42.73 @ 270.00 22.74 1.00 13.96 @ 270.00 7.43 1.00 0.87 @ 270.00 0.46 1.00 3.49 @ 270.00 1.86 1.00 7.85 @ 270.00 4.18 1.00 Smith International, Inc. Proposal Report Page Z Date: 1/15/93 WeLLpath ID: A-4OWP Measured Incl Drift TVD Depth Dir. (fl) (deg.) (deg.) (fl) 2500.00 0.00 0.00 2498.73 2600.00 0.00 0.00 2598.73 2700.00 0.00 0.00 2698.73 2800.00 0.00 0.00 2798.73 2900.00 0.00 0.00 2898.73 3000.00 0.00 0,00 2998.73 10-3/4" CSG, PT. 3051.27 0.00 0.00 3050.00 3100.00 0.00 0,00 3098.D START OF BUILD 3117.44 0.00 0,00 3116.17 Subsea Depth (fl) TOTAL Rectangular Offsets (ft) (ft) 2419.23 0.00 S 43.61 2519.23 0.00 S 43.61 2619.23 0.00 S 43.61 2719.23 0.00 S 43.61 2819.23 0.00 S 43.61 2919.23 0.00 S 43.61 2970.50 0.00 S 43.61 3019.23 0.00 S 43.61 3036.67 0.00 S 43.61 3217.44 2.00 211.59 3216.15 3136.65 3317.44 4.00 211.59 3316.01 3236.51 3417.44 6.00 211,59 3415.62 3336.12 3517.44 8.00 211.59 3514.87 3435.37 3617.44 10.00 211.59 3613.63 3534.13 3717.44 12.00 211.59 3711.79 3632.29 3817.44 14.00 211.59 3809.22 3729.72 3917.44 16.00 211.59 3905.81 3826.31 4017.44 18.00 211.59 4001.44 3921.94 4117.44 20.00 211.59 4095.98 4016.48 4217.44 22.00 211.59 4189.34 4109.84 UGNU 4A 4250.04 22.65 211.59 4219.50 4140.00 4317.44 24.00 211.59 4281.38 4201.88 4417.44 26.00 211.59 4372.01 4292.51 4517.44 28.00 211.59 4461.11 4381.61 4617.44 30.00 211.59 4548.56 4469.06 4717.44 32.00 211.59 4634.28 4554.78 4817.44 34.00 211.59 4718.14 4638.64 4917.44 36.00 211.59 4800.05 4720.55 END OF BUILD 4967.44 37.00 211.59 4840.24 4760.74 5067.44 37.00 211.59 4920.11 4840.61 5167.44 37.00 211.59 4999.97 4920.47 5267.44 37.00 211.59 5079.83 5000.33 5367.44 37.00 211.59 5159.70 5080.20 5467.44 37.00 211.59 5239.56 5160.06 5567.44 37.00 211.59 5319.42 5239.92 5667.44 37.00 211.59 5399.29 5319.79 5767.44 37.00 211.59 5479.15 5399.65 5867.44 37.00 211.59 5559.01 5479.51 5967.44 37.00 211.59 5638.88 5559.38 1.49 S 44.52 5.94 S 47.26 13.37 S 51.83 23.75 S 58.21 37.07 S 66.41 53.32 S 76.40 72.48 S 88.19 94.53 S 101.75 119.43 S 117.06 147.16 S 134.12 177.68 S 152.89 188.23 S 159.38 210.96 S 173.36 246.96 S 195.50 285.63 S 219.29 326.92 S 244.69 370.79 S 271.67 417.17 S 300.20 466.03 S 330.25 491.36 S 345.83 542.62 S 377.36 593.88 S 408.89 645.14 S 440.42 696.40 S 471.95 747.66 S 503.48 798.93 S 535.01 850.19 S 566.54 901.45 S 598.07 952.71 S 629.60 1003.97 S 661.13 Geographic Coordinates Latitude / Longitude 70.15.59.1559 N 148.45.04.9153 70.15.59.1559 N 148.45.04.9153 70.15.59.1559 N 148.45.04.9153 70.15.59.1559 # 148.45.04.9153 70.15.59.1559 # 148.45.04.9153 70.15.59.1559 N 148.45.04.9153 70.15.59.1559 N 148.45.04.9153 70.15.59.1559 N 148.45.04.9153 70.15.59.1559 N 148.45.04.9153 70.15.59.1413 N 148.45.04.9419 70.15.59.0974 N 148.45.05.0217 70.15.59.0244 N 148.45.05.1546 W 70.15.58.9223 # 148.45.05.3404 W 70.15.58.7913 N 148.45.05.5790 W 70.15.58.6315 N 148.45.05.8699 70.15.58.4430 N 148.45.06.2129 70.15.58.2262 N 148.45.06.6076 70.15.57.9813 N 148.45.07.0534 70.15.57.7086 N 148.45.07.5498 70.15.57.4084 N 148.45.08.0963 70.15.57.3046 N 148.45.08.2851 70.15.57.0810 N 148.45.08.6920 70.15.56.7270 N 148.45.09.3364 70.15.56.3467 N 148.45.10.0287 70.15.55.9406 N 148.45.10.7679 70.15.55.5091 N 148.45.11.5532 70.15.55.0529 N 148.45.12.3836 70.15.54.5724 N 148.45.13.2582 70.15.54.3233 N 148.45.13.7117 70.15.53.8191 N 148.45.14.6293 70.15.53.3149 N 148.45.15.5470 70.15.52.8108 N 148.45.16.4646 70.15.52.3066 N 148.45.17.3822 70.15.51.8025 N 148.45.18.2999 70.15.51.2983 # 148.45.19.2175 70.15.50.7941 N 148.45.20.1351 70.15.50.2900 N 148.45.21.0527 70.15.49.7858 N 148.45.21.9703 70.15.49.2816 N 148.45.22.8879 GRID Coordinates Northing Easting (ft) (ft) 5948585.31 654416.70 5948585.31 654416.70 5948585.31 654416.70 5948585.31 654416.70 5948585.31 654416.70 5948585.31 654416.70 Closure Dist. Dir. (ft) deg. Vertical DLS Section (ft) (dg/lOOft) 43.61 a 270.00 23.20 0.00 43.61 a 270.00 23.20 0.00 43.61 @ 270.00 23.20 0.00 5948585.31 654416.70 5948585.31 654416.70 5948585.31 654416,70 5948583.81 654415.82 5948579.29 654413.17 5948571.78 654408.76 5948561.27 654402.59 5948547.78 654394.67 5948531.33 654385.01 5948511.93 654373.62 5948489.62 654360.52 5948464.41 654345.71 5948436.33 654329.23 5948405.43 654311.09 5948394.75 654304.81 5948371.74 654291.30 5948335.30 654269.91 5948296.16 654246.92 5948254.36 654222.37 5948209.95 654196.30 5948162.99 654168.72 5948113.53 654139.68 5948087.89 654124.62 5948035.99 654094.15 5947984.10 654063.68 5947932.21 654033.20 5947880.31 654002.73 5947828.42 653972.26 5947'/76.53 653941.78 5947724.64 653911.31 5947672.74 653880.84 43.61 @ 270.00 23.20 0.00 43.61 a 270.00 23.20 0.00 43.61 a 270.00 23.20 ' ~ 44.54 @ 268.09 24.94 2.00 47.63 @ 262.83 30.18 2.00 53.52 a 255.54 38.89 2.00 62.87 @ 247.81 51.08 2.00 76.05 @ 240.83 66.72 2.00 93.17 g 235.09 85.80 2.00 114.15 @ 230.58 108.29 2.00 138.88 @ 227.11 134.17 2.00 167.23 @ 224.43 163.41 2.00 199.11 @ 222.35 195.96 2.00 234.41 @ 220.71 231.79 2.00 246.65 @ 220.26 244.18 2.00 273.06 @ 219.41 270.86 2.00 314.98 @ 218.37 313.12 2.00 360.10 @ 217.52 358.51 ' ~? 408.35 @ 216.81 406.99 2.00 459.66 @ 216.23 458.49 2.00 513.96 @ 215.74 512.95 2.00 571.18 @ 215.32 570.30 2.00 600.86 @ 215.14 600.04 2.00 660.94 @ 214.82 660.22 0.00 721.03 @ 214.55 720.40 0.00 781.14 @ 214.32 780.58 0.00 841.26 @ 214.13 840.75 0.00 901.39 @ 213.96 900.93 0.00 961.52 @ 213.81 961.11 0.00 1021.669 213.68 1021.29 0.00 1081.80 @ 213.56 1081.47 0.00 1141.65 0.00 1201.83 0.00 5947620.85 653850.36 1141.95 @ 213.46 5947568.96 653819.89 1202.10 @ 213.37 43.61 @ 270.00 23.20 0.00 43.61 @ 270.00 23.20 0.00 43.61 @ 270.00 23.20 0.00 Smith International, Inc. Proposal Report Page 5 Date: 1/15/93 Wettpath ID: A-4OWP Heasured 1nc[ Drift TVD Depth Dir. (ft) (deg.) (deg.) (ft) Subsea T 0 T A L Depth Rectangular Offsets (fl) (fl) (fl) 6067.44 37.00 211.59 5718.74 5639.24 1055.23 S 692.66 6167.44 37.00 211.59 5798.60 5719.10 1106.49 $ 724.19 6267.44 37.00 211.59 5878.47 5798.97 1157.75 S 755.72 SEABEE 6356.38 37.00 211.59 5949.50 6367.44 37.00 211.59 5958.33 6467.44 37.00 211.59 6038.20 6567.44 37.00 211.59 6118.06 6667.44 37.00 211.59 6197.92 6767.44 37.00 211.59- 6277.79 6867.44 37.00 211.59 6357.65 6967.44 37.00 211.59 6437.51 7067.44 37.00 211.59 6517.38 7167.44 37.00 211.59 6597.24 7267.44 37.00 211.59 6677.10 7367.44 37.00 211.59 6756.97 7467.44 37.00 211.59 6836.83 7567.44 37.00 211.59 6916.69 7667.44 37.00 211.59 6996.56 7767.44 37.00 211.59 7076.42 7867.44 37.00 211.59 7156.28 7967.44 37.00 211.59 7236.15 8067.44 37,00 211.59 7316.01 8167.44 37.00 211.59 7395.88 8267.44 37.00 211.59 7475.74 5870.00 1203.35 S 783.76 5878.83 1209.01 S 787.25 5958.70 1260.27 S 818.78 6038.56 1311.54 S 850.31 6118.42 1362.80 S 881.84 6198.29 1414.06 $ 913.37 6278.15 1465.32 S 944.90 6358.01 1516.58 S 976.43 6437.88 1567.84 S 1007.96 6517.74 1619.10 S 1039.49 6597.60 1670.36 S 1071.02 6677.47 1721.62 S 1102.55 6757.33 1772.88 S 1134.07 6837.19 1824.15 S 1165.60 6917.06 1875.41 S 1197.13 6996.92 1926.67 S 1228.66 7076.78 1977.93 S 1260.19 7156.65 2029.19 S 1291.72 7236.51 2080.45 S 1323.25 7316.38 2131.71 S 1354.78 7396.24 2182.97 S 1386.31 8367.44 37.00 211.59 7555.60 7476.10 2234.23 S 1417.84 8467.44 37.00 211.59 7635.47 7555.97 2285.49 S 1449.37 8567.44 37.00 211.59 7715.33 7635.83 2336.76 S 1480.90 IKRU/LCU 8647.79 37.00 211.59 7779.50 8667.44 37.00 211.59 7795.19 8767.44 37.00 211.59 7875.06 8867.44 37.00 211.59 7954.92 8967.44 37.00 211.59 8034.78 9067.44 37.00 211.59 8114.65 7700.00 2377.94 S 1506.24 7715.69 2388.02 S 1512.43 7795.56 2439.28 S 1543.96 7875.42 2490.54 S 1575.49 7955.28 2541.80 S 1607.02 8035.15 2593.06 S 1638.55 9167.44 37.00 211.59 8194.51 8115.01 2644.32 S 1670.08 9267.44 37.00 211.59 8274.37 8194.87 2695.58 S 1701.61 9367.44 37.00 211.59 8354.24 8274.74 2746.84 S 1733.14 9467.44 37.00 211.59 8434.10 9567.44 37.00 211.59 8513.9T 9667.44 37.00 211.59 8593.83 8354.60 2798.10 S 1764.67 8434.47 2849.37 S 1796.20 8514.33 2900.63 S 1827.73 Geographic Coordinates Latitude / Longitude 70.15.48.7775 N 148.45.23.8055 70.15.48.2733 N 148.45.24.7231 70.15.47.7691 N 148.45.25.6406 70.15.47.3207 70.15.47.2650 70.15.46.7608 70.15.46.2567 70.15.45.7525 70.15.45.2483 70.15.44.7442 70.15.44.2400 70.15.43.7358 70.15.43.2317 N 70.15.42.7275 N 70.15.42.2233 N 70.15.41.7192 N 70.15.41.2150 N 70.15.40.7109 N 70.15.40.2067 N 70.15.39.7025 N 70.15.39.1984 N 70.15.38.6942 70.15.38.1900 70.15.37.6859 70.15.37.1817 70.15.36.6775 70.15.36.1734 148.45.26.4567 148.45.26.5582 148.45.27.4758 148.45.28.3933 148.45.29.3109 148.45.30.2284 148.45.31.1459 148.45.32.0635 148.45.32.9810 148.45.33.8985 148.45.34.8160 148.45.35.7335 148.45.36.6510 148.45.37.5685 148.45.38.4860 148.45.39.4035 148.45.40.3209 148.45.41.2384 148.45.42.1559 148.45.43.0733 148.45.43.9908 148.45.44.9082 148.45.45.8257 148.45.46.7431 70.15.35.7683 70.15.35.6692 70.15.35.1651 70.15.34.6609 N 70.15.34.1567 N 70.15.33.6526 N 70.15.33.1484 N 70.15.32.6442 N 70.15.32.1401 N 70.15.31.6359 N 70.15.31.1317 N 70.15.30.6276 N 148.45.47.4802 148.45.47.6605 148.45.48.5779 148.45.49.4953 148.45.50.4127 148.45.51.3301 148.45.52.2475 148.45.53.1649 148.45.54.0823 148.45.54.9997 148.45.55.9170 148.45.56.8344 GRID Coordinates Closure Northing Easting Dist. Dir. (fl) (fl) (ft) deg. 5947517.07 653789.41 1262.26 @ 213.28 5947465.18 653758.94 1322.41 a 213.20 5947413.28 653728.46 1382.57 a 213.13 5947'367.13 653701.36 1436.08 a 213.08 5947361.39 653697.99 1442.73 @ 213.07 5947309.50 653667.51 1502.89 a 213.01 5947257.61 653637.04 1563.06 a 212.96 5947205.72 653606.56 1623.22 a 212.91 5947153.83 653576.08 1683.39 a 212.86 5947101.94 653545.61 1743.56 a 212.82 5947050.05 653515.13 1803.72 @ 212.77 5946998.16 653484.65 1863.89 @ 212.74 5946946.27 653454.18 1924.06 @ 212.70 5946894.38 653423.70 1984.23 a 212.67 5946842.49 653393.22 2044.41 ~ 212.64 5946790.60 5946738.71 5946686.82 653362.75 2104.58 @ 212.61 653332.27 2164.75 @ 212.58 653301.79 2224.92 @ 212.55 5946634.93 5946583.04 5946531.15 653271.31 2285.10 @ 212.53 653240.83 2345.27 a 212.50 653210.35 2405.44 @ 212.48 5946479.26 653179.87 2465.62 @ 212.46 5946427.37 653149.40 2525.79 @ 212.44 5946375.48 653118.92 2585.97 @ 212.42 5946323.59 5946271.70 5946219.81 653088.44 2646.14 a 212.40 653057.96 2706.32 a 212.38 653027.48 2766.50 8 212.36 5946178.12 653002.99 2814.85 a 212.35 5946167.92 652997.00 2826.67 a 212.35 5946116.04 652966.52 2886.85 ~ 212.33 5946064.15 652936.03 2947.02 a 212.32 5946012.26 652905.55 3007.20 a 212.30 5945960.37 652875.07 3067.38 @ 212.29 5945908.48 652844.59 3127.56 a 212.28 5945856.60 652814.11 3187.73 a 212.26 5945804.71 652783.63 3247.91 ~ 212.25 5945752.82 652753.15 3308.09 a 212.24 5945700.93 652722.66 3368.27 a 212.23 5945649.05 652692.18 3428.44 ~ 212.22 Vertical DLS Section (ft) (dg/lOOft) 1262.01 0.00 1322.18 0.00 1382.36 0.00 1435.89 0.00 1442.54 0.00 1502.72 0.00 1562.90 0.00 1623.08 0.00 1683.26 0 1743.44 1803.61 0.00 1863.79 0.00 1923.97 0.00 1984.15 0.00 2044.33 0.00 2104.51 0.00 2164.69 0.00 2224.87 0.00 2285.04 0.00 2345.22 0.00 2405.40 0.00 2465.58 0.00 2525.76 0.00 2585.94 0.00 2646.12 "~ 2706.30 2766.47 0,00 2814.83 0.00 2826.65 0.00 2886.83 0.00 2947.01 0.00 3007.19 0.00 3067.37 0.00 3127.55 0.00 3187.73 0.00 3247.90 0.00 3308.08 0.00 3368.26 0.00 3428.44 0.00 9767.44 37.00 211.59 8673.69 8594.19 2951.89 S 1859.26 W 70.15.30.1234 N 148.45.57.7518 W 5945597.16 652661.70 3488.62 @ 212.20 3488.62 0.00 Smith International, Inc. Proposal Report Page Date: 1/15/93 WeLLpath ID: A-4OWP Measured [ncl Drift Depth Dir. (ft) (deg.) (deg.) 9867.44 37.00 211.59 T. SAG-7-5/8" CSG.PT. 9923.71 37.00 211.59 TOP SHUBLIK 9951.26 37.00 211.59 9967.44 37.00 211.59 TSAD 10042.67 37.00 211.59 10067.44 37.00 211.59 TARGET 10134.07 37.00 211.59 10234.07 37.00 211.59 OOWC 10279.32 37.00 211.59 Z3 10301.86 37.00 211.59 Z2C 10404.53 37.00 211.59 TOTAL DEPTH 10429.32 37.00 211.59 TVD (ft) 8753.56 8798.50 8820.50 8833.42 8893.50 8913.28 8966.50 9046.36 9082.50 9100.50 9182.50 9202.30 Subsea Depth (ft) TOTAL Rectangular Offsets (ft) (ft) 1890.79 ~ 1908.53 w 1917.22 W 1922.32 W 1946.04 W 1953.85 W 8674.06 3003.15 S 8719.00 3032.00 S 8741.00 3046.12 S 8753.92 3054.41 S 8814.00 3092.97 S 8833.78 3105.67 S 8887.00 3139.83 S 8966.86 3191.09 S 9003.00 3214.28 S 1974.86 2006.39 2020.65 9021.00 3225.84 S 9103.00 3278.47 S 9122.80 3291.18 S 2027.76 2060.13 2067.95 Geographic Coordinates Latitude / Longitude 70.15.29.6193 N 148.45.58.6691 70.15.29.3355 N 148.45.59.1853 70.15.29.1966 N 148.45.59.4380 70.15.29.1151 N 148.45.59.5864 70.15.28.7358 N 148.46.00.2765 70.15.28.6109 N 148.46.00.5038 70.15.28.2750 N 148.46.01.1150 70.15.27.7708 N 148.46.02.0324 70.15.27.5427 N 148.46.02.4474 ~ 70.15.27.4291 N 148.46.02.6542 70.15.26.9114 N 148.46.03.5960 70.15.26.7~54 N 148.46.03.8234 GRID Coordinates Northing Easting (ft) (ft) (ft) 5945545.27 652631.22 3548.80 5945516.07 652614.06 3582.67 5945501.78 652605.66 3599.24 5945493.39 652600.73 3608.98 5945454.35 652577.80 3654.25 5945441.50 652570.25 3669.16 Ctosure Dist. Dir. deg. a 212.19 a 212.19 a 212.19 @ 212.18 @ 212.18 ~ 212.17 5945406.92 652549.94 3709.26 @ 212.17 5945355.04 652519.45 3769.44 a 212.16 5945331.56 652505.66 3796.66 @ 212.16 5945319.87 652498.79 3810.23 a 212.15 5945266.59 652467.49 3872.02 @ 212.14 5945253.73 652459.93 3886.93 @ 212.14 Vert i ca l DLS Sect i on (ft) (dg/lOOft) 3548.80 0.00 3582.66 0.00 3599.24 0.00 3608.98 0.00 3654.25 0.00 3669.16 0.00 3709.26 3769.43 0.~,~,~ 3796.66 0.00 3810.23 0.00 3872.02 0.00 3886.93 0.00 Smith International, Inc Travelling Cylinder Report Computed by the Sii Win-CADDS System Least Distance Method Page 1 Date: 1/15/93 REFERENCE WELL: Prudhoe Bay Drilling Prudhoe Bay A-PAD A-40 A-4OWP TVD, N/S and E/W are measured from the WELLHEAD Wek[path Slot Distance a01 A-01 276.41 a02 A-02 339.15 a03 A-03 213.92 a04 A-04 83.61-- 'a05 A-05 35.26 a06 A-06 63.33 a07 A-07 153.20 a08 A-08 250.74 a09 A-09 407.51 al0 A-10 521.92 all A-11 618.80 a12 A-12 723.98 a13 A-13 844.53 a14 A-14 477.77 a15 A-15 1046.49 a16 A-16 875.7'5 a17 A-17 1262.33 a18 A-18 1376.91 a19 A-19 776.42 a20 A-20 1527.36 a21 A-21 1432.46 a22 A-22 1344.51 a23 A-23 105.92 a24 A-24 348.42 a25 A-25 301.55 a26 A-26 1002.45 a27 A-27 293.55 a28 A-28 900.79 a29 A-29 804.35 a30 A-30 1322.77 a31 A-31 1105.19 a32 A-32 907.82 a33 A-33 577.43 a34 A-34 685.57 a34a A-34A 670.16 a35 A-35 787.59 A-3714P A-37 1465.15 Closest Points Direction Ref MD Ref TVD 119.11 4619.10 4550.00 179.78 50.00 50.00 206.98 3051.27 3050.00 108.27 3001.27 3000.00 178.39 50.00 50.00 4.07 750.08 750.00 3.78 2701.27 2700.00 15.20 3151.27 3150.00 5.61 3051.27 3050.00 6.09 3151.27 3150.00 4.80 2651.27 2650.00 5.32 3151.27 3150.00 2.48 2701.27 2700.00 255.70 6544.83 6100.00 182.52 1501.27 1500.00 188.56 6043.97 5700.00 181.73 2701.27 2700.00 182.34 1151.05 1150.00 129.90 6043.97 5700.00 208.17 1701.27 1700.00 210.57 1501.27 1500.00 213.45 1401.26 1400.00 131.57 5417.90 5200.00 144.96 3654.41 3650.00 298.92 2701.27 2700.00 227.29 1501.27 1500.00 303.12 5480.51 5250.00 239.95 850.22 850.00 254.82 2251.27 2250.00 183.88 0.00 0.00 184.56 100.00 100.00 157.89 4448.66 4400.00 0.42 750.08 750.00 4.19 3101.27 3100.00 5.27 2801.27 2800.00 3.58 3001.27 3000.00 210.31 1301.23 1300.00 RECEJVEg Alaska. Oil & Gas Cons. Anchorage Pr~udhoe Ppudhoe A-PAD A-40 A-4OWP Bay Sc~y Dpi~(in9 TRU~ N WI~E I~9.~ Eo~-~: ~::lin~fl:;o~ HBRIZ[3NTAL SCALE 500 REFERENCE', VIEW ~'-t::::, / DIVISIBN WELL HEAD 25OO 2000 1500 ~000 0 500 , RE£E VEb Alaska OU & Gas Cons, Col-amissio~'~ Anchorage Pr' udhoe 3o, y .__IS M i i h-40 A-40 P T ¢ve[[ing CT[inde - LeCs Bis ¢nce AIL Directions Re[ T ue / ~7~ . ~I~IC~ ~INT R,K.B. ELEVA~]~ 7~, 0 0,~ 0,~ 0 0 0 eO~ A-OJ 276,4J ~g.~ 46~g40 45~,~ ~ ~ ~R~]~ l~ 5.~ ~70,~ ~ -0 -22 ~ A-~ 3~. ~ 5 ~ 7g.78 ~.~ ~,~ E~ ~ ~ ~ 0,~ 0.~ J 4~ -0 -44 e~ A-OB 2~3,~ ~.~ ' ~J,~7 ~.~ ~ ~ I~J 0.~ 0,~ J~ -0 -44 ~ A-~ 83.6J ~.~7 ~J,~7 ~,~ 1~3/4' ~. PT, ~J 0.~ 0.~ ~ -0 -44 5T~T ~ ~L9 3t17 0,~ 0.~ 3~6 -0 -44 a~ A-~ ~.~ J78,~ ~.~ ~.~ ~ 4A 4~ ~.65 2~,~ 42~ -l~ a~ A-~ 63.33 4;07 ~.~ 7~,~ E~ ~ ~]L~ 4~7 37.~ 2JJ,~ 4840 -4OJ 007 A-07 J53~ 3.78 ~70J.~7 ~7~.~ ~A~E 6~ 37.~ 2JJ,~ 5~ -l~ -784 a~ A-~ ~.74 J5.~ 3JSJ.~7 3J~.~ ]K~ ~8 37.~ 2JJ,~ 77~ -2378 o J0 A-JO ~J.~ 6.~ 3JSJ.27 3J~.~ T~ ~]K ~J 37.~ 2JJ.~ ~ -~6 aJ J A-JJ ~A ~A N/A N/A T~D J~43 37,~ 2JJ,~ ~4 -~ -J946 T~T JOJ34 37,~ 2JJ.~ ~ -3140 o12 A-J2 ~A ~A ~A N/A ~ ]027g 37,~ 211.~ ~3 -~14-~l ~3 A-13 ~A N/A ~A N/A Z3 ~0~ 37.~ ell.~ 9~ -~-~ o J5 A-~5 ~A ~A N/A N/A T~ ~PTN ~04~ 37.~ 21~.~ g~ -~1 -~8 o J 6 A- J 6 ~A ~A N/A ~A o ~ 7 A- ~ 7 ~A ~A ~A ~A o ~ 8 A- ] 8 ~A N/A N/A N/A o ~ ~ A- ~ 9 ~A ~A N/A ~A o~ A-~ ~A ~A ~A N/A o2~ A-2~ N/A N/A ~A N/A o~ A-~ ~1.55 ~.92 270J.27 27~,~ '": ~ i'''~'' L,. o~ A-~6 ~A ~A N/A N/A o~7 A-~7 ~3.55 ~3. l ~ ~.5 ~ ~.~ o~ A-~ ~A N/A N/A N/A ... , o~ A-~ N/A N/A N/A N/A ~',~ '~'t ;:~ ~) '~ '~ '-~ ~2 J ~ ~TA T~ ~.~ o~ A-33 577.43 0.42 7~.~ 7~.~ . s,c;~;;.~2(. ~:; .~'- ~,-,, ~h -~1.~8 034 A-~ ~A N/A N/A N/A ~ .~-j ,,-~ r~ .. Eo~ -~7.~ o~ A-~ ~A N/A ~A N/A A-37~ A-37 ~A ~A N/A ~A NABORS 28E DIVERTER SYSTEM ARCO ALASKA, INC. FILL-UP UNE ! R~ER FLOWLINE 10" BALL VALVE 1 1 1(7' !~1 ! VALVE ~Y ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE ~=COND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT MNF_ THE SECOND VENT MNE VALVE CAN BE OPF. NED USING CONTROLS LOCATED ATTHE ACCUMULATOFL THIS IS THIS IS A VARIANCE FROM 2DAAC25.03~ '-RESERVE PIT IIY' VENT MNE 1(7' VENT UNE DtVERTER UNES DISCHARGE 100 FT. FROM RIG IGNITION SOU~ NABORS 28E 13 5/8" 5,000 psi Stack 2.42 10.93 4.50 4.82 1.51 3.07 2.13 1.13 1.5 ,f GROUND LEVEL /' RKB '~ HYDRIL g PIPE RAM I i BLIND RAM KR TC) RF RI( ~ FLO( 13.18 5.58 . 8.06 MUD CROSS PIPE RAM 12.58 I16.25 MUD CROSS TBG SPOOL i ~ASE FLG ~~lE]// 17.33 19.75 TO PIT TO FLARE ~ , CAVIEM UNIT 1 8H, SCI CA¥1~M UNIT 2 KER ~ EEN ~ FILL LINE ..SAND- TRAP 4 BBL CHOKE TRIP TANK 170 BBL VOLUME TANK 137 BBL DISTRI ~UTION DITCH 131 BBL 81BBL DEGASSlNG TANK DESlLTER NABoRs PIONEER MK I DEGASSER DRILCO 8EEFLOW EQ. MANIFOLD TO PIT TO STAND PIPE & KILL LINE VOLUME TANK 180 BBL tTO DISTRIBUTION WATER 87 BBL MUD HOPPERS & MIXINQ PUMPS 8UCTION 117 BBL 8UCT~N 134 BBL MUD PUMPS NABOR$ DRLLI',iG LTD RIG No. 28E MUD SYSTEM SURFACE FACILITIES TOTAL ACTIVE SYSTEM: 800 BBL TOTAL SURFACE CAPACITY: 97'0 BBL A-40CI~IT.XLS ' State: Well: Field: State Permit .4.40 P~UDHOE Engineer.' Work S beet: Date~ Casing T~e Casing Size Casing Length Hole Diamete~ Cement- Sacks Cement- Yield Cemenl - Cubic It Cement- Cubic fl Cement- Sacks Cement- Yield Cement- Cubic fi Cement- Cubic It Cement-Sacks Cement- Yield -Inches - Feet -Inches 111 111 111 111 112 112 112 112 ~3 Cement- Cubic f~. 113 Cement- Cubic ft113 Cement- Cubic It /Vol Cement- Fill Factor Conducto~ 20.000 80.000 30.000 0.000 0.000 0.000 297.000 0.000 0.000 0.000 0.O00 297.000 1.361 Su~lace 10.750 3,020.000 13.500 970.000 1.920 1,862.400 1,862.400 435.000 0.960 417. 600 417. 600 0.000 0.000 0.000 0.000 2,280.000 2.076 Liner 5.500 655.000 6.750 120.000 1.180 141.600 141.600 0.000 0.000 0.000 0.000 141.600 2.589 Casing T~pe Casing Size -Inches Casing Depth- Feet Hole Diamete[ -Inches Cement- Sacks 111 Cement-Yield111 Cement- Cubic tt 111 Cement- Cubic Il: 111 Cement- Sacks 112 Cement- Yield 112 Cement- Cubic ft 112 Cement- Cubic ft. 112 Cement-Sacks113 Cement-Yield113 Cement- Cubic I~t 113 Cement-Cubic ft 113 Cement- Cubic ft /Vol Cement-Inte[¥al ft Top of Cement- Feet Intermediate 111 0.000 0.000 0.0O0 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/0! I~DIV/0! Intermediate 112 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 IIDIV/0! ItDIV/0! Production 7.625 9,924.000 9.875 265.00 1.15 304.75 304.75 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 304.75 1,419.07 8,504.9 Measured Depth CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE~,~-/DD~T~3 (1) Fee (2) Loc ~ ,~/w_~'~. ~ '[2 thru 8] ' [9 thru 13] '" 10. [10 & 13] 12. 13. (4) Casg . ~ 14. [14 thru 22] 15. (5) BOPE .~ .... ~ . .~ [23 thru 28] 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company YES 1. Is permit fee attached ............................................... 2~_ 2. Is well to be located in a defined pool .............................. L 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. /~ 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ /~ Lease & Wel] ~ ~/_~ NO Does operator nave a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is 1 ease n~nber appropriate .......................................... Does well have a unique name $ nL~nber ................................ Is conductor st r i ng provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface g intermediate or production strings ...... Will cement cover all kno~ productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wel ]bore separation proposed ............................. Is a diverter System required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~"~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS FOR EXPLORATORY & 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 nLrnber of contact to supply weekly progress data ...... Additional requirements ............................................. -rZ geology' DWJ rev 12/92 jo/6.011 en9ineerinq' MTM~' RAJ). ~ I- Z ~- BE~L~ JDH -:~ LGG_~y~g INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' X MERTDIAFJ' SM" , , Exp/Dev ~ Inj WELL_ ~TYPE' Redri 1 1' Rev Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ~bASKA COMPUTING CENTER * ****************************** *------- $CHb{JMB~RG~R ****************************** COMPANY NA~ : ~P EXPLORATiOD ~EbL NAME : A-40 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE AP! NUMBER : 50-029-~2337-00 =r 0 ,IS Tame Verification Listing ;¢hlumberger Alaska Computing Center 29-Jr)N-!g93 09:16 **** REEL HEADER SERVICE NAME : EDIT DaTE : 93/06129 CONTINUATION , : PREVIOUS REEL : CO~MMT : BP E×PbORATION,PRUDHOE bAY,A-40 **** TAPE HEADER **** SERVICE NA~¢ : EDIT DATE : 93/06/~9 O~IGIN : FbIC TAPE NA~E : 93~68 C~NTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION,P~UDM~E BAY,A-40 C24-35-11-13),50-029-~2337-00 TAP~ HEADER PRUDHOE BAY UNIT OPg~ HOLE wIREL!NE LOGS W~bL NAM~: API NUMBER: OPERATOR: LOGGING COMPANY: TApE CREATION DATE: JOB DATA OPERATOR WITNESS: SURFACE LOC~TIOM SECTION: RANGE: FEL: ELEVaTION(MT KELLY BUS~IMG: DERRICK GROUND WELL CASING RECORD ~$T STRING ~ND STRING A-40 500292231700 BP EXPbORATION 29 93268 CRYER HAYWOOD RUN ~ RUN,3 35 921 79.50 47.00 OPEN HObE CASING DR II..,LER8 git SIZE (IN) SIZE (IN) DMDTH (PT) 6.750 7, ~ 985 PAGE: ~IS TaPe Verification [,istt. ho chlumberger Alaska Computin~ Center 29-JU~.i-] 993 09:!6 ]RD STRIgG PRODUCTION STRING R~i~ARKS: FIELD ENGTNEER'S RE~ARKS: DITE AND SONIC ~l!N IN CD~BINATI[}N ,8" STANDOFFS USED FOR CENTRALIZATION MAX. DEVIATION 38 PEG g 76~9 PULLED TIGHT 09890' ~ED. INDUCTION CURVE NOT PRESENTED DUE TO SPI~ING GR RUN TO 9!00' !NSIDF CASING $ $ PAGE: **** FILE HEADER FILF NA~E : EDIT .001 S~PVICE : FLIC V~RSION : O0~A07 DATE : 93/06/29 ~X REC S!Z~ : 10~4 F'~LE TYPE : bO LAST FILE F!L~ NEADE~ EDITED CURVES ~I1 tool strings; Depth shifted and clipped c%~rves~ all runs merged; no cased hole data, DEPTH INCREMENT 0.5000 FIL~ SUMNARY PBU TOOL CODE BC$ DT~ 10~47.0 !07~,0 ~0245.0 STOP DEPTH 9850.0 9850'0 9850.0 BAS~L!NE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) - ......... -EQUIVALENT UNSHIFT~D BASELINE DEPTH MERGED D~TA SOURCE DBU TOOL COD~: RUN NO, PASS NO, MERGE TOP $ RE~RKS: NO DEPTH ADJUSTMENTS WERE NEEDED COMBINATION, $ LIS FORMAT DATA Tame Yerificat~on Listing icblumberqer .~].asKa Compt. lti, ng Center 29-JUN-1993 09:16 ** DATA FORMAT SPECIFICATION ~KCORD SET TYPE - 64EB ** TYPE PEP~ COD~: VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 7 65 ~ 68 0,5 9 65 FT !1 66 21 !2 68 13 66 0 14 65 FT 15 66 68 !6 66 0 66 0 ** SET TYPE - CH&N ** N~E SERV UNIT SERVICE aPI aPI APl aPI FII, E NUMB NUmB SIZE REPR PROCESS ID ORDER # bOG TYPE CLgSS MOD NUmB SAMP ELE~ CODE DEPT Fl' 548517 00 000 O0 0 I 1 1 4 68 0000000000 DT BCS US/F 548517 00 000 00 0 1 ! I 4 68 0000000000 GP BCS GAPI 548517 O0 000 O0 0 I ! 1 4 68 0000000000 TENS BCS LB 548517 O0 000 O0 0 i 1 1 4 68 0000000000 TEND BCS LB 548517 O0 000 O0 0 i I 1 4 68 0000000000 IDPH DTE OHMS 548517 O0 000 O0 0 I ! ! 4 68 0000000000 ILO DT~ OHMM 548517 O0 000 O0 0 I 1 1 4 69 0000000000 IL~ DTE O~MM 548517 O0 000 O0 0 1 1 1 4 68 0000000000 $~b DTE 548517 O0 000 O0 0 1 1 I 4 68 0000000000 BP DTE MV 548517 O0 000 O0 0 I 1 !, 4 68 0000000000 MTE~ DTE DEGF 548517 O0 000 O0 0 I ! 1 4 68 0000000000 ~RES DTE OHMS 548517 O0 000 O0 0 I 1 1 4 68 0000000000 DATA -~99.~50 TENS,BCS -~9g,250 196o750 4130 000 -999!250 ,IS Tape Verification tisttnq ;chlumberger Alaska Computing Center D~PT. 10300.000 DT.BCS TEND.~CS 508.256 IDPM,DTE SFL,D?E -999,250 SP,DTE DEPT. 10200.000 DT.BCS TEND.ECS 597.000 IDPH.DTE SFL,DTE 13.063 SP.DTE DEPT. 10100,000 DT.BCS TEND.ECS 593.500 !DFH,DTE SFLoDTK !1.203 SP.DTE DEPT. 10000,000 DT,BCS TEND,ECS 756,000 IDPM,DTE SFT.,.DTE 15,516 SP,DTE DEPT, 9900,000 DT,BCS TEND,ECS 730,500 IDPH.DTE SFI,,DTE 48,813 SP,DTE DEPT, 9850 O00 DT,BCS TEND,ECS 767~500 IDPH.DTE SFI~.DTE 1.3t5 SP,DTE END OF DATA ** 2q-JUN-1993 09:16 ~999.~50 GR,BCS 999.250 IGD.DTE -999.250 NTF~.DTE 75.313 GR.BCS 4.078 ILD,DTE -J60.750 ~TEM,DTE 81 875 G~.BCS !o:438 -85.625 ~TE~.DTE 87.875 GR.8CS 9.313 ILD.DTE -124.313 ~TE~.OTE 59.~0o 35, 94 ILt.),DTE -84.500 ~TEM.DTE !59.0~0 G~.BCS 0.6 5 ILD,DTE -8!,313 MTE~,DTE -999.~50 -999.250 196.750 20.828 4.070 194.~50 61.719 9.805 193,625 36,906 9.141 191.250 78.375 36,750 157,375 TENS.ECS IL~.DTE MRES.DTE TENS.BCE ILM.DTE MRES.DTE TENS.ECS It, M.DTE MRES.DTE TENS.ECS ILM.DTE MRES.DTE TENS,ECS !LM.DTE MRES.DTE .ECS ~RES.DTE PAGE: 4135.000 -999.250 1.186 4225,000 7.000 1.200 4185,000 470,500 1.2i7 .000 1,246 4205,000 1950,000 !,306 °°° ,000 **** FILE TRAlbER **** F'!LF NAME : EDIT ,00! SERVICE : FLI£ VERSION : O01. A07 [)ATE : 93/06/29 ~A× REC SIZE : 1024 f'!bE TYPE : LO LAST FILE : **** FILM NEADER **** F!LF ~AME : EDIT ,002 SERVICE : FLIC VERS!O~ ~ O01A07 DAT~ : 93/06/29 MAX REC SIZE : 1024 F!L~ TYPE : LO LAST FILE EDITED CASED }'!OLg ~AIN PASS Depth shiited and clipped curves for open hole logs run into casing, ,IS Ta~-,e Veri~ication Ltstin~ ;c~lumber¢t~r ~laska Computing Center 29-jUN-lq93 OM:lB DEPTH !NCREM~NT 0,5000 FILF SIlk, MARY PBU TOOL COD~ START DEPTH .......... ;-;--. .... G 8 o,0 STOP DE~PTH BASELINE CURVE FOr SHIFTS: CURVE SHIFT DATA (m, EASURED DE:PTH) .... ------EQUIVALENT UMSHIFTMD DEPTH ~ASELINE DEPTH RF~RKS: THIS GAMMA RAY WAS FRO~-~ THE CONTINUOUS OPEN HO6E .[,,OG RUN INTO CASING AS;D IS PRESENTf;D HERE AS GR !N CASING. LIS FORM.~T DATA PAGE: ** OATh FORMAT SPECIFICATION RECORD ** ** SET TYPE - 6~8 ** r"'""'";;' ....... ";'"' 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0,5 g 65 FT 1! 66 42 12 68 13 66 ~4 65 FT 15 66 68 16 66 0 66 ,IS Tape Verification Llstino Icblumberger Alaska Computing Center ~O-JUN-19g3 09:16 PAGE: ** SET TYPE - C N~. SER. IT SERV C ID ORDER ~ mmmmmlmmmmmmmmmmmmmmmmmmmm DEPT FT 548517 GPCH BCS GAPI 548517 TENS BC$ LB 548517 MRE$ BCS OHMM 548517 ~'rE~ uCS OEGF 548517 ~T~v BCS bB 54~517 O0 000 O0 0 2 1 1 4 68 0000000000 On 000 O0 O 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 I 4 ~8 0000000000 O0 000 O0 0 2 1 1 4 68 O0 000 O0 0 2 I 1 4 68 0000000000 ** I)ATA ** EPT 9850.000 GRCH BCS ~5.625 TEN$.}%C$ 4305.000 MRES.BCS ~TE,:BCS '183.375 HTEN:BCS 7 7.500 DEPT. 9800.000 GRCH.BC$ 78.500 TENS.BCS 4030.000 ~RS:S.BCS MTE~.BCS 180.125 HTEN.BC$ 721.000 EPT. 9700.000 GRCH.BCS 64.875 TENS.BCS 4065 000 MRES.BCS TE~.BC$ 176.750 HTEN.BCS 715.500 ...... ' EPT. 9600 000 GRCH.BCS 7!.563 TEN$.~CS 4070.000 MRES,BC$ TE~o~CS 1731625 ~TEN.BCS 728'500 soo.ooo ' . TE~...o,BCS 4050 000 MRES ECS ~TE~,BC$ 171,125 HTE.. BC$ 745, 0 DEPT, 9400,000 GRC0,BCS 54.06~ TEN$.BC$ 4055,000 ~T~.BC$ 168.625 ~Tg~,SCS 757.000 DEPT, g300.O00 GRCH BC$ 76.500 TEM8.BC$ 4065,000 MRE$.BC$ gTE~.BCS 166'000 hTEi~:BC$ 74~.000 ... ~ , . ? , , DEPT. 920(i),000 GRCH BC~. 66 438 TS:N$,BCS 3895 000 MRES BCS MTE~,BCS 164.125 MTEN:BCS 740.000 D:EPT 9100.000 GRC'H.BCS 67.000 TENS,BCS 3990.000 MRES.BCS MTE~'Bc$ !62 500 BTEN.BC8 730,000 .,.- . · DEPT. 0025 000 GRCH.BCS 74 56.] TENS.BCS 3990.000 MRES.BCS MTE~,BC8 16!:125 HTEN.BCS 715:500 1,373 !.420 1.430 1.447 1.472 1.500 1,521 1',533 1.548 ** END OF DATA ** ils Tape Verification Listing ;chlumberqer Alaska Computing Center 29-JUN-~993 09:16 PAGE: 7 **** FILE TRAILER FILE NAME : EDIT ,002 SERVICE : FLIC VERSION : O01A07 DATE : 93/06/~g ~AX REC SIZE : !024 FILE TYPE : LAST FII,E : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSIO~ : 00!A07 DAT~.: : 93/06/2g MAX REC STZE : ]024 FILE TYPE : LC) I, AST FILE : FILE HEADER FILE NUMBER 3 RaW OPEN HOLE ~AIN PASS Curves and log header data for each run and tool string in separate files; Sadlerochit rum presented first (primary depth control string used to depth interval) followed by files for other main pass strings per run, RUN NUMBER: l TOO[.,, STRING NUMBE~.: 1 PASS NUMBER: 2 DEPTH !.NCRE~ENT: 0.5000 FILE SU~RY VENDOR TOOL CODE START DEPTH 1027~,0 1.0245.0 LOG ~EADER DATA ~ATE bOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON bOTTOM: STOP DEPTH 9769.0 983t.0 T~ D~IbLER TD LOGGER(ET): TOP LOG INTERVAL (MT): BOTTO~ bOG INTERVAL (FT): LOGGING SPEED (FPHR): 14-JUN-93 CP 32.6 1030 14-JUN-93 1500 14-JUN-93 10315,0 !0300., 1800,0 TO[~L STRING (TOP TO BOTTOM) VE~DOR TOOL' CODE TO{LL TYPE Tt)O[: NU~BER ''''''''''' TI.~LI~,RY ~4EASU~E~E~TS ~-AA 774 Tool Strina #I fo Shift the-sadler ,lS Tape Verification Listin~ ~cbl. u~berger Alaska Computing Center 29-Jti~-1993 09;1.6 PAGE~ fcc GR E~HC BHC DTE DTE TCM S S ~rELM~ETRY CARTklPGE GA~A paY BO~EHObE SONIC BOREHObE SONIC PHASOR INDUCTION PMASOR INDUCTIQN TELEMETRY MODUI;E TCC-B 320 SGC-SA 60 SLC-UA 136 SLS-wA 2001 DIC-EB 427 DIS-H~ 434 TCg-A6 95 SEa-DB 1596 BOREHObE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPT~ (FT): 6,750 9857 0 98so:o BORE~tOLE COMD!TIONS MUD TYPE: DENSITY (L~/G): MUD VISCOSITY ~UD PH: F~U~D ~oss MAXIMUM Rf~CORDED TEMPERATURE (DEGF){ RESISTIVITY (OHMic) AT TEMPERATURE (DEGF): MOD AT MEASURED TEMPERATURE MUD AT ~OTTO~ HOLE TEMPERATURE MUD FII~TRATS AT ~uo c~E AT (~T): LS~D 8,90 38,00 9.40 6 O0 19 ;o 4,140 5,!00 2,710 73.0 73.0 73.0 NEUTRON TOO~ TOOL TYP (EPITHERMAb OR THERMAL): ~ATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL ST~MDOFF ~E~ARKS: DIT~ AND SONIC RUM IN: COMBINATION ,8" STANDOFFS USED FOR CENTRALIZATION ~AX,~ DEVIATION ]8 DEG M 7619 PULLED TiGhT ~9890' ~t~D. INDDCTION CDR'YE NOT P~.ESE..TED DUE TO SPIKING: GR RUN TO 9100' INSIDE CASING $ LIS FORMAT DATA ,,IS Ta~e Verification Listing ;cblumberger Alaska ComDutinq Cemter 29-JUN-J993 09:16 PAGE: ** DATA FOR,'~AT SPE¢I?!CA~'ION ~EC[!PD ~* ** S~T TYPE - 64E& ** TYP~ REPR CODE VALUE 1 66 0 2 66 0 3 73 136 5 66 6 73 7 65 ~ 68 0,5 9 65 FT 11 66 7 13 66 0 14 65 FT 15 66 68 !6 66 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APl &PI API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS ~OD NUMB SAMP EhEM CODE (HEX) DFPT FT 548517 00 000 00 0 ] ! ! 4 68 DT BHC US/F 548517 00 000 O0 0 3 t I 4 68 TTI BHC US 548517 00 000 O0 0 3 1 I 4 68 TT2 BHC [iS 548517 O0 000 O0 0 3 I I 4 68 TT3 BHC US 548517 O0 000 O0 0 3 I i 4 68 TT4 B~C US 548517 O0 000 O0 0 ] 1 I 4 68 SP BHC MV 548517 00 000 00 0 ] 1 1 4 68 GR BNC GAPl 548517 00 000 00 0 3 I 1 4 68 T~NS BHC LB 5485~.7 O0 000 O0 0 3 I t 4 68 ~TE~ BHC DEGF 5485!7 O0 000 O0 0 3 1 I 4 68 MRES B~C O~MM 548517 OD 000 O0 0 3 I ! 4, 68 HTEN B~C LB 548517 00 000 O0 0 3 I I 4 68 CIDP DTE MMHO 548517 O0 000 00 0 3 t 1 4 68 IDP~ DTE OHM~ 548517 O0 000 O0 0 3 1 i 4 68 CIMP DTE M~HO 548517 O0 000 O0 0 3 ! 1 4 68 IMPM DTE OH~M 5485~7 00 000 O0 0 3 I ~ 4 68 CIL~ DTE ~HO 548517 00 000 00 O 3 1 I 4 68 ILO DTE OHM~ 548517 00 000 0(? 0 3 1 I 4 68 C!b~ DTE ~MHO 548517 00 000 O0 0 3 ! I 4 68 ILM DTE OH~ 548517 O0 000 OO 0 3 ~ ! 4 68 IFR~ DTE HZ 548517 00 000 O0 0 3 1 I 4 68 IOOF DTE 548517 O0 000 O0 0 3 1 I 4 68 !~QF DTE 548517 00 0O0 O0 0 3 1 ! 4 68 IIRD DTF MNHO 548517 00 000 O0 0 3 ! 1 4 68 tI×O DTE M~MC 548517 00 000 O0 0 3 I I 4 68 IIR~ DTE ~MHO 548517 O0 000 O0 0 3 1 ! 4 68 0o00000000 0000000000 0000000o00 0000000000 0000000000 0o0o000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ~000000000 .000000000 0000:000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 Tame Verification Listinq ;chlumberger AlasKa Commuting Center 29-JUN-1993 09:lb PAGE: NAM~ SERV U _ P ~PI A API FILE NUmB NU SIZE R PROCESS ID ORDER # bOG TYPE CbASS MO[) NUmB SA~P gbfM CODE (HEX) ]IX~ DT~ MMH[3 548517 O0000 O0 G~ ~ a~, s4~,7 oo ooo oo ~ ~T~ o~ ~4~5,7 oo ooo oo o a ~ , ~ ~ oooooooooo 0 ~ , 1 4 68 0000000000 o ~ , , ~ ~ oooooooooo o ~ ~ , ~ s8 oooooooooo o s , , ~ o~ oooooooooo o s ~ , ~ ~8 oooooooooo o ~ ~ , ~ ~ oooooooooo o ~ , ~ 4 ~ ooooo~oooo mmmmmmmmmmmmmmmm .mmmsmmm.mm mmmmmmmmm mmmmm. 10 DATA DEPT. 10364,500 DT,BHC TT3,BHC 512,500 TT4.BHC T~N$.BHC 2375,000 MTEM,BHC CIDP'DTE 483,750 IDPH,DTE CILD DTE 490,750 .ILD,DTE IFRE[D.YE 20,000 IDQF,DTE ITXD'DTE 70,025 !!RM.DTE SP.DTE -151.000 GR,DTE ~RES.DTE ~.i86 HTEN.DTE DEPT. 10300.000 DT.BHC TT3.BMC 5!2,500 TT4.BHC TEuS.B~C 4135,000 ~TE~,BHC CYDD,DTE 486,750 IDPH,DT5 CILD,DTE 49.3.750 ILD,DTE IFRE,DTE 20,000 IDQF,DTE IIXD,DTE 70.500 IIRM,DTE SD,DTE -150'500 GR,DTE MRES.DTE 1,186 HT~N,DTE DEPT. 10200 . 000 DT. BHC TT3 BHC 488,750 TT4.BHC ~s BHC ~s.ooo ~T~.~..C CIDP DTE 245 000 IDPH.DTE CILD"DTE 245]375 !~.o~ 2o..ooo ~O~.D~ SP.DTE -160,750 GR,DTE MRES,DTE 1,200 HTEN,DTE fDEPT, 10!00.000 DT,BHC TT3,BHC 506,000 TTq,BHC TEN$,BHC 4185,000 ~TE~I'BHC CIDP.DTE 95.750 IDPH,OTE CILD,DT~ 101,875 ILD'DTE IFRM.DTE 20,O00 IDQF DTg iIXD.DTE 15,680 IIRMi?TE SP.DTE -85.6~5 ' GR 80.375 TT!,BHC 353 500 SP,BHC !96:750 ~RES,BHC 2.064 CI~P,DT£ 2.035 C~6M.OTE 3.000 IMQF.DTE 251.875 IIXM,DTE 19,047 TENS,DTE -376.500 522.000 -15! 000 I 1.86 267 000 269 000 2 000 -70 313 2375,000 80,375 TT!.BHC 522.000 353,500 SP,BHC -!50,500 1,96,750 ~RE$.BHC 1,186 ~.053 CIMP,DTE 303,7~0 2'023 CXL~,DTE 304.2 0 0.000 IMOF,OTE 0.000 284,250 IIXM'DTE -67.438 19,047 TENS'DTE 4135'000 508.250 75.313 TT1.BHC 340'000 SP.BHC 194.256 MRE$,BHC 4.078 CIMP,DTE 4,070 CIbM,DTE 0.000 IMOF.DTE 134,750 IIX~,DTE 20,828 TEN$,DTE 597.000 81,875 TT!.BHC 353.000 SP.BHC 193,625 MRES.SHC !0'438 CIMP.DTE 9,805 C!bM,OTE 0.000 !~QF.DTE 2,023 IIXM,DTE 6!.719 TEN$.DTE -160.750 1 '200 .4 .750 , O 00 B 5.3 1 3 4225 ~000 ~06,750 85':6~5 1,2.7 -1.O30 . ~:'~ 000 9911s~ 4185.000 TT2.BHC GR.BHC HTEN,BMC IMPH.DTE IIRD.DTE SFLU,DTE MTEM.DTE TT2.BHC GR,BHC HTEN.BHC IMPH.DTE ILM,DTE IIRD,DTE SFLU'DTE MTEM,DTE TT2.BHC GR'BHC HTE..~ IMPH,DTE IbM,DTE iIRD'DT~ $FbU'DTE: MTE.~.DTE TT2,BHC GR.BHC HTEN,BHC IMPH.DTE ILM.DTE I!RD DTE MTEM,DTE 359 500 19i047 -376 500 ,740 ~.715 394,000 8,336 ~96.750 359.500 19.'047 508'250 3.289 3.283 395,000 6,895 196"750 339.500 20'828 597;,000 61,789 7,000 214,000 13,063 !94,250 353,000 61'.719 593'5OO 1950,000 470'500 99,000 !1,203 193,625 lis Tame verification bi ~¢hlumberger Alaska Comp ~RES.DTE 1.2t7 DFPT 10000.000 TT3:BHC '542.500 TEN$.BHC 4-345.000 CIDP.DTE 1.07.313 CILD.DTE 109.313 IFRE.OTE 20.000 IIXD.DTE 8.086 SP.DTE -124.313 ~RES.DTE 1.246 DEPT. 9900,O00 TT3.BHC 425,000 TEM$,BHC 4205,000 CTDD,DTE 28,469 CILD DTE 27.188 IFRE:DTE 20,000 II×D.DTE 4,559 SP.DTE -84,500 ~RES.DTE !.306 sting utinq Center HTKN.DTE DT,SHC TT4.B~C MTEq,8BC !DPH.DTE ILO,DTE IDOF.DTE IImM.DTE GR.OTE DT.BHC TT4.BHC MTEM.BHC IDPH.DTE ILO,DTE IDQF,DTE IIRM,DTE GR.DTE HTEN,DTE DEPT, 9800,000 OT.BHC TT3.BHC 413,500 TT4.BMC ~s sac 4o3o.ooo ~.~c CIDP:DTE 42.688 ~DP~.DTE C!LD.DTE 43.844 ILD.DTE ~RES,DTE ! 373 HTEL DTE DEP? 9700.000 TT3~BHC 414,000 TENS BHC 4065,0.00 CIDD~DT~ '~ 27.984 CILD.DTE 29.484 IFRE'DTE 20.000 IIXD,DTE 38,03! SP.DTE '96.250 ~RE$,DTE 1,420 DEPT. 9600.000 DT,BMC TT3. BHC 412. 000 TT4.8HC ENS.BNC 4070.000 ~4TE~ OMC !DP.DTE 31.031 !DPH~DTE ClLD.DTE 32.469 ILD IFRE DTE 20,000 IDOF' DTE 32,406 IIRM,DTE IIXO.) ~' . ,. ,.. SP.[~E -101 063 GR DTE f4RES. DTE !.430 H L. i,.: .DTE 29-JUN-!993 09:!6 593.500 87.875 TT1.BMC 302.750 SP.BHC 191..250 MRE$.BHC 9.313 CIMP,DTE 9.141 CI!~M.DTE 0.000 I~OF.DTE 12.930 I!×M.DTE 36,906 TENS.DTE 756.000 59.000 TTI.BHC 300.250 SP.BHC 187.375 MRES.BHC 35.094 CIMP,DT~ 36.750 CIL~,OTE 0.000 I~QF,DTC '49.406 IIX~.DTE 78.375 TEMS'DTE 730.500 67.188 TT1.BMC 182'375 SP,B~C 1~ ~5 MRES,BHC 6 CI~P~DTE 22'781 CILi4.DTE 0,000 I~OF.DTE -25 516 II~,DTE 78.500 TENS,DTE 721'000 45,969 TTi.OHC X~2.750 S~.SHC !76 ~50 MRES,'~MC 35:19 CIMP.DTE 33-906 CILM,OTE o.0oo I~OF.DTE 2.~3~ IIX~.QTE 64.875 TE~S.OTE 715,500 ]O5 7 3o 0 12 728 .625 .000 .625 '766 ,000 '656 5~3 5OO TI~ 1. BHC S?. BHC MRES.BHC CIMP,DT£ CIL~,, . OTE I ~QF, OTE 11 X ~. OTE TENS ' DTE 545.500 -124.313 1.246 14.81t 13.578 0.000 -98 313 4345~000 418.750 -84.500 1.306 -5!.875 -51.625 0.000 -93.625 4205.000 412.750 -99.563 -25,500 0 0 -!04~188 4030,000 413 000 -96 250 7 . 2 553 0 000 -100 063 4065 000 4!2.750 -!01,063 !,430 13,289 0.000 -I00,250 4070,000 TT2.BHC GR.BHC HTEN.BHC IMPH.DTE ILM.DT£ IIRD.DTE SFLU.DTE MTEM.DTE TT2.BHC GR.BHC HTEN.BHC IMPH.DTE ILM.DTE IIRD.DTE SFLU,DTE MTEM.DTE TT2.BHC GR, BMC HTE..i. BHC I MPH. DTE ILM.DTE IIRD,DTE; SFLD ,DTE ~TE~.DTE TT2,BHC , GR~BHC H~EN.BHC IMPH.DTE ILM'DTE IIRD,DTE SFLU'DTE ~!TE~oDTE TT2,BHC GR,BHC HTEN.BHC ILM.DTE ItRD.DTE SFLU,DTE ~TEM.DTE PAGE: 11. 375 O0 756,000 67.500 73,563 95.438 18.516 191,250 292.750 78.375 730.500 1950,000 1950,000 27,047 48.813 187.375 307.000 78,500 721 000 i950 000 !950 000 39 2:50 9696 000 180 304,750 64'875 7!5'500 125,t25 391'500 27'.063 9696,000 176.:750 303,500 71..563 72:8,500 76 125 75 !88 29 375 9696 000 173 62:5 ,IS 'rape verification Listing ,chlu~berqer Alaska Comput. lDg Center EPT. 9500.000 DTT3.BHC ' 412.000 TEN$.RHC 4050.000 CIDP.DTE 41,063 CILD.DTE 42.219 IFRE.DTE 20.000 IIXD.DTE '0.054 SP.DTE '101,000 ~RES.DTE 1.447 DEPT. 9400,000 TT3.BHC 262.250 TEN$,BHC 4055,000 CIDP.DTE 38.656 CILD.DTE 40,594 IFRE,DTE 20,000 I!XD.DTE -0,692 SP,DTE -105.375 MRES.DTE 1,472 DEPT. 9300.000 ?T3,BHC 263,000 TENS,BHC 4065,000 CIDP.DI~ .... 49,938 CILD,DTE 51.188 IFR~,DTE 20.000 -;oo:ooo ~E~.DTE 1.500 DEPT, 9200,000 TT3,BHC 4~7,500 TENS.B~C 3895,000 CIDP,DTE 35,844 C!LD DIE 37,906 ~r~:.~T~ 20.000 IIXD,DTE 10,594 S~.~T~ -1!3.750 DEPT, 9100,000 TT3,BHC 305.000 TENS'BHC 3990,000 C!DP,DTE 40,188 CY~D,DTE 4!,71g IFRE,DTE 20,000 .... '[E '11.5 375 M~ES,DTE .!,533 DEPT. 9025,000 TT3'BHC 3!4,250 TENS,BHC 3990,000 CTDP LIE 36.219 CIL~.OTE DT.BHC TT4,BHC MTEM.BHC IDPH,DTE ISD,DTE IDOF.DTE IIR~.DTE GR.DTE HTEN.DTE DT,BHC TT4.BHC MTEM,MHC IDPH,DT£ ILD.DTE IDOF,DTE IIRa,DTE GR,DTE HTEN,DTE DT.BHC TT4,BHC [ H,DTE ILD,DTE IDQF,DTE IIR~'DTE GR,DTE MIEN'DIE DT.BHC TT4,BHC MTEM.OHC IDPH,[>TE IbO DIE IDOF DTE IIRM DTE GR DTE HTEN.DTE DT,BHC TT4.BHC MTEM.BHC IDPH,DTE ILD,DTE IDQF,DTE IIRM,DTE GR,DTE HTEN,DTE 2q-JUN-1993 09:16 53.125 TT1,BHC 306,000 SP,BHC 71 125 MRES,BHC 124[32~ CI~P.DTE 23.672 CIL~,DTE O.000 IMOF.DTE -32.125 IIXM.OTE 66.313 TENS,DTE 745.500 35.750 TT1.BHC 308.750 SP.BHC 16~.625 MRE$,BHC 25.844 CIMP,DTE 24.625 CILM DIE 0.000 IEOF:DT¢ -56.188 ItX~,OT~ 64.063 TENS.DIE 757.000 49.188 TT!.BHC 254,000 SP,BHC !66,000 MRE$,BHC 20,000 CIMP.DTE 19.516 ClLM'DTE 0,000 IMOF,DTE -40,813 XIX~.DTE 76,500 TENS'DIE 74~'000 ' 6.37s 310 000 i64,125 MRES'SHC 27,875 CIMP,DTE 26,359 CIL~,DTE 0.000 IMOF,DTE -t9,34~ IIXM,DTE 66,438 TEN$,DTE 740.OO0 10 656 TTI,BHC !82 750 8P,BHC 1.62 500 MRES,BHC 24 875 CIMP' DT~ 23,969 CIL~,D~T~ 0.000 IMOF.DTE '72'563 IIXM,DTE 67,00'0 TENS,DTE 730,000 410.750 -101.000 1.447 -34.000 -33.594 0.000 141. 125 loso:ooo 366 750 -!052375 1.472 -57.406 -58,688 0,000 -130 375 ~o~ooo 69 500 ! 500 ~19 0 ~00 4o 25°° O0 .416.250 t13.750 .'t.5 I .17.1~6 20,266 0.000 -!I7.563 3895.000 95.500 -[15,375 1..533 ,750 ,000 14 's°° ,ooo DT,B}i~ 59.469 TT1,OHC 361.500 TT4i~HC 255,125 ..... SP.BHC -114..188 MTE~,BHC 1~'' 1.25 ~RES.B ~C 1 548 ID~,'I)TE ,, :594 CIMP,DT£ -32,188 'i~D~iOTE 2.6,266 CILg,DTE -33,969 TT2.BHC GR.BHC HTEN,BHC I~PH.DTE ILM.DTE IIRD.DTE SFLU.DTE MTEM.DTE TT2,BHC GR.BHC HTEN,BHC IMPH.DTE IhM,DTE !IRD.DTE SFLU.DTE MTEM.DTE T?2 BHC HTEN,BMC INPH~DTE ILM.DTE IIRD,;DTE SFLU.DTE MTEM'DTE TT2. ~ HTEN.BHC !MPH,DTE IL~.DTE IIRD'DTE SFLU,DTE K,rE~ DTE TT2.BHC GR,BHC HTEN,B~C IMP~,DTE IbM.DIE I!RD,DTE SFLU~.DTE MTE~,DTE TT2.BMC GR,BHC HTEh..,BHC IMPH,DTE It~N,DTE PAGE: 12 304.750 66.313 745.500 1950.000 1950.000 37.813 9696.000 171.125 308.000 64.063 757,000 1950.000 !950,000 37.063 9696,000 168.625 202 000 74 000 1950 000 1950,000 45,406 9696.000 166.000 255 1:5 740,000 1950,000 1950,000 34'750 9696,000 I64,125 262,250 67,000 730.000 !950,000 1950,000 37'750 9696-000 162,500 82. 750 74'563 15 ' 500 1950'000 t950,000 Tape Verification bistinq ;chlumherqer Alaska Computlnq Center 2g-dUN-1993 09:16 PAGE~ IFRE.DTE 20.000 IDQF.DTE IIXD.DTM 1!.094 IIRM.DTM SP.DTE -114,1~8 GR,DTE ~RES,OT£ !,548 HTEN,DTE 0.O00 IMOF.DTE -32.43~ IIXN,DTE 74.563 TEN$.OTE 715.500 O O00 IIRD.DTE -!30;750 SFLU.DTE ]990.000 MTE~.DTE 34,500 9696,000 161.125 ** END OF DATA ** **** FI[,E TRAIl,ER FILE NAME : EDIT ,003 SERVICE : F~IC VERSION : O01A07 [)ATE : 9]!06/~9 MaX ~EC SIZE : !024 FILE TYPE : LO L~ST FILE **** FILE HEADER FILE NA~E : EDIT ,004 SERVICE : FL!C YERSION : o0!a07 DATE : 93/g6/~9 ~AX REC SiZ~ : 1024 FILE TYPE : bO baST FILE : F!bE }lEADER E~ HOLE REPEAT PASSES RaWc~ves aha l, og header data for each pass, too~ strin(a, anti run in separate files, RUN NUMBER: 1 TOOL STRING NUMBER: paSS NU~BERI DEPTH INCREMENT: 0.5000 FILF SU~M~R¥ VENDOR TOOL CODE START DEPTH ~0~74,0 1025~.0 LOG HEADE~ DATA DATE bOGGED: SOFTWARE VERSION: T!~E CIRCULATION TIML~ LOGGE~ ~ BOTTOM: TO DRIbLE~ (FT): vD bOGGER(FT): I4-dU~-93 CP 32.6 t030 1,4-jUN-9~ !500 14-JUN-9~ !03!5,0 10306.0 ,IS Tape Verification ListinO icblt!mberqer AlasKs Computing Center 29-JUN-1993 09:16 PAGE: 14 TOP LOG INTEPVAb ~OTTO~ LOG INTERVAL LqGGIMG SPEED TNOL STRING (TOP TO BOTTOm) VENDOP TOOL CODE TOOL TYPE TCC &NC DTE TCM 9050.0 10300,o TOOL NUMBER .×ILLIARY ~A$I. IRE .... "=,~TS ~MM-AA 77.. TELEMETRY C~RTRIDGg G~A R~Y BORE~ObE SOb~IC PHASOR IMD!}CTION PHASOR INDUCTION TELemETRY BCRE~OLE AND CASING DATA OPEN MOLE B?T SIZE (IN): D~ILLERS CASING DEPTH LOGGERS CASING OE~TH (FT): ROREHOLE CONDITIONS MUD TYPE: DENSITY (LB/G): VISCOSITY PM: ~×I~[l~ RECORDED TEMPerATURE (DEGF): RESISTIUITY (OHMS) AT ~UD AT ~EASURED TEMPERATURE ~UQ AT BOTTO~ HOLE TEMPERAT~JRE (BHT)~ ~!JD FILTRATE AT ~UD FILTRATE a.T (BHT): ~UD CAKE AT (MT)~ ~U9 CAKE AT NEUTRON TOOL TOOL TYPE (EPITMERMAL OR qATRI× DENSITY: HOLE CORRMCTIOU (IN): TOOL STANDOFF fiN): TCC=B ]20 SGC=SA 60 SLC-[!A 136 SLS-wA 2001 D!C-EB 4~7 DIS-MB 4]4 TCM-AB 95 Sb~-DB ~596 6,750 9857.0 9850.0 LSND 8,90 ~8,00 9.40 6.00 !97.0 5,100 73.<0 7].0 73.0 .......... mr~ NATI1, ~E:"ARK8: O'IT~ AND sONIC RUN IN ,8" STANDOFFS USED FOR CENTRA~IZ~T!ON M~X. DEVIATION 38 D~G ~ 76i9 PULLED TIGHT ~9~90' ~ED, INDUCTION.C[i~VE [~OT PRe, cEa{TED OI. IE TO SPIKING GR RUN TO 9100' INSIDE C~SING $ [,IS FO~AT DATA ,IS Tape Verificstlon bistt, nq ;chlumberqer A].asKa Computt~ Center PAGE: 15 ** D~TA FORMAT SPECIFICATION ~ECORD ** ** SET TYPE - 64FB ** TYPE RMP~ C~DE VALUE 1 66 o i 66 0 ] 73 136 4 66 ~ 5 66 6 73 7 65 8 68 0,5 g 65 FT !! 66 7 12 69 I~ 65 FT 15 66 68 !6 66 1 0 66 ! ** SET TYPE - C~AN ** SERV UNIT SE~VI lPl APl: API FILl; Nt.J~ NU~ $I REPR SS ID ORDER # LOG TYPE CIiASS MOD NUmB S.A~P El, EM CODE (HEX) ...... F,. 548517 0 000 0 0 4 ! 4 S 00000 000 DT BHR U$./F 5485~7 00 000 O0 0 4 1. i 4 68 0000000000 TTi BHR US 5485!.7 00 000 00 0 4 TT2 BH~ US 548517 00 000 00 0 4 ! TT3 BHR US 54~517 00 000 O0 O 4 I TT4 B~ !.)S 5485~7 O0 000 O0 0 4 1 SP BM~ ~V 54851.7 O0 000 O0 0 4 GR Bg~ GAP! 54~5!7 00 000 O0 0 4 1 T~N$ ~HR LB 5485~7 OO 000 O0 0 4 MTE~ BHR DEGF 548517 O0 000 00 O 4 ~RES BH~ OHM~ 548517 O0 000 O0 0 4 ~E~ B~ LB 548517 O0 OOO O0 0 4 1 CIDP DTR ~HO 54~51~ O0 000 00 0 4 1 IDPg DTR OHMi~ 548517 00 000 00 0 4 C!~P DTR MMHO 548517 00 000 O0 0 4 ! I~Pl:~ DTR OH~M 5485!7 O0 000 O0 0 4 1 CILD DTR ~HO 548517 00 00O 0O 0 4 ! iLD DT~ OH~ 5485~7 00 000 00 (ii 4 1 CIL~ DT? MMHO 548517 ILM DTR OWM~ 548517 IFR~ DTR HZ 548517 O0 000 O© o 4 IDOF DTR 5485~7 00 0O0 I~QF DTR 5485!7 O0 000 00 0 I!~D DT~ ~MH~ 54~5~7 00 000 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 68 68 68 68 68 68 68 68 68 68 68 68 68 6a 6.8 68 68 68 6~ 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 000000000o 0000000000 0000000000 00000o0000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 000o000000 0000000000 0000000000 0000000000 ?ave Verification Listing ;chlumber~er alaska Comout~nO Center 29-.JU.q-lq93 09:i.5 PAGE: 1.6 II mmmmtm TTXD OTR M~HO 548517 O0 000 O0 0 4 ITR~ DTR ~HO 548517 O0 000 O0 0 4 IiX~ 9TP ~HO 548517 00 000 O0 0 SF5~? DT~ OMM~ 54~517 O0 000 O0 9 SD DTR MV 548517 O0 000 O0 0 4 G~ DT~ GAPI 548517 O0 000 O0 0 4 TF~S DT~ LB 548517 O0 000 O0 0 4 MTE~ BTR DEGF 5485~7 00 000 OO 0 4 uRE$ DTP Og~ 548517 O0 000 O0 0 4 ~TEw 9TR bB 548517 00 000 O0 0 4 ~ IT gE~V APl APT I bP! ~II, NtIMg MB SIZE ID ~RDER ~ LOG TYPE CLASS ~,IPB NI.!~B S~I~P EI..,E~ C P PROcE,$ ODE (HEX) ~ !. 4 68 O000000oon 1 ~ 4 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000o00 1 2. 4 68 0000000000 ~. 1 4 68 0000000000 I 1 4 68 0000000000 ~ I 4 68 0000000000 ! 1 4 68 0000000000 ! 1 4 68 O000000OO0 I.ImI.III~II~$mIImImm.m.m..ImIItImIlIIIIIIIi! ** DAT~ ** DFpT, 10367,500 DT,BH~ B0.375 TT3,BHR 512.500 TT4,BMR 353.000 TFNS,BH~ ~310.000 STEM.BMR 192'750 CiDP.DT~ 482 750 IDPM,DTR 2,070 CILD.DTR 491:750 iLD,DT~ 2.()3~ IFRF DTP 20.000 IDOF.DTR 3 OOO IIXD:DT~ 6B,3i3 II~,DTR 252:125 SP,DTR -80,563 GR,DTR !4: 359 ~RES.DT~ I.'23! HT~M.DTR -327 ~50 DEP?, !0300,000 DT,BMR 80,375 T'T3 BH~ 512,500 TT4.BHR 353 000 T~$:BM~.. .... 4120,000 M'.~"_.M,BHR~E~ . 192:750 C!DD,DTR 486,500 IDPI.:{, DTR 2.053 C! [~m, BTR 495,750 It, D, BTR ~, 016 IFRE ~T~ 20 000 !EOF DTR 0.000 IIXD,DTR 6~,375 II~M,QTR 299,000 SP DT~ -81,938 G~.DTR 14,359 ~RS;M ~QTR 1,2~ HTE~4, DTR 537.500 DEPT. 10200 000 DT.BMR 76 ~63 ?v~,~aa 4a81250 TT4,BHR 340: 50~ TFN~.BHR 4.!70'000 MTEM,BHR 192,375 C!DP.DTR 245 ~00 IDPH,DTR 4,078 CILD,PTR ~45:,50 ILO,DTR 4,066 i~'~ . I .. rlFR~ :..~R 20,000 IDOF DTR 0.000 I!XD.DTR 33,969 !IRM.[)TR 132'375 S~.DTP -98.938 gR.DTR 18.688 ~E$.DTP !,220 HTE~,DTR 585,000 D~PT. !0100,000 DT,BHR 81 ~88 C!DP.DT~ 95,938 IDPH.DTa 10.414 C!L~.DTR i01'813 II.D.DTR 9.820 !FRM,DTR 20,000 IDOF DTR 0 000 TT1,BMR 521.500 TT2.BHR BP,BMR -80.563 GR,BHR ~ES.B~R 1..23! HTEN,BHR C!MP,DT~ 267,250 IMPH.DTR CI!..,M,DTR 269,250 ILM,DTR I~OF,DTR . 2,000 IIRD DTR I!X~,DTR 75o81~ SFbU:DT~ TENS,DTR 23~0,000 ~TE~,DT~ TT!.,BHR 521 500 TT2,BHR SP,B}IR '8~!:938 GR.BHR MRES,BMR 1 231 HTEN,B~R CI~P.DTR 332.000 IMP~.DTR CILM.DTR 320.500 ILM.DTR IMOF.DTR O 000 I!RD.DTR ZZX~,VT~ 682 '.... - 500 8FLU DT~ TENS,O?~ 4120.000 ~:TE~,DT~ TT!,B~R BP.BMR CIMP.~TR CIL~,DTR I~OF,DTR II×M,DTR TENS,!)TR TTJ'BHR CIMP,DTR CIbM,OTR IMQF.DTR 488,000 -98.938 ~ ~0 ~ 46 125 140 25O 0:000 -89 375 4170.000 ~04750 4 5 ::1 o o o -2.361. 2'832 0.000 TT2 .BHR GR. BMR HTE, .BHR I~Pff. DTR IL~.DTR IIRD,gTR SFLU, DTR MTE~,DTR TT2.BMR GR,BMR IMPH.DTR ILM.DTR IIRD.DTR 359,500 14359 -3272250 394,750 8,336 192,750 359,500 14,359 537,500 3,010 3,117 395,750 6.500 102,750 340,750 18'688 585,000 6,840 7,I25 214500 13ii56 192375 35~-750 5.'344 589;500 1950,000 3532000 98'813 .IS 'rape V~rification Llstln~ ;ch!umberger ;%lasKa Compt!tlnu Center IIXD.OTR 14.414 !IR~.DTR SP.DTW -45.000 ~RES.DT9 1,24] HTEN,DTR DEPT. 10O00.000 DT.BHR TT3.BHR 542,000 TT4.BHR TEN$.BH~ 4345.000 CIDm. DT~ 106.000 IDP~.¢TP C!bg,DTR 108.063 !LD,DTR IF~E.DT~ 20.000 IDOF.DTR IIXD.DTR 6.105 !I~q. DTR KD.DT~ -66.250 ~RES.DTP ~.315 HTEN.DTR DEPT. 9900.000 DT.BHR TT3.BHR 4~4.000 TT4.BHR TENS.BN~ 4165.000 ~TE~.BHR CIDP.DTR 48.281 IDPH.DT¢ CIbD.DTR 50.500 ILD.DT~ IFNE.DTR ~0.000 IDQF.DTR I7×D.DT~ 4,777 !IR~,DTR Sm DTR -]5,719 GR,DTR ~E$~DTR !.3~9 HTE~.DTR TT~.BHR 413,000 TT4.BHR T~$.~ ~10.000 ~.~ CIDP.DTR 33.93B iDP~.DTR CILD.DTR 35'750 ILD.I)TR IFRF.DT~ P0.000 !DOF.DTR I!XB.DT~ ~7.797 IIRM.DTR SP.DTR -36.438 G~.DTR ~ES.DTR 1.403 HTEN.DTP ** END OF DATA ** **** FILE TRAILER **** FILM NA~E : EOIT .004 SERVICE : FLIC VERSION : 00~A07 DAT~ ~ 93/06/29 ~AX REC SIZE : 1024 FILE TYPE 29-JUN-19O3 O9:!6 2.6~9 IIX~.D*R 5~.3 4 TENS.DTR 5~0.500 92.438 TTt.BH~ 364.000 SP.BHR 186.375 ~RES.BHR 9.430 CI~P.DTR 9.250 CILq. DTR 0.000 IHOF.DTR 11 234 III~.DTR 361375 TEMS.DTR 759.500 279:ooo sp.5~ 19.797 CIL~,DTR 748.500 77,688 TT1.B~R 18.4 000 SP.BHR 1,76i375 29 45] CI~P.DTR 27'953 CIb~,,DTR 0.000 INOF..DTR 0.7~0 IIXM.DTR 58.719 TEN$'DTR 773.000 -97.1~8 41@0.000 542.000 -66.250 !.3t5 12.984 11.797 0.000 -100.563 4345.000 414.o00 -35.719 1.349 -6~.~56 -56.156 0.000 -98:.06~ 4165.000 412.000 -36.438 1.403 3.387 0.766 0.000 -106.125 4210.000 SFLU.DT~ TT2.BHR GR.BHR HTEM.BHR IMPH.DTR !L~.DTR IIRD.DTR SFLU.OTR MTE~.DTR TT2.BHR . HTEN.BHR iMPM.DTR IL~.DTR IIRD.DT~ SFLU.DTR MTE~.DTR TT2.BHR GR*BH~ HTEN.BHR IMP~.DTR ILM.DTR IIRD,DTR SFLU.DTR MTEM.DTR PAGE: 17 12.750 lO1.000 371.O00 36,375 759.500 76.938 84.750 94.500 18141 186~375 2~7~000 2:094 748 500 1950i000 1950 000 46 094 54.656 183.125 255.125 58,1:719 77~'O00 295,000 !305,000 32'2!9 9696,000 176,375 ,IS Tare Yerlfl. catlon I, istinq ;chlum~erqer Alaska Computino Center 29-JU~-! 993 09:16 **** TAPE TRAILE~ SFRVICE NA~E : EDIT D~TE CONTINI~ATION # : 1 P~EV!OIJ$ T~PE CO~ENT : BP EXPLORATIO~,P~UDHOE bAY,A-40 (~4-35-11-~3),50'029'22337'00 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 93106129 O~IG!N : ~LIC REEL NAME : 9326~ CONT'INIJ~TION ~ : PPEVYOUS REEL : CO,RENT : BP EXPI.[}RATION,P~!]')HPE ~5¥,A-40 (24-35-1!-!3).50-029-22337-00