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202-143
Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. 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 have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 S-113B 202143 500292309402 10 9/19/2023 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 STATE OF ALASKA 41IkASKA OIL AND GAS CONSERVATION COMMIS• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 202-143 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23094-02-00 7. Property Designation(Lease Number): ADL 028257&028258 8. Well Name and Number: PBU S-113B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,AURORA OIL(Undefined) 11.Present Well Condition Summary: Ric.CEIVED Total Depth: measured 13515 feet Plugs measured None feet i true vertical 7191 feet Junk measured None feet (J r� 2 7 2016 6 Effective Depth: measured 13044 feet Packer measured 12884 feet true vertical 6771 feet Packer true vertical 6629 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 33-113 33-113 1490 470 Surface 5553 10-3/4" 33-5586 33-3370 5210 2480 Intermediate Production 13460 7" 31 -13491 31-7170 7240 5410 Liner Perforation Depth: Measured depth: 13039-13044 feet tui, i MAP, 0 True vertical depth: 6767-6771 feet S�,6p�4tiV45) Tubing(size,grade,measured and true vertical depth) 3-1/2"9.2#L-80 29-12942 29-6680 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 12884 6629 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 144 428 774 1501 213 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 ® Exploratory 0 Development m Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil m Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Browning,Zachary H Email Zachary.Browning@bp.com Printed Name Joe Lastuf a 1 Title Drilling Technologist Signature ✓""\ Phone +1 907 564 4091 Date 6 0/2:// Form 10-404 Revised 5/2015 V ri- 2/ `4, RBDMS "OCT 3 1 2016 Submit Original Only i5 • S-1138 Well History (Pre-Rig Lateral) LRS LOADED TUBING W/ 135 BBLS OF CRUDE. LRS PERFORMED SUCCESSFUL MIT-IA TO 3000 PSI. PULL EMPTY 3-1/2"X-CATCHER SUB FROM 12,821' SLM/ 12,862' MD. 9/11/2016 ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** emp= S/I Assist SSL (CTD) MIT-IA to 3000 psi ***PASSED***2nd attempt, Pumped 4 bbls 60/40 up FL for FP, Pumped 135 bbls HOT 110*crude down TBG, Line up to IA, Pumped 10.8 bbls down IA to reach test pressure, IA lost 20 psi in 1st 15 min and 15 psi in 2nd 15 min for a total loss of 35 psi in 30 min test, Bleed IAP, Bled back —7 bbls, AFE sign and tags hung on well, Valve postion @ departure-SV,WV,SSV= Closed MV= Open IA& 9/11/2016 OA= OTG FWHP= 33/10Nac CTU #9 - 1.75" Coil Job Scope =Tie in log/cement squeeze MIRU CTU. Make up GR/CCL in 2.2"carrier with 2.5" JSN and RIH. Tag TD at 13187' CTMD and paint red/green TD flag at 13171' CTMD. Log from TD to 12,500'with a white 9/17/2016 coil flag at 12850', POOH. Job Objective: Pre-Rig Cement P&A Lay down logging tools and confirm good data, +6' correction. Make up Cementing BHA with 2.5" BDJSN and RIH. Tie in at white flag and correct nozzle depth. Load will with 100 bbls 1 % KCI and 80 bbls diesel. Pumped 27.7 bbls of 16.5 ppg Class G cement, 10.5 bbls behind pipe. Pressured up to 1500 psi over baseline injection pressure for 30 minutes, lost 100 psi. Bled wellhead pressure to 500 psi and contaminated cement down to 12900'. 9/18/2016 Chased out at 80%washing jewelry on the way out. Trapped 500 psi at surface. RDMO. ***WELL S/I ON ARRIVAL***(ctd) 9/20/2016 DRIFT WITH 2.70" x 20'WHIPSTOCK- IN PROGRESS TAGGED TOP OF CEMENT AT 12,856' SLM W/20' x 2.70" DUMMY WHIPSTOCK(hard bottom) 9/21/2016 ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** T/I/O = 245/Vac/0. Temp= SI. MIT-T to 3000 psi Max PASSED to 2984 psi, MIT-OA to 1200 psi Max. (Pre-CTD).TBG FL = Surface, OA FL=48' (1.2 bbl). ALP = 1960 psi & SI @ IA casing valve. Used 2 bbl of diesel to acheve test pressure of 3001 psi. TP lost 11 psi in the first 15 minutes, 6 psi in the second 15 minutes for a total loss of 17 psi in 30 9/22/2016 minutes. T/I/O = 250Nac/0. Temp= SI. MIT-T to 3000 psi Max PASSED to 2984 psi, MIT-OA to 1200 psi Max PASSED to 1131 psi. (Pre-CTD). TBG FL = Surface, OA FL = 48' (1.2 bbl). ALP = 1960 psi & SI @ IA casing valve. Used 2 bbl of diesel to achieve test pressure of 3001 psi. TP lost 11 psi in the first 15 minutes, 6 psi in the second 15 minutes fora total loss of 17 psi in 30 minutes. Used 3.1 bbl of diesel to pressure OAP to 1200 psi. OA lost 50 psi in the first 15 minutes, 19 psi in the second 15 minutes for a total loss of 69 psi in 30 minutes. Bled OAP from 1131 psi to 0 psi in 10 minutes (1.33 bbl returns). *** MIT Tags hug*** Final WHP's = 272/0/0. 9/23/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. T/I/O= 160NACNAC. Pre Nordic 2. Installed Nordic TS#01, XO#01 . Torqued and PT'd to API specs. RDMO***Job Complete*** . SEE LOG FOR DETAILS. Final T/I/O= SI/ 9/30/2016 VAC/VAC. Note: Attached copy of Tree/Valve Pressure Test to MV handle. T/I/O = 160/Vac/Vac. Temp = SI. WHP's (Pre rig). No well house or flowline. Valve crew on location. 9/30/2016 Valve crew in control of valve positions upon departure. 11:00 • S North America-ALASKA-BP Page 1 Operation Summary Report Common Well Name:S-113 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/2/2016 End Date:10/14/2016 X3-017VQ-C:(2,843,222.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time:6/17/2002 12:00:00AM ,Rig Release:10/16/2016 Rig Contractor:NORDIC CALISTA UWI:500292309400 Active datum:Kelly Bushing/Rotary Table @70.33usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 10/2/2016 19:00 - 19:30 0.50 MOB P PRE I PREPARE RIG TO BACK OFF WELL 19:30 - 20:30 1.00 MOB P PRE PJSM WITH ALL INVOLVED PARTIES. DISCUSS LIGHT POLE PROXIMITY TESTED AND VERIFIED ESD WAS I FUNCTIONAL AND IS MANNED BY TOOLPUSHER -VERIFIED 12 X 12 WHEEL CHOCK IN PLACE -ASSIGNED SPOTTERS TO AREA OF I RESPONSIBILITY -AGREED ON STOP WAS THE COMMAND TO STOP RIG. PERFORMED RADIO CHECK PRIOR TO MOVING RIG. -DISCUSSED WITH CREW THAT THERE WAS NO BPV INSTALLED 20:30 - 21:30 1.00 MOB P PRE STAGE RIG CLEAN UP AROUND WELLHEAD. PICKUP MATS DRILLER/TOURPUSHER PERFORMED ROUTE DRIVE 21:30 - 23:00 1.50 MOB P PRE I MOVE RIG FROM W-PAD TO MOBILE PAD. STAGE FOR RIG MAT SHUFFLE. 23:00 - 00:00 1.00 MOB N WAIT PRE STAND-BY FOR RIG MATS TO BE SHUFFLED 10/3/2016 00:00 - 03:00 3.00 MOB N WAIT PRE CONTINUE TO WAIT FOR MATS. 03:00 - 06:00 3.00 MOB P PRE CONTINUE MOVE TO S-PAD. 06:00 - 08:00 2.00 MOB P PRE MOVE UP ACCESS ROAD AND STAGE AT S-113. -LOCK OUT ADJACENT WELLS PER WELL I PLAN -PJSM FOR PULLING OVER WELL. EMPHASIZE THAT PLUG IS NOT IN WELL, PROXIMITY OF ADJACENT WELLS. DISCUSS j VISUAL SIGNALS AND AUDIBLE COMMANDS. IASSIGN PERSON TO 12X12 BLOCK AND ESD. i FUNCTION ESD. -PULL OVER WELL. RIG ACCEPT AT 0800 HRS. 08:00 - 12:30 4.50 MOB P PRE BEGIN RIG UP OPERATIONS -STAGE SUPPORT EQUIPMENT -OPEN UP SSV,CYCLE TREE VALVES PER WELL PLAN -TEST AND ND TREE CAP NU BOP:ANNULAR ELEMENT,BLIND/SHEAR RAMS,UPPER 2"COMBI RAMS,2-3/8"COMBI RAMS,LOWER 2"COMBI RAMS -TAKE ON WATER FOR BOP TEST,FLUID PACK LINES -PRE-SPUD FOR WELL WITH ENTIRE TEAM. CONDUCT H2S RIG EVAC DRILL WITH TEAM. CONDUCT AAR. -PJSM FOR BEGINNING BOP TEST Printed 10/24/2016 9.42:16AM *All depths reported in Drillers Depths* North America-ALASKA-BP Page 29 Operation Summary Report Common Well Name:S-113 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/2/2016 End Date:10/14/2016 X3-017VQ-C:(2,843,222.00) Project:Prudhoe.Bay I Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time:6/17/2002 12:00:00AM Rig Release:10/16/2016 Rig Contractor:NORDIC CALISTA UWI:500292309400 Active datum:Kelly Bushing/Rotary Table©70.33usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 18:30 6.00 BOPSUR P PRE BODY TEST BOP WITH AOGCC REP BRIAN BIXBY ON LOCATION. GOOD TEST. I-BEGIN BOP TEST PER PERMIT AND WELL PLAN. TEST TOAOGCC,NORDIC,BP REGULATIONS AND REQUIREMENTS. -TEST ALL COMPONENTS TO 250 PSI LOW/ 13500 PSI HIGH. FUNCTION RAMS FROM DRILLERS CONSOLE. TEST WITH 2"AND 2-3/8"TEST JOINTS CONDUCT ACCUMULATOR DRAWDOWN TEST WHILE FUNCTIONING RAMS FROM COIL TUBING CONSOLE -STAB ON WITH COIL,PRESSURE TEST INNER REEL VALVE AND PACKOFFS TO 250 PSI LOW/3500 PSI HIGH 18:30 19:30 1.00 BOPSUR P PRE POP OFF AND INSTALL FLOATS. TEST TO 300 LOW/3500#HIGH GOOD 19:30 - 22:00 2.50 BOPSUR P PRE STAB ON. TEST QTS. SWAP COIL OVER TO METHAANOL SPEAR /1%KCL FOR ENTRY. 22:00 - 22:30 0.50 BOPSUR P PRE PRESPUD/RIG EVACUATION DRILL WITH NIGHT CREW 22:30 - 23:10 0.67 BOPSUR P PRE PJSM, DISCUSS OPEN WELL UP FOR FLOW CHECK. PJSM FOR BHA MAKEUP 23:10 23:45 0.58 BOPSUR P PRE OPEN WELL WITH 30#. BLEED TO FLOWBACK TANK. IMMEDIATELY DROPPED OFF. PERFORM 10 FLOW CHECK. WELL STATIC 23:45 - 00:00 0.25 BOPSUR P PRE MAKE UP 2-3/8"MILLING BHA#1 -PICK UP 2-3/8"XTREME MOTOR(0.9 DEG AKO)AND 2-3/8""COILTRAK TOOLS -MAKE UP 2.80"HUGHES D331GEB MILL. SMOOTH GAUGE. 2.81"GO/2.80"NOGO -SURFACE TESTED TOOL.GOOD TEST. -PRESSURE TEST QTS TO 300 PSI LOW FOR 5 MINUTES/3500 PSI HIGH FOR 5 MINUTES -INJECTOR ON:23:59 _ 10/4/2016 00:00 - 00:25 0.42 CONDHL P WEXIT 'ESTABLISH CIRCULATION. START IN HOLE. TAKING RETURNS TO FLOWBACK TANK. BHI COUNTER NOT TRACKING. 00:25 - 02:00 1.58 EVAL N SFAL WEXIT BHI COUNTER NOT TRACKING BHI TROUBLESHOOT. 02:00 - 05:00 3.00 CONDHL P WEXIT ,START IN HOLE -DISPLACE WELL FLUIDS TO FLOW BACK TANK WITH WARM 8.33 PPG KCL WHILE HOLDING 100 PSI BACK PRESSURE -NO ISSUES WITH INITIAL DISPLACEMENT, NO GASEOUS RETURNS 05:00 - 06:30 1.50 EVAL P WEXIT LOG FOR PRIMARY DEPTH CONTROL TIE-IN. -CONTINUE DISPLACING WITH WARM 8.33 PPG KCL TO FLOW BACK TANK HOLDING BACK PRESSURE -INITIAL CORRECTION OF-31.5'TO PDC LOG BUT HAVING DIFFICULTY ALIGNING WITH LOG PROVIDED TO GEOLOGIST -TAG TOP OF CEMENT AT 12,900' —- 4 UNCORRECTED DEPTH Printed 10/24/2016 9:42:16AM `AII depths reported in Drillers Depths* • • North America-ALASKA-BP • Page 3 Operation Summary Report Common Well Name:S-113 1 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/2/2016 End Date:10/14/2016 'X3-017VQ-C:(2,843,222.00) Project:Prudhoe Bay Site:PBS Pad Rig Name/No.:NORDIC 2 Spud Date/Time:6/17/2002 12:00:00AM Rig Release:10/16/2016 Rig Contractor:NORDIC CALISTA UWI:500292309400 Active datum:Kelly Bushing/Rotary Table @70.33usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:30 - 07:45 1.25 CONDHL P WEXIT DISPLACE TO HI-VIS KCL MILLING FLUID -GEO CONFIDENT THAT LOG CORRELATES TO PREVIOUS CALIPER LOG PROVIDED BY PDS BEFORE CEMENTING. RECORD-32' CORRECTION. LOG CCL WHILE CONTINUING TO DISPLACE TO THE 8.4 PPG VIS KCL -GOOD KCL ALL THE WAY AROUND -SEND DATA TO TOWN TEAM,WAIT ON CONFIRMATION TO PROCEED 07:45 - 09:00 1.25 STMILL N WAIT WEXIT CONSULTED WITH TOWN,VERIFIED AND AGREED UPON DEPTH SHIFT AND TOC. 09:00 - 14:00 5.00 STMILL P WEXIT MOVE DOWN TO TOP OF CEMENT. -INITIAL PARAMETERS:MM IN 1.72 BPM,MM OUT 1.71 BPM,MW IN 8.46 PPG,MW OUT 8.43 PPG,WOB.2K -MILL FROM 12,870'WITH SEVERAL STALLS TO START OFF. MAKE PROGRESS DOWN TO 12,875'BUT HAVE A COUPLE OF QUICK 'STALLS WITH SLOW ROP. THIS CORRELATES TO WHERE PACKER IS SET. -PICK UP,TURN 180°OUT AND RE-ENGAGE MILLING. MAKE PROGRESS,ROP AND WOB PICKED UP INDICATING THAT MILL IS NOT ON METAL. -PICK UP,REAM AROUND EDGES TO CLEAN IT UP. MOVE BACK DOWN WITH MILLAT 15° ORIENTATION TO CONTINUE MILLING HIGH SIDE. CONTINUE MILLING PILOT AT 15°ROHS. ATTEMPT TO MAINTAIN 1.5 TO 2.5 K WOB. MULTIPLE STALLS WHILE DRILLING. ROP -ECD CLIMBING, RATTY PICK UP WEIGHTS. PUMPED 10 BBLS HIVIS SWEEP. 14:00 - 16:00 2.00 STMILL P WEXIT -STARTED PACKING OFF. PUMP SWEEP. DISCUSS ADDITION OF CFS-520 WITH ODE AND BAROID. -WIPER UP TO 12500'. RIH AT 100 FPM TO 'ACCELERATE CUTTINGS. -INCREASE AV TO 452 FPM. -RIH AND RE-ENGAGE DRILLING 16:00 - 17:00 1.00 STMILL P WEXIT CALL ODE AND DISCUSS ISSUES WITH MILLING FLUID,STICK SLIP ISSUES,PUMP PRESSURE IS HIGH,CARRYING CAPACITY OF THE FLUID IS NOT KEEPING THE HOLE CLEAN BECAUSE WE ARE PACKING OFF AND HAVE TO PU TO PULL FREE AND ESTABLISH RETURNS AGAIN 17:00 - 18:30 1.50 STMILL P WEXIT STOP MILLING AND PU TO ENSURE THE HOLE BEHIND US IS CLEAN BEHIND US PU 2000'TO 10900' 12500'ECD'S ARE STARTING TO CLIMB AND THE COIL WEIGHT IS CYCLING.LOOKS LIKE THE CMT IS FALLING OUT OF THE FLUID AND PACKING OFF THEN CLEARING CAUSING THE WEIGHT TO CYCLE PUMP A 10 BBL HIGH VIS PILL HIGH VIS PILL BROUGHT UP A FAIR AMOUNT OF CMT CUTTINGS,RIH Printed 10/24/2016 9:42:16AM *All depths reported in Drillers Depths* 11111• North America-ALASKA-BP Page 4 otsg Operation Summary Report Common Well Name:S-113 AFE No Event Type:RE-ENTER-ONSHORE(RON) I Start Date:10/2/2016 End Date:10/14/2016 X3-017VQ-C:(2,843,222.00) Project.Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time:6/17/2002 12:00:00AM Rig Release:10/16/2016 Rig Contractor:NORDIC CALISTA UWI:500292309400 Active datum:Kelly Bushing/Rotary Table©70.33usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 19:30 1.00 STMILL P WEXIT BACK ON BOTTOM MILLING !WT TRANSFER IS LOW BUT THE WOB IS STAYING CONSISTENT TO MILL THE PILOT HOLE 19:30 - 20:00 0.50 STMILL P WEXIT MADE 5'WITH CONSISTENT WOB AVG 1.5-2.0K WOB AT 25-30 FPH ROP START 80 BBL PILL OF 0.5%NXS LUBE DOWN THE COIL 20:00 - 20:40 0.67 STMILL P WEXIT ROP SLOWNG DOWN TO-20 FPH AND STILL ABLE TO MILL WITH CONSISTENT WOB 20:40 - 20:50 0.17 STMILL P WEXIT NXS LUDE AT SURFACE AND SURFACE WEIGHT HAS INCREASED FROM 4.5-5.5K TO 5.5K-6.5K WHILE MILLING 20:50 - 00:00 3.17 STMILL P WEXIT ECD SLOWLY INCREASING. PUMP SWEEP. LET 10 BBLS OUT. CHASE UP TO 11,000' OPEN EDC ONCEABOVETOC. CHASE AT MAX RATE. SWEEP BROUGHT BACK AN INCREASED AMOUNT OF CUTTINGS. RIH AT 100'/MIN TO ACCELERATE CUTTINGS. INCREASE AV TO 580 FPM. STOP AT 12800' CLOSE EDC. 10/5/2016 00:00 - 03:20 3.33 STMILL P WEXIT !MILL 2.80"CEMENT PILOT HOLE IN 7.0"LINER :PER WELL PROGRAM FROM 13010"MD TO 13070'MD -RATE:1.80 BPM IN,1.80 BPM OUT -MUD WEIGHT:8.56 PPG IN,8.51 PPG OUT -DWOB:1.5-2.0 KLBS -FREE SPIN 3680#@ 1.80 BPM -CIRC PRESSURE:3940 PSI -RELATIVELY CONSISTENT ROP OF 15-20 FPH. -0.5%ADDITION OF NXS LUBRICANT HELPED WITH MAINTAINING CONSISTENT WOB AND SLIDE 03:20 - 06:40 3.33 STMILL P WEXIT PERFORM REAMING PASSES 45°LOHS/45° ROHS MADE TWO PASSES. 12960'UP TO TUBING TAIL I REAMED TUBING TAIL. RAN TO BOTTOM. REAM TUBING TAIL. LOG+15'CORRECTION TO PDC LOG CCL FROM 12800'TO 13050'FOR LINER. PUMP 10 BBLS HI VIS SWEEP. TAG CORRECTED TD OF 13084' 06:40 - 06:50 0.17 STMILL P WEXIT PERFORM 10 MIN DYNAMIC FLOW CHECK 06:50 - 07:05 0.25 STMILL P WEXIT GOOD FLOW CHECK,POOH TO TOP OF PILOT HOLE PUMPING THROUGH THE MILL 07:05 - 10:00 2.92 STMILL P WEXIT ABOVE THE PILOT HOLE,OPEN THE EDC AND POOH PUMPING AT MAX RATE PUMPING 2 HIGH VIS PILLS ON THE WAY OUT FIRST PILL HAD A SLIGHT INCREASE IN CMT CUTTINGS,2ND PILL HADA LOT OF METAL SHAVINGS HOLD A PJSM WHILE POOH TO LD THE MILLING BHA AND MU THE LOGGING BHA JOG IN HOLE THEN PU TO 200'AND FLOW CHECK WELL 10:00 - 10:10 0.17 STMILL P WEXIT FLOW CHECK WELL Printed 10/24/2016 9:42:16AM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page ( r Operation Summary Report Common Wet Name:S-113 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/2/2016 End Date.10/14/2016 X3-017VQ-C:(2,843,222.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time:6/17/2002 12:00:00AM Rig Release:10/16/2016 Rig Contractor:NORDIC CALISTA UWI:500292309400 Active datum:Kelly Bushing/Rotary Table©70.33usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:10 - 10:35 0.42 STMILL P WEXIT GOOD NO FLOW,TAG UP AND REMOVE THE INJECTOR 10:35 - 10:45 0.17 STMILL P WEXIT BHA OOH,MILL IN GAUGE AT 2.80 NO GO PERFORM 5 MIN PULL TEST ON RED TUGGER FOR ANNUAL TEST 10:45 - 11:00 0.25 STMILL P WEXIT LOAD PDS CALIPER TOOL ON RIG 11:00 - 11:15 0.25 STMILL P WEXIT MU LOGGING BHA 11:15 INJECTOR ON 11:15 - 11:30 0.25 STMILL P WEXIT ONLINE WITH PUMP NEST-PURGE AIR FROM LUBRICATOR WITH LIQUID TO SEE IF WE CAN DO THIS WHEN WE HAVE GAS AT SURFACE CONNECT 1/2"HP HOSE FROM LUBRICATOR WHITEY TO CHOKE VALVE 18 WHITEY AND OPEN VALVES AIR WAS PURGED FROM THE LUBRICATOR WITH FLIUD IN JUST UNDER A MINUTE. THIS PROCESS CAN BE USED WHEN WE HAVE GAS TO SURFACE TO REMOVE ALL FREE GAS FROM THE RIG AND SEND OUT TO THE TIGER TANK THIS WILL HELP ENSURE WE DO NOT ALLOW ANY FREE GAS TO ENTER THE RIG PIT AREA 11:30 - 13:50 2.33 STMILL P WEXIT RIH WITH LOGGIN BHA 13:50 - 14:15 0.42 STMILL P WEXIT LOG TIE IN 14:15 - 15:05 0.83 STMILL P WEXIT CORRECT DEPTH-30 CORRECTION,RIH TO BOTTOM STACKING WT AT 12893'PU AND R 15:05 - 17:15 2.17 STMILL P WEXIT 10 ATTEMPTS TO GET PAST 12892 WERE UNSUCCESSFUL.CALL ODE AND DISCUSS LIMITED OPTIONS AS THE CALIPER ARMS ARE SET TO OPEN AT 15:37 POOH TO 11,000'ABO BEFORE THE CALIPER ARMS OPEN DECISION MADE TO POOH FOR CLEAN OUT BHA WITH A 2.80 STRING MILL 17:15 - 17:25 0.17 STMILL P WEXIT FLOW CHECK WELL 17:25 - 17:35 0.17 STMILL P WEXIT GOOD NO FLOW,TAG UP AND PULL THE BHA 17:35 - 19:00 1.42 STMILL N HMAN WEXIT BHA OOH,WAIT ON STRING REAMER FROM BAKER THRU TUBING,MIS COMMUNICATION BETWEEN BTT TOWN ENGINEER AND SLOPE SHOP i — 19:00 19:25 0.42 STMILL P WEXIT MAKE UP 2-3/8"DRILLING BHA#3 -PICK UP 2-3/8"XTREME MOTOR(0.6 DEG AKO)AND 2-3/8""COILTRAK TOOLS -MAKE UP 2.80" STRING REAMER/2.80" D331GEB MIL(HUGHES CHRISTENSEN) -SURFACE TESTED TOOL.GOOD TEST. -PRESSURE TEST QTS TO 300 PSI LOW FOR 15 MINUTES/3500 PSI HIGH FOR 5 MINUTES -INJECTOR ON:19:25 Printed 10/24/2016 9:42:16AM *All depths reported in Drillers Depths* 6 North America-ALASKA-BP • Page 6 Operation Summary Report Common Well Name:S-113 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/2/2016 I End Date:10/14/2016 !X3-017VQ-C:(2,843,222.00) Project:Prudhoe Bay y Site PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time:6/17/2002 12:00:00AM Rig Release:10/16/2016 Rig Contractor:NORDIC CALISTA U WI:500292309400 Active datum.Kelly Bushing/Rotary Table @70.33usft(above Mean Sea Level) Date From-To (hr) Task Code NPT NPT Depth Phase Description of Operations — _ ' (usft) 19:25 - 22:20 2.92 STMILL P WEXIT RIH WITH 2-3/8"MILLING BHA#3 FROM SURFACE'MD TO 12770'MD RATE:0.6 BPM IN,0.96 BPM OUT.CIRC PRESSURE:1100 PSI -MUD WEIGHT:8.61 PPG IN,8.53 PPG OUT -LOG DOWN FOR TIE-IN FROM 12770'TO 12791'MD(FORMATION)WITH-30' ' CORRECTION 22:20 - 00:00 1.67 STMILL PWEXIT RIH TO DRY TAG DRY TAG 12877'WITH 0°TOOLFACE PICKUP AND ROTATE TO 180°TOOLFACE. TAG SAME PLACE. PICKUP AND ATTEMPT MINIMUM RATE. NO LUCK. PICKUP BRING UP TO 1.80 BPM (MILLING i RATE). STALLED. PICK UP AND RIH AT 30 FPH. SMALL INCREASE IN MOTOR WORK. BUT WENT RIGHT BY. INCREASED TO 60 FPH REAMING PASS DOWN AT 180°TOOLFACE. 10/6/2016 00:00 - 06:00 6.00 STMILL P WEXIT 1.80 BPM IN/1.81 BPM OUT 8.60 PPG IN / 8.53 PPG OUT -CONTINUE REAMING IN THE HOLE AT 60 FPH AT 180°TOOLFACE. NOTHING SEEN TO TUBING TAIL. ROLL TOOLFACE TO 0°. RUN 'DOWN TO 12974'. -BACK REAM AT 0°TOOLFACE FROM TRANSITION AREA UP TO 12960'AT-70 FPH. NOTHING SEEN. -RUN BACK TO 12974'MAINTAINING HIGH SIDE ORIENTATION. NOTHING SEEN , -BACK REAM AT 45°LOHS FROM 12974'TO TUBING TAIL AT 12937.ROLL TOOLFACE TO '90°LOHS AND CONTINUE BACKREAMING AT 6OFPH TO 12960'. NO ISSUES -RUN BACK TO 12975. MAINTAINING A 0° I TOOLFACE. NO ISSUES. -BACK REAM AT 45°ROHS FROM 12975 TO TUBING TAIL AT 12937, ROLL TOOLFACE TO ' 90°ROHS AND CONTINUE BACKREAMING AT 60 FPH TO 12960' -RUN BACK TO 12932'(TUBING TAIL). BACK REAM AT 180°TOOLFACE AT 60 FPH. 06:00 - 08:45 2.75 STMILL P WEXIT CONTINUE FINAL BACKREAM UP PASS UP TO ,12860 07:15-CLEAN PASS UP,RIH TO TD AND PUMP A 15 BBL HIGH VIS PILL AND CHASE OOH TO TOC 07:30-DRIFT TO TD WAS CLEAN,PUMP HIGH VIS PILL 08:25-ABOVE TOC JOG IN HOLE 100'AND OPEN EDC TO FINISH CIRC OUT OF HIGH VIS PILL 08:45 - 09:20 0.58 STMILL ' P , 1 WEXIT BOTTOMS UP HADA LITTLE INCREASE IN CUTTINGS AND A LITTLE METAL. CLOSE THE EDC AND PREP TO DRY DRIFT TO 12900'PAST THE PACKER DEPTH AS PER DISCUSSION FROM MORNING CALLAT ALL 4 QUADRANTS 0°,90°,180°AND 270° ALL 4 QUADRANTS HAD CLEAN DRIFTS I RIH TO TD WITH A 0°TF _ - Printed 10/24/2016 9.42.16AM *All depths reported in Drillers Depths* •• North America-ALASKA-BP Page 7 oftG& • Operation Summary Report Common Well Name:S-113 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/2/2016 End Date:10/14/2016 X3-017VQ-C:(2,843,222.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 I Spud Date/Time:6/17/2002 12:00:00AM Rig Release:10/16/2016 Rig Contractor:NORDIC CALISTA I UWI:500292309400 Active datum:Kelly Bushing/Rotary Table @70.33usft(above Mean Sea Level) Date From-To Hrs Task Code j NPT NPT Depth I Phase Description of Operations (hr) (usft) 09:20 - 09:50 ' 0.50 STMILL P WEXIT TAG HAD BOTTOM PU AND BRING PUMP ONLINE AT MAX RATE AN PUH TO 12000'(60°HOLE INCLINATION) JOG IN HOLE 150'THEN SHUT DOWN TO OPEN THE EDC 09:50 - 10:00 0.17 STMILL P WEXIT EDC OPEN DYNAMIC FLOW CHECK WELL TO POOH 10:00 - 12:15 2.25 • STMILL P WEXIT GOOD FLOW CHECK,POOH HOLD A PJSM TO LD THE MILLING BHAAND MU THE CALIPER DRIFT BHA ATR SURFACE JOG IN HOLE 150' 12:15 - 12:25 0.17 STMILL P WEXIT FLOW CHECK WELL 12:25 - 12:45 0.33 STMILL P WEXIT ,GOOD NO FLOW,TAG UP,REMOVE INJECTOR AND LD THE BHA 12:35 INJECTOR OFF MILLS IN GAUGE 12:45 - 12:55 0.17 STMILL P WEXIT 1 BHA OOH MU PDS CALIPER TOOL AND INITIATE TOOL FOR SURFACE TEST 12:55 - 13:10 0.25 STMILL N DFAL WEXIT PDS TOOL FAILED,CALIPER ARMS OPENED, STARTED CLOSING THEN STOPPED WITH ;ARMS-30%OPEN SWAP OUT TOOL 13:10 - 13:40 0.50 STMILL P I WEXIT I MU TOOL AND INITIATE FOR SURFACE TEST GOOD TEST,MU BHA TIME DELAY SET FOR 3-HRS&45 MIN FROM 13:25 I NEED TO BE STOPPED BY 17:07,FINGERS SET TO OPEN AT 17:10 BEGIN LOGGING UP AT 17:16 FINGERS CLOSED AT 17:34 13:40 - 15:55 2.25 STMILL P WEXIT RIH 15:55 - 16:15 0.33 STMILL P WEXIT LOG TIE IN 16:15 - 17:15 1.00 STMILL P WEXIT CORRECT DEPTH-31.5'AND RIH 17:15 - 17:35 0.33 STMILL P WEXIT CALIPER ARMS ARE OPEN START LOGGING UP AT 17:16 17:35 - 19:45 2.17 STMILL P WEXIT LOGGING COMPLETED,POOH PJSM FOR BHA PICKUP/LAYDOWN. PERFORM 10 MIN FLOW CHECK. WELL STATIC. TAG UP 19:45 - 21:05 1.33 STMILL P WEXIT INJECTOR OFF:19:45 LAY DOWN PDS CALIPER /DRIFT ASSEMBLY. PDS DOWNLOAD AND VERIFIED DATA WHILE PICKING UP WHIPSTOCK. GOOD DATA. PDS UPLOADED TO HOUSTON FOR PROCESSING. MAKE UP 2.625"WHIPSTOCK AND 2-3/8" COILTRAK TOOLS. -SURFACE TESTED TOOL.GOOD TEST. -PRESSURE TEST QTS TO 300 PSI LOW FOR 5 MINUTES/3500 PSI HIGH FOR 5 MINUTES _INJECTOR ON:20:45 Printed 10/24/2016 9.42:16AM *All depths reported in Drillers Depths* North America-ALASKA-BP Page 8 gf,14 k Operation Summary Report Common Well Name:S-113 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date.10/2/2016 End Date.10/14/2016 X3-017VQ-C:(2,843,222.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time.6/17/2002 12:00.00AM Rig Release:10/16/2016 Rig Contractor:NORDIC CALISTA UWI:500292309400 Active datum:Kelly Bushing/Rotary Table©70.33usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:05 - 23:30 2.42 STMILL P WEXIT RIH WITH 2.625"WHIPSTOCK BHA#5 FROM SURFACE TO 12850'MD -RATE:0.4 BPM IN,0.79 BPM OUT.CIRC PRESSURE:1300 PSI -MUD WEIGHT:8.56 PPG IN,5.58 PPG OUT -LOG DOWN FOR TIE-IN FROM 12850'TO 12915"MD(FORMATION)WITH-33' CORRECTION 123:30 - 00:00 0.50 STMILL P WEXIT LOG CCL FROM 12881'TO 13080' 10/7/2016 00:00 - 00:15 0.25 WHIP P WEXIT CONTINUE LOGGING CCL TO 13080' REVIEW PDS LOG TO CCL LOG. LOOKING LIKE+6'TO CCL LOG. 00:15 - 01:30 1.25 WHIP P WEXIT DISCUSS WITH ODE THE CORRELATION BETWEEN CCLAND PDS. DECISION TO SHIFT TOWS DOWN TO 13038' TOWS I 10°ROHS. 01:30 - 02:00 0.50 WHIP P WEXIT PU HOLE ABOVE SET DEPTH 36K PICKUP WEIGHT. CLOSE EDC. RIH TO SET DEPTH OF 13046.72' -8.72'=13038'TOWS SET DEPTH. RIH WEIGHT 7K. ORIENTATION SET TO 10°ROHS PICKUP TO NEUTRAL WEIGHT. COME ONLINE WITH PUMP DOWN COIL. PRESSURE UP TO 4300#, SHEARED. GOOD INDICATION WITH WOB. STACKED 5K. GOOD. PICKED OFF WHIPSTOCK CLEAN 02:00 - 02:10 0.17 WHIP P WEXIT PERFORMED 10 MIN FLOW CHECK. WELL STATIC. 02:10 - 03:55 1.75 WHIP P WEXIT -MUD WEIGHT:8.58 PPG IN,8.58 PPG OUT -RATE:1.07 BPM IN,0.60 BPM OUT -POH FROM 13038'MD TO SURFACE'MD -RATE:1.08 BPM.CIRC PRESSURE:1761 PSI PJSM FOR BHA SWAP AT 2500' 03:55 - 04:15 0.33 WHIP P WEXIT LD BHA MONITOR WELL FOR 10 MINUTES AT BHA STATIC -INJECTOR OFF:04:15 04:15 - 04:45 0.50 WHIP P WEXIT MAKE UP 2.80"WINDOW MILLING BHA#6 -PICK UP 2-3/8""XTREME MOTOR(0.6 DEG AKO)AND 2-3/8""COILTRAK TOOLS MAKE UP 2.80"WINDOW MILL AND 2.79" STRING REAMER -SURFACE TESTED TOOL.GOOD TEST. -PRESSURE TEST QTS TO 300 PSI LOW FOR 5 MINUTES/3500 PSI HIGH FOR 5 MINUTES -INJECTOR ON:04:45 04:45 - 07:00 2.25 WHIP P WEXIT RIH WITH 2-3/8""MILLING ASSEMBLY BHA#6 FROM SURFACE'MD TO 12870'MD -RATE:1.39 BPM IN,1.77 BPM OUT.CIRC PRESSURE:2263 PSI -MUD WEIGHT:8.59 PPG IN,8.59 PPG OUT 07:00 - 07:25 0.42 WHIP P WEXIT LOG TIE IN SWAP TO NEW MUD 07:25 - 08:25 1.00 WHIP P WEXIT CORRECT DEPTH-31',CONTINUE SWAPPING WELL OVER TO NEW MUD Printed 10/24/2016 9:42.16AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 9 151* Operation Summary Report Common Well Name:S-113 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/2/2016 End Date:10/14/2016 1X3-017VQ-C:(2,843,222.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time:6/17/2002 12:00:00AM I Rig Release:10/16/2016 Rig Contractor:NORDIC CALISTA UWI:500292309400 Active datum:Kelly Bushing/Rotary Table @70.33usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase I Description of Operations (hr) I (usft) 08:25 - 08:30 0.08 STWHIP P WEXIT WELL SWAPPED TO NEW MUD,RIH TO TAG PINCH POINT PARAMETERS BEFORE SWAPPING TO NEW ,MUD RIH AT 100 FPM =2-3K SURFACE WT PU WT=32K LOGGING SPEED 2.5 FPM=5.5K PARAMETERS AFTER SWAPPING TO NEW MUD RIH AT 100 FPM=6-7K PU WT=28K LOGGING SPEED 2.5 FPM=8K 08:30 - 08:40 0.17 STWHIP P WEXIT DRY TAG WS AT 13039,PU AND BRING THE PUMP ONLINE AND WORK DOWN TO THE PINCH POINT FS=3757 AT 1.75 BPM 08:40 - 11:35 2.92 STWHIP P WEXIT TAG WS AT 13,088.9,START MILLING THE WINDOW MILL 2.80"WINDOW IN 7"CASING PER BAKER REP FROM 13,038.9'MD TO 13,044.1'MD I-RATE:1.75 BPM IN,1.76 BPM OUT -MUD WEIGHT:8.64 PPG IN,8.56 PPG OUT -DWOB:1.65-3.50 KLBS '-CIRC PRESSURE:4040 PSI 11:35 - 13:00 1.42 STWHIP P ` WEXIT CONTINUE TO MILL 2.80"WINDOW IN 7" CASING PER BAKER REP FROM 13,038.9'MD TO 13,044.1'MD -RATE:1.74 BPM IN,1.76 BPM OUT MUD WEIGHT:8.63 PPG IN,8.56 PPG OUT -DWOB:2.35-2.65 KLBS -CIRC PRESSURE:3915 PSI 13:00 - 13:45 0.75 STWHIP P WEXIT i CONTINUE TO MILL 2.80"WINDOW IN 7" CASING PER BAKER REP FROM 13,038.9'MD TO 13,044.1'MD '-RATE:1.74 BPM IN,1.75 BPM OUT -MUD WEIGHT:8.60 PPG IN,8.55 PPG OUT -DWOB:2.00-2.45 KLBS CIRC PRESSURE:3918 PSI 13:45 - 15:10 1.42 STWHIP P WEXIT LOOKS LIKE WE EXITED THE BOTTOM OF THE WINDOWAT 13,043.7',WINDOW LENGTH =4.8'OUTOF5.2' CONTINUE REAMING TO 13,045'(1.3')TO DRESS THE BOTTOM OF THE WINDOW WITH THE STRING MILL THEN START MILLING 10' OF RAT HOLE TO 13,055' _ 15:10 - 15:45 0.58 STWHIP P WEXIT MILL 10'OF RAT HOLE 15:45 - 16:55 1.17 STWHIP P WEXIT RAT HOLE DRILLED,PU AND BACKREAM AS PER OCN#4 START LOW&HIGH VIS PILLS GEO IS SEEING SAND IN THE SAMPLES START UP PASSES 1 EACH AT 1 FPM AS MILLED=10°ROHS 15°LEFT OF AS MILLED '15°RIGHT OF AS MILLED Printed 10/24/2016 9:42:16AM *All depths reported in Drillers Depths* 0 fi WELLNEAD= 13-5/8"5M FMC NOTES: 3-1/2"CHROME NIPPLES. WELL t, ACTUATOR= JMD DRAFT S-1 1 3B sky ANGLE> 70'g 5009'.MAX DLS:37°ig 13175. OKB.REV= 70.33' Li REF EIEV= 70.33", BF.ELEV= 35.96' KOP= 700' I I _ 2367 -13-112-I- x NIP,ID=2.81!] Max Angle= 113°@ 13 • '.., Datbm MD= 6700' Datum TVD= 6700'SS 10-3/4"CSG,45.5#,L-80,ID=9.950' H 6687' 1--4 L GAS LFT MANDRELS ST MD TVD 0EV TYPE VLV LATCH PORT DATE LI 4 6713 3800 69 WAG DOME RK 16 0918/15 3 11147 5598 62 MMG DONE RX 16 09/18/15 Minimum ID = 1.92" @ 12838' 2 12712 6480 33 IMAG OW RK 0 07/12/02 2.63" DEPLOYMENT SLEEVE 1 _12802 6557, 30 WGSO RK 22 09/18/15 ..1 12838' —2.63'DEPLOY •:' SL - E,ID= 1 92" I I 12862 H3-1/7HES X NIP,ID=2,813' BEHIND CT LNR Z 12884' —7*X 4-112'BAKER S-3 PKR,ID=3.875"] I I 12910' .-13-1/2 HES X NP.ID=2.813' I 12930' —13-1/2"HES X NP,C=2.813" . • 12939' —E LOW PLUG#3 (2.64'FLOW COLLAR,ID=1.930") 3-1/2'TBG,9.2#,L-80,.0087 bpf.It)=2.992" -L 12942' \ 12942' I—3-1/7 WLEG.ID=2,99r(:LI ND CT LNR) 12932' E1MD TT (LOGGR)07/28/02) • • ' 12971 —FLOW PLUG#2 (2,64'FLOW COLLAR,I)=1.930') [3-i/2" ;ORE VV1teSTOCK(10/07/16) — 13039' I MILLOUT W(S-113E1 L1) 13039'-13044' FERFORATION SUMMARY 13695 —FLOW PLUG#1 A., REF LOG: i."&&V „. (2.64"FLOW COLLAR,D=1.930 ) ANGLE AT TOP FEW: NA 14600' —PUP JT w iRA TAG Note:Refer to Production DB for historical pert data SIZE.1 SPE INTERVAL Opn/Sqz SI-OT SQZ S-11313 - 2-1/2' 6 13014- 13038 S 07/28/02 09(18/16 2-1/2' 6 13018- 13038 S 11/08/02 09/18/16 V ---. ----, 2-1/2' 6 13038- 13098 S 06/29/14 09/18/16 ---.. ---„, OH 13039- 13044 0 10/07/16 ----.. ---, 2-3/8'SOLID LMR, — 12845' - 15240' '-- ---, S-113B L1 ---. -- 4.7#,L-60 TH511, SLTD 15240- 15638 SLOT 10/13/16 -...ii. .0039 bpi,11.)=1.995' 2-3/6'SLID LNR, — 15240' - 15638' PBTD — 13404' , 44.4.4.4444 4.7#,L-80 T1-1511, S-113B L1 , . 7'CSG,26#,L-80 BTC,10=6.278" — 13491' ..................At .0039 bpf,Es=1.995" 5-1136 DATE REV BY COMANTS DATE REV BY CONSAENTS AURORA LNT 07/1 3102 DACACK ORIGINAL COMPLETION WELL: S-1138 L1 10/16/16 •'.t CiCTDML(S-11313 L1) FERMT No: 2152180 10/21/16 JA13 I . G HO eil'Y... *NS API Nb 50-029-23094-02/60 10/25/16 JNI../.11.C/ REF&EIF e_Ev-M3 OH DEPTHS FEW SUM - SW 35,T12N,R12E,738'FM &783 PM. - BP Exploration(Alaska) ( Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0:2. - ~ 4-3 Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 0 Rescan Needed 1111111111111111111 RESCAN DIGITAL DATA ØSkettes, NO."'" 0 Other, No/Type: OVERSIZED (Scannable) 0 Maps: 0 Color Items: 0 Greyscale Items: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: Scanning Preparation :h x 30 = (06 0 Other:: . 1 Date: q :;q 0 c.¡ Is! vv¡f , i I 1111111111111111111 Date: q, !J-1 0 ft 151 WI j , + & = TOTAL PAGES C:,?, (Count doe:! not include cover Sheet)rnf> Date: {i, ar. mliî/llW III . NOTES: BY: Helen ~ Project Proofing BY: Helen e BY: Helen~ Production Scanning Stage 1 Page Count from Scanned File: (°7 Page Count Matches Number in Scanning Preparation: Helen e~ If NO in stage 1, page(s) discrepancies were found: (Count does include cover sheet) ¡/ YES Date: Cf /.30/0lf YES NO NO 151 vwP Stage 1 BY: BY: Helen Maria Date: Isl Scanning is complete at this point unless rescanning is required. ReScanned 1111-1111 1 BY: Helen Maria Date: Isl Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page.doc i • June 25, 2009 ; ~-, ~ ;-g ~ ~~, ~~ ~~~ ~ ~ ~-. .~ ~~~ ~ ~.~~ Mr. Tom Maunder ~~L ~ ~. 2009 Alaska Oil and Gas Conservation Commission ~r~~~~~~~ ~,~ ~~~;~ ~:~c~~~ ~~r~r~~~~E~~ 333 West 7th Avenue ~r~~~~~s~~t,~ Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of S-Pad ~~ °2'~ ~~3 5-113 Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from S-Pad 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, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this fetter 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, Anna Dube, at 659-5102. Sincerely, _ ,t; ~,~, ~~~, a; ~~ ; t~- ~.~~~~~ ~~~:~w~~~$.~.• .;uti Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Heport of Sundry Operetions (10-404) S-pad natw 6/'25/2009 Well Name PTD N Initial rop of cement ., Vol. of cement um ed Final top of cement Cemem top off date Corrosion inhibitor Corrosion inhibitod sealant date f~ bbis ft na al S-O78 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25/2009 S-03 1811900 7325 NA 13.25 NA 92.65 5/20/2009 5-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-05A 1951890 0 NA 0 NA 0.9 5/26/2009 5-W 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/262009 S-OBB 2010520 0 NA 0 NA 0.85 5/27I2009 S-09 1821040 1.5 NA 1.5 NA 9.4 5/31@009 S-t0A 1911230 0.5 NA 0.5 NA 3.a 5/31/2009 5-778 1990530 0.25 NA 025 NA f.7 5/27/2009 S-12A 1851930 0.25 NA 025 NA 1.7 6/1/2009 S-13 1821350 8 NA 8 NA 55.3 6!7/2009 S•IS 1840170 025 NA 025 NA 3 6/2/2009 S-t7C 2020070 0.25 NA 025 NA 2.6 6/1/2009 S-1BA 2021630 0.5 NA 0.5 NA 3 6!2/2009 S-~9 1861160 0.~5 NA 0.75 NA 22 5/19/2009 S-20A 2010450 025 NA 0.25 NA 1.3 5/19/2009 5-27 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 S-22B 1970510 0.75 NA 0.75 NA 3 5l19/2009 5-23 1901270 025 NA 025 NA 1.7 5/25/2009 5-248 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 S-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 5-288 2030020 0.5 NA 0.5 NA 2.s 5/37/2009 S-29a17 7960720 0 NA 0 NA O.sS 5/27I2009 S30 1900660 0.5 NA 0.5 NA 5.1 5/31/2009 S-37A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 5-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 S-34 1921360 0.5 NA 0.5 NA 3.4 5/31l2009 S35 1921480 0 NA 0 NA .85in 5/31/2009 5-36 1921760 0.75 NA 0.75 NA 425 5/27/2009 S-37 )920990 1.25 NA 125 NA 11.9 5/27/2009 5-38 1921270 025 NA 025 NA 102 5/27/2009 S-ai 1960240 1.5 NA 1.5 NA 11.7 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5/30/2009 S-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 S-44 1970070 025 NA 0.25 NA 1.7 5/28/2009 S-t00 2000780 2 NA 2 NA 21.3 5/29/2009 5-107 2001750 125 NA 125 NA 77.s 5/29/2009 Sa02L1 2037560 725 NA 725 NA 77.7 5/31Y2009 5-103 2001680 1.5 NA 1.5 NA ~t.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 S-105 2001520 4 NA 4 NA 32.7 5/20/2009 S-106 2070120 Y625 NA 1625 NA 174.3 6/2/2009 S-to7 2011130 225 NA 225 NA 28.9 5/18/2009 S-7oe 2011000 3.5 NA 3.5 NA 40 5/30/2009 5-109 2022450 2 NA 2 NA 21.3 5/30/2009 S-! 10 201/290 11 J5 NA 11.75 NA 98.6 5/30/2009 S-111 2050510 2 NA 2 NA 19.6 5/30/2009 5-172 2027350 0 NA 0 NA 0.5 5/30/2009 ~ 5-113 2021430 1.75 NA 1.75 NA 22.7 5/78l2009 S71aA 2021980 125 NA 125 NA tOZ 5/30/2009 S-115 2022300 2.5 NA 2.5 NA 272 5/29/2009 5-118 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 5-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 SJ7B 2032000 5 NA 5 NA 76.5 5/28/2009 S-119 2041620 1 NA 1 NA 52 5J30/2009 S-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 S-121 2060410 4.5 NA 4.5 NA 53.8 5/28/2009 5-122 2050810 3 NA 3 NA 21.3 5/29/2009 5-723 2041370 1.5 NA 1.5 NA 20.4 5/2&2009 5-124 2067360 1.75 NA 1.75 NA 11.9 5/26I2009 5-125 2070830 225 NA 225 NA 20.4 5/28J2009 S-726 20710970 125 NA 125 NA 75.3 6!1/2009 5-200 1972390 125 NA 125 NA 74.5 5/28l2009 5-201 20D1840 0 NA 0 NA 0.85 6/19/2009 5-213A 2042130 2 NA 2 NA 13.8 5/29/2009 S-215 2021540 2 NA 2 NA 18.7 6/1/2009 S-216 2001970 4.75 NA 4.75 NA 57 5/29/2009 S-217 2070950 025 NA 025 NA ~.7 6l1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 S~107 2060780 1fi NA 16 NA 99.5 6!2/2009 S-SDa 0 NA 0 NA 0.&5 5/28/2009 P.I. Su~rv ~ ` Z Z~ ~ Safety Valve & Well Pressures Test Report ReviewedB~ l Comm Pad: PBU_s InspDt: 2/18/2008 Inspected by John Crisp Interval [nspNo svsJCr080221140934 Related lnsp: Field Name PRUDHOE BAY Operator BP EXPLORATION (ALASKA) INC Operator Rep Rich Vincent Reason 180-Day `~ Sre: Inspector . _ -- _ _ - _ _ __ Well, Data - ~ Pilots ~ SSV ' SSSV rShutln Dt Well Type jl_ Well Pressures- ~ Gas Lift l Waiver i Comments __. __._:._ .. __ ----._ . _ _ .._ _ ------- --- _L_- ------~- _ Well Permit Separ Set VP Test Test Test Date SI OiI,WAG,GINJ, Imier Outer Tubing Number Number PSI PSI Trip Code Code Code GAS.CYCLE. SI PSI PSI PSI Yes/Nn Yep/Nn S-100 2000780 _ _ , S-103 2001680 ~ '. _.. -_ ._ -.___ .__ S 105 I 2001520 _ 153 125 ~ _ _'_- __ , 153 I 125 _ 1 153 ~ 125 i r 125 __ 120 _.._._ 110 ! P -P _ P~ 1--- Y i ___ ~ P P _~ I L~ _- ! _ _ ~ I _.__ _- 1-0[L -_- __ _- I-OlL T- -___ _ 1-O1L ~- -_i -- __ __ ~ -..._~_- -_ I - - - -. _~ - I I -- . ____ ~ ~ -~ 7 ~ -- -_ -" --- -"- _ _ _ ___-_ - S 106 i 20(0120 i -- -- - ~ S-108 ~ 201(000 I- S-109 ~ 2022450 125 153 - 153 125 153 125 ~ 40 25 125 30 - P P P - -- P ---- ~P _ -- --- --_ _ j l-OIL ---- 1-OIL ~-- i 1-OIL - __--a ~ -'- - _ ~ -._ ___ - __.. -- ~ _ __ ___- C I - ---- ~ r -- ---- ---- _ _ _ _ ____ ____ ____ __ I ~S-1138 _ j - 2021430 S 115 ~ 2022300 ~ 153 125 153 [25 ~ -- 125 120 _ P P P ---{ - -------- l-O1L - E- -~ ~ - - t. -- - ---- --- - - --" - - --- ---- - - - - - - - -- - - S-117 I 203U12U ~ - - ------- - ! 153 ! 125 ! - - - 135 - P - P P -- ~ _ ~ ---- -- _-- -- -- 1-OIL l-OIL - - - ~ - I I - ~ ! ----- _ -, --- - _-- S-121 L_20604I0 - - - - - 5-f22 ~ 2050810 - -- -- S-125 I 2070830 153 125 153 125 -- -.~_ 153 i 125 125 110 _ 115 P - P - - P P P T F. -- P ---- -- - - - - _ 1-UIL. I r ----- - ~ 1-0IL I-O1L -r- -- - - --. _. - ~ - ~ - - _.-- i -- -- ~ --- - ---- i- -...- - - -. - -- -- _ -..~ - T - --- -- _-" -~ - - _ S-17C I 2020070 153 T 125 ~ 110 P P -- --- - l-OIL j S-t8A 2021630 -- --~ --- --- S-213A 2042130 153 125 ' -4---- 153 125 ~ 100 -- 125 ~ P P -- P -- __ - -- -- i - 1-OlL -- 1-O1L -~ - - i - _- --- _ __ _--- S-44 I 1970060 153 t25 100 P P i 1-OIL -.. - _...__ __--J__-_._ I _ , Comments ``~~%~~~ MAR .~ ~ 2008 • rformance Wells Components Failures Failure Rate 1- ---- 3.12%_ _ I - 16 -- - 32--- - --- Monday, February 25, 2008 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marlœr.doc ~'J ~ ^ ~~V\ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2021430 Well Name/No. PRUDHOE BAY UN AURO S-113B Operator BP EXPLORATION (ALASKA) INC MD 13515 /' TVD 7191 ~ Completion Date 7/28/2002 ~ Completion Status 1-01L Current Status 1-01L REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes -----~ .--~----~---- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, DEN, NEU Well Log Information: J fí (A J... Y J '-40 ~ l-- API No. 50-029-23094-02-00 UIC N -~----- -~~--~ ~~-----~~--~---- (data taken from Logs Portion of Master Well Data Maint) Received Comments ~-~- A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 7/9/2002. 13469 Open 8/23/2002 13515 ~'-"11/7/2002 Digital Data: Rate of ~\i~ penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Çftment Evaluation Log Log Run Scale Media No Interval OH / Start Stop CH ~D (~D C L.A6984 LIS Verification ¿.A1267 See Notes 45 45 ~ ~~nt Evaluation Directional Survey LIS Verification Directional Survey Directional Survey Directional Survey 5 Col 12744 13336 Case 8/20/2002 9659 13515 Open 8n /2002 45 13469 Open 8/23/2002 9659 13515 Open 8n /2002 9659 13515 Open 8n /2002 9659 13515 Open 8n /2002 Rpt \Rpt (.:BJ D Rpt v6 D Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received MWD MWD -~-----~- Permit to Drill 2021430 MD 13515 TVD 7191 Well Cored? ADDITIONAL INFORMATION vB Chips Received? ~ Analysis Received? Comments: ~ Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Well Name/No. PRUDHOE BAY UN AURO S-113B Operator BP EXPLORATION (ALASKA) INC Completion Date 7/28/2002 Completion Status 1-01L Current Status 1-01L Daily History Received? WN WN Formation Tops fd-a Date: API No. 50-029-23094-02-00 UIC N ~-------~--- ----~~--- /-, d& ~j--)~ ~1--c .'-". ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: ADD PERFS 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing - 738'FNL,4497'FEL, Sec. 35,T12N, R12E,UM At top of productive interval 5210'FNL,3745'FEL,Sec.28,T12N, R12E,UM At effective depth 4' FNL, 3904' FEL, Sec. 33, T12N, R12E, UM At total depth 25'FNL,3949'FEL,Sec.33,T12N,R12E,UM 12. Present well condition summary Total depth: measured true vertical Stimulate - Alter casing - 5. Type of Well: Development _X Exploratory- Stratigraphic- Service- (asp's 618930,5980745) (asp's 609110, 5981404) (asp's 608952, 5981328) (asp's 608907,5981306) 13515 feet 7191 feet Plugs (measured) Plugging - Perforate _X Repair well - Other - 6. Datum elevation (DF or KB feet) RKB 70 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-113B 9. Permit number / approval number 202-143 / 302-257 10. API number 50-029-23094-02 11. Field / Pool Prudhoe Bay Field / Aurora Pool Effective depth: measured 13404 feet Junk (measured) true vertical 7092 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 115' 20" 260 sx AS (Approx) 149' 149' Surface 5553' 10-3/4" 784 sx Arcticset III Lite 3, 5587' 3371' 750 sx Class 'G' Production 13460' 7" 504 sx Class 'G' 13491' 7170' Perforation depth: measured Open Perfs 13014'-13038' true vertical Open Perfs 6744'-6766' Tubing (size, grade, and measured depth) 3-1/2",9.2#, L-80 @ 12932'. Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker S-3 PBR @ 12884'. 3-1/2" HES 'X' Nipple @ 2367'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. ReDresentative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl 127 2567 6 Prior to well operation 10/06/2002 Subsequent to operation 11/11/2002 15. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations - Oil _X Gas - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. A/t'~ £ J ~ Title: Techni';'! Assistant DeWayne R. Schnorr ~ ~ 1032 RBDMS 8Fl Form 10-404 Rev 06/15/88 . RECEIVED DEC 0 4 2002 Alaska Oil & Gas Gons. Commission Anchorage Casing Pressure Tubing Pressure 273 280 20727 16. Status of well classification as: rQR i 42 Suspended - Service ~\[ -DEC Date November 13. 2002 Prepared by DeWayne R. Schnorr 564-5174 ~ SUBMIT IN DUPLICATE 10/06/2002 1 0/31/2002 11/01/2002 11/01/2002 11/07/2002 11/08/2002 11/09/2002 ( (' S-113B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS TESTEVENT --- BOPD: 127, BWPD: 6, MCFPD: 3,387, AL Rate: 820 NEW WELL POST: BRUSH / BROACH; HOT OIL TREATMENT NEW WELL POST: BRUSH / BROACH; HOT OIL TREATMENT NEW WELL POST: BRUSH / BROACH; DRIFT/TAG NEW WELL POST: HOT OIL TREATMENT NEW WELL POST: HOT OIL TREATMENT NEW WELL POST: PERFORATING EVENT SUMMARY 10/06/02 TESTEVENT --- BOPD: 127, BWPD: 6, MCFPD: 3,387, AL Rate: 820 10/31/02 BRUSH & FLUSH ---- TUBING WITH 3 1/211 WIRE BRUSH AND 2.5011 GAUGE RING, FROM 3001 TO 16001 SLM, PUMPED 90 BBLS AWAY AND FLOWED WELL, PUMPING MORE HOT DIESEL 190 DEG. ---JOB IN PROGRESS. 11/01/02 PUMPED A TOTAL OF 129 BBLS OF HEATED DIESEL DOWN TUBING TO ASSIST HES WITH BRUSH-N-FLUSH. 11/01/02 CONTINUE BRUSH AND FLUSH --- STARTED SITTING DOWN @ 3001 WORKED TO 13851 FLOWED WELL 1 1/211 HRS --- BRUSHED MORE WHILE PUMPING HOT DIESEL. WORK FROM 13801 TO 16501 NOT GETTING ANY BETTER. COMP REP SAID TO RIG DOWN. HE SAID WE WOULD COME BACK LATER. GAVE WELL BACK TO PAD OP. LEAVE WELL SHUT-IN. INFORMED HIM THAT THE FLOW LINE WAS NOT FREEZE PROTECTED. 11/07/02 MIRU OS CTU #9. RIH WITH 2.2511 JSN. JET HOT DIESEL AND CRUDE TAKING RETURNS TO SYSTEM. 11/08/02 RIH JETTING HOT CRUDE. TAGGED TD @ 13,4021 CTMD. SWAP HOLE OVER TO DIESEL. POOH. CHANGED OUT PACK-OFFS. RIH WITH MEMORY GR/CCL. LOGGED 13,1001 TO 12,9001. FLAGGED PIPE & POOH. RIH WITH 201 X 2.511 (2506 POWER JET) PERF GUN. TIED INTO FLAG AND PERFORATED 13,0181 TO 13,0381. DROPPED FIRST BALL BUT DID NOT HEAR IT LAUNCH. DROPPED SECOND BALL, HAD GOOD INDICATION IT LAUNCHED. FLOWED WELL TO TIGER TANK WHILE PUMPING BALL. NO INDICATION ON SURFACE THAT THE GUNS FIRED. POOH. GUNS DID NOT FIRE, BOTH BALLS WERE AT THE CHECKS. CHECK AND RE-MU MHA. RIH WITH GUN #1. 11/09/02 RIH WITH GUN #1. POSITION GUN. HAD TROUBLE GETTING BALL TO SEAT AGAIN. FINALLY GOT BALL ON SEAT. SHOT INTERVAL 13,0181 TO 13,038 WHILE FLOWING WELL TO TANK. SHUT-IN WELL IN. POOH WITH GUN #1. POP WELL. NOTIFY PAD OPERATOR AND PCC OF WELL STATUS. RD OS CTU #9. «< JOB COMPLETED »> Page 1 BBLS 1 50 96 699 379 1225 ( S-1138 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED PRESSURE TEST LUBRICATOR W/ 2 BBL OF DIESEL, (1 TEST) METHANOL 60/40 METHANOL WATER DIESEL CRUDE TOTAL ADD PERFS 11/09/2002 THE FOLLOWING INTERVAL WAS PERFORATED WITH THE 2-1/2" PJ 2506, 6 SPF, 60 DEGREE PHASED GUN, RANDOM ORIENTATION. 13,018' - 13,038' Page 2 aoa - /43 { (dW -¡ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas ConseIVation Comm. Attn.: Lisa Weepie 3 33 West 7th Avenue, Suite 100 i\nchorage,Alaska 99501 September 27,2002 RE: MWD Fonnation Evaluation Logs: S-113B AURORA, AK-MW-22095 S-113B AURORA: Digital Log Images: 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. i\nchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Si~LJ2ø}rJ RECEIVED NOV 07 2002 Alaska O~ & Gas Cons. CommiSlion Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ( 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. L:::~~~~[,~~~~~ ~~~~~EC. 35, T12N, R12E, UM ..').;.'.;..... Zffi~~.~~:.~'~:Y5~1"........ At top of productive interval 'ì ... 7" Û:: ~ . 70' NSL, 3745' WEL, SEC. 28, T12N, R12E, UM VERJ118J At total depth l ~ r (J' 5255' NSL, 3949' WEL, SEC. 33, T12N, R12E, UM ¡:;,,-~~ ~ Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 70.33' ADL 028258 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 7/8/2002 7/10/2002 7/28/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 13515 7191 FT 13404 7092 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU 23. CASING SIZE 7" Classification of Service Well 7. Permit Number 202-143 8. API Number 50- 029-23094-02 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 5-1138 10-3/4" WT. PER FT. 26# 45.5# 26# GRADE L-80 L-80 L-80 11. Field and Pool Prudhoe Bay Field I Aurora Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2367' MD 1900' (Approx.) ø~ Q7oD/ hlb I./q 12. I' f'lb CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 115' 9-7/8" 518 sx Class 'G' 34' 5587' 13-1/2" 784 sx Articset III Lite 3, 750 sx 'G' 31' 13491' 9-7/8" 504 sx Class 'G' AMOUNT PULLED 7" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 4 spf MD TVD 13014' - 13038' 6744' - 6766' SIZE 3-1/2", 9.2#, L-80 TUBING RECORD DEPTH SET (MD) 12942' PACKER SET (MD) 12884' 25. MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protect with 95 Bbls Diesel 13014' - 13038' Frac'd: Placed 78,492#'s of 16/20 & 12/18 Carbolite Behind Pipe 27. Date First Production August 6, 2002 Date of Test Hours Tested 8/14/2002 4 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR OIL -BBL TEST PERIOD 1345 Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF 2198 GAs-McF WATER-BBL -0- WATER-BBL CHOKE SIZE 1760 OIL GRAVITY-API (CORR) GAS-OIL RATIO 1634 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit CO~r~!p~t" No core samples were taken. 28. Form 10-407 Rev. 07-01-80 6F- ORIGINàLRBDMS BFl AU] 28 ~itlnDuplicate '4u'<r~~'a~~ ( 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Ugnu 6131' 3577' Ugnu M Sands 8981' 4639' Schrader Bluff N Sands 9572' 4865' Schrader Sluff 0 Sands 9838' Sase Schrader / Top Colville 10416' HRZ 12784' Kalubik 13000' Kuparuk C 13017' LCU / Kuparuk S 13185' Kuparuk A 13337' Miluveach 13420' 4971' 5252' 6542' 6732' 6747' 6897' 7032' 7106' 31. List of Attachments: SUrnmary of Daily Drilling Reports and Post-Rig Work, Surveys 32. I ~erebY certify that the f/oin: is true and correct to the best of my knowledge Signed Terrie Hubble ---1~ J\J\Aa.. ~ ~- Title Technical Assistant S-113S 202-143 Well Number Permit No. I Approval No. Date oa '?Jo.()~ Prepared By Name/Number: Terrie Hubb/e, 564-4628 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 (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: 8-113 Common Name: 8-113 Test Date 6/23/2002 Test Type Test Depth (TMD) 5,587.0 (ft) LOT BP EXPLORATION Leak-Off.Tesf.Summary Test Depth (TVD) 3,371.0 (ft) AMW 9.40 (ppg) Surface Pressure 1 ,220 (psi) Leak Off Pressure (BHP) 2,866 (psi) Page 1 of 1 EMW 16.37 (ppg) Printed: 7/15/2002 8:52:25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-113 S-113 DRILL +COMPLETE DOYON DOYON 14 Start: 6/16/2002 Rig Release: 7/13/2002 Rig Number: Spud Date: 6/17/2002 End: 7/13/2002 6/15/2002 18:00 - 00:00 6.00 MOB P SURF Jack back rig floor. Move Rig off well. Remove BOP from Cellar and place in transport rack. PU rig mats and Herculite. Install back boosters. Install goose neck and front boosters. Trouble shoot and repair front booster steering. 6/16/2002 00:00 - 07:30 7.50 MOB N RREP SURF Repair steering on front booster tires. 07:30 - 18:00 10.50 MOB P SURF Mob rig from W pad to S pad. 18:00 - 21 :00 3.00 MOB P SURF RD back booster tires. PU BOP stack and adapter, SB in BOP bay. PU mouse hole. RU cellar doors. PU surface stack and hang in cellar. 21 :00 - 23:00 2.00 MOB P SURF Spot rig over hole and shim. 23:00 - 23:30 0.50 MOB P SURF Skid rig floor forward. 23:30 - 00:00 0.50 MOB P SURF NU Diverter Stack. 6/17/2002 00:00 - 06:30 6.50 MOB P SURF NU Diverter System. Take on Mud. RU drill floor. Load pipe shed with 5" DP, BHA and strap. 06:30 - 07:30 1.00 MOB P SURF Function Test Diverter. Test waived by AOGCC Chuck Schieve. 07:30 - 14:00 6.50 MOB P SURF PU 5" DP & HWDP. Rack back in derrick. 14:00 - 16:00 2.00 MOB P SURF MU BHA #1: Bit, Mud Mtr, Fit sub, IBS, NM Flex DC, Hang off sub, orienting sub, 2- NM Flex DC's, Jars, 20 - HWDP. 16:00 - 16:30 0.50 MOB P SURF Fill stack, conductor, and flow line. Check for leaks. Pressure test surface lines to 3000 psi. 16:30 - 17:00 0.50 MOB P SURF Pre-spud safety meeting. RU slick line for Gyro. 17:00 - 00:00 7.00 MOB P SURF Directionally drill surface hole from 115' - 479'. Gyro every 95'. AST: 2.78 hrs, ART: 1.32 hrs, ADT: 4.1 hrs. 6/18/2002 00:00 - 01 :30 1.50 DRILL P SURF Viscosity of mud dropped & pump suctions plugging up. Circulate and Condition mud. 01 :30 - 22:30 21.00 DRILL P SURF Directionally drill f/479' - 1485'. Gyro every stand down to 960'. RD Gyro slick line. AST: 14.5 hr, ART: 0.32 hr, ADT: 14.82 hr. 22:30 - 23:30 1.00 DRILL P SURF Poor ROP & Build rate. Circulate prior to bit trip. 23:30 - 00:00 0.50 DRILL P SURF POOH. 6/19/2002 00:00 - 02:00 2.00 DRILL P SURF POOH. LD orientating sub. Change out bit, stabilizer to 12 3/16" (from 12 3/8"), & MWD probe (for 500 - 650 gpm). 02:00 - 02:30 0.50 DRILL P SURF TIH. Tag bridge @ 560'. Wash through bridge and continue TIH & wash last stand to bottom @ 1485'. 10' fill on bottom. 02:30 - 20:30 18.00 DRILL P SURF Directiionally drill f/1485' - 2970'. AST: 10.25 hr, ART 4.62 hr, ADT: 14.87 hr. 20:30 - 21 :30 1.00 DRILL P SURF Circulate hole clean. Flow Check. 21 :30 - 23:00 1.50 DRILL P SURF Short trip to 1335'. tight hole @ 1822' - 1716', 1570' & 1550', pull +/- 20k over. Tight hole @ 1534' -1448', pull 50 k over. NU Top Drive back ream 1530' - 1430', 105 SPM, 1250 PSI. Work thru tight spot several times. Pull dry to 1335'. 23:00 - 23:30 0.50 DRILL P SURF TIH. Tag @ 1550', work thru. Wash last stand to bottom @ 2970'. 23:30 - 00:00 0.50 DRILL P SURF Directionally drill f/2970' - 2995'. AST: 0.25 hr ART: 0 hr, ADT: 0.25 hr. 6/20/2002 00:00 - 20:00 20.00 DRILL P SURF Directionally drill f/2995' - 5600'. AST: 2.77 hr, ART: 11.46 hr, ADT: 14.23 hr. Encountered gas cut mud(hydrates) after drilling into the top of the SV2 formation. Picked up and circulated for app. 20 minutes while observing well. Continued to drill ahead while monitoring returns. Mud was cut from a 9.7 to 8.7. Once main influx reached surface, returns and flow were normal and no futher indication of hydrates were seen while Printed: 7/15/2002 8:52:33 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-113 S-113 DRILL +COMPLETE DOYON DOYON 14 Start: 6/16/2002 Rig Release: 7/13/2002 Rig Number: Spud Date: 6/17/2002 End: 7/13/2002 6/20/2002 00:00 - 20:00 20.00 DRILL P SURF drilling the well to surface TD. 20:00 - 22:30 2.50 DRILL P SURF Circulate hole clean and condition mud to 9.8 ppg, 175 Vis. Circulate @ 650 gpm, 2700 psi, 80 rpm. 22:30 - 00:00 1.50 DRILL P SURF POOH for wiper trip to 2700'. Hole slick. 6/21/2002 00:00 - 01 :00 1.00 DRILL P SURF TIH to bottom @ 5600'. Wash last stand to bottom. No fill. Hole slick. 01 :00 - 02:30 1.50 DRILL P SURF Circulate and condition mud for casing run. Vis: 150 in, 225 out. MW: 9.8 in, 9.8 out. 02:30 - 05:30 3.00 DRILL P SURF TOOH. SLM no correction. Tight @ 381'. Wipe out tight spot. 05:30 - 07:00 1.50 DRILL P SURF Stand back HWDP, Flex Jts, Jars. LD mud motor, Stabilizer, UBHO, Bit, & float sub. 07:00 - 08:30 1.50 CASE P SURF Clear rig floor. RU casing tools and equipment: Fill-up tool, 350T slip type elevators and slips, power tongs& working platform. 08:30 - 17:30 9.00 CASE P SURF TIH with 135 jts, 10.75", L-80, BTC casing, Float shoe, Float collar, TAM Port collar, and casing hanger. PU landing jt. Start pumps @ 6 bpm and wash to bottom. Land hanger in well head. Casing shoe @ 5587'. 17:30 - 20:30 3.00 CASE P SURF Circulate and condition mud @ 9 BPM, 800 psi, while reciprocating casing 15'. Load Top & Bottom plug in cement head. NU Cement head and lines. Final mud properties: YP 21, Vis 82, MW 9.6. Final bottoms up @ 13 bpm, 820 psi. PJSM for cement job. 20:30 - 00:00 3.50 CEMT P SURF Switch to Dowell pumps. Pump 5 bbls water. Test lines to 3,500 psi. Pump 75 bbls 10.2 ppg Mud Push wI dye @ 6 bpm, 500 psi. Drop bottom plug. Mix and pump 620 bbl (784 sxs) "G" ArcticSet 3 - Lite Lead cement @ 8 bpm, 820 psi. Mix and pump 155 bbls (750 sxs) "G" Tail Cement @ 8 bpm, 1100 psi. Drop Top plug. Clear Dowell lines with 10 bbl water. Switch to rig pumps and displace cement with 515 bbls 9.6 ppg Mud @ 13 bpm, 1450 Max pressure. Slow pumps to 2 bpm. Bump plug to 1500 psi (@ 00:17 hr, 06-22-02). Reciprocated casing untill 90 bbls lead cement around shoe. Estimate 30 bbls cement in returns. 6/22/2002 00:00 - 00:30 0.50 CEMT P SURF Finish displacing cement. Bump plug to 1500 psi. Bleed pressure & check floats. 00:30 - 01 :30 1.00 CEMT P SURF RD cement head. LD landing jt. RD casing equipment. 01 :30 - 02:00 0.50 DIVRTR P SURF PU stack washer and wash riser & diverter stack. 02:00 - 03:00 1.00 DIVRTR P SURF NO Diverter system. 03:00 - 03:30 0.50 WHSUR P SURF NU Well head & test to 1000 psi. 03:30 - 06:30 3.00 BOPSUR P SURF NU BOP stack. 06:30 - 11 :30 5.00 BOPSUR P SURF Test BOPE to 250 psi I low & 3500 psi I High for 5 min each step. Change out two valves on Choke manifold. Test witnessed by Lou Grimaldi AOGCC. 11 :30 - 12:00 0.50 BOPSUR P SURF Pull test plug. ND test equipment. Set Wear bushing. 12:00 - 14:00 2.00 DRILL P SURF PU & TIH 45 jts 5" DP. POOH rack back in derrick. 14:00 -18:00 4.00 DRILL P PROD1 PU BHA #3: Bit, Mud Mtr, Stabilizer, LWD, Hang off sub, NM DC's, Jars, & HWDP. Upload MWD. Test adjustable stabilize @ 650 gpm, 890 psi in, 1150 psi out. Surface test LWD / MWD @ 600 gpm, 1540 psi. 18:00 - 23:00 5.00 DRILL P PROD1 TIH picking up singles from pipe shed. Rotate through TAM port collar @ 984'. Test casing to 1000 psi after BHA through TAM collar. Continue TIH with singles from pipe shed + 4 Printed: 7/15/2002 8:52:33 AM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-113 S-113 DRILL +COMPLETE DOYON DOYON 14 Start: 6/16/2002 Rig Release: 7/13/2002 Rig Number: Spud Date: 6/17/2002 End: 7/13/2002 6/22/2002 18:00 - 23:00 5.00 DRill P PROD1 stands from derrick. Tag top of cement @ 5491'. Picked up total 60 stands DP (Total 110 stands DP in hole + derrick). 23:00 - 23:30 0.50 DRill PROD1 Circulate bottoms up. 23:30 - 00:00 0.50 DRill P PROD1 Slip & cut drill line. 6/23/2002 00:00 - 01 :30 1.50 DRill P PROD1 RU test equipment and test 10.75" casing to 3500 psi /30 min. 01 :30 - 04:00 2.50 DRill P PROD1 Drill float collar, shoe track, & float shoe. Clean old hole to TD @ 5600'. Drill 20' of new formation to 5620'. Displace well to new 9.4 ppg lSND mud system while drilling float equipment. 04:00 - 04:30 0.50 DRill P PROD1 Circulate and condition mud for lOT. 04:30 - 05:00 0.50 DRill P PROD1 lOT. 9.4 ppg MW, 3371' TVD, 1220 psi leak off. EMW = 16.35 ppg. 05:00 - 16:00 11.00 DRill P PROD1 Establish baseline ECD = 10.13 ppg. Directionally drill fl 5620' - 7324'. Pump sweeps every 500 ft. or as hole dictates. Sweeps bringing additional cuttings back. 16:00 -17:00 1.00 DRill P PROD1 CBU with sweep. 17:00 -19:30 2.50 DRill P PROD1 Wiper trip to 10.75" casing shoe. Tight @ 6230'. Pump out f/ 5890' - 5690' due to swabbing. Pull into casing shoe. 19:30 - 20:30 1.00 DRill P PROD1 Repair Top Drive. Trouble shoot and adjust back-out pressure. 20:30 - 22:00 1.50DRlll P PROD1 TIH. Tag up @ wash thru @ 6230',6267', & 6469'. Tag and work thru @ 6500'. Wash last stand to bottom @ 7324'. 22:00 - 00:00 2.00 DRill P PROD1 Directionally drill f/7324' -7515'. Daily AST: 0.82 hrs, ART: 6.78 hrs, ADT: 7.6 hrs. ECD = 10.4 ppg. 6/24/2002 00:00 - 14:30 14.50 DRill P PROD1 Directionally drill f/7515' - 8384'. AST: 0.5 hr, ART: 10.96 hr, ADT: 11.36 hr. Unable to drill ahead with acceptable ROP. Suspect bit damage. Torque at 18-19,000 while on bottom drilling. 14:30 - 15:30 1.00 DRill P PROD1 Circulate bottoms up and hole clean. 15:30 - 21:30 6.00 DRill P PROD1 TOOH. Back ream f/7420' - 6941'. Hole swabbing and tight. 21 :30 - 22:00 0.50 DRill P PROD1 Stand back HWDP & DC's. 22:00 - 23:00 1.00 DRill P PROD1 Down load MWD IlWD data. 23:00 - 23:30 0.50 DRill P PROD1 lD PWD, lWD tools with stabilizer. Bit rung out with missing cutters. Stabalizer above bit also damaged due to hardlsharp formation or junk. 23:30 - 00:00 0.50 DRill P PROD1 PU Bit #4 & BHA #4: Bit, Mud mtr, Adj Stab, Fit sub, Dbl pin sub, Rll string, MWD, lWD, DC's, HWDP. 6/25/2002 00:00 - 01 :30 1.50 DRill P PROD1 MU directional BHA, upload MWD 01 :30 - 02:00 0.50 DRill P PROD1 Surface test MWD, motor, AGS 02:00 - 03:00 1.00 DRill P PROD1 PJSM, load sources into MWD, trip in BHA to 830' 03:00 - 06:00 3.00 DRill P PROD1 Trip in BHA, pick up DP, 1 x 1 from pipe shed, 105 jts 06:00 - 06:30 0.50 DRill P PROD1 Trip in from derrick to 5587' 06:30 - 07:30 1.00 DRill P PROD1 Rig service, slip I cut drilling line 07:30 - 09:00 1.50 DRill P PROD1 Trip into 8324' 09:00 - 10:30 1.50 DRill P PROD 1 Orient, wash and work junk on bottom, back ream and wash I work junk off bottom 10:30 -12:00 1.50 DRill P PROD1 Directional drill 97/8" production wellbore From 8384' to 8572' AST 0, ART 0.99, ADT 0.99 12:00 - 20:00 8.00 DRill P PROD1 Directional drill from 8572' to 9542' 20:00 - 20:30 0.50 DRill P PROD1 Circulate sweep, SPRs, flow check 20:30 - 21:30 1.00 DRill P PROD1 Wiper trip from 9542' to 8300' Wellbore in good condition 21:30 - 00:00 2.50 DRill P PROD1 Directional drill from 9542' to 9830' AST 2.32, ART 5.3, ADT 7.62 Printed: 7/15/2002 8:52:33 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 5-113 5-113 DRILL +COMPLETE DOYON DOYON 14 Start: 6/16/2002 Rig Release: 7/13/2002 Rig Number: Spud Date: 6/17/2002 End: 7/13/2002 6/26/2002 00:00 - 12:00 12.00 DRILL P PROD1 Directional drill 97/8" production wellbore From 9830' to 11,267' AST 1.32, ART 6.63, ADT 7.95 12:00 - 14:00 2.00 DRILL P PROD1 Directional drill from 11,267' to 11,554' Adding lubricants to control high torque. Current system has app. 3% of T.T. and drilnslide. 14:00 - 15:00 1.00 DRILL P PROD1 Circulate sweep, surface to surface. No significant increase in cuttings when sweep reached surface. 15:00 - 17:00 2.00 DRILL P PROD1 Wiper trip from 11,554' to 9449' Wellbore in good condition 17:00 - 00:00 7.00 DRILL P PROD1 Directional drill from 11,554' to 12.254' AST 2.93, ART 2.73, ADT 5.66 6/27/2002 00:00 - 06:30 6.50 DRILL P PROD1 Directional drill 97/8" production wellbore From 12,254' to 12,816' 06:30 - 08:30 2.00 DRILL P PROD1 Circulate and condition mud properties Raise mud weight to 10.1 ppg 08:30 -12:00 3.50 DRILL P PROD1 Directional drill from 12,816' to 13,087' AST 1.5, ART 6.24, ADT 7.74 12:00 - 17:30 5.50 DRILL P PROD1 Directional drill from 13,087' to 13,566' 17:30 - 18:30 1.00 DRILL P PROD1 Circulate sweep surface to surface, no significant increase in cuttings when sweep to surface 18:30 - 20:30 2.00 DRILL P PROD1 Wiper trip from 13,566' to 11,461' Wellbore in good condition 20:30 - 00:00 3.50 DRILL P PROD1 Directional drill from 13,566' to 13,756' AST 3.83, ART 2.73, ADT 6.56 6/28/2002 00:00 - 11 :00 11.00 DRILL P PROD1 Directional drill 97/8" production wellbore From 13,791' to 14,440' AST 0.66, ART 7.56, ADT 8.22 11 :00 - 12:30 1.50 DRILL P PROD1 Circulate sweep surface to surface 12:30 - 16:30 4.00 DRILL P PROD1 Wiper trip from 14,440' to casing shoe at 5585' Flow checks, pump slug, wellbore in good condition 16:30 - 17:30 1.00 DRILL P PROD1 Rig service, slip / cut drilling line Service top drive 17:30 - 21 :30 4.00 DRILL P PROD1 Trip in wellbore, wellbore in good condition Fill pipe every 30 stands. No adverse hole conditions or fill onTIH. 21 :30 - 00:00 2.50 DRILL P PROD1 Circulate bottoms up, circulate and condition mud properties for logging. Mud coming back heavy and high vis. (up to 10.6 and 165.) Thin and treat with 3 ciculations. 6/29/2002 00:00 - 01 :30 1.50 DRILL P PROD1 Circulate and condition mud properties for logging 01 :30 - 02:00 0.50 DRILL P PROD1 Flow check, pump slug, drop 2.25" drift 02:00 - 08:00 6.00 DRILL P PROD1 Trip out, SLM, no correction, wellbore in good condition 08:00 - 09:00 1.00 DRILL P PROD1 LD BHA, NMDCs, jars 09:00 - 10:30 1.50 DRILL P PROD1 MWD, PJSM, remove sources, download 10:30 - 12:00 1.50 DRILL P PROD1 LD BHA, MWD, motor, AGS 12:00 - 14:00 2.00 EVAL C PROD1 PU, MU MDT logging tool, function test 14:00 - 16:00 2.00 EVAL C PROD1 Trip in MDT on DP, control running speed, 5587' 16:00 - 16:30 0.50 EVAL C PROD1 Break circulation, hang sheave in derrick 16:30 - 20:30 4.00 EVAL C PROD1 Trip in to 13,400', control speed, fill pipe every 10 stands. No adverse hole conditions. Hole appears to be in excellent shape. 20:30 - 23:00 2.50 EVAL C PROD1 Break circulation, 3 bpm at 600 psi, MU side entry sub, run wireline to 13.412', wet connect, function test Printed: 7/1512002 8:52:33 AM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 5-113 8-113 DRILL +COMPLETE DOYON DOYON 14 Start: 6/16/2002 Rig Release: 7/13/2002 Rig Number: Spud Date: 6/17/2002 End: 7/13/2002 6/29/2002 23:00 - 00:00 1.00 EVAL C PROD1 Trip in to 13,823', begin to log 6/30/2002 00:00 - 09:30 9.50 EVAL C PROD1 Log w/ Schlumberger, run MDT log. Recover Pressures and samples in the Kuparuk at several different internals. Hole in good shape during logging operation. 09:30 - 10:30 1.00 EVAL C PROD1 Pull free from wet connect, POOH w/ wireline 10:30 - 11 :00 0.50 EVAL C PROD1 LD side entry sub, rig down sheaves 11 :00 - 16:00 5.00 EVAL C PROD1 Flow check, pump slug, improper hole fill, circulate and condition mud to trip. Mud coming back from 175 vis and up. Stage from 3 bpm at 820 psi to 7.5 bpm at 800 psi. Saw small amount of gas with bottoms up. 16:00 - 19:30 3.50 EVAL C PROD1 Flow check, trip out at controlled speed, wet. No adverse hole conditions on trip to shoe. 19:30 - 21:30 2.00 EVAL C PROD1 Flow check at shoe, POOH wet 21:30 - 22:00 0.50 EVAL C PROD1 LD HWDP from derrick to pipe shed 22:00 - 23:30 1.50 EVAL C PROD1 LD logging tools, MDT tool, clear rig floor 23:30 - 00:00 0.50 STKOH C PROD1 Pull wear bushing 7/1/2002 00:00 - 03:00 3.00 STKOH C PROD1 Pressure test BOPE as per BP / AOGCC regulations Witness of test waived by AOGCC representative, John Spalding. 03:00 - 03:30 0.50 STKOH C PROD1 Pull test plug, run wear bushing 03:30 - 05:30 2.00 STKOH C PROD1 MU mule shoeBHA, RIH to 5587', casing shoe 05:30 - 06:30 1.00 STKOH C PROD1 Rig service, slip / cut drilling line, service top drive Circulate mud 06:30 - 09:00 2.50 STKOH C PROD1 Trip in breaking circulation every 20 stands to 12,500' 09:00 - 10:30 1.50 STKOH C PROD1 Trip in breaking circulation every 500' to 14,440' 10:30 - 15:00 4.50 STKOH C PROD1 Circulate and condition mud, 650 gpm, at 90 RPM no losses 15:00 - 16:00 1.00 EVAL C PROD1 Set cement plug #1, 14,440' to 13,440' Set as per program with 105 bbls. of 15.8 cement. No losses during spotting of cement. 16:00 - 17:00 1.00 STKOH C PROD1 Trip out to 13,440', pull at 3.5 minutes / stand 17:00 - 20:00 3.00 STKOH C PROD1 Circulate bottoms up, overboard 60 bbls contaminated mud, cement strung out in mud. No losses during circulation of mud. 20:00 - 22:00 2.00 STKOH C PROD1 Circulate and spot 10.8 mud spacer, 475 bbls as per program 22:00 - 23:30 1.50 STKOH C PROD1 Trip out to 10,750', pull at 3.5 minutes / stand 23:30 - 00:00 0.50 STKOH C PROD1 Circulate bottoms up to confirm 10.8 ppg mud at surface 7/2/2002 00:00 - 01 :00 1.00 STKOH C PROD1 Circulate bottoms up to confirm 10.8 ppg mud spacer, spacer to surface, Pipe tally error, actual depth 10,870' not 10,750' 01 :00 - 01 :30 0.50 STKOH C PROD1 Circulate and spot 35 bbls of 10.8 ppg mud spacer 01 :30 - 02:30 1.00 STKOH C PROD1 Trip out to 10,750', circulate to confirm 10.8 ppgmud spacer, spacer to surface 02:30 - 03:00 0.50 STKOH C PROD1 Batch mix form-a-plug, circulate wellbore 03:00 - 03:30 0.50 STKOH C PROD1 Circulate and spot form-a-plug from 10,750' to 10,475' as per program 03:30 - 04:00 0.50 STKOH C PROD1 Pull out of plug at cotrolled speed, trip out to 10,400' 04:00 - 06:30 2.50 STKOH C PROD1 Break circulation, pump 50 bbls mud to clean pipe, POOH to casing shoe at 5585' 06:30 - 09:00 2.50 STKOH C PROD1 Wait on form-a-plug to set 09:00 - 10:30 1.50 STKOH C PROD1 Trip in to 10,200' 10:30 -11:30 1.00 STKOH C PROD1 Break circulation, wash from 10,200' to 10,575' Printed: 7/15/2002 8:52: 33 AM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-113 S-113 DRILL +COMPLETE DOYON DOYON 14 Start: 6/16/2002 Rig Release: 7/13/2002 Rig Number: Spud Date: 6/17/2002 End: 7/13/2002 7/212002 10:30 -11:30 1.00 STKOH C PROD1 No indication of plug 11 :30 - 12:00 0.50 STKOH C PROD1 Trip out to 10,525' 12:00 - 17:00 5.00 STKOH C PROD1 Circulate form-a-plug to surface, overboard 110 bbls, circulate and condition mud, offload mud from trucks to mud tanks 17:00 - 17:30 0.50 STKOH C PROD1 Spot balanced kick off plug from 10,575' to 10,150' as per program 17:30 - 18:30 1.00 STKOH C PROD1 Trip out of plug at cotrolled speed to 9850' 18:30 -19:30 1.00 STKOH C PROD1 Break circulation, drop pipe wiper ball, pump ball out mule shoe, flow check, pump slug 19:30 - 23:30 4.00 STKOH C PROD1 Trip out, lay down 30 singles of excess drillpipe 23:30 - 00:00 0.50 STKOH C PROD1 Clear / clean rig floor of tools, function blind rams 7/3/2002 00:00 - 02:30 2.50 STKOH C PROD1 PU, MU, directional BHA #5, bit, motor set at 1.5 degree, adjustable stablizer, function test AGS, install MWD probe 02:30 - 05:00 2.50 STKOH C PROD1 Trouble shoot MWD, upload MWD 05:00 - 05:45 0.75 STKOH C PROD1 PU, MU, NMDCs, surface test MWD 05:45 - 06:30 0.75 STKOH C PROD1 PJSM, load MWD w/ nuclear sources 06:30 - 08:30 2.00 STKOH C PROD1 Trip in to casing shoe at 5587' 08:30 - 09:30 1.00 STKOH C PROD1 Rig service, slip / cut drilling line, service top drive 09:30 - 11 :30 2.00 STKOH C PROD1 WOC, circulate and condition mud 11:30 -13:30 2.00 STKOH C PROD1 Trip in to 10,000', fill pipe every 30 stands 13:30 -14:00 0.50 STKOH C PROD1 Wash down from 10,000' to 10,045', tag cement, Cement plug compressive strength held 20,000 Ibs WOB Ë"¿' ~ Drill cement from 10,045' to 10,095' S.\\3 Circulate and record drilling parameters 14:0'0 - 21:00 7.00 'DRI[C""'C--"" -,_'°....--'.. . 'p'RõI52""~~Õrrect¡oñaï drill from 10,095 to 1 0,437' Directional drill off "kick off plug" with no time drilling 21 :00 - 22:00 1.00 DRILL C PROD2 Change out mud while drilling, transfer truck pump could not keep up to drilling rate, circulate at a reduced rate during transfer of mud to rig tank 22:00 - 00:00 2.00 DRILL C PROD2 Directional drill from 10,437' to 10,604' AST 1.83, ART 2.56, ADT 4.39 7/4/2002 00:00 - 12:00 12.00 DRILL C PROD2 Directional drill side track # 1, 97/8" production well bore From 1 0,604' to 11,700' AST 3.35, ART 4.94, ADT 8.29 12:00 - 12:30 0.50 DRILL C PROD2 Directional drill from 11,700' to 11,725' Circulate sweep in wellbore 12:30 - 13:30 1.00 DRILL C PROD2 Circulate sweep to surface, 50 % increase in cuttings SPRs, flow check 13:30 - 14:30 1.00 DRILL C PROD2 Wiper trip from 11,725' to 10,125', flow check Wellbore in good condition 14:30 - 00:00 9.50 DRILL C PROD2 Directional drill from 11 ¡725' to 12,345' Control drill from 12,345' to 12,540', 90 ft / hr Wellbore in good condition, slight gas at shakers AST 1.33, ART 4.82, ADT 6.15 7/5/2002 00:00 - 01 :30 1.50 DRILL C PROD2 Directional drill sidetrack # 1, 97/8" production wellbore From 12,540' to 12,640', TD Wellbore in good condition AST 0.0, ART 1.18, ADT 1.18 01 :30 - 03:30 2.00 DRILL C PROD2 Circulate / condition mud, raise mud weight from 10.1 + to 10.2+, gas cut mud at surface, SPRs 03:30 - 04:30 1.00 DRILL C PROD2 Wiper trip from 12,640' to 11,600', wellbore in good Printed: 7/1512002 8:52:33 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( Page 7 of 11 BPEXPLORA TION Operations.' Summary Report S-113 S-113 DRILL +COMPLETE DOYON DOYON 14 Start: 6/16/2002 Rig Release: 7/13/2002 Rig Number: Spud Date: 6/17/2002 End: 7/13/2002 7/512002 7/6/2002 717/2002 b é")J ~ s~ \ r3A 7/8/2002 03:30 - 04:30 04:30 - 05:30 05:30 - 07:30 07:30 - 08:00 08:00 - 09:30 09:30 - 14:00 14:00 - 15:30 15:30 -19:00 19:00 - 20:30 20:30 - 21 :30 21 :30 - 00:00 00:00 - 02:30 02:30 - 04:00 04:00 - 05:00 05:00 - 06:00 06:00 - 07:30 07:30 - 08:30 08:30 - 09:00 09:00 - 12:00 12:00 - 13:00 13:00 -14:00 14:00 - 15:30 15:30 - 17:30 17:30 - 18:30 18:30 - 23:00 23:00 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 04:00 04:00 - 04:30 04:30 - 07:00 07:00 - 07:30 07:30 - 12:30 12:30 - 14:30 14:30 - 16:00 16:00 - 17:30 17:30 - 19:00 19:00 - 20:00 20:00 - 00:00 00:00 - 12:00 - 1.00 DRILL C 1.00 DRILL C 2.00 DRILL C 0.50 DRILL C 1.50 DRILL C 4.50 DRILL C 1.50 DRILL C 3.50 DRILL C 1.50 STKOH C 1.00 STKOH C 2.50 STKOH C 2.50 STKOH C 1.50 STKOH C 1.00 STKOH C 1.00 STKOH C 1.50 STKOH C 1.00 STKOH C 0.50 STKOH C 3.00 STKOH C 1.00 STKOH C 1.00 STKOH C 1.50 STKOH C 2.00 STKOH C 1.00 STKOH C 4.50 STKOH C 1.00 STKOH C 1.00 STKOH C 0.50 STKOH C 2.50 STKOH C 0.50 DRILL C 2.50 DRILL C 0.50 DRILL C 5.00 DRILL C 2.00 DRILL C 1.50 DRILL C 1.50 DRILL C 1.50 DRILL C 1.00 DRILL C 4.00 DRILL C 12.00' DRICLC~-"~"'''--- PROD2 condition, flow check, wellbore static, PROD2 Circulate bottoms up, gas cut mud PROD2 Circulate I condition mud, raise mud weight from 10.2+ to 10.3+ PROD2 Circulate for SPRs, flow check, wellbore static PROD2 Trip out, tight at 9903' PROD2 Back ream tight wellbore from 9903' to 9800', work tight hole from 7500' to 5587', casing shoe PROD2 Pump slug, trip out from casing shoe to BHA PROD2 Flush BHA, rack jars, NMDCs, PJSM, remove sources, download MWD, LD MWD, motor, bit PROD2 MU mule shoe, trip in to 5587', casing shoe PROD2 Rig service, slip / cut drilling line, service top drive PROD2 Trip in, break circulation every 20 stands, wash from 12,000' at 6 bpm at 650 psi to bottom, Wash from 12,000' to 12,640' Circulate bottoms up, 600 gpm at 1650 psi Spot P&A plug, 12,640' to 11,840', as per program Pull 1 stand at 5 minutes I stand, pull next stands at 3.5 minutes / stand PROD2 Circulate bottoms up, PROD2 Spot 307 bbls of mud spacer, 11,840' to 10,185', as per program PROD2 Pull 1 stand at 5 minutes I stand, pull next stands at 3.5 minutes / stand, PROD2 Circulate bottoms up, confirm mud spacer, 5 bbls of spacer to surface PROD2 Spot 35 bbls of M I, form-a-plug, 10,185' to 9,740', as per program PROD2 Pull 1 stand at 5 minutes / stand, pull next stands at 3.5 minutes / stand Trip out to casing shoe at 5587' Wait on form-a-plug to set Trip in to 9700' Wash from 9700' to 10,025', circulate form-a-plug out, overboard 210 bbls mud, circulate / condition mud Spot kick off plug, 10,025'to 9,600', as per program POH w/ OEDP to 9,272 ft Drop DP wiper ball and displace out of DP POH w/OEDP. Pull wear bushing, RU to test BOPE Test BOPE to BP & AOGCC regs RD test equip. Run wear bushing MU 9 7/8" bit, MM, MWD / LWD. Load same. Surface test same O-K PROD3 RIH w/9 7/8" bit to 103/4" shoe @ 5,620 ft. PROD3 Circ & cond mud. WOC PROD3 Con't RIH to 9,136 ft PROD3 Circ & cond mud. WOC PROD3 Wash 9,136 - 9,518 ft. TOC ".. .PROD~.~._. Dress Qff cmt phJ.R9,518.- 9,70q.__.- _. . PROD3 Directional drill sidetrack # 2, 97/8" production wellbore From 9700' to 10,187', well bore in good condition PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD3 PROD3 PROD3 PROD3 Printed: 7/1512002 8:52: 33 AM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 5-113 5-113 DRILL +COMPLETE DOYON DOYON 14 Start: 6/16/2002 Rig Release: 7/13/2002 Rig Number: Spud Date: 6/17/2002 End: 7/13/2002 7/812002 00:00 - 12:00 12.00 DRILL C PROD3 AST 6.81, ART 1.69, ADT 8.50 12:00 - 00:00 12.00 DRILL C PROD3 Directional drill from 10,187' to 10,889' Wellbore in good condition wI additions of new mud AST 2.61, ART 3.61, ADT 6.22 7/9/2002 00:00 - 06:00 6.00 DRILL C PROD3 Held PJSM. Drilled 9-7/8" Directional Hole by Rotating and Sliding from 10,889' to 11,626'. WOB 15,000# - 20,000#, RPM 80, Motor RPM 215, Torque Off Bottom 21,000 ft Ilbs, Torque On Bottom 24,500 ft Ilbs, Pump Rate 650 gpm, SPP Off Bottom 2,950 psi, On Bottom 3,100 psi. ART = 3.01 hrs, AST 1.30 hrs. 06:00 - 07:00 1.00 DRILL C PROD3 Pumped and Circulated Around Hi-Vis Sweep. Pump Rate 650 gpm, 2,900 psi. Circulated until Returns over Shaker were Clean. 07:00 - 09:30 2.50 DRILL C PROD3 Held PJSM. Made Wiper Trip from 11,626' to 10-3/4" Shoe at 5,587'. Worked Through Tight Spots @ 9,350',9,000',8,900', 8,330'. Maximum Drag 100,000#, Average Drag 75,000# 09:30 - 10:30 1.00 DRILL C PROD3 Held PJSM. Slipped and Cut Drilling Line. 10:30 - 12:00 1.50 DRILL C PROD3 RIH after Wiper Trip from 5,587' to 11,626'. No Fill. 12:00 - 00:00 12.00 DRILL C PROD3 Held PJSM. Drilled 9-7/8" Directional Hole by Rotating and Sliding from 11,626' to 12,585'. WOB 15,000# - 20,000#, RPM 80, Motor RPM 215, Torque Off Bottom 18,000 ft I Ibs, Torque On Bottom 21,500 ft Ilbs, Pump Rate 650 gpm, SPP Off Bottom 2,950 psi, On Bottom 3,200 psi. ART = 4.04 hrs, AST = 2.47 hrs. 7/10/2002 00:00 - 12:00 12.00 DRILL P PROD3 Held PJSM. Drilled 9-7/8" Directional Hole by Rotating and Sliding from 12,585' to 13,515'. WOB 8,000# - 20,000#, RPM 75 - 85, Motor RPM 215, Torque Off Bottom 19,500 ft Ilbs, Torque On Bottom 22,000 ft Ilbs, Pump Rate 650 gpm, SPP Off Bottom 3,000 psi, On Bottom 3,250 psi. ART = 7.85 hrs, AST = 1.28 hrs. 12:00 - 13:30 1.50 DRILL P PROD3 Held PJSM. Pumped and Circulated around 25 bbl Hi-Vis Sweep. Pump Rate 15 bpm, 2,900 psi. Circulated until Returns over Shaker were Clean. 13:30 -15:00 1.50 DRILL P PROD3 Flow Checked Well, Well Static. Made Wiper Trip from 13,515' to 9,600'. No Overpull, Average Drag 15,000#. 15:00 - 16:30 1.50 DRILL P PROD3 Flow Checked Well, Well Static. RIH after Wiper Trip from 9,600' to 13,515'. No Fill. 16:30 - 19:30 3.00 DRILL P PROD3 Pumped and Circulated around 35 bbl Hi-Vis Sweep. Pump Rate 15 bpm, 2,900 psi. Circulated until Returns over Shaker were Clean. 19:~0 - 20:00 0.50 DRILL P PROD3 Pumped and Spotted 200 bbl Casing Running Pill on bottom. Pump Rate 10 bpm, 1,500 psi. Flow Checked Well, Well Static. 20:00 - 21 :30 1.50 DRILL P PROD3 Held PJSM. POOH from 13,515' to 12,850'. LID 21 jts of 5" DP. Pipe Pulled Wet. POOH from 12,850' to 10,500', Racked 5" DP in Derrick. No Overpull, Average Drag 20,000#. 21 :30 - 23:30 2.00 DRILL P PROD3 Pumped and Spotted 520 bbl Casing Running Pill at 10,500'. Pump Rate 10 bpm, 1,200 psi. Flow Checked Well, Well Static. 23:30 - 00:00 0.50 DRILL P PROD3 POOH, LID 5" DP to 9,600'. No Overpull, Average Drag 20,000#. 7/11/2002 00:00 - 03:30 3.50 DRILL P PROD3 Held PJSM. POOH, LID 5" DP to 5,200'. 03:30 - 04:00 0.50 DRILL P PROD3 RIH wI 25 stands from Derrick. 04:00 - 08:30 4.50 DRILL P PROD3 POOH, LID 5" DP to 230'. 08:30 - 09:00 0.50 DRILL P PROD3 Held PJSM. Slipped Drilling Line. Printed: 7/1512002 8:52:33 AM ( ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-113 S-113 DRILL +COMPLETE DOYON DOYON 14 Start: 6/16/2002 Rig Release: 7/13/2002 Rig Number: Spud Date: 6/17/2002 End: 7/13/2002 7/11/2002 09:00 - 10:00 1.00 DRILL P PROD3 Held PJSM. Cleared Rig Floor, Sperry Sun removed Radioactive Sources from Tools. 10:00 - 11 :00 1.00 DRILL P PROD3 Broke out and L / D Directional BHA. 11 :00 - 11 :30 0.50 CASE P PROD3 M I U Retrieving Tool. RIH, Latched and Pulled Wear Bushing. L / D Retrieving Tool. 11 :30 - 14:00 2.50 CASE P PROD3 Held PJSM. R I U 7" Casing Equipment. Loaded Drillers Side wI remaining 7" Casing. 14:00 - 14:30 0.50 CASE P PROD3 M I U Shoe Jt and Float Collar Jt. BakerLock'd Connections. 14:30 - 19:30 5.00 CASE P PROD3 RIH w/135 jts 7" 26# L-80 BTC-M Casing to 5,587'. M / U Torque 7,000 ft /Ibs. 19:30 - 21 :00 1.50 CASE P PROD3 Broke Circulation and Circulated Bottoms Up. Pump Rate 8 bpm, 580 psi. Circulated back abundant Sand and Cuttings. Circulated Until Returns over Shaker were Clean. String Weight Up 142,000#, String Weight Down 110,000# 21 :00 - 00:00 3.00 CASE P PROD3 RIH w/ a total of 201 jts 7" 26# L-80 BTC-M Casing to 8,100'. Circulated down as a Precaution Jt#185 - Jt#196, 7,400'-7,900'. Pump Rate 6 bpm, 440 psi, Running Rate 6 min / Jt, while Circulating. M I U Torque 7,000 ft Ilbs. String Weight Up 185,000#, String Weight Down 112,000#. Circulated back abundant Sand. Circulated until Returns over Shakers were Clean. 7/12/2002 00:00 - 07:00 7.00 CASE P PROD3 RIH w/ a total of 333 jts 7" 26# L-80 BTC-M Casing to 13,490'. Circulated down as a Precaution Jt#253 - Jt#267 , 10,100'-10,800'. Pump Rate 6 bpm, 600 psi, Running Rate 6 min / Jt while Circulating. M / U Torque 7,000 ft /Ibs. Circulated back abundant Sand and Cuttings. 07:00 - 07:30 0.50 CASE P PROD3 M I U Landing Jt and 7" Casing Hanger. 7" Casing Set As Follows: Item Length Depth Float Shoe 1.64' 13,490.00' 2 Jts 7" 26# L-80 BTC-M Csg 82.79' 13,406.37' Float Collar 1.10' 13,405.27' 5 Jts 7" 26# L-80 BTC-M Csg 202.11' 13,203.16' 2-7" 26# L-80 BTC-M Mkr Pups 40.45' 13,162.71' 326 Jts 7" 26# L-80 BTC-M Csg 13,127.04' 35.67' 7" Casing Hanger 1.87' 33.80' 07:30 - 10:00 2.50 CEMT P PROD3 Held PJSM wI Dowell Crews,. Rig Crews and Peak Truck Drivers. Circulated to Condition and Cool the Hole. Pump Rate 11 bpm, 850 psi. 10:00 - 12:00 2.00 CEMT P PROD3 Switched over to Dowell. Pumped 5 bbls of CW 100 to Clear the Lines of Air. Shut in Cement Manifold and Tested Lines to 3,500 psi, OK. Pumped 35 bbls of CW 100 Chemical Wash at 4.0 bpm, 575 psi. Pumped 40 bbls of MudPush at 4 bpm, 600 psi. Dropped Bottom Plug, Pumped 105 bbls (510 sx) 15.8 ppg Premium Cement w/ 0.002% bwoc Retarder, 0.04% bwoc Dispersant, 0.20 gaVsk AntiFoam and 2.00 gal/sk GASBLOK. Pumped Cement at the Following Rates: Pumped Rate Pressure 20.0 bbls 6.00 bpm 1 ,138 psi 40.0 bbls 6.00 bpm 980 psi 60.0 bbls 6.00 bpm 857 psi 80.0 bbls 6.00 bpm 853 psi 100.0 bbls 6.00 bpm 845 psi Printed: 7/15/2002 8:52:33 AM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-113 S-113 DRILL +COMPLETE DOYON DOYON 14 Start: 6/16/2002 Rig Release: 7/13/2002 Rig Number: Spud Date: 6/17/2002 End: 7/13/2002 7/12/2002 10:00 - 12:00 2.00 CEMT P PROD3 105.0 bbls 2.50 bpm 117 psi Cleaned up and Flushed Cement Lines. Dropped Top Plug, Switched to Rig Pumps and Displaced wI 510 bbls of Sea Water at the Following Rates: Pumped Rate Pressure 5.0 bbls 10.0 bpm 250 psi 100.0 bbls 10.0 bpm 600 psi 200.0 bbls 10.0 bpm 700 psi 300.0 bbls 10.0 bpm 720 psi 400.0 bbls 10.0 bpm 850 psi 450.0 bbls 10.0 bpm 1 ,200 psi 480.0 bbls slw'd pmps 5.0 bpm 990 psi 500.0 bbls 5.0 bpm 1,210 psi Wiper Plug Bumped w/510 bbls Pumped. Pressured up to 3,000 psi to Test Casing, Held f/10 minutes, OK. Cement in Place @ 1200 Hrs. Bled off Pressure, Floats Held. 12:00 - 13:30 1.50 CEMT P PROD3 Held PJSM. RID Cement Head and Lines. Broke out and LID Landing Joint. 13:30 - 14:30 1.00 WHSUR P PROD3 Ran and Set 7" Packoff. Tested Packoff to 5,000 psi f/1 0 minutes, OK. 14:30 - 18:30 4.00 EVAL P COMP Held PJSM wI Rig Crews, Halliburton Slickline Crew and Little Red Crew. R I U Slickline. RIH wI 6.00" Gauge Ring and Junk Basket to 13,397', Float Collar @ 13,405.27'. POOH wI Gauge Ring on Slickline. Simops - R I U and Pumped Down 9-5/8" x 7" Annulus at 1.5 bpm, Formation Broke Down at 700 psi. Established Injection Rate of 4 bpm at 900 psi. R I U Little Red Hot Oil Unit. Tested Lines to 3,500 psi. Bullheaded 130 bbls of Dead Crude Oil Down Annulus to Freeze Protect. 18:30 - 19:00 0.50 EVAL P COMP RID Halliburton Slickline and Little Red Hot Oil Unit. 19:00 - 20:00 1.00 RUNCOtItP COMP Held PJSM. R I U Equipment to Run 3-1/2" Completion. 20:00 - 20:30 0.50 RUNCOtItP COMP M I U 3-1/2" Tail Pipe and Packer Assemblies. M I U Torque 2,750 ft Ilbs. BakerLocked All Connections Below Packer. 20:30 - 00:00 3.50 RUNCOt\P COMP RIH wI 3-1/2" 9.3# L-80 IBT Tubing. Average M I U Torque 2,250 ft I Ibs. 81 jts, 2,725', Ran at Report Time. 7/13/2002 00:00 - 09:30 9.50 RUNCOfItP COMP Held PJSM. RIH wI a Total of 406 jts 3-1/2" 9.3# L-80 1ST Tubing. Average M I U Torque 2,250 ft Ilbs. 09:30 - 11 :00 1.50 RUNCOtItP COMP M I U Tubing Hanger and Landing Joint. Landed Tubing Hanger in Wellhead, RILDS. Completion Equipment Set at the Following Depths: Item WLEG X Nipple Assembly X Nipple Assembly 7" x 3-1/2 8-3 Packer Assembly X Nipple Assembly 1 Jt 3-112" 9.3# IBT L-80 Tbg #1 GLM Assembly wI RP Shr Vlv 2 Jts 3-1/2" 9.3# IBT L-80 Tbg #2 GLM Assembly Length 21.71' 20.40' 27.14' 20.72' 31.19' 28.31' 62.19' 28.20' Depth 12,944.00' 12,897.25' 12,870.11' 12,849.39' 12,818.20' 12,789.89' 12,727.70' 12,699.50' Printed: 7/1512002 8:52:33 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 5-113 5-113 DRILL +COMPLETE DOYON DOYON 14 Start: 6/16/2002 Rig Release: 7/13/2002 Rig Number: Spud Date: 6/17/2002 End: 7/13/2002 7/13/2002 09:30 - 11 :00 1.50 RUNCOf\ P COMP 49 Jts 3-1/2" 9.3# IBT L-80 Tbg 1,536.70' 11,162.80' #3 GLM Assembly 28.23' 11,134.57' 141 Jts 3-1/2" 9.3# IBT L-80 Tbg 4,406.01' 6,728.56' #4 GLM Assembly 28.25' 6,700.31' 139 Jts 3-1/2" 9.3# IBT L-80 Tbg 4,325.45' 2,374.86' X Nipple Assembly 20.72' 2,354.14' 74 Jts 3-1/2" 9.3# IBT L-80 Tbg 2,323.43' 30.71' Tubing Hanger 4.65' 28.71' 11 :00 - 13:30 2.50 RUNCOf\P COMP Held PJSM. R / U Circulating Equipment. Reverse Circulated 350 bbls of Corrosion Inhibited Clean Sea Water Down 7" x 3-1/2" Annulus. Pump Rate 3 bpm, 390 psi. 13:30 -15:30 2.00 RUNCOfvP COMP Held PJSM. Dropped BallI Rod Assembly. Pressured up on Tubing to 2,500 psi to set Packer. Tested Tubing to 3,500 psi f/ 30 Minutes. OK. Bled Tubing Pressure Down to 1,500 psi. Pressure Tested IA to 3,500 psi fl 30 Minutes, OK. Bled Down Tubing Pressure Sheared RP Valve. Bled Down All Pressure. 15:30 - 16:00 0.50 RUNCOfvP COMP Cleaned and Cleared Rig Floor. 16:00 - 16:30 0.50 WHSUR P COMP Set TWC in Tubing Hanger Profile. Tested TWC from Below to 2,900 psi. 16:30 - 19:30 3.00 BOPSURP COMP Held PJSM. Opened Ram Doors and Cleaned out Ram Cavities. N I D BOPE. 19:30 - 21:00 1.50 WHSUR P COMP Held PJSM. N I U Adapter Flange and Production Tree. FMC Tested Adapter Flange to 5,000 psi f/1 0 minutes. R I U and Tested Tree to 5,000 psi, OK. 21 :00 - 21 :30 0.50 WHSUR P COMP Held PJSM. R / U DSM Lubricator, Pulled TWC. RID DSM 21 :30 - 22:30 1.00 WHSUR P COMP Held PJSM. R / U Little Red Hot Oil. Tested Lines to 3,000 psi, OK. Pumped 95 bbls of Diesel Down 7" x 3-1/2" Annulus to Freeze Protect. Pump Rate 2.5 bpm, 1,100 psi. 22:30 - 23:30 1.00 WHSUR P COMP R / U Lines and U-Tubed Diesel between IA and 3-1/2" Tubing. Freeze Protected IA and Tbg to 2,500'. 23:30 - 00:00 0.50 WHSUR P COMP Removed 2nd Annulus Valve, Installed Tree Cap & Gauges. Installed Blind Flange on Annulus Valve. Secured Well. Released Rig @ 23:59 Hrs, 07 113 / 2002. Printed: 7/1512002 8:52:33 AM { Well: Field: API: Permit: S-113B Prudhoe Bay Unit 50-029-23094-02 202-143 Rig Accept: 06/17/02 Rig Spud: 06/17/02 Rig Release: 07/13/02 Drilling Rig: Doyon 14 POST RIG WORK 07/25/02 PULLED BALL & ROD FROM RHC BODY. 07/26/02 PULLED 2.81" RHC PLUG BODY. DRIFTED WITH 2.5" X 10' DUMMY GUN. TAGGED TD @ 13362' WLM. (TARGET DEPTH=13038'+). LEFT WELL SHUT IN. NOTIFIED OPER. PUMP 295 BBLS CRUDE FOLLOWED BY 194 BBLS DIESEL DOWN TUBING TAKING RETURNS UP IA AND TO PRODUCTION SYSTEM TO LOAD TUBING & IA. 07/28/02 PERF 13014-13038 FT MD WITH 2.5" HSD @ 4 SPF ( ALTERNATING 2506 HYPERJET AND 2506 POWERFLOW CHARGES). PHASED 180 DEGS, ORIENTED 90 DEGS OFF BOTTOM. ALL SHOTS FIRED. WHP WHEN SHOT = 50 PSI, WHP IN 1 HOUR = 550 PSI. SCMT TAGGED AT 13349 FT MD. CEMENT SEEN IN VARYING QUALITY FROM FIRST READING AT 13336 FT MD TO T TAIL AT 12932 FT MD. VERY GOOD CEMENT WAS SEEN FROM 13196 - 13270 FT MD AND FROM T TAIL AT 12932 - 13005 FT MD. PAD OPERATOR INFORMED - LEAVE WELL SHUT IN. 07/29/02 RUN PETRADAT GAUGES FOR SBHPS. STOP @ 13040' (6700' TVD) = 2971.4 I 2974.3. STOP @ 12930' (6600' TVD) = 2927.8 I 2930.4. CORRECTED TO MD. RAN 31/2" CATCHER. MISSET. RAN 3 1/2" GS TO PULL CATCHER. 07/30/02 SET SLIP STOP CATCHER. PULL BOTTOM STA -- RP SHEAR VLV, RK. SET BOTTOM STA -- SIDE POCKET MEMORY GAUGE. PULL CATCHER. MITIA TO 3500 PSI FOR 30 MIN. TEST PASSED. 07/31/02 DISPLACE DIESEL FROM WB WI SLICK WATER. PERFORM SRT. DISPLACE SLICK WATER WI X-LINK 25# LG FLUID @ 10 BPM. INCREASE RATE WHEN PAD ON PERFS AND PUMP 200 BBL DATA FRAC. SD AND MONITOR FALL OFF. FLUID EFF = 32%, CLOSURE TIME- 6.5 MIN. RE-DESIGN JOB WI 150 BBL PAD. PUMP JOB @ 20 BPM START WI 1 PPA 16/20 CARBO-LITE. RAMP TO 4 PPA FLAT STAGE. RAMP TO 6 PPA FLAT STAGE. STEP TO 8 PPA FLAT STAGE SWAP TO 12/18 CARBO-LITE 162 BBLS INTO STAGE AND PUMPED AND ADDITIONAL 68 BBLS 12/188#. SCREENED OUT ON 9 PPA FLAT STAGE. PLACED 78,492# BEHIND PIPE 4,000# WAS 12/18 PROP 8# ON PERF. AVERAGE PRESSURE 6200 PSI. LEFT 31,667# 12/18 PROP IN THE WELL. 08/01/02 POST FRACISCREEN OUT CLEAN OUT. MI/RU COIL UNIT 5. MIU 2" JET SWIRL NOZZLE & CLEANOUT 3 1/2" TBG TO 12,875'. CHASE SWEEP TO SURFACE. RBIH WI 2" JET SWIRL NOZZLE. CLEAN OUT 7" TO 13150' CTD. SWEEP WITH 1.5# BIO, AND FLOPRO. CHASE TO SURFACE AT 50% CLEANING GLM'S. 08/02/02 POST FRAC CLEAN-OUT. POOH AFTER CIO TO 13150' CTD. FREEZE PROTECT TO 4500' WITH 50/50 METH. STAND BACK MAST, WAIT FOR SIL TO RUN CS AND PULL BOTTOM SPMG. CATCHER SUB SET & BOTTOM SPMG RETRIEVED OK. WELL SHUT IN ON ARRIVAL. RIG UP NEXT TO CTU. SET 3112 X - CS @ 12868' SLM. PULL SPMG STA 1. PULL DGL V'S ST A 3 & 4. SET LGL V'S ST A 3 -4. ATTEMPTED TO SET SIO BUT PULLED IT BACK OUT OF POCKET. S-113B, Post-Rig Work Page 2 DS OPERATOR NOTIFIED, WELL LEFT SHUT IN WI SLlCKLlNE RIGGED UP. 08/03/02 CONTINUE OOH WI KOT. VALVE NOT SET @ STA #1. WOBBLE RING HUNG UP WI SAND. CHECK VALVE. CHANGE OUT LATCH. SET @ 12767' SLM. PULLED 3-1/2" XCATCHER SUB @ 12868' SLM. RIG DOWN. SECURED WELL. NOTIFIED DSO OF WELL STATUS. APC TO RIG UP & TEST WELL. CJ,O~-J4 3 04-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well S-1138 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,659.25' MD Window / Kickoff Survey 9,700.00' MD (if applicable) Projected Survey: 13,515.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED td i~ 0 7 "002 iVv' ¡ j L Alaska Oil & Gas Cons. Commission Anchorage North Slope Alaska BPXA PBU_WOA S Pad, Slot 5-113 5-113B Job No. AKZZ22095, Surveyed: 10 July, 2002 ~"- SURVEY REPORT 2 August, 2002 Your Ref: API 500292309402 Surface Coordinates: 5980744.90 N, 618930.13 E (70021' 21.7672" N, 149002' 02.8638" W) Kelly Bushing: 70.33ft above Mean Sea Level ~, Iii :.".., ....""Y-!iiUIl DRILLING SERVices A Halliburton Company Survey Ref: svy11238 Sperry-Sun Drilling Services . Survey Report for S-1138 Your Ref: API 500292309402 Job No. AKZZ22095, Surveyed: 10 July, 2002 BPXA North Slope Alaska PBU_WOA S Pad Measured Sub.Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9659.25 68.440 286.360 4826.88 4897.21 1766.42 N 7381.62 W 5982393.91 N 611521.40 E 5853.4 7 Tie On Point ~ 9700.00 68.440 286.290 4841.86 4912.19 ~ 1777.07 N 7417.99 W 5982403.98 N 611484.86 E 0.160 5881.45 Window Point 9731.79 65.120 285.750 4854.39 4924.72 1785.14 N 7446.07 W 5982411.60 N 611456.66 E 10.560 5903.13 9828.36 62.750 282.810 4896.83 4967.16 1806.55 N 7530.11 W 5982431.68 N 611372.29 E 3.674 5969.20 GG24 O~) (j 1 . GOO 280.090 4941.50 5011.83 1823.36 N 7613.04 W 5982447.16 N 611289.10E 2.786 6036.29 1001 ~J. ~)B G1.2E:>0 278.120 4987.19 5057.52 1836.64 N 7695.87 W 5982459.13 N 611206.07 E 1.846 6104.86 10114.67 60.630 275.080 5033.38 5103.71 1846.20 N 7778.43 W 5982467.37 N 611123.37 E 2.872 6174.80 10211.41 60.720 272.090 5080.76 5151.09 1851.47 N 7862.59 W 5982471.31 N 611039.13 E 2.696 6248.08 10306.01 59.810 268.440 5127.70 5198.03 1851.86 N 7944.72 W 5982470.40 N 610957.02 E 3.485 6321.67 10403.38 60.670 262.470 5176.06 5246.39 1845.15 N 8028.92 W 5982462.35 N 610872.93 E 5.395 6400.25 1049B.lU 61.5BO 256.200 5222.12 5292.45 1829.69 N 8110.88 W 5982445.59 N 610791.22 E 5.838 6480.66 10594.09 61.880 251.680 5267.32 5337.65 1806.45 N 8191.58 W 5982421.08 N 610710.90 E 4.185 6563.36 10691.60 62.020 248.040 5313.19 5383.52 1776.83 N 8272.36 W 5982390.17 N 610630.61 E 3.297 6648.94 10788.82 61 .900 243.450 5358.91 5429.24 1741.59 N 8350.56 W 5982353.70 N 610552.97 E 4.169 6734.67 10883.33 61.250 239.380 5403.91 5474.24 1701.85 N 8423.53 W 5982312.80 N 610480.64 E 3.849 6817.68 10978.88 62.360 235.940 5449.06 5519.39 1656.80 N 8494.66 W 5982266.63 N 610410.24 E 3.379 6901.37 1107509 G2.030 234.090 5493.95 5564.28 1608.01 N 8564.38 W 5982216.74 N 610341.30E 1.735 6985.44 11170.61 61 .880 235.560 5538.86 5609.19 1559.44 N 8633.28 W 5982167.09 N 610273.18 E 1.367 7068.68 ,~-~" 11266.04 61 . 1 80 234.180 5584.35 5654.68 1511.18 N 8701.89 W 5982117.73 N 610205.35 E 1.468 7151.52 11361.03 60.890 233.140 5630.35 5700.68 1461.93 N 8768.83 W 5982067.43 N 610139.19 E 1.005 7233.30 11457.88 60.990 234.100 5677.40 5747.73 1411.72 N 8836.99 W 5982016.14 N 610071.84 E 0.873 7316.59 11553.64 61 . 1 80 235.330 5723.70 5794.03 1363.30 N 8905.41 W 5981966.65 N 610004.20 E 1.142 7399.33 11650.35 61 .080 236.760 5770.39 5840.72 1316.00 N 8975.66 W 5981918.23 N 609934.71 E 1.299 7483.22 11743.98 60.630 236.380 5815.99 5886.32 1270.95 N 9043.91 W 5981872.11 N 609867.19 E 0.597 7564.32 11839.63 60.600 236.070 5862.93 5933.26 1224.61 N 9113.18 W 5981824.68 N 609798.65 E 0.284 7646.92 11936.24 60.280 234.960 5910.59 5980.92 1177.04N 9182.45 W 5981776.01 N 609730.15 E 1.053 7730.05 12032.23 59.670 235.430 5958.62 6028.95 1129.60 N 9250.69 W 5981727.49 N 609662.67 E 0.764 7812.19 12129.81 57.130 235.870 6009.75 6080.08 1082.70 N 9319.30 W 5981679.51 N 609594.82 E 2.631 7894.43 12225.46 54.090 236.260 6063.77 6134.10 1038.64 N 9384.78 W 5981634.42 N 609530.05 E 3.196 7972.61 12319.58 52.230 237.840 6120.20 6190.53 997.66 N 9447.97 W 5981592.44 N 609467.51 E 2.390 8047.39 _.~~--.--~~--~ ~ -~_.'-----~------ 2 August, 2002. 10:59 Page 2 0'4 Dril/Quest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for S-1138 Your Ref: API 500292309402 Job No. AKZZ22095, Surveyed: 10 July, 2002 BPXA North Slope Alaska PBU WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 12415.09 47.430 239.470 6181.79 6252.12 959.68 N 9510.26 W 5981553.48 N 609405.83 E 5.192 8120.04 12511.30 4 1 .7 50 240.990 6250.28 6320.61 926.12 N 9568.84 W 5981518.99 N 609347.79 E 6.007 8187.40 12606.61 37.240 241.920 6323.81 6394.14 897.14 N 9622.06 W 5981489.17 N 609295.04 E 4.772 8247.95 12703.28 33.180 242.620 6402.78 6473.11 871.20 N 9671.38 W 5981462.45 N 609246.14 E 4.220 8303.65 127~)ß.11 JO 110 2.15.630 6483.68 6554.01 849.40 N 9716.20 W 5981439.94 N 609201.67 E 3.632 8353.49 12893B] 27.930 ¿.Il.] 00 6567.18 6637.51 830.81 N 9758.62 W 5981420.68 N 609159.55 E 2.,W2 8399.77 12989.77 26.540 246.270 6652.50 6722.83 813.44 N 9798.96 W 5981402.66 N 609119.50 E 1.502 8443.63 13085.35 26.930 245.120 6737.86 6808.19 795.74 N 9838.14 W 5981384.35 N 609080.60 E 0.678 8486.60 13181.02 27.340 245. '130 6823.00 6893.33 777.38 N 9877.73 W 5981365.36 N 609041.31 E 0.429 8530.23 13276.23 27.050 244.930 6907.69 6978.02 759.01 N 9917.17 W 5981346.37 N 609002.16 E 0.319 8573.73 1337Uß 2C).lOO 244.550 6993.05 7063.38 740.55 N 9956.30 W 5981327.29 N 608963.33 E 0.407 8616.99 13444.18 26.370 245.330 7057.69 7128.02 726.88 N 9985.53 W 5981313.16 N 608934.32 E 0.664 8649.26 13515.00 26.370 245.330 7121.14 7191.47 713.75 N 10014.12 W 5981299.58 N 608905.94 E 0.000 8680.71 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to S-113. Northings and Eastings are relative to 5-113. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 5-113 and calculated along an Azimuth of 243.920° (True). ~~.: Based upon Minimum Curvature type calculations, at a Measured Depth of 13515.00f1., The Bottom Hole Displacement is 10039.52f1., in the Direction of 274.077° (True). ---.-----...-- 2 August, 2002 - 10:59 Page30f4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 5-1138 Your Ref: API 500292309402 Job No. AKZZ22095, Surveyed: 10 July, 2002 . North Slope Alaska BPXA PBU WOA S Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9659 ?r, ~/OU.UU 13515.00 4897.21 4912.19 7191.47 1766.42 N 1777.07 N 713.75 N 7381.62 W 7417.99 W 10014.12 W Tie On Point Window Point Projected Survey Survey tool program for 5-1138 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 861 .00 0.00 861.00 856.19 13515.00 856.19 Tolerable Gyro (8-113 GYRO) 7191.47 AK-6 BP _IFR-AK (8-113) '-"'" -----'--~-- - -~--_._._--_.._-~------_.~~~ -- 2 August, 2002 - 10:59 Page4of4 DríllQuest 2.00.08.005 ~oa-JY~ 04-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well S-1138 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,659.25' MD Window / Kickoff Survey 9,700.00' MD (if applicable) Projected Survey: 13,515.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUG 0 T 2002 Alaska Oil & Gas Cons. Commission Anchorage North Slope Alaska BPXA PBU_WOA 5 Pad, Slot 5-113 5-113B MWD Job No. AKMW22095, Surveyed: 5 July, 2002 SURVEY REPORT 2 August, 2002 Your Ref: API 500292309402 Surface Coordinates: 5980744.90 N, 618930.13 E (70021' 21.7672" N, 149002' 02.8638" W) Kelly Bushing: 70.33ft above Mean Sea Level '~":-' .~""""'Y-55U1! DFULLtNG SEAVlces A Halliburton Company Survey Ref: 5vy11260 Sperry-Sun Drilling Services . Survey Report for 5-1138 MWD Your Ref: API 500292309402 Job No. AKMW22095, Surveyed: 5 July, 2002 BPXA North Slope Alaska PBU WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9659.25 68.440 287.580 4826.93 4897.26 1748.76 N 7385.60 W 5982376.18 N 611517.70E 7339.66 lie UIl Point 9700.00 68.440 285.670 4841.90 4912.23 1759.60 N 7421.91 W 5982386.45 N 611481.22E 4.359 7375.69 Window Point 9731.79 65.120 285.450 4854.43 4924.76 1767.44 N 7450.05 W 5982393.84 N 611452.95 E 10.463 7403.63 9828.36 62.750 281.5ÔO 4896.88 4967.21 1787.72 N 7534.37 W 5982412.78 N 611368.33 E 4172 7487.41 9924.05 61.600 280.820 4941.54 5011.87 1804.14 N 7617.38 W 5982427.88 N 611285.06 E 1.383 7GGD.9D 1001958 61.260 277.000 4987.24 5057.57 1817.14N 7700.25 W 5982439.56 N 611202.01 E 3.530 7652.50 10114.67 60630 274.450 5033.43 5103.76 1825.43 N 7782.94 W 5982446.54 N 611119.19 E 2.43G 7734.96 10211.41 60.720 271740 5080.81 5151.14 1829.99 N 7867.15 W 5982449.76 N 611034.92 E 2.444 781 f)Jn 10306.01 59.810 269.320 5127.74 5198.07 1830.75 N 7949.28 W 5982449.22 N 610952.78 E 2.421 7001.12 10403.38 60.670 263.100 5176.10 5246.43 1825.15 N 8033.56 W 5982442.28 N 610868.60 E 5.615 7~JW).51 10498.70 61.580 ¿51.070 5222.17 5292.50 1810.77 N 8115.72 W 5982426.60 N 610786.68 E 5.621 SOfj!\. () 1 10594.09 61.880 251.410 5267.37 5337.70 1787.96 N 8196.53 W 5982402.51 N 610706.25 E 5.235 8149.36 10691.60 62.020 248.760 5313.23 5383.56 1758.65 N 8277.43 W 5982371.91 N 610625.82 E 2.403 8230.96 10788.82 61 .900 244.170 5358.95 5429.28 1724.40 N 8356.07 W 5982336.42 N 610547.74 E 4.169 8310.43 10883.33 61.250 239.640 5403.96 5474.29 1685.28 N 8429.37 W 5982296.14 N 610475.07 E 4.271 8384.69 10978.88 62.360 236.310 5449.11 5519.44 1640.62 N 8500.74 W 5982250.36 N 610404.41 E 3.284 8457.15 11075.09 62.030 234.170 5494.00 5564.33 1592.11 N 8570.65 W 5982200.74 N 610335.28 E 1.997 8528.25 11170.61 61.880 235.280 5538.91 5609.24 1543.43 N 8639.48 W 5982150.97 N 610267.24 E 1.038 8598.27 11266.04 61 .180 233.760 5584.40 5654.73 1494.74 N 8707.79 W 5982101.21 N 610199.71 E 1.581 8667.77 11361.03 60.890 233.250 5630.40 5700.73 1445.31 N 8774.60 W 5982050.72 N 610133.69 E 0.560 8735.80 11457.88 60.990 233.840 5677.44 5747.77 1395.01 N 8842.69 W 5981999.35 N 610066.41 E 0.542 8805.12 11553.64 61.180 234.820 5723.75 5794.08 1346.13 N 8910.79 W 5981949.39 N 609999.10 E 0.918 8874.42 11650.35 61 .080 236.180 5770.44 5840.77 1298.16 N 8980.58 W 5981900.32 N 609930.07 E 1.236 8945.39 11743.98 60.630 236.240 5816.04 5886.37 1252.68 N 9048.54 W 5981853.77 N 609862.84 E 0.484 9014.46 11839.63 60.600 235.620 5862.98 5933.31 1206.00 N 9117.58W 5981805.99 N 609794.55 E 0.566 9084.64 11936.24 60.280 234.760 5910.64 5980.97 1158.02 N 9186.58 W 5981756.93 N 609726.33 E 0.842 9154.82 12032.23 59.670 235.410 5958.67 6029.00 1110.46 N 9254.72 W 5981708.29 N 609658.94 E 0.865 9224.13 12129.81 57.130 236.020 6009.80 6080.13 1063.64 N 9323.38 W 5981660.39 N 609591.03 E 2.657 9293.94 12225.46 54.090 236.430 6063.81 6134.14 1019.76 N 9388.98 W 5981615.47 N 609526.14 E 3.198 9360.61 12319.58 52.230 237.720 6120.25 6190.58 978.81 N 9452.20 W 5981573.52 N 609463.58 E 2.260 9424.83 2 August, 2002 - 10:58 Page 20f4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 5-1138 MWD Your Ref: API 500292309402 Job No. AKMW22095, Surveyed: 5 July, 2002 . BPXA North Slope Alaska PBU WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 12415.09 47.430 240.090 6181.84 6252.17 941 .09 N 9514.64 W 5981534.82 N 609401.75 E 5.371 94BB.19 12511.30 41.750 241.140 6250.33 6320.66 907.93 N 9573.45 W 5981500.73 N 609343.47 E 5.953 9547.81 12606.61 37.240 241.460 6323.86 6394.19 878.82 N 9626.61 W 5981470.78 N 609290.78 E 4.737 9601.68 1270328 33180 2431/0 6402.83 6473.16 852.88 N 9675.92 W 5981444.06 N 609241.89 E 431 S CJGS1.ô2 12798.31 30.110 245.340 6483.72 6554.05 831 .17 N 9720.79 W 5981421.64 N 609197.37 E 3.455 UV)ì .02 12893.81 27.930 246.960 6567.23 6637.56 812.42 N 9763.14 W 5981402.22 N 609155.32 E 2.426 9739.83 12989.77 20540 245.840 6652.55 6722.88 794.85 N 9803.39 W 5981384.01 N 609115.36 E 1.544 SJ7BO.50 13085.35 26.930 244.730 6737.91 6808.24 776.87 N 9842.44 W 5981365.41 N 609076.59 E O.GG3 ~)ß 1 ~U)9 13181.02 27.340 244.840 6823.05 6893.38 758.28 N 9881.92 W 5981346.20 N 609037.42 E 0.432 9R59.92 13276.23 27.050 ::'4,+'510 6907.74 6978.07 739.67 N 9921.25 W 5981326.97 N 608998.39 E 0 . :34 3 ~)WYJ.70 13371.93 ¿6.1UU 24/+'51 U 6993.10 7063.43 721.05 N 9960.30 W 5981307.73 N 608959.64 E: O.Jlj() U:JJ<J.21 13444.18 26.370 245.370 7057.74 7128.07 707.38 N 9989.54 W 5981293.60 N 608930.62 E 0.701 9968.77 13515.00 26.370 245.370 7121.19 7191.52 694.27 N 10018.13 W 5981280.03 N 608902.24 E 0.000 9997.69 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to S-113. Northings and Eastings are relative to 8-113. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from S-113 and calculated along an Azimuth of 268.570° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13515.00ft., The Bottom Hole Displacement is 10042.16ft., in the Direction of 273.964° (True). 2 August, 2002 - 10:58 Page 30f4 DrillQtlest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S-1138 MWD Your Ref: API 500292309402 Job No. AKMW22095, Surveyed: 5 July, 2002 . North Slope Alaska BPXA PBU WOA S Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment - 9659.25 9700.00 13515.00 4897 26 4912.23 7191.52 1748.76 N 1759.60 N 694.27 N 7385.60 W 7421.91 W 10018.13 W Tie On Point Window Point Projected Survey Survey tool program for S-1138 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 861.00 0.00 861.00 856.19 13515.00 856.19 Tolerable Gyro (S-113 GYRO) 7191.52 MWD Magnetic (S-113 MWD) ..-,.. --------. - 2 August, 2002 - 10:58 Page 4 of4 DrillQuest 2.00.08.005 a o2).-1L/3 lO9~y WELL LOG TRANSMlTfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska August 16,2002 RE: MWD Fonnation Evaluation Logs S-113B, AK-MW-22095 1 LDWG fonnatted Disc with verification listing. API#: 50-029-23094-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~ I.t OOOf0 RECEIVED AUG 2 3 2002 AlaiœOiJ & Gas COns. cornrnaon Anchorage Schlumbel'ger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well L-103 dCk;), Igq S-112 ~O~- 1:\5 S-113 ~O~-Ic.. ~ -- Job# 22367 USIT 22368 USIT 22369 SCMT Log Description Date 08/06/02 08/03/02 07/28/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED AUG 20 2002 Alaska 011 & Gas Cons. Commissicn Anchorage NO. 2329 8/19/2002 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Wee pie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Color Borealis Aurora 2 2 2 Sepia BL CD Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TTN: Beth ReC~Y: ~tJ)OIlp<Å) bp ( .'. ,"f.'II. -..,~ ~...- ~..- ~...-- ..~ ~...... .,.,.".\- ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 12, 2002 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Tom: RE: Sundry Notice for S-113B Re-Perforations (permit #202-143). ) A re-perf is proposed in well S-113B using conductor line as soon as possible (est. 8/19/02). The existing 24' perfs are moderate quality reservoir but we're intentionally limited entry for the fracture treatment, so re-perforating at higher shot density and phasing is recommended. / If you have any questions, please contact Jim Young, Aurora Petroleum Engineer, at 564-5754 or by email atYoungj3@bp.com. Sincerely, \/ (' ~ fð', Jim Young \ Aurora Petroleum Engineer RECE~ E . I f"\ .~ -: '1002 ALl!:; ! -) t... . Alaska on & Gas Gons. COHHí1íSSIO¡' Anchorage Page 1 ORiGiNAL yJ6A- -~ oÇS> APPLICATION FOR SUNDRY APPROVALS 111310'- '¡I;,/~ cxf!¡s/O L STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Type of request: Abandon- Suspend- Alter casing - Repair well - Change approved program - 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 738' FNL, 783' FWL, Sec. 35, T12N, R12E, UM At top of productive interval 5211' FNL, 3748' FEL, Sec. 28, T12N, R12E, UM At effective depth 4'FNL,3904'FEL, Sec. 33, T12N, R12E,UM At total depth 25' FNL, 1331' FWL, Sec. 33, T12N, R12E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Intermediate Liner Size 20" Length 115' 5587' 13488' 10.75" 7" Perforation depth: I~-)% measured 13014' - 13038' true vertical 6744.51 - 6765.91 Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service- (asp's 618930, 5980745) (asp's 609106, 5981402) (asp's 608952, 5981328) (asp's 608907, 5981306) 13491 feet 11235 feet 13404 feet 111 89 feet Plugs (measured) Junk (measured) Cemented Driven 1584 saks Class G 550 saks Class G Tubing (size, grade, and measured depth 3-1/2",9.2#, L-80 Tubing at 12941' MD Packers & SSSV (type & measured depth) 7"X4-1/2" Baker 8-3 PKR at 12884' MD 13. Attachments Description summary of proposal _X 14. Estimated date for commencing ope ratio.'} August 19,2002 16. If proposal was verbally approved Re-enter suspended well - Time extension - Stimulate - Variance - Perforate_X 6. Datum elevation (DF or KB feet) RKB 70.3 feet 7. Unit or Property name Other - AURORA UNIT 8. Well numbe~ 8-113B 9. Permit number / approval number 202-143 10. API number 50-029-23094-02 11. Field/Pool ~~JSiðf1-1J.. AURORA PI:::::":) :PtÞI>/ Measured Depth 115' 5587' 13488' True vertical Depth 115' 3371' 7167' ~''"' ~ t~ AI In -1 ':' P,) it) ¡ ,) " t\"'-\ Alaska OB & GêiS Cons. Commission Anchorage Detailed operations program - 15. Status of well classification as: BOP sketch- Oil_X Gas- Suspended - Name of approver Date approved Service 17. I hereby certify t~ th~ foreglng is true and correct to the best of my knowledge. Signed ((¡#) ~ ~ WL...J Title: Production Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance -.' II Mechanical Integrity Test - Subsequent form required 10-40 T c~ C1clv).~ ~ \ G-.. \ 0 R,.w" \ Approved by order of the Commission Form 1 0-403 Rev 06/15/88 . Date 8/13/02 Prepared by Garry Catron 564-4657 I Approval no. 302..- 2.5? Commissioner ~ff'~ ~ Date L SUBMIT IN TRIPLICATE Well: Date: 5-113B """"""""""""""""""""""""""'''''''''',. 8/11/02 PERFORATING PROCEDURE Var 4.0 06104/01 API #: 50-029-23094-02 """""","''''''0''''"""""""",>", Prod Engr .~~!!I..Y~~.~.~.................... 1\ H2S Level: j¡ <1oppmll Office Ph: 564-5754 """,,,,,,,,,,,,,,,,,,,,,,,"'"'''''''>'''''''''''''''''''''''''>.>....... Home Ph: 248-0133 ,,,,,,,,,,,,,,,,,,,""''''0'''''''''''''''''''''''''''''''''''''''''''''''''' Cell/Pager: .,.,.,.,...,.,.............~.~.~.:~~~?,...............,.......,. CC or AFC: 5M0044 Detail Code: 9335-070-770 Description: :þ'~ç~::ï.::çq:Mþ':Ç$.t.)9.N:ï.::Þ.:~.!3.f.............................:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::............................................................................ WBL Entries Work Oesciption Perforate 20' underbalanced ../ >......,...........,>,>,....>.>.................................- lOR 200 Type E Well Objectives and Loaaina Notes: drift&tag 1st, may need HOT/brush&flush Attachment: Reference log with proposed perfs annotated, 5"/100' scale Reference Log Tie in Log Log: .MY.Y.P9.!3........ CCL Date: ......~'y?(?ggg, Company: .êp~tlY............. Depths (from-to) ........~.~.~.9.~..ê....... ......~.~.!.9~.ê..... "..........".,...............", ....,.,.""........,.,.....,. ...,.....,...",.,...,.,.",,,..., ......,."....,.",,,...,.,.,. ......,................""""", ",.,.""......",...,,,...,. """,.,.,.....,.,.,.,."........ .....................".,..... Gas Jetting Expected? Schlum Depths (from-to) Feet .....~..~!.9..1.ê.'...... - ......~..~~.9.?ê~..... 20' ,.........",.,....."..,..... ........,.",....."",.....". ""'"'''''''''''''''''''''''' '"'''''''''''''''''''''''''''' 5PF 6 ,.."..,.,...",.",...,...".. ,.."..,."...,..,..."..".". .".",.....,,,,.,,,.,,..,,..,,, ..,..................,.....,...' .............!':J.<?...u...... At what Depth? Requested Gun 5ize: ..........?:.!?:~."......... Charge: ,......~.?g?~.9.~.~.~~.~!.. Desired Penetration: >20" ,.....",...,."..,.,.,...............",. Is Drawdown Necessary/Desired/Unnecessary During Perforating Describe below how to achieve drawdown (check wi Pad Operator to see if necessary piping is installed) (e.g. N2 Lift, Hardline Lift Gas, Gas Lift, Flow Well, Backflow Through Drain or Hard/ine) Tie in to Jewelry @ Minimum ID: Tail Depth: Last Tag: ft MD on ....,,,......................,, Well: Date: 5-113B General Comments: API#: Depths Referenced to BHCS Balance O/B/U O/B/U O/B/U O/B/U O/B/U Tie in using: Min ID Type: Casing Size: Est Res. Pres. @ .....,.,.....,..,..,,,......,,, Peñoration Summary 50-029-23094-02 ,.......................,.."..,.......,,,,,.,..........,, Gun Dia. Orient. SPF Add 0 .....",.",.......,..-,.,..."""....",.".."" to the tie-in log to be on depth with the reference log. feet ".",.",...........,.,.,. Orient. Phasing 60 Zone Ad/Rellperf ........ç..........................I.P..~Œ................. ,,,,,..,.,...........,...,. .,...,...................",.......,........."",. "..,.............,........ ,.,.,.,."..,.....",...""..,....."",.,....." ,.,.,....",.......",.",."",.,.....".."..,."""...."",...,. ......,."....,.....,.,.,., """"""""""""""""""""""""" """".."..,.....""..",.....",,,.,.,.,,,,,,,,,...,,,.,.,.,.,. ,.........,,'...,...,...... ..,.,.,..."."...........,.,......."..",.."...., """'''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''. "...,.,,,.....,,............ .....,."........,.,.,...........,................. ..................",...",...,.....,...".....,....."............,.. N/A MAX Swell=2.72" in GAS Max Penetration Entry Hole Diam: .....;....................... .Y!!.!~.~..~.f~!!..~.<?I.~.~n.g!..çx.':!.~.~..~~.?~99p.~!..~~.P!..~~P.~.~~.~.9..~n~~r.þ.~!~n~~....... ...!~,§,qgP~!!..~!9~.~9~..1.~?n:~!n.':!~~~..~.<?..~!!.<?~..P~Œ..9.~.ÞEi.~..!.<?gl.~~~:.....................,........ SHORT JOINTS ''''''''''''''''''''MULTïpLjrX~ÑTppL:.1~su",,,,,,,,,,,,,,,,@,,,,,,,,,,,,,,,,,,,,,"';'MDu",,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, """""""j"""''''''ìïï'''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''' ................... :::j:~;9.9.9.::::: MD is ................?~99.. psi Prod Engr: Summary Oist Town: Anch Prod Engr P.O. Center PBTD Phasing Zone Aperf/Reperf 00 00 0 , ( (fù IT m 1T fP rmrrri re,' ¡!R\,,\,., ! ~, I'! F: .l\,\~' (QJ,~ r" ',r(', ¡ ¡jr:l!f\\\¡, \'\ 'I" /t L1 \ ',' ; Þ, LJ II ~'" u,. - '" ~ I~, ru J f:=' \ L!l II I ¡ í"n \ ¡ L Inn 'j ) ¡ ,!\ \ l, f. ~'\ \ ~ 'U U ',~ ~ L '-' w L....... W \ \,..:'.../ w wL 'w A.ItA.SKA OILAIVD GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 w. ¡tH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit S-113B BP Exploration (Alaska), Inc. Permit No: 202-143 Surface Location: 738' SNL, 783 EWL, Sec. 35, TI2N, RI2W, UM Bottomhole Location: 68' SNL, 1261' EWL, Sec. 33, TI2N, RI2E, UM Dear Mr. Crane: Enclosed is the approved application for permit to redrill the above development well. The permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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. Sincerely, ~~.~ Cammy cgechsli Taylor Chair BY ORDER 9,f THE COMMISSION DATED this~dayof July, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Hole 9-7/8" ALASKA ílL AND ~::;~g~S~~;~ON COMMlv'ION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned RKB= 70.331 Prudhoe Bay Field / Aurora 6. Property Designation Pool (Undefined) ADL 028258 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 8-1138 / 9. Approximate spud date 07/05/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13595" MD I 72451 TVD 0 17. Anticipated pressure {s~20 AAC 25.035 (e) (2)} 70.8 Maximum surface 2825 psig, At total depth (TVD) 6745' / 3500 psig Setting Depth Top Bottom ,Quantitv of Cement Lenath MD TVD MD TVD / (include staae data) 13570" Surface Surface 135951 7245" 518 sx Class "G" V4~A- 1/1/0L ~ 7/=¡!OÞ 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 738" SNL, 783 EWL, SEC. 35, T12N, R12E, UM At top of productive interval 42" NSL, 1484' EWL, SEC. 28, T12N, R12E, UM At total depth 68" SNL, 1261" EWL, SEC. 33, T12N, R12E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028259,12611 MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 10300" MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade Couclina 711 26# L -80 BTC-m 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 126401 feet 6990 feet feet feet Plugs (measured) Kick Plug at 9600' MD with abandoment plugs below. Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 115" 5553" 34" X 20" 10-3/4" 260 sx Arctic Set (Approx.) 784 sx Arcticset Lite 3, 750 sx "G" 1151 5587' 115' 33741 RECEIVED Perforation depth: measured None JUL 8 2002 Alaska Oil & Gas Cons. Commission - Anchorage true vertical II Filing Fe~ 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: BiIIlss on, 564-5521 Michael Triolo, 564-5774 .g is true a co ct to the best of my knowledge Title Senior Drilling Engineer Prepared By Name/Number: Sondra Stewman, 564-4750 20. Attachments Date 7-8-~ Permit Number 2o¿-/~3 Conditions of Approval: API NtJmber 50- 029-23094-02 Samples Required 0 Yes IBI No Hydrogen Sulfide Measures 0 Yes Ii No Required Working Pressure for BOPE 0 2K 0 3K Ot~glñ¡r~~oP6 f<, ')Soo f~è.-t.. Cammy Oechsli Taylor by order of 0 Ri . l~ A Che commission AEP~O~~I D.ate See cover letter r I J (''1./ {) ~ for other reauirements Mud Log equired 0 Yes 121 No Directional Survey Required IS Yes 0 No D4K D5K D10K D15K 0 3.5K psi for CTU Approved By Form 10-401 Rev. 12-01-85 Date '1 ! q I ¡);:)-. Submit tn' Triplicate bp ( ( To: Winton Aubert - AOGCC Date: July 5, 2002 From: William Isaacson - BPXA GPB Drilling & Wells Subject: Reference: 8-113B Permit to Drill - Open Hole Sidetrack Operations on Current Well S-113A API # 50-029-23094-01 Dear Mr. Aubert, After successfully sidetracking the original open hole section, Aurora Well S-113A was drilled as planned to the proposed target. However the reservoir once again contained gas, and the well will not be / completed at this location. The well penetrated the Kuparuk reservoir approximately -147' high and LWD logs showed signs of gas in the reservoir. Plans are to plug back and sidetrack to a Kuparuk target approximately 1400' to the southwest of the S-113A penetration. Below is an outline of the proposed plug back and sidetrack operations as well as the standard Drill and Complete Summary. Also enclosed is a schematic of the existing wellbore with proposed plug-back, and proposed completion for the sidetrack well S-113B. If you have any questions or require any additional information, please contact me at 564-5521. Scope Ria Operations: 1. RIH to TO at 12,640' MD with 5" DP cement stinger. Circulate and condition well for cementing operations. Spot a balanced 15.8 ppg cement P&A plug from TO to +/-11,840' MD (-450' above the Top Kuparuk Reservoir). Plug volume should be based upon an equivalent hole diameter of 10.4" throughout this section (84 bbls total). Pull above cement plug and circulate DP clean. 2. Spot a 11.0 ppg heavy mud spacer from top of cement P&A plug at -11,840' MD to -9450' MD. Pull DP up to 10,200' MD and circulate out any excess heavy mud spacer above this point. 3. Spot a 10.7 ppg Form-A-Plug pill (cross-linked polymer pill) from 10,200' to -9925' MD to act as a base for the upcoming cement kick-off plug. Pull DP above top of plug and circulate any excess pill out of DP. Pull to shoe and wait on Form-A-Plug to set (-6 hrs). 4. RIH to -9800' and wash down looking for top of plug. Once top of plug is verified, condition mud as required for spotting the cement kick-off plug. 5. Spot a 15.8 ppg cement kick-off plug from 10,000' to 9600' MD (estimated depths). Plug volume should be based upon an equivalent hole diameter of 11.4" throughout this section (51 bbls total). Pull DP above plug and circulate DP clean. POOH. If 6. PU 9-7/8" drilling assembly and RIH. Dress top of cement as required. Planned kick-off point is at -9750' MD, however will kick-off soon if plug allows. Kick-off and drill the 9-7/8" hole section as per directional plan to TO @ :t13,595' MD (7245' TVD). POOH. 7. Run and cement the 7", 26# production casing as required to cover all significant hydrocarbon intervals (no significant hydrocarbons were seen in the Ugnu or West Sak intervals and therefore, plans are to bring cement -1200' above top Kuparuk formation only). Displace the 7" casing with seawater during cementing operations. Once cement has had adequate time to set, freeze protect the 7" x 10-3/4" annulus as required. 8. RU slick-line and run gauge ring / junk basket to PBTD. S-113B Permit to Drill I f 9. Run a 4-1/2",12.6#, L-80 TC-II completion and space-out tubing tail -50' MO above top Kuparuk. 10. RU slick-line. RIH with standing valve"ahd set in 'XN' nipple below packer. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. Shear open RP valve in bottom GLM. 11. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 12. Freeze protect the well to -2400'. Secure the well. Rig down and move off. Post-RiQ Work: 1. RU e-line and perforate Kuparuk interval, using bottom most GLM to circulate guns down as required. 2. Pull RP shear valve from bottom GLM and install dummy valve. 3. Fracture stimulate Kuparuk and perform cleanout as required. 4. Install gas lift valves. I Well Name: 18-1138 Drill and Complete Summary I Type of Redrill (producer or injector): I Development Producer x = 618,930.63 / Y = 5,980,744.9 7381 FNL 7831 FWL 835 T12N R12E X = 609,060 / Y = 5,981,375 42' F8L 1484' FWL 828 T12N R12E X = 608,839 / Y = 5,981,262 68' FNL 1261' FWL 833 T12N R12E I 1 I RKB: 170.33' 1 I Kuparuk production well in the Aurora Development (Mid Beechey Block) I Surface Location: Target Location: Bottom Hole Location: I AFE Number: 1 AUD5M0044 I I Estimated Start Date: 107/05/02 1 I MD: 113,595' I I TVD: 17245' I Umiat Umiat Umiat I RiQ: 1 Doyon 14 /" I Operating days to complete: 19.0 /' I Cellar Elevation: 136.0' I I Well Design (conventional, slim hole, etc.): I 81imhole I Objective: 1 Formation Markers Formation Tops Schrader N Sands Kick-off Point Schrader 0 Sands Colville - CM3 Top HRZ Top Kuparuk Top Miluveach TO - 7" Csg Point MD 9570' 9750' 9863' 10,508' 12,867' 13,098' 13,508' 13,595' TVDss 4795' 4860' 4902' 5190' 6545' 6745' 7100' 7175' Comments -9.0 ppg EMW (possible hydrocarbon bearing) Kick-off in Schrader N (West Sak) -9.0 ppg EMW (possible hydrocarbon bearing) -9.9 ppg required for good hole stability -9.8 ppg EMW Max (hydrocarbon bearing) 5-1138 Permit to Drill ( Casing/Tubing Program Hole Size Csgl WtlFt Grade Conn Length Top 8tm Tbg O.D. MDrrVD MDrrVD 9-7/8" 7" 26# L-80 BTC-M -13,570' GL 13,595' / 7245' Tubing 4%" 12.6# L-8J TC-II -13,025' GL 13,050' /6773' Directional KOP: I -10,300' MD Maximum Hole Angle: Close Approach Well: Survey Program: -70.8° at -3500' MD All wells pass BP Close Approach guidelines. With respect to allowable deviation, the nearest close approach well is V-200. The well is -1358' well- to-well at -10,307', which allows for only 11.65' of deviation from the proposed directional plan (toward the subject well). IFR & Multi-Shot corrected MWD Surveys from KOP to TD. Mud Program 9-7/8" Intermediate / Production Hole I LSND From KOP to TD -150' MD into Miluveach Interval Density PV YP M8T pH API (ppg) Fluid Loss Ugnu & Schrader 9.5 8-12 22-28 <15 8.5 - 9.5 6-8 Colville 9.6 8-12 22-28 <15 8.5 - 9.5 6-8 HRZ 10.1 /' 8-14 20-24 <15 8.5 - 9.5 4-6 Kuparuk 10.1 8-14 20-24 <15 8.5 - 9.5 4-6 Integrity Testing: Test Point Surface Casing Shoe Depth Test Type 20' of new hole below shoe LOT EMW LOT - Had successful LOT to 16.35 / EMW at surface casing shoe. Logging Program 9-7/8" Inter / Prod: Drilling: MWD / GR / Res -_Realtime over entire interval Den / Neu -_Realtime over Kuparuk interval only Open Hole: None Cased Hole: No cased hole logs are planned with the rig on location. S-1138 Permit to Drill ( Cement Program Casing Size I 7" Intermediate I Production Basis: Lead: None Tail: Based on 1700' of open hole (to -1200' MD above top Kuparuk formation) with 30% excess + 82' shoe track volume. Tail TOC: -1200' MD above top Kuparuk at 11,898' MD Fluid Sequence & Volumes: Pre 40 bbls Chemical wash at 8.3 ppg Flush Spacer Lead Tail 40 bbls MudPUSH Viscosified Spacer weighted to 11.0 ppg None 108 bbls / 606 fe / 518 sks of Dowell Premium Latex 'G' at 15.8 ppg and 1.17 cf/sk, BHST 1600 / BHCT 1200, TT == 1.5 hrs Batch Mix + 3.5 hrs *See Attached Dowell Cement Program for Details on Cement Formulation* S..113B Permit to Drill .. (' ( We/J Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential suyace pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. . Production Section- Maximum anticipated BHP: 2200 psi @ 4600' TVDss - Schrader Bluff Maximum surface pressure: 1740 psi @ surface (based on BHP and a full column of gas from TO @ 0.10 psi/ft) . . Maximum anticipated BHP: 3500 psi @ 6745' TVDss - Kuparuk Maximum surface pressure: 2825 psi @ surface (based on BHP and a full column of gas from TO @ 0.10 PSi// Planned BOP test pressure: 3500 psi (the casing will be tested to 3500 psi) Planned completion fluid: Estimated 8.5 ppg Seawater / 6.8 ppg Diesel . . . Disposal . No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. ' . . 5-113B Permit to Drill TREE: 4-1/16" - 5M Carbon WELLHEAD: 135/8" - 5M FMC SH 10-3/4",45.5 #/ft, L-80, BTC j I 5587' I Planned KOP from 9600' to 9750' MD Base of West Sak / Top Colville Shale at -10.608' MD TO of 9-7/8" hole 112,640' I ~ Date 7/05/02 Rev By WSI Proposed Plug Back for Sidetrack Operations Aurora WELL: S-113A API NO: 50-029-23094-01 - I \ , S-113A Proposed Plug-Back 15.8 ppg Cement Kick-off Plug 10.7 ppg Form-A-Plug Cement Base 15.8 ppg Cement P&A Plug Cellar Elevation = 36.0' Doyon 14 RKB = 70.33' .. / Top of 15.8 ppg Kick-off Plug at I 9600' I / Top of Form-A-Plug pill at I 10,000' I Top of 11.0 ppg Mud Spacer at I 10,200' I Top of 15.8 ppg P&A Plug at I 11,840' I Top Kuparuk Reservoir at I 12,284' I ... Comments BP Alaska Drilling & Wells TREE: 4-1/16" - 5M Carbon WELLHEAD: 13 5/8" - 5M FMC SH 10-3/4",45.5 #Ift, L-80, BTC ~ I 5587' I 7",26 #/ft, L80, BTC-Mod 113,595' I ~ Date 7/05/02 Rev By WSI . l \ \ 5-1138 Proposed Completion I I L L L L ir 4-1/2" tubing hanger Cellar Elevation = 36.0' Doyon 14 RKB = 70.33' I 2350' I 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 12.6# L-80 TC-II Tubing .. 4-1/2" Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS TVD I Size # 4 3 2 1 3800' 5600' 6600' One full joint above packer Valve Type 1" 1" 1" 1" DV DV DV RP Shear 4-1/2" 'X' Landing Nipple with 3.813" seal bore. T' x 4-1/2" Baker 'S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.813"seal bore and 3.725" No-Go 10. 4-1/2" WireLine Entry Guide at -13,050' (approximately 50' MD above the top Kuparuk). Plug Back Depth I 13,495' I ~ Proposed Completion Comments Aurora WELL: 5-1138 API NO: 50-029-23094-02 8P Alaska Drilling & Wells . - North 510pe Alaska BPXA PBU_WOA 5 Pad, 510t5-113 5-113 WP5 - 5-113B WP04 --"'- Revised: 5 July, 2002 PROPOSAL REPORT 5 July, 2002 Surface Coordinates: 5980744.91 N, 618930.63 E (70021' 21.7672" N, 149002' 02.8492" W) Surface Coordinates relative to Project H Reference: 980744.91 N, 118930.63 E (Grid) Surface Coordinates relative to Structure Reference: 111.33 S, 1013.91 E (Grid) Kelly Bushing: 70.33ft above Mean Sea Level ---.. spel""""'rtY-5Uf1 q_fÜ.b,.I=...L"",-§.=:::.~.,~.B..v:..n~ E(~ A HaUiburt'On Company Proposal Ref: pro11235 Sperry-Sun Drilling Services Proposal Report for 5~113 WP5 - 5-1138 WP04 Revised: 5 July, 2002 BPXA North Slope Alaska PBU- WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9750.00 68.440 285.300 4859.67 4859.67 5982415.40 N 611440.11 E 5982415.40 N 611440.11 E 5916.57 9800.00 67.769 283.500 4878.32 4878.32 5982426.93 N 611395.18E 5982426.93 N 611395.18E 3.600 5951.37 9900.00 66.487 279.848 4917.19 4917.19 5982445.59 N 611304.97 E 5982445.59 N 611304.97 E 3.600 6023.29 10000.00 65.293 276.127 4958.05 4958.05 5982458.28 N 611214.61 E 5982458.28 N 611214.61 E 3.600 6098.05 Begin 9-7/8" Hole 10100.00 64.191 272.337 5000.74 5000.74 5982464.97 N 611124.44 E 5982464.97 N 611124.44 E 3.600 6175.36 10155.16 63.626 270.218 5025.00 5025.00 5982466.07 N 611074.91 E 5982466.07 N 611074.91 E 3.600 6218.99 OBc 10200.00 63.190 268.480 5045.07 5045.07 5982465.62 N 611034.83 E 5982465.62 N 611034.83 E 3.600 6254.92 10254.79 62.686 266.338 5070.00 5070.00 5982463.42 N 610986.09 E 5982463.42 N 610986.09 E 3.600 6299.35 OBd 10300.00 62.295 264.557 5090.88 5090.88 5982460.24 N 610946.12 E 5982460.24 N 610946.12 E 3.600 6336.41 10400.00 61.513 260.573 5137.99 5137.99 5982448.83 N 610858.67 E 5982448.83 N 610858.67 E 3.600 6419.51 10500.00 60.848 256.535 5186.21 5186.21 5982431.46 N 610772.82 E 5982431.46 N 610772.82 E 3.600 6503.89 10507.77 60.801 256.219 5190.00 5190.00 5982429.86 N 610766.22 E 5982429.86 N 610766.22 E 3.600 6510.49 Base OBfrrop Colville 10600.00 60.305 252.449 5235.35 5235.35 5982408.19 N 610688.92 E 5982408.19 N 610688.92 E 3.600 6589.22 10700.00 59.890 248.323 5285.22 5285.22 5982379.11 N 610607.28 E 5982379.11 N 610607.28 E 3.600 6675.16 10800.00 59.604 244.169 5335.62 5335.62 5982344.33 N 610528.24 E 5982344.33 N 610528.24 E 3.600 6761.37 10900.00 59.450 239.995 5386.35 5386.35 5982303.99 N 610452.11E 5982303.99 N 610452.11 E 3.600 6847.52 11000.00 59.430 235.814 5437.21 5437.21 5982258.25 N 610379.19 E 5982258.25 N 610379.19 E 3.600 6933.26 11025.16 59.446 234.763 5450.00 5450.00 5982245.92 N 610361.38 E 5982245.92 N 610361.38 E 3.600 6954.72 CM2 11032.74 59.452 234.446 5453.86 5453.86 5982242.14 N 610356.06 E 5982242.14 N 610356.06 E 3.600 6961 .18 11100.00 59.452 234.446 5488.04 5488.04 5982208.45 N 610308.93 E 5982208.45 N 610308.93 E 0.000 7018.46 11200.00 59.452 234.446 5538.87 5538.87 5982158.38 N 610238.87 E 5982158.38 N 610238.87 E 0.000 7103.62 ~. 11300.00 59.452 234.446 5589.70 5589.70 5982108.30 N 610168.80 E 5982108.30 N 610168.80 E 0.000 7188.78 11400.00 59.452 234.446 5640.52 5640.52 5982058.22 N 610098.74 E 5982058.22 N 610098.74 E 0.000 7273.94 11500.00 59.452 234.446 5691 .35 5691 .35 5982008.15 N 610028.67 E 5982008.15 N 610028.67 E 0.000 7359.11 11548.53 59.452 234.446 5716.01 5716.01 5981983.85 N 609994.67 E 5981983.85 N 609994.67 E 0.000 7400.43 End Dir, Start Sail @ 70.841 ° : 11548.53ftMD,5607.98ftTVD 11589.86 59.452 234.446 5737.02 5737.02 5981963.15 N 609965.71 E 5981963.15 N 609965.71 E 0.000 7435.63 Begin Dir @ 3.6000/100ft : 11589.86t MD, 5621.55ft TVD 11600.00 59.452 234.446 5742.17 5742.17 5981958.07 N 609958.61 E 5981958.07 N 609958.61 E 0.000 7444.27 11700.00 59.452 234.446 5793.00 5793.00 5981908.00 N 609888.54 E 5981908.00 N 609888.54 E 0.000 7529.43 11800.00 59.452 234.446 5843.83 5843.83 5981857.92 N 609818.48 E 5981857.92 N 609818.48 E 0.000 7614.59 11900.00 59.452 234.446 5894.65 5894.65 5981807.84 N 609748.41 E 5981807.84 N 609748.41 E 0.000 7699.75 5 July, 2002 - 14:21 Page2of6 DríllQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for 5-113 WP5 - 5-1138 WP04 Revised: 5 July, 2002 BPXA North Slope Alaska PBU_WOAS Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 12000.00 59.452 234.446 5945.48 5945.48 5981757.77 N 609678.35 E 5981757.77 N 609678.35 E 0.000 7784.91 12044.83 59.452 234.446 5968.27 5968.27 5981735.32 N 609646.94 E 5981735.32 N 609646.94 E 0.000 7823.09 12100.00 57.489 234.797 5997.11 5997.11 5981708.09 N 609608.60 E 5981708.09 N 609608.60 E 3.600 7869.60 12105.36 57.298 234.832 6000.00 6000.00 5981705.49 N 609604.91 E 5981705.49 N 609604.91 E 3.600 7874.08 CM1 12200.00 53.932 235.473 6053.44 6053.44 5981660.86 N 609540.83 E 5981660.86 N 609540.83 E 3.600 7951.43 12300.00 50.380 236.214 6114.78 6114.78 5981616.52 N 609475.50 E 5981616.52 N 609475.50 E 3.600 8029.77 12400.00 46.833 237.035 6180.90 6180.90 5981575.25 N 609412.87 E 5981575.25 N 609412.87 E 3.600 8104.30 12500.00 43.293 237.958 6251.52 6251.52 5981537.20 N 609353.19 E 5981537.20 N 609353.19 E 3.600 8174.75 12600.00 39.761 239.010 6326.37 6326.37 5981502.53 N 609296.69 E 5981502.53 N 609296.69 E 3.600 8240.83 12700.00 36.240 240.230 6405.16 6405.16 5981471.38 N 609243.60 E 5981471.38 N 609243.60 E 3.600 8302.27 12800.00 32.734 241 .673 6487.57 6487.57 5981443.87 N 609194.13 E 5981443.87 N 609194.13 E 3.600 8358.84 12867.40 30.382 242.811 6545.00 6545.00 5981427.43 N 609162.93 E 5981427.43 N 609162.93 E 3.600 8394.11 THRZ 12878.36 30.000 243.011 6554.47 6554.47 5981424.92 N 609158.02 E 5981424.92 N 609158.02 E 3.600 8399.62 12900.00 30.000 243.011 6573.22 6573.22 5981420.01 N 609148.38 E 5981420.01 N 609148.38 E 0.000 8410.44 13000.00 30.000 243.011 6659.82 6659.82 5981397.32 N 609103.82 E 5981397.32 N 609103.82 E 0.000 8460.44 13037.94 30.000 243.011 6692.67 6692.67 5981388.71 N 609086.92 E 5981388.71 N 609086.92 E 0.000 8479.41 End Dir, Start Sail @ 20.000° : 13037.94ftMD,6608.60ftTVD 13098.36 30.000 243.011 6745.00 6745.00 5981375.00 N 609060.00 E 5981375.00 N 609060.00 E 0.000 8509.62 TKUP Target - S-1138 T1, Drillers 13100.00 30.000 243.011 6746.42 6746.42 5981374.63 N 609059.27 E 5981374.63 N 609059.27 E 0.000 8510.44 13200.00 30.000 243.011 6833.03 6833.03 5981351.94 N 609014.71 E 5981351.94 N 609014.71 E 0.000 8560.44 13277.33 30.000 243.011 6900.00 6900.00 5981334.39 N 608980.26 E 5981334.39 N 608980.26 E 0.000 8599.11 LCU 13300.00 30.000 243.011 6919.63 6919.63 5981329.24 N 608970.16 E 5981329.24 N 608970.16 E 0.000 8610.44 13400.00 30.000 243.011 7006.23 7006.23 5981306.55 N 608925.60 E 5981306.55 N 608925.60 E 0.000 8660.44 13450.54 30.000 243.011 7050.00 7050.00 5981295.09 N 608903.09 E 5981295.09 N 608903.09 E 0.000 8685.71 A5 13500.00 30.000 243.011 7092.83 7092.83 5981283.86 N 608881.05 E 5981283.86 N 608881.05 E 0.000 8710.44 13508.28 30.000 243.011 7100.00 7100.00 5981281.98 N 608877 .36 E 5981281.98 N 608877.36 E 0.000 8714.58 TMLV 13594.88 30.000 243.011 7175.00 7175.00 5981262.33 N 608838.78 E 5981262.33 N 608838.78 E 0.000 8757.88 TO 5 July, 2002 - 14:21 Page 30f6 DríllQuest 2.00.09.001 H 206974 DATE 7/01/02 INVOICE I CREDIT MEMO CK062602H 3 -lI3:5 DESCRIPTION DATE CHECK NO. GROSS JULY 1, 02 :H206974 VENDOR DISCOUNT PERMIT TO DRILL FEE NET :: ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ I3I?,gìG.~L0RATIQN,(~~SKA).'.'I(\J€ò P.0.B0X 196612 ANCH0RAGE,ALASI<A99519~6612 PAY RECEIVED JUL 8 2002 Alaska on & Gas Cons. Cc mmissîon .- .' Anchorage FIRST NATlONALBANKOFASHLAND AN'AFFIUATEOF NATIONAL.CrTY BANK CLEVELAND. OHIO No.H ,20697'4 CONSOLIDATED COMMERCIAL ACCOUNT 56~389 -m- , ø,',"".",.,' ".,',. ..',", lIJ,',:,',.' ,','.',",', E"-~,,,.,',',.,,",.,.,',',.,'"':',',.,.,.,','.,.',',r,',,.,.",'"','.~,',,".,.,...,'..,,...',:.".".,/,'.:"r.;--~i,It,J,", It:,:::"J¡,....'.",'.,'~""".'I::Þ,~1,,;f,"~,: D. IF '. ..!I..lt.. '_t', ' "~ ,.,.,,11 ~ ..". H -" '-" (, TRANSMIT AL LETTER CHECK LIS4 CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME CHECK 1 ST ANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) DEVELOPMENT REDRILL PILOT HOLE (PH) / EXPLORATION INJECTION WELL S-ll~ß "CL UE" The permit is for a new wellbore segment of existing well --J Permit No, API No. Production should continue to be reported as a.function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). INJECTION WELL RED RILL ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD <-.) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 6/18/02 C\jody\templates Enclosed is the. approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a. conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples. are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY ðfX WELL NAME,ÞA/~ ,<:,,//3 B PROGRAM: Exp - Dev.x Redrll ~ Se~ - Wellbore seg - Ann. disposal para req-: FIELO&POOL 67'0/2-0 INITCLASS bill-v /-~.i GEOLAREA "~ UNIT# //C-("~ ON/OFFSHORE t'9,.,;J ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . ry.. N 2. Lease number appropriate. . . . . .. . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N Ají}~. Q9;J~... 12. Permit can be issued without administrative approval.. . . . . Y N /fli.. 6iw/¿-,,- 13. Can permit be approved before 15-day wait.. . . . . . . . . . ~ N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . /Y)N 15. Surface casing protects all known USDWs. . . . . . . . . . . 7!tJ N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . - Y N . AI (Æ- 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ;t.-..@. 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N 19. Casing designs adequate for C, T" B '& permafrost. . . . . . . &2. N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . ~ N 21. If a re-drill, has a 10-403 for abandonment been approved. . . ,N 22. Adequate wellbore separation proposed.. . . . . . . . . .-. . N 23. If diverter required, does it meet regulations. . . . . . . . . . iv,' , N /'itA 24, Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N I ("\ .-, ~ f 26. BOPE press rating appropriate; test to ~500 psig. . N fI/l? I"" (,.....-6" 2'5 f~' L ' 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . : DL, 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~. 30. Permit can be issued w/o hydrogen sulfide measures. . . .. ß/Y) N 31. Data presented on potential overpressure zones. . . . . . . L.(( N ~) /J 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y / v. H " AffR !JJ\ TF 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . , N ¡r¡Jr- ~/fl t:J7. 34. Contact name/phone for weekly progress reports [exploratory 0 1 Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for dispo (0) will not damage producing formation or impair recovery fr a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP~C JDH ~ - #< WGA ~G,t- APPR OA TE GEOLOGY APPR DATE ~ Gl~;1. Comments/Instructions: COT. .' DTS ,\J1jr::ljjO¿ G:\geology\permits\checklist. doc Well History File APPENDIX Infonnation of detailed nature that is not particularly germane to the Well Pennitting 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 APPEN.DIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Aug 08 07:01:01 2002 Reel Header Service name. ......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/08/08 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ......... ...UNKNOWN Continuation Number... ...01 Previous Reel Name... ....UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS a Od-J4 '3 / 09 WLf Writing Library. Scientific Technical Services Tape Header Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/08/08 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name...... ...... ....UNKNOWN Continuation Number. .... .01 Previous Tape Name..... ..UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: Writing Library. Scientific Technical Services MWD RUN 1 AK-MW-22095 T. MCGUIRE A. MADSEN MWD RUN 4 AK-MW-22095 C.A. DEMOSKI A. MADSEN MSL 0) S-l13B 500292309402 BP Exploration Sperry Sun 08-AUG-02 MWD RUN 2 AK-MW-22095 C.A. DEMOSKI A. MADSEN MWD RUN 6 AK-MW-22095 T. MCGUIRE L. VAUGHN 35 12N 12E 738 783 .00 70.33 36.00 (Alaska), Inc. MWD RUN 3 AK-MW-22095 C.A. DEMOSKI A. MADSEN OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.500 10.750 5587.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 & 2 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3. MWD RUN 3 IS DIRECTIONAL UTILIZING GEIGER MUELLER TUBE DETECTORS, RESISTIVITY PHASE 4 (EWR4) . WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE 4. MWD RUNS 4 & 6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD). 5. GAMMA RAY (SGRC) IS LOGGED BEHIND CASING FROM 5528' MD, 3350' TVD TO 5587' MD, 3371' TVD. 6. FOR LOG DATA ABOVE THE KICKOFF POINT REFERENCE THE LOG FOR S-113. 7. DEPTH SHIFTING / CORRECTION WAIVED PER THE EMAIL FROM D. SCHNORR OF 07/16/02. MWD CONSIDERED PDC. WELL S-113B IS TIED INTO S-113 AT THE KICKOFF POINT. THIS WELL KICKS OFF FROM S-113 AT 9700' MD, 4912' TVD. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1 - 4 & 6 REPRESENT WELL S-113B WITH API # 50-029-23094-02. THIS WELL REACHED A TOTAL DEPTH OF 13515' MD, 7191' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRD = SMOOTHED GAMMA RAY SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME SBD2 = SMOOTHED BULK DENSITY (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE ENVIRONMENTAL PARAMETERS USED IN PROCESSING THE NEUTRON LOG DATA: HOLE SIZE: 9.875" MUD WEIGHT: 10.25 PPG MUD FILTRATE CHLORIDES 9.40 - SALINITY: 350 - 700 PPM FORMATION WATER SALINITY: FLUID DENSITY: G/CC MATRIX DENSITY: 20,000 PPM CHLORIDES 1. 00 LITHOLOGY: SANDSTONE $ File Header Service name.. ...... .... .STSLIB.001 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .02/08/08 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPX RPS RPM RPD NPHI FCNT NCNT RHOB PEF DRHO $ 1 2.65 G/CC clipped curves; all bit runs merged. .5000 START DEPTH 45.0 115.5 5567.0 5567.0 5567.0 5567.0 5567.0 8300.0 8300.0 8300.0 8300.0 8300.0 8300.0 STOP DEPTH 13469.0 13514.5 13461. 5 13461. 5 13461. 5 13461. 5 13461. 5 13421.0 13421.0 13421.0 13430.0 13430.0 13430.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 3 4 6 # REMARKS: MERGED MAIN PASS. $ MERGE TOP 45.0 1485.5 5600.5 8384.5 9700.5 MERGE BASE 1485.0 5600.0 8384.0 9700.0 13514.5 # Data Format Specification Record Data Record Type........ ... .......0 Data Specification Block Type... ..0 Logging Direction..... ... ..... ....Down Optical log depth units.. ...... ...Feet Data Reference Point........... ...Undefined Frame Spacing............ ...... ...60 .1IN Max frames per record.... ...... ...Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CP30 4 1 68 36 10 NCNT MWD CP30 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 45 13514.5 6779.75 26940 45 13514.5 ROP MWD FT/H 0.39 4382.62 206.206 26799 115.5 13514.5 GR MWD API 7.48 416.38 77.0586 26849 45 13469 RPX MWD OHMM 0.76 127 . 95 5.3009 15790 5567 13461.5 RPS MWD OHMM 0.57 300.22 5.49821 15790 5567 13461.5 RPM MWD OHMM 0.68 2000 6.57482 15790 5567 13461.5 RPD MWD OHMM 0.71 2000 7.97361 15790 5567 13461.5 FET MWD HR 0.08 57.36 1.12079 15790 5567 13461.5 NPHI MWD PU-S 13.83 74.32 35.3825 10243 8300 13421 FCNT MWD CP30 426.83 1020.5 569.567 10243 8300 13421 NCNT MWD CP30 2139.9 3308.84 2599.65 10243 8300 13421 RHOB MWD G/CM 1. 79 3.2 2.3294 10261 8300 13430 DRHO MWD G/CM -0.27 0.89 0.0679758 10261 8300 13430 PEF MWD B/E 1.18 9.26 2.87674 10261 8300 13430 First Reading For Entire File.. ... .....45 Last Reading For Entire File... ...... ..13514.5 File Trailer Service name..... ....... .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. .... ..02/08/08 Maximum Physical Record. .65535 File Type................ LO Next File Name. ... ...... .STSLIB.002 Physical EOF File Header Service name.. ....... ... .STSLIB.002 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .02/08/08 Maximum Physical Record. .65535 File Type................ LO Previous File Name.. ... ..STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 45.0 115.5 STOP DEPTH 1413.5 1485.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 18-JUN-02 Insite 4.05.5 3.3 DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... .......... ..0 Data Specification Block Type.....O Logging Direction..... ... ........ . Down Optical log depth units.......... .Feet Data Reference Point. .... ........ .Undefined Frame Spacing..... .... ...... ..... .60 .1IN Max frames per record.... ........ .Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Memory 1485.0 .0 26.0 TOOL NUMBER 015 13.500 Spud Mud 9.30 350.0 9.1 700 9.6 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT /H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 .0 61. 5 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 45 1485 765 2881 45 1485 ROP MWD010 FT/H 0.39 374.28 92.2224 2740 115.5 1485 GR MWD010 API 19.39 94.46 48.8119 2738 45 1413.5 First Reading For Entire File.... .... ..45 Last Reading For Entire File........ ...1485 File Trailer Service name..... ....... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. ... ..02/08/08 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name........ .... .STSLIB.003 Service Sub Level Name... Version Number.... .......1.0.0 Date of Generation... ... .02/08/08 Maximum Physical Record. .65535 File Type................ LO Previous File Name. ..... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 1414.0 1485.5 STOP DEPTH 5528.5 5600.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 20-JUN-02 Insite 4.05.5 3.3 Memory 5600.0 27.9 71.3 TOOL NUMBER 011 13.500 5587.0 Spud Mud 9.80 240.0 8.6 500 6.0 .000 .000 .000 .000 .0 82.6 .0 .0 REMARKS: $ # Data Format Specification Record Data Record Type............. .....0 Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units...... .... .Feet Data Reference Point. .... .... .... . Undefined Frame Spacing........ ....... ... ...60 .1IN Max frames per record. ........ ....Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1414 5600 3507 8373 1414 5600 ROP MWD020 FT/H 6.51 1079.34 222.913 8230 1485.5 5600 GR MWD020 API 29.33 128.62 76.9918 8230 1414 5528.5 First Reading For Entire File.... ..... .1414 Last Reading For Entire File.... ... ... .5600 File Trailer Service name......... ... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..02/08/08 Maximum Physical Record..65535 File Type... .......... ...LO Next File Name. ...... ... .STSLIB.004 Physical EOF File Header Service name....... ... ...STSLIB.004 Service Sub Level Name... Version Number. ... ... ... .1.0.0 Date of Generation. ..... .02/08/08 Maximum Physical Record. .65535 File Type................ LO Previous File Name.. .... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 5529.0 5567.0 5567.0 5567.0 5567.0 5567.0 5600.5 STOP DEPTH 8335.0 8327.0 8327.0 8327.0 8327.0 8327.0 8384.0 # LOG HEADER DATA DATE LOGGED: 24-JUN-02 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... .... ..... .....0 Data Specification Block Type.....O Logging Direction............ .... . Down Optical log depth units.... ... ... .Feet Data Reference Point.. ..... ... ....Undefined Frame Spacing......... ........... .60 .1IN Max frames per record. ........ ....Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Insite 4.05.5 66.37 Memory 8384.0 66.3 70.4 TOOL NUMBER PB00220HWRG6 PB00220HWRG6 9.875 LSND 9.40 41. 0 10.3 500 5.8 .590 .381 1. 850 2.000 67.0 107.6 67.0 67.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5529 8384 6956.5 5711 5529 8384 ROP MWD030 FT/H 2.54 1156.01 291. 636 5568 5600.5 8384 GR MWD030 API 7.48 124.83 62.9345 5613 5529 8335 RPX MWD030 OHMM 1. 61 127 . 95 7.36926 5521 5567 8327 RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HR 0.57 1. 61 1. 29 0.08 300.22 2000 2000 57.36 7.64402 5521 10.5079 5521 13.8988 5521 1. 3665 5521 First Reading For Entire File.. ... ... ..5529 Last Reading For Entire File... .... ....8384 File Trailer Service name........ ... ..STSLIB.004 Service Sub Level Name... Version Number.. ..... ... .1.0.0 Date of Generation...... .02/08/08 Maximum Physical Record..65535 File Type........ ...... ..LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name.. ........ ...STSLIB.005 Service Sub Level Name... Version Number..... ... ...1.0.0 Date of Generation...... .02/08/08 Maximum Physical Record. .65535 File Type................ LO Previous File Name.... ...STSLIB.004 Cormnent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE SC02 SPSF SNFA SNP2 SBD2 SNNA SEXP SESP SEMP SEDP SFXE SGRC SROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 8300.0 8300.0 8300.0 8300.0 8300.0 8300.0 8327 .5 8327.5 8327.5 8327.5 8327.5 8335.5 8384.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP STOP DEPTH 9700.0 9700.0 9700.0 9700.0 9700.0 9700.0 9700.0 9700.0 9700.0 9700.0 9700.0 9700.0 9700.0 28-JUN-02 Insite 4.05.5 66.37 Memory 9700.0 29.8 70.3 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON TOOL NUMBER PBOO157HRG6 PBOO157HRG6 PB00233NL6 5567 5567 5567 5567 8327 8327 8327 8327 SLD $ STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ..... ......0 Data Specification Block Type.....O Logging Direction...... ..... ...'. . Down Optical log depth units..... .... ..Feet Data Reference Point... ......... ..Undefined Frame Spacing....... ... ..... ......60 .1IN Max frames per record.. ...... .....Undefined Absent value...................... -999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 PB00233NL6 9.875 LSND 10.10 45.0 9.2 400 3.6 1.250 .628 2.200 1.800 67.0 140.0 67.0 67.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CP30 4 1 68 36 10 NCNT MWD040 CP30 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8300 9700 9000 2801 8300 9700 ROP MWD040 FT/H 2.15 4382.62 251. 666 2632 8384.5 9700 GR MWD040 API 18.45 112.21 56.8812 2730 8335.5 9700 RPX MWD040 OHMM 1.17 27.42 5.12022 2746 8327.5 9700 RPS MWD040 OHMM 1.16 31.76 5.33863 2746 8327.5 9700 RPM MWD040 OHMM 1.15 32.63 5.53899 2746 8327.5 9700 RPD MWD040 OHMM 1.19 34.47 5.98355 2746 8327.5 9700 FET MWD040 HR 0.13 22.16 1.4497 2746 8327.5 9700 NPHI MWD040 PU-S 20.51 52.29 31.7492 2801 8300 9700 FCNT MWD040 CP30 433.5 655 540.668 2801 8300 9700 NCNT MWD040 CP30 2336 3128 2705.89 2801 8300 9700 RHOB MWD040 G/CM 1. 79 2.98 2.2564 2801 8300 9700 DRHO MWD040 G/CM -0.1 0.67 0.034859 2801 8300 9700 PEF MWD040 B/E 1.18 6.51 First Reading For Entire File..... ... ..8300 Last Reading For Entire File. ........ ..9700 File Trailer Service name....... ..... .STSLIB.005 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .02/08/08 Maximum Physical Record. .65535 File Type................ LO Next File Name. ... ..... ..STSLIB.006 Physical EOF File Header Service name... ........ ..STSLIB.006 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .02/08/08 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR PEF ROP RPX RPS RPM RPD NPHI FCNT NCNT RHOB DRHO FET $ 6 1.96384 2801 header data for each bit run in separate files. 6 .5000 START DEPTH 9700.5 9700.5 9700.5 9700.5 9700.5 9700.5 9700.5 9700.5 9700.5 9700.5 9700.5 9700.5 9700.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ # STOP DEPTH 13469.0 13430.0 13514.5 13461. 5 13461.5 13461.5 13461.5 13421.0 13421.0 13421.0 13430.0 13430.0 13461.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN 10-JUL-02 Insite 4.05.5 66.37 Memory 13515.0 26.4 65.1 TOOL NUMBER PB00259HRG6 PB00259HRG6 PB00256NL6 PB00256NL6 8300 9700 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Based Water 9.90 47.0 10.7 400 4.5 1. 800 .849 2.800 2.100 70.0 156.0 70.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... .......... ..0 Data Specification Block Type... ..0 Logging Direction........ ........ . Down Optical log depth units.. ........ .Feet Data Reference Point..... ........ .Undefined Frame Spacing... ......... ........ .60 .1IN Max frames per record.... ..... ... . Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HR 4 1 68 28 8 NPHI MWDO 60 PU-S 4 1 68 32 9 FCNT MWD060 CP30 4 1 68 36 10 NCNT MWD060 CP30 4 1 68 40 11 RHOB MWD060 G/CM 4 1 68 44 12 DRHO MWD060 G/CM 4 1 68 48 13 PEF MWD060 B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9700.5 13514.5 11607.5 7629 9700.5 13514.5 ROP MWD060 FT/H 0.84 424.19 151.085 7629 9700.5 13514.5 GR MWD060 API 40.96 416.38 105.216 7538 9700.5 13469 RPX MWD060 OHMM 0.76 22.87 3.84892 7523 9700.5 13461.5 RPS MWD060 OHMM 0.73 25.19 3.98169 7523 9700.5 13461.5 RPM MWD060 OHMM 0.68 25.64 4.06651 7523 9700.5 13461.5 RPD MWDO 60 OHMM 0.71 29.21 4.35161 7523 9700.5 13461.5 FET MWD060 HR 0.19 6.49 0.820409 7523 9700.5 13461.5 NPHI MWD060 PU-S 13.83 74.32 36.75 7442 9700.5 13421 FCNT MWD060 CP30 426.83 1020.5 580.444 7442 9700.5 13421 NCNT MWD060 CP30 2139.9 3308.84 2559.67 7442 9700.5 13421 RHOB MWD060 G/CM 1. 81 3.2 2.35681 7460 9700.5 13430 DRHO MWD060 G/CM -0.27 0.89 0.0804102 7460 9700.5 13430 PEF MWD060 B/E 1. 33 9.26 3.2195 7460 9700.5 13430 First Reading For Entire File. ........ .9700.5 Last Reading For Entire File....... ....13514.5 File Trailer Service name........ .....STSLIB.006 Service Sub Level Name... Version Number. ..... .....1.0.0 Date of Generation... ....02/08/08 Maximum Physical Record..65535 File Type................ LO Next File Name.. ....... ..STSLIB.007 Physical EOF Tape Trailer Service name... ...... ....LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/08/08 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name... ... ......... . UNKNOWN Continuation Number.... ..01 Next Tape Name. ...... ....UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/08/08 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name...... ...... ....UNKNOWN Continuation Number. .....01 Next Reel Name.... ... ....UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
