The URL can be used to link to this page

Home My WebLink About209-017K-55/L-80 1413 sx CS III, 550 sx G, 200sx CS II 4-1/2" 12.6# x 3-1/2" 9.2# 13Cr80 x 3-1/2" 9.2# L-80 4/11/2009 8/7/2024 By James Brooks at 2:13 pm, Aug 23, 2024 RBDMS JSB 082924 xGDSR-9/4/24 Drilling Manager 08/22/24 Monty M Myers Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.08.22 19:53:26 - 08'00' Bo York (1248) ACTIVITYDATE SUMMARY 6/17/2024 ***WELL S/I ON ARRIVAL*** BRUSH X-NIP @ 8,418' MD W/ 3-1/2" BRUSH & 2.75" G-RING SET 2.81 PX PLUG BODY IN X-NIP @ 8,418' MD ***CONTINUE ON 6/18/24*** 6/17/2024 T/I/O=2331/515/0 TFS Unit 1 Assist Slick line (Load and Test) Pumped a Total of 108 BBLS of Crude. Pumped 100 BBLS Crude to Load the TBG and Pumped at min Rate while Slickline Ran in hole. ***JOB CONTINUES*** 6/18/2024 ***CONTINUED FROM 6/17/24*** SET 1.75" PRONG IN 2.81" PX PLUG BODY @ 8,418' MD MIT-T TO 2,750 (PASS) PULL 1.75" PRONG FROM 2.81" PX PLUG BODY @ 8,418' MD PULL 2.81'' PX-PLUG BODY FROM X-NIP @ 8418'MD DRIFT FREELY TO 8950'SLM w/2.73'' x 140'' NS WHIPSTOCK DRIFT RAN READ 24 ARM CALLIPER (GOOD DATA) ***WELL LEFT S/I ON DEPARTURE*** 6/18/2024 T/I/O= 312/521/0 TFS Unit 1 Assist Slickline (Test) Pumped a total of 8 BBLS Crude. Pumped 7 BBLS While Slickline was RIH. Then Pumped 1 BBL of Crude to Reach a MAP of 2750 on the Tubing. MIT-T ***PASSED*** to 2565 psi. 1st 15 min TBG lost 127 psi. 2nd 15 min TBG lost 52 psi. for a total loss of 179 psi in a 30 min test. FWHP=278/518/0 Slick Line in control of well upon departure. 6/20/2024 **WELL S/I ON ARRIVAL, DSO NOTIFIED*** (GYRO SURVEY) PT 300L/3000H RUN W/CH/X2 1 11/16'' WB/ GYRO TOOL MAX OAL 31' MAX OD 1.8'' RECORD DOWN WITH MULTIPLE STOPS FROM SURFACE TO 8950' PULL SURVEY DATA WITH MULTIPLE STOPS FROM 8950' TO SURFACE JOB COMPLETE ***WELL S/I ON DEPARTURE*** 7/3/2024 LRS CTU #2- 2.0" Coil ***Continued from WSR 7-2-24*** Job Objective: Mill Cement, plug, tubing punch, Cement annulus Travel to DS18, MIRU CTU. M/U YJ milling BHA w/2.76" 4 blade reverse clutch mill. Push plug to 9503' CTMD (9544' MD) and dress tubing. Dry drift from 8800' down to tag and confirm corrected depth at the flag. POOH. Standby at surface while tractor taken to assist CTU #1. ...Continued on WSR 7-4-24... 7/4/2024 LRS CTU #2 - 2.0" Coil ***Cont. from WSR 7-3-24*** Job Objective: Mill CIBP, Tubing Punch, Cement annulus Make up 5' of 2" tubing punch, 4 spf and RIH. Tie-in to milled CIBP tag and punch 9530-9535'. POOH. M/I YJ CICR. RIH, set at 9500'. Test communication and injectivity. Pump 18 bbls 15.8ppg class G cement. pumped 15bbls through retainer with 700psi WHP bump. Unsting, Contaminate and clean out down to 9490', chase OOH at 80%. FP well with 38bbls diesel. RDMO 2 Hours NPT waiting on Contam truck ***Job Complete*** 7/5/2024 ***WELL S/I ON ARRIVAL*** RAN 2.73' x 13' NS DMY WHPSTK DRIFT, 2.75'' SWAGE. SET DWON @ 8941' SLM. UNABLE TO WORK PAST. POH. ***WSR CONT. 07-06-2024*** Daily Report of Well Operations PBU 18-26B Daily Report of Well Operations PBU 18-26B 7/6/2024 ***WSR CONT. FROM 07-05-2024*** RAN 2.5'' x 10' PUMP BAILER TO 9100' SLM (NO ISSUES) RAN 2.74'' SWAGE, 2' STEM, 2.74'' G. RING, WORK THROUGH TIGHT SPOTS FROM 8937' SLM TO 8971' SLM, FALL FREE TO 9030' SLM RAN 2.73'' x 10' NS DMY WHPSTK DRIFT TO S/D @ 8937' SLM, UNABLE TO WORK FURTHER RAN 2.70'' CENT., 2' STEM, 2.747'' BROACH, WORK THROUGH TIGHT SPOTS FROM 8937' SLM TO 8971' SLM RAN 2.73" SWAGE, 2' STEM, 2.767" BROACH, WORK THROUGH TIGHT SPOTS FROM 8956' SLM TO 9031' SLM DRIFT TO 9058' SLM RUN READ CALIPER FROM 9060' SLM TO 8400' SLM. RUN 2.73'' SWAGE, 5' STEM, 2.77'' CENT., 2' STEM, 2.79'' BROACH, S/D @ 8479' MD, WORK THROUGH PUMPING 1 BPM, @ 400 FPM, DRIFT TO S/D @ 9099' MD ***WSR CONT. ON 07-07-2024*** 7/6/2024 T/I/O=500/500/0 (TFS Unit 1 Assist Slickline with broaching) Pumped 107 bbls of Crude down the TBG to assist SL in broaching. Well left SL control. Final WHPS 1000/500/0 7/7/2024 ***WSR CONT. FROM 07-06-2024*** RAN 2.73'' x 10' NS DMY WHIPSTOCK DRIFT, 2.30'' SWAGE, FALL FREELY TO 9099' MD, MAKE PASSES FROM 8900' TO 8980' SLM @ VARIABLE SPEEDS (No Issues) RAN 2.73'' x 10' NS DMY WHIPSTOCK DRIFT, 2.75'' SWAGE, 2.30'' SWAGE, FALL FREELY TO 9099' MD, MAKE PASSES FROM 8900' TO 8980' SLM @ VARIABLE SPEEDS (No Issues) ***WELL LEFT S/I ON DEPARTURE*** 7/9/2024 ***WELL SHUT IN ON ARRIVAL*** (WHIPSTOCK SETTING) RIG UP AKE PCE FUNCTION TEST WLV'S PT 250 LP 3000 HP SET NS WHIPSTOCK 181 DEGREES ROHS WITH TOW @ 9030' CCL STOP DEPTH= 9016.2 (CCL-WS=13.8') LOG CORRELATED TO SLB CNL DATED 14-APR-09 RDMO AKEL ***WELL SHUT IN ON DEPARTURE, PAD OP NOTIFIED*** 7/14/2024 T/I/O = 620/520/VAC Pre CDR3. Set 4" "H" BPV #110 @125", BPV LTT Passed. PT tree cap to 500 psi. Pass. Final WHP BPV/520/VAC. 7/16/2024 T/I/O = BPV/520/VAC Pre CDR3. Removed 4" CIW upper tree and installed 4" CDR tree #4 and kill line #1. Torqued flanges to spec. RU Ciw lubricator and "H" pulling tool to tree. PT CDR / kill line tree agaisnt MV to 350/5000 psi for 5 min. Passed. Pulled 4" "H" BPV #110 @125", RD lubricator and install tree cap. PT cap to 500 psi. Pass. ***Job Complete) Final WHP 620/520/VAC. 7/23/2024 T/I/O = 527/520/VAC. Temp = SI. IA FL (FB request). No AL. Flowline disconnected. IA FL @ 5446' (sta # 3 SO, 310 bbls). SV, WV = C. MV = O. IA, OA = OTG. 16:45 7/27/2024 T/I/O= 527/520/0 Load IA Pumped 5 bbls 50/50 followed by 330 bbls DSL Tags Hung DSO notified of well status upon departure FWHP's=1850/1798/0 Daily Report of Well Operations PBU 18-26B 7/29/2024 T/I/O=500/500/0. Pre CDR3. Removed 4" tree cap assembly and installed 4" x 7" x- over with 7" tapped blind on SV. Torqued flanges to spec. Pressure tested x-over against SV to 300/5000 psi. Passed. Cycled SV.***Job Complete*** Final WHP's 500/500/0. 8/4/2024 T/I/O = 680/440/VAC. Temp = SI. Bleed IAP (pre rig). CDR tree installed, flowline disconnected. No wellhouse or grating. IA FL @ surface. Bled IAP to BT to 10 psi in 40 min (10.7 bbls). Monitored for 30 min. IAP decreased 10 psi and went on a vac. Final WHPs = 680/VAC/VAC. SV = C. MV = O. IA, OA = OTG. 10:00 David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Date: 07/15/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Well Name PTD Number API Number 18-26 193-005 50-029-22329-00-00 18-26PB1 193-005 50-029-22329-70-00 18-26A 197-194 50-029-22329-01-00 18-26APB1 197-194 50-029-22329-71-00 18-26APB2 197-194 50-029-22329-72-00 18-26B 209-017 50-029-22329-02-00 Definitive Directional Surveys (Composited) -Gyrodata Re-Survey 06/20/2024 Main Folder Contents: Please include current contact information if different from above. T39182 T39183 T39184 T39185 T39186 T3918718-26B 209-017 50-029-22329-02-00 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.15 13:40:18 -08'00' 4-1/2" 12.6# x 3-1/2" 9.3#/9.2# Drilling Manager 05/01/24 Monty M Myers 324-262 By Grace Christianson at 3:02 pm, May 01, 2024 * BOPE test to 2500 psi. * Variance to 20 AAC 25.112(i) approved for alternate plug placement for reservoir abandonment with fully cemented liner and all drilling within the PB oil pool. DSR-5/2/24 10-407 SFD 5/3/2024MGR10JUN24*&:JLC 6/10/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.11 13:50:17 -05'00'06/11/24 RBDMS JSB 061424 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: May 1, 2024 Re:PBU 18-26C Sundry Request Sundry approval is requested to set a whipstock and mill the window in 18-26B, as part of the pre-rig and drilling/completing of the proposed 18-26C CTD lateral. Proposed plan for PBU 18-26C Producer: Prior to drilling activities, prep work will be conducted to set the well up for screening/sidetracking. Service coil will cleanout cement to top of CIBP, mill CIBP and push to lower plug, perforate, set cement retainer and squeeze cement to perfs above to get cement in IA for dual string window exit. After the prep work is done, the screening will be conducted to drift for whipstock and MIT (caliper if needed). E-line will set a 3-1/2" packer whipstock. If unable to set the whipstock, for scheduling reasons, the rig will perform that work. See 18-26C PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 3-1/2" packer whipstock. A 3-1/2”x7” dual string 2.80" window + 10' of formation will be milled. The well will kick off drilling in the Ivishak Zone 4 and lands in Zone 1. The lateral will continue in Zone 1 to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will isolate the parent Sag perfs. This Sundry covers plugging the existing Sag perforations via the liner top packer set post rig (alternate plug placement per 20 AAC 25.112(i)). Pre-Rig Work - (Estimated to start May 2024): 1. Service Coil: Mill plug/cement, perf, set retainer, cement IA a. Mill cement cap at 8,990’ MD to CIBP at 9,000’ MD b. Mill CIBP at 9,000’ MD and push to 9,545’ MD c. Perf 3-1/2” above plug at 9,545’ MD d. Set cement retainer and squeeze cement in IA from 9,545’ MD up to perfs at 8,905’ MD e. Cleanout 3-1/2” to whipstock setting location 2. Slickline: Dummy WS drift and Caliper (if needed) a. Drift and Caliper past whipstock setting location 3. Fullbore: MIT-IA or T to 2,500 psi (minimum) 4. E-line: Set 3-1/2” packer whipstock a. Top of whipstock at 9,030’ MD (top of window at 9,030’ MD = pinch point) b. Oriented 180° ROHS (high side) 5. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: x Reference PBU 18-26C PTD submitted in concert with this request for full details. x General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,460 psi a. Give AOGCC 24hr notice prior to BOPE test 2. Mill Window 3. Drill Production Lateral 4. Run and Cement Liner 5. Freeze Protect and RDMO 6. Set LTP* and perforate post rig * Approved alternate plug placement per 20 AAC 25.112(i) Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 PTD 224-042 Suicide squeeze from lower perfs to top perfs taking possible returns back to the well bore. - mgr Sundry 324-262 ,p yp This completion will isolate the parent Sag perfs. Perf through 9-5/8" too. Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B3 B4 B1 B2 Choke Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer PRUDHOE BAY UNIT 18-26B 209-017 324-262 SFD 5/3/2024 SFD 5/3/2024 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:209-017 6.50-029-22329-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 12061 12020 8692 8392 9633 none 7854 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 34 - 114 34 - 114 1490 470 Surface 3434 13-3/8" 36 - 3470 36 - 3404 5020 2260 Intermediate 8904 9-5/8" 34 - 8938 32 - 8240 6870 4760 Liner 1141 7" 8649 - 9790 8047 - 8588 8160 7020 Perforation Depth: Measured depth: 10220 - 12010 feet True vertical depth:8677 - 8692 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr x 3.5" 9.3#1 31 - 8495 31 - 7933 8392 7854Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Liner 2466 2-3/8" 9590 - 12056 8535 - 8691 11200 11780 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 45305061440 39373848 0 14194 90 384 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Dave Bjork David.Bjork@hilcorp.com Authorized Name:Torin Roschinger Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-4672 Treatment descriptions including volumes used and final pressure: 13. Sr Operations Engineer Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing 5 GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8691 Sundry Number or N/A if C.O. Exempt: 321-180 No SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Swap tubing Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028321, 0028307 PBU 18-26B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Meredith Guhl at 4:49 pm, Jul 29, 2021 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), c=US, o=Hilcorp North Slope, LLC, ou=Prudhoe Bay East, email=Torin.Roschinger@hilcorp.com Date: 2021.07.29 15:35:43 -08'00' Torin Roschinger (4662) MGR30JUL2021 DSR-7/29/21 RBDMS HEW 8/2/2021 SFD 7/30/2021 ACTIVITYDATE SUMMARY 3/20/2021 T/I/O = SSV/150/0+. Temp = SI. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (50 psi), bled to 0 psi. Functioned LDS, all moved freely. Pumped through void, good returns Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (0+ psi). Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. SV, WV, SSV = C. MV = O. IA & OA = OTG. 11:44 4/10/2021 CMIT-TxIA & MIT-OA (RWO EXPENSE) CMIT-TxIA to 2730/2726 psi ***PASS*** Terget=2500 psi Max Applied=2750 psi MIT-OA to 1170 psi***PASS*** Pumped 9.2 bbls crude down IA to pressure up Tbg/IA for CMIT-TxIA tests. On final tet took Tbg/IA to 2771/2767 psi for CMIT-TxIA. Tbg/IA lost 22/22 psi in 1st 15 mins and 19/19 psi in 2nd 15 mins for a total loss of 41/41 psi in 30 min test. Bled Tbg/IA to 200/200 psi and got back ~ 9 bbls. Pumped 5.1 bbls total DSL down OA on 2 MIT-OA tests. 2nd test took OA to 1202 psi. OA lost 19 psi in 1st 15 mins and 13 psi in 2nd 15 mins for a total loss of 32 psi in 30 min test. Bled OA to 20 psi and got back ~ 4 bbls. DSO notified of well status per LRS departure. 4/19/2021 ***WELL S/I ON ARRIVAL*** (RWO expense) TAG 4-1/2" HOLD OPEN SLEEVE AT 2,165' SLM / 2,192' MD W/ 3.80" SWAGE. ***LDFN, WELL S/I & SECURED, CONTINUED ON 4/20/21 WSR*** 4/20/2021 ***CONTINUED FROM 4/19/21 WSR*** (RWO expense) PULL BAKER 35KB STRADDLE PATCH (Upper 3 elements intact) FROM 5,685' SLM / 5,705' MD. 2-3/8" SPACER STL PIN SEPERATED 2 THREADS DOWN LEAVING 4.22' ANCHOR PACKER IN HOLE. ***LDFN, WELL S/I & SECURED, CONTINUED ON 4/21/21 WSR*** 4/21/2021 ***CONTINUED FROM 4/20/21 WSR*** (RWO expense) RAN 2.50" L.I.B. TO THE TOP OF ANCHOR PACKER AT 5,478' SLM (Good impression). FISH BAKER 35KB ANCHOR PACKER (Missing two slips - Elements intact) FROM 5,478' SLM. RAN 2.84" CENT, INLINE MAGNET, FLAT MAGNET TO 8,484' SLM (Recovered misc. metal). EQUALIZE & PULL 1-11/16" BAKER IBP (Missing 1" stiffener ring) FROM 8,591' SLM / 8,625' MD. RAN 2.67" MAGNET TO LINER TOP AT 9,558' SLM / 9,590' MD (Recovered both missing slips). ***LDFN, WELL S/I & SECURED, CONTINUED ON 4/22/21 WSR*** Daily Report of Well Operations PBU 18-26B Daily Report of Well Operations PBU 18-26B 4/22/2021 ***CONTINUED FROM 4/21/21 WSR*** (RWO expense) FOUND FLUID LEVEL IN TUBING AT 70' SLM W/ 4-1/2" GS. SET 3-1/2" PX PLUG BODY W/ 19.25" FILL EXTENSION & P-PRONG AT 8,507' MD. MADE ONE ATTEMPT TO PULL EQ. PRONG FROM TGE-DGLV AT ST #5 (8,456' MD). TOOL APPEARED TO BE SHEARED BECAUSE CHUNK OF METAL BEHIND DOGS. PULL TGE-DGLV FROM ST #5 (8,456' MD, Eq. prong missing). LRS PERFORMED SUCCESSFUL CMIT-T x IA TO 2879 PSI (T/IA bled back to 23/14 psi). ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** NOTE: EQUALIZING PRONG (.875" Fish neck) FROM TGE-DGLV & 1.69" IBP STIFFNER RING LEFT IN HOLE. 4/22/2021 T/I/O= 50/35/69. Temp= SI. LRS unit 72 Assist Slickline (RWO EXPENSE). CMIT- TxIA to 2750 psi. PASSED at 2879 psi. (3000 psi max applied pressure). T/IA lost 88/100 during the first 15 minutes. T/IA lost 34/35 psi during the second 15 minutes. T/IA lost 122/135 psi during the 30 minute test. Pumped 10.75 bbls 0f 44* F crude to achieve test pressure. Bled back 12.7 bbls to Final T/I/O= 30/20/70. S/L had control of the well upon departure. 4/24/2021 T/I/O = 40/0/0. Set 4" H TWC #440 @120". Leak tested against TWC (Pass). Pulled 4" H TWC. RD tree platforms. RDMO. ***Job Complete*** 4/29/2021 T/I/O=35/44/73 SI PERFORM CIRC OUT (RWO EXPENSE) PUMPED 5 BBLS 60/40 FOLLOWED BY 845 BBLS KCL DOWN TBG TAKING RETUNS UP IA TO FL OF 18-14. PUMPED 2 BBLS 60/40 SPACER FOLLOWED BY 172 BBLS OF DIESEL DOWN IA TAKING RETURNS UP TBG TO 18-14 FL. U-TUBE DIESEL TXIA FOR 1 HR FOR FP. PUMPED 3 BBLS 60/40 TO FREEZE PROTECT SURFACE LINES. DSO/WSL NOTIFIED. TAGS HUNG ON MV AND IA. VALVE POSITIONS=SV WV SSV CLOSED MV OPEN CVS OTG FWHP=749/789/0 5/6/2021 WELL SI ON ARRIVAL (AK E-line Chem Cut Tbg) MIRU STRING SHOT TBG OVER INTERVAL: 8469' - 8479' MD CHEMICAL TUBING @ 8479' MD (4' BELOW TOP OF FIRST FULL JOINT ABOVE X-NIPPLE @ 8507' MD) ***JOB COMPLETE*** 5/7/2021 T/I/O = 0/0/Vac. Temp = SI. CMIT-TxIA PASSED to 982/984 psi (Post Chem Cut). No AL, flowline, or wellhouse. Rig scaffold installed around well. T & IA FL @ surface. Max applied pressure = 1000 psi. Used 2.5 bbls amb Diesel to pressure T/IA to 1002/1004 psi. T/IA decreased 15/14 psi in the 1st 15 min, and 5/6 psi in the 2nd 15 min for a total of 20/20 psi in 30 min. Bled T/IA to 0 psi (2.5 bbls). Hung tags. Final WHPs = 0/0/Vac. SV, WV, SSV = C. MV = O. IA, OA = OTG. 11:30 5/19/2021 ***COST PLACEHOLDER *** Shear Valve and 4 dglv's and latches 6/4/2021 cost placeholder for CalIV pups and crossovers Invoice # 002307 6/4/2021 placeholder for CalIV invoice #002315 test plug Daily Report of Well Operations PBU 18-26B 6/26/2021 T/I/O = VAC/VAC/VAC. Temp = SI. Bleed Control line (pre RWO). Wellhouse, grating, and flowline disconnected. Rig scaffold installed. Bled CLP from 360 psi to 0 psi in <1 min (1/4 cup of energized fluid). Held open bleed for 30 min. CLP immediately began increasing pressure. Held open bleed on CLP for an additional 1 hr. Monitored for 30 min. CLP increased 2 psi. Final WHPs = VAC/VAC/VAC. Control line pressure = 2 psi. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:30 6/26/2021 T/I/O = 0/0/0 (Pre-Rig Circ-Out). Pumped 5 BBL's of 50/50 methanol down 18-15 FL to verify flowpath per DSO. Pumped 5 BBL's of 50/50 methanol down the IA w/ returns up TBG to 18-15 FL. Pumped 50 BBL's of 2% Baraklean in fresh water followed by 216 BBL's of 1% KCL. ***JOB CONTINUED ON 27-JUN-2021*** 6/27/2021 Job continued from 6-26-21, (PRWO circ-out) Pumped 499 (Job total of 715) bbls 1% KCL down IA w/returns up TBG to 18-15. Shut in well and reverse out skid RDMO, WV,SB,SSV=closed MV=open IA/OA=OTG, FWHP's 900/900/300. Notify DSO 6/27/2021 T/I/O = 700/700/0. Bleed WHP's to 0. Set 4" CIW H CTS BPV. Pull 4-1/16" CIW tree & 13-5/8" 5M x 4-1/16" 5M FMC THA. Wellhead techs set CTS plug, install test adapter in hanger lift threads & PT (pass). Function & torque TBG spool LDS's. Install new BX-160 ring gasket. Install 13-5/8" BOP's, torque BOP flange x TBG spool flange to 1990 ft/lbs. Install target 90's on BOP choke & kill lines. Install integral flanges on pitside IA & OA. RDMO. *NOTE - Test adapter galled to TBG hanger lift threads - 4-1/16" CTS BPV will not drift test adapter. 6/29/2021 TBird - 1: Continue to RU TB-1. Spot and RU over Well # 26. Limited RU on Day crew due to Crew numbers and Personell changes that were made. Prep for AOGCC witnessed BOP testing. Pre-BOP test w/ both crews. Rig Pit #1 brought back in service. Review procedure for testing BOP's, WC Plan, and line up. Chk valves per Standing Orders. Set up PVT's, trip tank, and trip sheet. Test PVT alarms, calibration & set points. Test gas alarms. Perform BOPE test 250psi low/3000psi high- AOGCC witness waived by Jeff Jones. Email 6/29. 24 notice given 6/28 at 10:13 am. 6/30/2021 TBird-1: Contiue WSR from 6/29/21 Job Scope: TBG Swap. Prep and preform BOPE testing. AOGCC waived witness ( Jeff Jones) RU landing joint. BOLDS pull 80k with no issues hanger to floor and laid down. Diesel seen at surface RU and circluated to clear. Shift Change PJSM/Procedure pulling pipe from well. Check for flow... flow coming from TBG. RU to Rock Diesel out of well. Pumped 1% KCL down IA to clear diesel from TBG saw diesel after 25 bbls clean fluid. Continued to pump until cleaned up 70 bbls total. Start pulling completion with single control line counting bands on control line. Possilby 56 bands no clear number based on previous completion tally. Called out BOP drill; kick while tripping, went faily well but like all things we have room for improvement. Continue pulling TBG while spooling control line. ...Continue WSR on 7/1/2021... Daily Report of Well Operations PBU 18-26B 7/1/2021 TBird-1: Continue WSR from 6/30/21 Job Scope TBG Swap. Continue pulling 4 1/2 TDS w/control line. After 40 jts pulled 1/4" conrtol line parted at surface. Found kink in line may have been caused by line slipping while pulling completion out of hole. Able to pull five joints while pulling control line by hand roughly 200'. Retied onto spool and continued pulling TBG to TRSV. Decompletion of well completed. Chemical cut looked clean and fit tesed in Overshot. Tally pipe and verify jewery placement in string. RU WFD Torque turn services. Start running new completion. Baker-Loc on all connections below PKR assembly with light coating. Continue running new 4 1/2" x 3 1/2" using Best Life 2000 on VAM connections and Clear Glide on JFEBear connections. ...Continue WSR on 7/2/2021... 7/2/2021 T/I/O = TWC/0/0. Post Rig. ND BOP. Wellhead Tech. Prepped hanger. Set THA and torqued to API specs. Wellhead Tech PT adapter void. C/O with dayshift. ***Job In Progress*** Day shift...(Mott) Torqued 4" Cameron tree to API spec. Set tree scaffold. RU Cameron lubricator PT 4" Cameron tree to low 300psi and high 5000psi. Passed. Pulled 4" H TWC @ 125" Installed floor timbers. Reconnected production pipe. Torqued to spec. Set house installed floor kit and backing. Job Complete. 7/2/2021 TBird-1: Continue WSR form 7/1/2021 Job Scope TBG Swap. Continue running new 4 1/2" x 3 1/2" completion. Conduct well control drill; kick wihile tripping, with TB and Weatherford torque turn team. Run New 3-1/2" x 4-1/2" Completion. Locate and Land tubing, Set Packer and perform MIT's on Tbg and IA. Shear GLM valve and install "H" style TWC and test from above to 500psi. RDMO and release rig at 11:59pm. 7/2/2021 T/I/O=0/0/0 Assist Rig MIT-T / MIT IA PASSED (RWO) Pump 1.2 bbls 1% kcl down tbg to MIT T (Rig charted both tests) Pump 6 bbls 1% kcl down IA to MIT IA. FWHPs=0/0/0 7/3/2021 ***WELL S/I ON ARRIVAL*** R/U HES 759 ***CONT WSR ON 7/4/2021*** 7/3/2021 T/I/O= 50/11/2 (Freeze protect) Pump 5 bbls 50/50 meth followed by 230 bbls diesel followed by 5 bbls 50/50 meth down TBG taking returns up IA to OTT. SV WV closed MV open CV/s OTG FWHP's T/I/O= 3/1/3 7/4/2021 ***CONT WSR FROM 7/3/2021*** PULL BALL & ROD FROM 3-1/2" RHC @ 8,398' MD PULL STA# 3 RK-DMY GLV FROM 5,488' MD PULL STA# 4 RK-DKC GLV FROM 3,143' MD SET 1-1/2" RK-LGLV IN STA #4 @ 3,143' MD SET 1-1/2" RK-OGLV IN STA #3 @ 5,488' MD PULL 3.5" RHC BODY @ 8418' MD PULL PX PRONG @ 8,491' SLM, TIGHT SPOTS @ 8,470' SLM (CHEM CUT) @ 8,489' SLM (POSSIBLE FILL) PULL 3.5" PX PLUG BODY @ 8,507' MD (8,498' SLM) RECOVERED TGE PRONG & CONTROL LINE BANDING IN FILL EXTENSION ***WELL LEFT SI*** Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:209-017 6.API Number:50-029-22329-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028321, 028307 Property Designation (Lease Number):10. 8. PBU 18-26b 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well 5 Operations shutdown Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 12061 Effective Depth MD: L-80 11. 5/5/2021 Commission Representative: 15. Suspended Contact Name: David Bjork Contact Email: David.Bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 4-1/2" Camco TRDP-4A SSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8691 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 8548 / 7973 2192 / 2186 Date: Liner 2466 2-3/8"9590 - 12056 8535 - 8691 11200 11780 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 36 - 3470 36 - 3404 14. Estimated Date for Commencing Operations: BOP Sketch 36 - 114 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" Basker SB3 10220 - 12010 8677 - 8692 4-1/2 12.6# x 3-1/2 9.2#32 - 9790 Liner 8625 8029 8625 9633 36 - 114 470 13-3/8 9-5/8" Contact Phone:(907)564-4672 Date: 4-7-21 4760 80 149020"Conductor 2260 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3434 5020 Intermediate 8904 34 - 8938 32 - 8240 1141 7" 8649 - 9790 8047 - 8588 8160 7020 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2470 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 55 By Samantha Carlisle at 10:06 am, Apr 09, 2021 321-180 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.09 09:07:27 -08'00' Bo York DSR-4/12/21SFD 4/9/2021MGR14APR2021 BOPE test to 3000 psi. Annular to 2500 psi. 10-404YesRequired? Comm 4/15/21 dts 4/15/2021 JLC 4/15/2021 RBDMS HEW 4/16/2021 RWO 18-26b PTD: 2090170 Well Name:18-26b API Number:500292232902 Current Status:Shut-In Rig:Thunderbird #1 Estimated Start Date:5/05/2021 Estimated Duration:4 days Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd:N/A Regulatory Contact:Carrie Janowski Permit to Drill Number:2090170 First Call Engineer:Dave Bjork 907-564-4672 907-440-0331 Second Call Engineer:Ryan Thompson 907-564-5280 907-301-1240 AFE Number:215-01275 IOR 150 Current Bottom Hole Pressure:3,350 psi @ 8,800’ TVD 7.4 PPGE | Offset producer 18-14c - 12/19 Max. Anticipated Surface Pressure:2,470psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:600 psi (Taken on 11/24/14) Min ID:1.83” ID KB patch @ 5,705’ MD Max Angle:95 Deg @ 11,159’ Brief Well Summary: 18-26 is a Z1A lateral producer that was CTD sidetracked in 2009 and stayed online until 2014. An LDL Indicated 9 tubing leaks, it is not worth patching. We will now pursue a RWO to replace the L-80 tubing. Objective: Pull the existing 4 ½” x 3-1/2” L80 tubing out of the well and replace with 4-1/2” x 3-1/2” 13 chrome tubing. Achieve a passing MIT-IA & MIT-T. Pre RWO work: SL - Pull 35KBME patch Pull IBP Secure well with 2.81” PX plug at 8,507’ DHD – MIT OA – 1200 psi CMIT-TxIA to 3,000-psi after resecuring well, run eline LDL if failing. Cycle LDS’s PPPOT-T PPPOT-IC EL – LDL if necessary Circulate well to 1% KCL w/ diesel FP on T & IA DHD - Bleed WHP’s to 0 Cut tubing @ ~8480 00 SFD 4/9/2021 RWO 18-26b PTD: 2090170 Proposed RWO Procedure: 1. MIRU Thunderbird #1 Rig. 2. Circulate KWF as necessary and bleed pressure to 0. 3. Set TWC 4. ND tree. 5. NU BOPE configured top down, Annular, 2-7/8” x 5-1/2” VBRs, Blinds and integral flow cross. Test BOPE to 250psi Low/3000psi High, annular to 250psi Low/2500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Thunderbird #1 BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8” x 5-1/2” VBR’s with 4 ½” and 2-7/8” test joints. Test the Annular preventer with a 2-7/8” test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 6. Pull TWC 7. Pull 4 1/2” x 3-1/2” tubing 8. Run 4 ½”x 3-1/2” Chrome tubing with stacker packer completion 9. Land Hanger 10. Drop ball and rod. 11. Set Packer. 12. Perform MIT-T to 3000 psi and MIT-IA to 3000 psi. 13. Shear valve and circulate FP fluid. 14. Set TWC 15. ND BOPE 16. NU tree and tubing head adapter. 17. Test both tree and tubing hanger void to 500psi low/5,000psi high. 18. Pull TWC 19. Rig down Thunderbird #1. Post rig Slickline Work 1. Pull Ball and rod and RHC profile 2. Set GLV’s per GL Engineer 3. RDMO & pop well Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing RWO 18-26b PTD: 2090170 Wellbore Schematic RWO 18-26b PTD: 2090170 Proposed Wellbore Schematic RWO 18-26b PTD: 2090170 RWO BOPs 109017 25 482 WELL LOG TRANSMITTAL DATA LOGGED 3/G/201S ;al K.BENDER To: Alaska Oil and Gas Conservation Comm. March 2, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 MAR 0 6 2015 RE: Leak Detection Log: 18-26B Run Date: 2/21/2015 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 18-26B Digital Log Image files 1 CD Rom 50-029-22329-02 Leak Detection Log 1 Color Log 50-029-22329-02 VANED :;: . , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed. 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. h~ ®~ - ~ ~ ~ Well History File Identifier Organizing (done) RES N for Items: Greyscale Items: ^ Poor Quality Originals: ,.~,_~~ ~IIII~I~~u~IV~I~ DIG AL DATA Diskettes, No. ,. ^ Other, No/Type: o ae,~a,~~cea IIIIIIIIIGIllllll OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: Maria BY: Date: /s/ Pro'ect Proofing I II I II (I II I (I II I I III BY: _ Maria Date: D /s/ Scanning Preparation _~ x 30 = ~ + _~~ -TOTAL PAGES (Count does not include cover sheet) ~ BY: Maria ) _ Date:. ~ ~ ~ ~ ~ © /s/ ~, Production Scanning Stage 1 Page Count from Scanned File: ~~ ~ (Count does include cov heet) Scanning is complete at this point unless rescanning is required. Page Count Matches Number in Scanning Preparation: YES _ BY: Maria Date: Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: NO /s/ ~~ NO "iuumuuAUiii ReScanned BY: Maria Date: /s/ Comments about this file: a~,,,~~e~~ iuuiuimuiim 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA RECEIVED i Alk KA OIL AND GAS CONSERVATION COM ION 3 i 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.ShutdownD Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development 0 Exploratory ❑ 209-017-0 • 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-22329-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028321 1 kOu00L,63ori• PBU 18-26B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): '10.Field/Pool(s): LDL,Caliper PRUDHOE BAY,PRUDHOE OIL • 11.Present Well Condition Summary: Total Depth measured 12061 feet Plugs measured None feet true vertical 8691.23 feet Junk measured 9633 feet Effective Depth measured 12020 feet Packer measured See Attachment feet true vertical 8691.67 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 34-114 34-114 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 8901 9-5/8"47#NT8OS 32-8933 32-8236.48 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10220-10350 feet 10400-10940 feet 10990-11030 feet 11120-11170 _feet 11350-11530 feet 11640-11780 feet 11870-12010 feet True Vertical depth 8677.24-8679.79 feet 8679.84-8682.93 feet 8682.52-8682.4 feet 8680.04-8676.5 feet 8677.91-8679.87 feet 8682.21-8685.41 feet 8688.54-8691.76 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4-1/2"Camco TRDP-4A SSSV 2192 2185.91 SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED NOV 2 5 2013 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: 28 14172 3556 0 1061 Subsequent to operation: 116 2586 556 0 2014 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development IN• Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil U , Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email GarrY.Catronc BP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564-4424 Date 10/28/2013 `t-F' RBDMS NOV - 4 2,131 ii /x / 13 Form 10-404 Revised 10/2012 ( (9 Submit Original Only , • • Packers and SSV's Attachment ADL0028321 SW Name Type MD TVD Depscription 18-26B SSSV 2192 2133.91 4-1/2" Camco TRDP-4A SSSV 18-26B PACKER 8548 7920.95 4-1/2" Baker SB3 Packer 18-26B PACKER 8658 8001.29 7"TIW Liner Top PKR 1 Casing / Tubing Attachment ADLOO28321 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 34 - 114 34 - 114 1490 470 LINER 2237 7"29# NT80S 8649 - 10886 8046.82 - 8683.22 8160 7020 LINER 2466 2-3/8"4.6# L-80 9590 - 12056 8534.85 - 8691.28 11200 11780 PATCH 27 3-1/2" KB Patch 5705 - 5732 5449.51 - 5474.33 PRODUCTION 8901 9-5/8"47#NT80S 32 - 8933 32 - 8236.48 6870 4760 SURFACE 71 13-3/8"68# K-55 36 - 107 36 - 107 3450 1950 SURFACE 3633 13-3/8"68#L-80 107 - 3740 107 - 3651.89 5020 2260 • TUBING 3094 4-1/2" 12.6# L-80 31 - 3125 31 - 3082.67 8430 7500 TUBING 6665 3-1/2" 9.2# L-80 3125 - 9790 3082.67 - 8588.36 10160 10530 • NW i • o-) -a co o U Z Co o N U) LL p EL- N o U) Q O — d O O O 00 co co b O ° Q ° d 0 ID a) H a) cp. 0) _ 2 eC Oo -0 "° 2 E E > - Y 3 5OCD Co U) LL U W ° 0) ° O t 0 cn N- W —1 O TD -0 (.�\ d a) `C)2 u) lJ I d (A __ cJ o c J ca 0—0 oN ° 2 LL L - 2 Z c -o fA a) a) o a)0 W Z L - o - c a) m Q co �_ u°i U Ill a)E _, o S? H o_ c-) N J 0 it Q +-, E J o < `.LL W W a) V' a) in a) ¢ a) a) W J 00 CO Q = 3 Z 5' o U) U) U) U) QO _ . Q Q u) >-I— U) J ° n A co Oc 0 w '0 0H Lo QQc a) ?� 7 s� i rN Z - a°'j m2 o � O 3 o c a) � Q O N W O a) 2 H J ca.0 o N 'p • J 0 „sr)) V H cc:, .� U) Z U) L N a) J N U) N EH � C a W I- Y ° ouj o -0 co z E o a) in — el 71; 03 IA w Z 0 a t J CO (a Q U LL CO V7 o a) 00 N Uw cc � ti m r: c6 oLL N Q- a) U Ca) OO w 00 woO © J2 J u) E Q -a _o wO * O J c)) 00 U � O 2oLL0_ 2 � I- LS �a °6 c aa)) � - II t p cn00 --s)-� a00 � F- LL HN �� H 0- -a a) — I__ -1 a) Z O Q Q= O Q c � H � � �C� U ° .c al ca Quit 0Et > * 0.. Z X M W 3 (X LHL m N •_ H 0 * J H ID t) o o u) a CL -I Maco N coo0_ C � CC o0 -Q0CD>> CD ~ 2 E Cl- c > Uw0 < cli �+ > > M � N <Y U) co .o H _ H W > ? a) M a) Q � N W Z Z ▪CO CC Q co a) � co IZ r ~ ~ H co w Lt O -- ~ a) )) W O N Z Qn LLi �� UpoQ � °o Q-,- o ca r- c � 0 � Z � O L Z aoO) 0 ' U) U) coY ,— o N E ' > E � 2YHHWct Ofa J N �) I— OccooH � ddd Wes ,° 3 m °; cm `n o o -o° OWw = UcA U) NJ NCV M � 0u_ - 00wwwoOp2 � -0 -0 O � OL -0 .2) J Lij JCD JELL � � p � HH QLLHHHp _ ,nEZ in o S > o = cH0 � J WZ w4U (01 co � I- OO � -' > QHQQn 00 a oo a°) II O ! o0dw> w>> � 0 W W J UU U) HU) U) U) ZU0 JO to 0Oto J o � * < * * U U Z D 2 a 0 : : 0 _1 U) <Y _J _1 c * H CO N o -H i CO �Q * w' co co co co � co co f C) CD CD O O O O CD CD O N N N N N N N N- ti N- h. Daily Report of Well Operations ADL0028321 ***CONT WSR FROM 8/8/13 *** DRIFT TBG W/2.80" PATCH DRIFT(340" OAL) TO WRP AT 8563' SLM/8570' MD PULL 3-1/2"WFD WRP FROM 8560' SLM/8570' MD D &T 3-1/2" KB LTP W/2'x1-7/8" STEM, 2.73" CENT., XO &2.60" LIB @ 9562' SLM, 9584' MD. LOG 24 ARM CALIPER UP FROM 9550' SLM. (good data) 8/9/2013 ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** ***WELL SHUT-IN ON ARRIVAL*** (Patch/tbg Liner) ATTEMPTED TO PULL 35 KB LTP AT 9,564'SLM, UNABLE TO LATCH. RAN 3 1/2 SPEAR, SAT DOWN @ 9564'SLM, RECOVERED 13" OF 35 KB LTP, MOST OF ONE • ELEMENT& PIECES OF CORRODED METAL FROM LTP RAN 2.50 CENT,2 3/8 BRUSH,SAT DOWN AT 9,566' SLM,MOVED PKR UP 30',FELL BACK DOWN. MADE 2 RUNS W/2.5 CENTS' STEM,2 7/8 BRUSH,SAT DOWN AT 9,567'SLM (recovered 94.75" of 35 kb Itp & 1 stinger seal ring, all pieces very corroded, missing 1 slip & stinger assy) RAN 2.50" CENT., 5' OF STEM, 2-7/8" BLB &2.15" MAGNET TO 9,574' SLM (recovered 1/2 of missing slip) RAN 2.50" CENT., 5' OF STEM, 1.85" MAGNET TO 9,574' SLM (recovered 8 small pieces of corroded metal) 9/9/2013 ***CONT. WSR ON 9/10/13*** T/I/0=281/247/0, Temp=S/I, Assist Slickline, Toolstring stuck in hole (Corrosion Mitigation) Pumped 2 bbls meth followed by 119 bbls of 120*crude down tubing to free up toolstring and flush tubing. 9/10/2013 ***Job continued to 9-11-13 WSR*** • Daily Report of Well Operations ADL0028321 ***CONT. WSR FROM 9/9/13*** (Patch/tbg Liner) RAN 3-1/2" BLB &2.50" MAGNET TO 9,370' SLM, PUSH OBSTRUCTION DOWN TO 9,402' SLM (no pieces of Itp recovered) RAN 3-1/2" BLB, 2-7/8" BLB, &2.13" MAGNET TO 9,558' SLM, WORK DOWN TO 9,574' SLM (recovered x3 small pieces of corroded metal from Itp) RAN 2-7/8" BLB &2.13" MAGNET TO 9,574' SLM (recovered x2 small pieces of corroded metal from Itp) RIH W/ KJ, 2'x1-1/2" STEM, 1.90" CENT., B. NOSE, SAT DOWN @ 9574'SLM.WORKED DOWN TO 9581'SLM,TOOLS HUNG UP,LOST JAR ACTION, • LRS ON LOC,PUMPED 92 BBLS CRUDE ,2 BBLS METH,TOOLS CAME FREE,REC ALL TOOLS.. RAN 3 1/2 BRUSH,2.72 G.RING,SAT DOWN @ 9527'SLM,WORKED DOWN TO 9580'SLM. RAN 3 1/2 BRUSH,2 PRONG GRAB,SAT DOWN @ 9572'SLM,NO REC. RAN 3 1/2 BRUSH,3 PRONG GRAB,SAT DOWN @ 9582'SLM,NO REC. RAN 3-1/2" BLB, 2.50" CENT., 5'x1-1/2" STEM, &2-7/8" BLB, SD AT 9,582' SLM &WORKED DOWN TO 9,590' SLM (recovered small metal ring) RAN 2.73" LIB TO DEPLOYMENT SLEEVE AT 9,582' SLM (9,590' MD) (impression of deployment sly, possible trash on side of lib) RAN 1.75" CENT. TO 9,602' SLM, WORKED DOWN TO 9,508' SLM, LOST JARRING ACTION FOR 5 MIN 9/10/2013 ***CONT. WSR ON 9/11/13*** ***CONT. WSR FROM 9/10/13*** (Patch tbg/Liner) RAN PDS 24 ARM CALIPER IN DEPLOYMENT SLV FROM 9,593' SLM-9,146" SLM (good data). 9/11/2013 **** LEFT WELL SHUT IN,TURNED WELL OVER TO PAD OPER. ***** ***WELL SI UPON ARRIVAL*** (ELINE SET PATCH) • INITAIL T/I/O = 200/220/0 SPOT IN EQUIPMENT DUAL BARRIER TEST WELL SI AND SECURE UPON DEPARTURE FINAL T/I/O = 200/220/0 9/29/2013 ***JOB CONTINUED ON 30-SEP-2013*** Daily Report of Well Operations ADL0028321 ***WELL SI UPON ARRIVAL*** (ELINE SET PATCH) INITIAL T/I/O = 200/220/0 RIH W/ HEAD/UPCT/BAKER-10/PATCH OAL=44.5' MAX OD = 2.78" FISHING NECK= 1.33" SET 23' BAKER 35 KB PATCH @ 5707'-5730.6' ELEMENT TO ELEMENT. TOP OF PATCH @ 5705' (PATCH SPECS: MAX OD = 2.78", MIN ID = 1.83", OAL= 29.37') TIED INTO PDS LDL/CCL DATED 09-JUL-2013. FINAL TWO = 200/220/0 • 9/30/2013 ***JOB COMPLETE -WELL SI AND SECURE UPON DEPARTURE. HAND OVER W/ DSO*** T/I/O= 154/218/15 Temp= S/I MIT-IA FAILED to 2500 psi --5 attempts-- (Post Patch) Pressured up IA with 16 bbls 50*f crude. IA lost 54 psi in 1st 15 mins and 37 psi in 2nd 15 mins for a total loss of 91 psi in 30 min test. Estimated and LLR of.45 GPM @ 2500 psi. Bled pressure back, bled - 5 bbls crude. Final WHPs 169/205/14 10/4/2013 SV,WV,SSV= Shut MV,IA,OA= Open T/I/O =181/319NAC. Temp= SI. MIT-IA PASSED to 2500 psi (Post patch). No AL. Pumped 7 Bbls diesel to pressure up IAP to 2500 psi. IAP lost 55 psi in the 1st 15 minutes &29 psi in the 2nd 15 minutes for a total of 84 psi in 30 minutes. Bumped IAP back up to 2500 psi. IAP lost 22 psi in the first 15 minutes & 15 psi in the 2nd 15 minutes for a total loss of 37 psi in 30 minutes. Bled IAP to 300 psi in 42 minutes (7.8 Bbls). Final WHP's 180/300NAC. 10/8/2013 SV, WV, SSV=C. MV=O. IA, OA=OTG. 02:30. • ■ .A TREE= 41116•CM/ • SA NOTES:W ELL ANGLE>70°@ 9933' "VELL'-EA° 18-26B ACTUATOR AXELSON NTIAL KB.ELE 52' BF ELEV= ___ _. ' 20" H ? N KOP= 2075' Max Angle= 95°@ 11159' 13.3/8'CSG, H 106' / 2192' --14-1/2 CAMCO TROP-4A,TRSSSV,D=3.812" 1 Datum MD= 9981' 68#,K-55, �Y 1 2640• HEST TOP OF CEMNT(12105/03) 1 Datum TV D= 8600' D=12.415" •1 4-1/2'TBG,12.8#,L-80,.0152 bpf,D=3.958" H 3125 �, �'� 3125' H41JY X 3 1/2"XO,D=2.992" 1 /�/ 1441 GAS LFT MANDRELS 1/ 14 ST MD TVD DEN TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80,D=12.347" --1 3740' H 1* 1 3257 3206 21 MMG MY RIC 0 07/31/11 2 5497 5258 23 MNG DMY RK 0 07/31/11 Minimum ID =1.83" 5705' -5734' 3 7673 7250 27 M1A3 OMY 1110 0 02/16/93 3-1/2" BKR 35 KB ME PATCH . 4 8338 7811 37 WAG MK RK 0 02/16/93 . 5 8456 7904 40 MMG DM/ TGE 0 02/16/93 3-1/2"BKR 35 KB ME PATCH,D=1.83" —1 5705'-5734'1 '' (09/30/13) 1 850T H3-1n•OTIS X NP,D=2.813" 8546' H3-1/2"X 4112"XO,D=2.992" 1 8548' H9-518'X 4-1/2"BKR SB-3 PKR ►.∎ w/K ANCHOR D=3.875' woo 8555 H4-1/7 X 3-1/2'XO,D=2.992" 1 'TOP OF 7°LNR H 8649' I 8593' H3-1/7 FICR SWN NP,MLL D TO 2.80"(04/12(98) e - 8649' H 9`518"x7"TiW TIEBACK En, D=a I 1 8658' H9-518-x r my S-3 R(R w/D1H S HGR,ID=? 1 1 9-5/8"CSG,47#,NT-80S NSCC D=8.681" H 8933' TOP OF 2-3/8"LNR 9590' ' 9590' H2.70"BTT DEPLOY MBYT SLV,D=2250" •1 /•4 141 144 2-3/8'BKR W-EGTOCK(04/05/09) —1 9790' 141 ►41 ►4 ? 1—{FISH-PARTIAL(19')3-1/2"KBOP(9/10113) I w/RA TAG�9796' •'• .01•X 1 3-1/2'TBG,9.2#,1-80,.0087 bpf,D=2.992' H -9790 -**/ 1411 *04 ••• 7"LM,29#,NT-80S NSCC,.0371 bpf, D=6.184' 1 ^9790 X41�4/ I••• MLLOUT Wf1OOW{18-268) 9780'-9798 ∎y X44`. x`41 41!•4♦ PERFORATION SUMMARY S I x`440.4 FIEF LOG:MOM.ON 04/15/09 ANGLE AT TOP PERF:89°@ 10220' Nate:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 1.56" 6 10220-10350 0 04/14/09 1.56" 6 10400-10940 0 04/14/09 1.56" 6 10990-11030 0 04/14/09 1.56" 6 11120-11170 0 04/14/09 1.56" 6 11350-11530 0 04/14/09 1.56" 6 11640-11780 0 04/14/09 1.56" 6 11870-12010 0 04/14/09 PBTD H 12020' 1 '4;�4� 12-3/8'LNR,4.7#,L-80,.0039 bpf,D=1.995" H 12066' I. DATE REV BY OOMVENTS DATE REV BY COM ENTS P UDHOE BAY UNIT 02/16/93 D9 ORIGINAL COMPLETION 08/09/13 RKT/JM3 PULLEDWRP(08/09/13) WH_L: 18-26B 06/21/98 NORDIC 1 CTD SIDETRACK (18-26A) 09/12/13 JIG/PJC PULL LTPf FISH DH(9/10/13) PERMT No: 2090170 04115/09 NORDIC 1 CTD SIDETRACK (18.268) 10/09/13 ATO/JMD SET BKR 35 KB PATCH(9/30/13) API No: 50-029-22329-02-00 1 08/08/11 RCT/PJC GLV C/O(07/31/11) SEC 19,T11N,R15E,755'FNL&296'PM. 05/23/13 TJWJMD SET WRP/FISH(05/04/13) 07/22/13 S(YJMD RUN MP(07/08-09/13) BP Exploration(Alaska) DATA SUBMITTAL COMPLIANCE REPORT 9/9/2010 Permit to Drill 2090170 Well Name/No. PRUDHOE BAY UNIT 18-26B Operator BP EXPLORATION (ALASK/y INC API No. 50-029-22329-02-00 MD .12060 TVD 8691 Completion Date 4/14/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION _. ..~~- / Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR, RES, GR /CCL / CNL (data taken from Logs Portion of Master Well Data Maint WeII Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ~ e mea/rrmi rvumoer Name acair ~r~euia rvo ararr atop a.n rcecervea a.unnnGnw Log Neutron 5 Blu 8500 12007 Case 6/3/2009 MCNL, Lee, CCL, GR, TNN, TNF 14-Apr-2009 D C Lis 18100~eutron 8507 12014 Case 6/3/2009 LIS Veri, GR, CNT D D Directional Survey 36 12061 Open 5/18/2009 pt Directional Survey 9636 12061 Open 5/18/2009 pt LIS Verification 9643 12063 Open 7/10/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS D C Lis 182431nduction/Resistivity 9643 12063 Open 7/10/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS og Induction/Resistivity 25 Col 9789 12061 Open 7110!2009 MD MPR, GR og Induction/Resistivity 5 Col 9789 12061 Open 7/10/2009 TVD MPR, GR ag Gamma Ray 25 Col 9789 12061 Open 7/10/2009 MD GR og Gamma Ray 5 Col 9640 12040 Open 7/10/2009 Depth Shift Monitor Plot Well Cores/Samples Information: u Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 9/9/2010 Permit to Drill 2090170 Well Name/No. PRUDHOE BAY UNIT 18-26B Operator BP EXPLORATION (ALASF(A) INC API No. 50-029-22329-02-00 MD 12060 TVD 8691 Completion Date 4/14/2009 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMAION (~'' Well Cored? Y / II~11LL~ii Daily History Received? " / N Chips Received? ~-~Ffid~' Formation Tops ~ N Analysis ~LLAI~ Received? Comments: Compliance Reviewed By: Date: ~ ~-9~/~ ~~ ~ L? ~ ~ ~~: ~~a~~ ~~ Alaska -~~~~~,~~ 333 Wo 7gh Aveo Suite 100 Aneh®rage, Alaska 99501 Attention: Christine Mahnken 12eference: 18-26B k Contains the following: k 1 LDWG Compact Disc f (Includes Graphic Image files) '~ 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 2539510 Sent by: Catrina Guidry Date: 07/08/09 q 12eceived by: ~ / Date: PLEASE r~CKN®VVLEDGE RECEIPT BY SIGNING ~ RETURNING ®R FAXING Y®jJR C®PY P'AXe (9u7j 267-6683 ~-, `l !lRliE~ faker lFIughes Ile1')<'E~j 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~~ ~~ ~~~ p~ ~ ~''.~ a s r r ~^'. RAKER HvGMES ~a~~~- Atlas PRII~TT' ISTRI~IJT'I®l~ I.IS'T COMPANY BP EXPWKAIlUN (ALASKA) INC CUUNIY NOKCH SWPE BUKUUGH WELL NAME 18-266 STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 7/8/2009 THIS DISTRIBUT[ON LIST AUTHORIZED BY CATRINA GUIDRY SO #: 2539510 Copies of Copies Digital Copies of Copies Digital Each Lag oC Film Data Ench Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC l Company DNR -DIVISION OF OIL & GAS Person PETROTECHN[CAL DATA CENTER Person CORAZON MANAOIS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE. AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Persun F[LE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 l Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Br' BAKER ATLAS-PDC 170 f 5 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed By ~ y~,~r ~;~ Page 1 of 1 05/26/09 ~~ ril~iJ~~r~~ N0.5242 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Loa Description Date BL Color CD 4-04A/T-30 BOCV-00014 CH EDIT PDCL-GR (SCMT) / 04/27/09 1 4-02lO-28 AYKP-00019 RST 05/07/09 1 1 H-19B B2WY-00004 MCNL 7/09 1 1 18-26B 82NJ-00001 MCNL - 04/14/09 1 1 J-20B AXED-00020 MCNL ~ 04/12/09 1 1 W-06A AZCM-00027 RST ~ _ (. 05/16/09 1 1 15-15C BOOR-00004 MCNL ~ 03/15/09 1 1 14-31 BOCV-000015 RST _ ~ ~ 05/15/09 1 1 E-05B 09AKA0035 OH MWD/LWD EDIT 04!06/09 2 1 06-146 09AKA0031 OH MWD/LWD EDIT 03/27/09 2 1 r~.~rax r~~nrvvnr~evue ne~ur ~ at aiurvmu Hrvu ne i ~rtrvirvu vrvt Puri twin l v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 _ ~ ~ ,,; 900 E. Benson Blvd. _ Anchorage, Alaska 99508 ~ ` ~' Date Delivered: ~]~N ® 3 2®G9 ~s iii ~ so ~®rr~i~~ieart /~ ~tich~r~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 0 Anchorage, AK 9 3-28 ATTN: Beth Received by: U ~~~ ~~~ ~~N 1 7260 Homer Drive Anchorage, AK 99518 • To Whom It May Concern: May 15, 2009 Please find enclosed directional survey data for the following wells: 09-33A 18-26B 03-14B 03-14BL1 G-31BPB1 G-31B Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: ~ ~J~ ,State of Alaska AOGCC DATE: ~ ~ ~f~ ~~ °~ Cc: State of Alaska, AOGCC ~~~_ ~i~ Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, May 18, 2009 11:03 AM To: Saltmarsh, Arthur C (DOA) Subject: FW: PBU 18-26B /PTD # 209-017 Page 1 of 1 Oops... Just found an error on this Completion Report. Please hand correct the TD to 12061'. The TVD does not change. Thanks! Terrie From: Hubble, Terrie L Sent: Monday, May 18, 2009 10:41 AM To: 'Saltmarsh, Arthur C (DOA)' Subject: PBU 18-26B /PTD # 209-017 H i Art, Please reference the following well: Well Name: PBU 18-26B Permit #: 209-017 API #: 50-029-22329-02-00 Top Perf MD: 10220' Bottom Perf MD: 12010' This well began Production on May 6, 2009 Method of Operations is: Flowing Test Data Reported on Completion Report Dated 05/13/09 5/18/2009 Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.comJ Sent: Monday, May 18, 2009 10:41 AM To: Saltmarsh, Arthur C (DOA) Subject: PBU 18-266 / PTD # 209-017 Hi Art, Please reference the following well: Well Name: PBU 18-26B Permit #: 209-017 API #: 50-029-22329-02-00 Top Perf MD: 10220' Bottom Perf MD: 12010' This well began Production on May 6, 2009 Method of Operations is: Flowing Test Data Reported on Completion Report Dated 05/13/09 5/18/2009 STATE OF ALASKA =~"~~ ALAS~OIL AND GAS CONSERVATION CO•SSION ~~~w~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG SAY ~ ~ ~g~g 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended (QlC~LS685 ~OftS. Ot1lffltSStOn zoAAC zs.,os zoAAC zs.,,o Develo~8 Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ~ Strati raphic 2. Operator Name: 5. Date Comp., Susp., or Aband. „/ 12. Permit to Drill Number BP Exploration (Alaska) Inc. 4/1 009 ~ 209-017 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 4/9/2009 ~ 50-029-22329-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 4/11/2009 ~ PBU 18-266 FWL, SEC. 19, T11 N, R15E, UM 755 FNL, 296 Top of Productive Horizon: 8. KB (ft above MSL): 52' 15. Field /Pool(s): 2413' FSL, 2022' FEL, SEC. 13, T11 N, R14E, UM Ground (ft MSL): 17' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Oil Pool 2968' FSL, 387' FEL, SEC. 13, T11N, R14E, UM 12020' 8692' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 692051 y- 5961121 Zone- ASP4 12060'- 8691' ADL 028321 & 028307 TPI: x- 689653 y_ 5964229 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: - 5964825 Zone- ASP4 Total De th: x- 691273 2192' 2186' y p 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): ' Submit electr i n rin informs i n r 20 AAC 25.050 N/A ft MSL 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 C 25.071 ): MWD DIR, GR, RES, GR / CCL / CNL ~ //11/,D O`iJ~ J~~ i~?~4 ~~$,3.6.5 '~7Y~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM .TOP BOTTOM SIZE. CEMENTING RECORD PULLED 0" 91.5# H-4 urface 110' u 11 2000 # old et II _ / / _ 1413 sx CS III, 550 sx 'G' 200 sx CS II / " 47# NT-80S 8 4 ' 12-1/4" 1 x Class'G' 7" 2 NT-80S 8649' 7' 8 8' -1/2" 35 x I s' ' 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RecoRD If Yes, IISt each I (MD+TVD of To Bottom Pe 8 nteNal Open rforation Size and Number): SIZE DEPTH SET MO PACKER SET MD ; p ~ 1 56 Gun Diameter 6 spf 4-1/2", 12.6#, L-80 3126' . , MD TVD MD TVD 3-1/2", 9.2#, L-80 3126' - 9790' 8549' 10220' - 10350' 8677 - 8680' 10400' -10940' 8680' -8683' 2rj, ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10990' - 11030' 8683' - 8682' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 11120' - 11170' 8680' - 8677' 7 ' ' ' ' 2200' Freeze Protect w/ McOH 11350 -11530 86 8 - 8680 11640' - 11780' 8682' - 8685' 11870' - 12010' 8689' - 8692' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Yet N/A Date Of Test: HOUfS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 5/10/2009 12 TEST PERIOD 540 373 -0- 40 690 Flow Tubing Casing Press: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): Press. 1,037 20 24-HouR RATE. 1,080 745 -0- Not Available 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 2@ AAC 250.471. .,.,..., : ~ lu~i None ~i ? Form 10-407 Revised 02/2007 CONTINUED ON I?i as -QE z '< 28. GEOLCSGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS - NAME TVD Well Tested. ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Zone 1 B 9940' 8639' None Zone 1A /TDF 10058' 8670' Formation at Total Depth (Name): Zone 1A /TDF 10058' 8670' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore ing is tru and correct to the best of my knowledge. w 5 ~~ Signed Terrie Hubble Title Drilling Technologist Date PBU 18-266 209-017 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A rOV81 NO. Drilling Engineer: Mel Rixse, 564-5620 INSTRUCTIONS GeNerv-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Operations Summary Report Legal Well Name: 18-26 Common Well Name: 18-26 Event Name: REENTER+COMPLETE Start: 3/3/2009 Contractor Name: NORDIC CALISTA Rig Release: 4/16/2009 Rig Name: NORDIC 1 Rig Number: Page 1 of 12 ~ Spud Date: 2/3/1993 End: 4/16/2009 Date From - To Hours Task Code ~~ NPT Phase i Description of Operations 4/4/2009 09:00 - 23:30 14.50 MOB P PRE Move rig from DS9-33A to DS18-33B 23:30 - 00:00 0.50 MOB P PRE PJSM, Spot rig over well 4/5/2009 00:00 - 00:15 0.25 BOPSU P PRE ACCEPT RIG AT MIDNIGHT 00:15 - 03:30 3.25 BOPSU~P PRE 03:30 - 10:30 7.00 BOPSU P PRE 10:30 - 13:00 2.501 RIGU P PRE 13:00 - 15:00 2.00 RIGU N SFAL PRE 15:00 - 21:45 6.75 RIGU P PRE 21:45 - 23:00 1.25 RIGU P WEXIT 23:00 - 00:00 1.00 RIGU P WEXIT 4/6/2009 00:00 - 03:45 3.75 WHIP P WEXIT 03:45-03:50 ~ 0.08~WHIP ~P 03:50 - 06:15 2.42 WHIP P 06:15 - 06:30 0.25 STWHIP P 06:30 - 08:45 I 2.251 STWHIPI P 08:45 - 10:30 1.75 STWHIP P 10:30 - 10:45 0.25 STWHIP P 10:45 - 14:00 3.25 STWHIP P PJSM for N/U of BOPE N/U BOPE Pressure test BOPE at 250 and 3500 psi. Test witness waived by AOGCC inspector Chuck Scheeve. Send test report to AOGCC. Rig up new injecter head and guide arch. Found both inside support arms for guide arch were 2" to long. There was no way to measure the length until the guide arch was mounted, Call out for SWS welder to fix guide arch support Shorten support arms for guide arch at SWS shop. Install internal grapple and pull 2" coil from reel to injecter. Cut off grapple, boot end of E-Line. Fill coil, PT inner reel valve. Reverse circ. at 3800 psi for 30 seconds once E-line started moving, to limit E-Line slack. Cut off 330' of coil to find E-Line. Pressure test inner reel valve @ 3500psi for 10min Install, Pressure test & pull test Kendal CTC P/U whipstock BHA Function test MWD Tool RIH with Whipstock BHA RIH with whipstock BHA Tie in @ 9,670' to 9,750.3' no correction Run CCL From 9,670' to 9,812' Close EDC Shear at 3,900psi Set Top of Whipstock @ 9,790' POOH SAFETY MEETING. Review procedure, hazards and mitigation for UO BHA and M/U 2.80" window milling BHA with CoilTrak tools. Lay out whipstock setting tools. M/U 2.80" window milling BHA #2 with 2.80" HCC, diamond window mill and string reamer, Xtreme motor, 2 jts CSH and CoilTrak. BHA OAL = 108.19'. RIH with milling BHA #2. _Circ 0.3 bpm, 1100 psi. Log GR tie-in, added 3' to CTD RIH and tagged top of whipstock at 9790'. Mill 2.80" window thru 3-1/2" and 7" liners. Lowside exit. Hole inclination = 73 deg at 1.5 bpm, 3150 psi, RIH very slow, not able to get WOB without a stall. Several stalls, 12 stalls and no progress. Strong stalls, not a motor problem. Tme mill at 0.05' every 5 min to ease down onto tray. Still stalls. Top of whipstock appears to be out from ID of 3-1/2" tubing. Ham Cement from the cement squeeze was mi a out wit a WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT a F'flnt6tl: 4/"L//LUU'J 1U:14:5L HM BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: 18-26 Common Well Name: 18-26 Spud Date: 2/3/1993 Event Name: REENTER+COMPLETE Start: 3/3/2009 End: 4/16/2009 Contractor Name: NORDIC CALISTA Rig Release: 4/16/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code ~ NPT ~ Phase ~, Description of Operations 4/6/2009 10:45 - 14:00 3.25 STWHIP P WEXIT on the hig h side of the 3-1/2" tubing. This would allow the w ipstoc tray to set out rom the D of the tubing or did not allow the whipstock to set correctly. 14:00 - 16:00 2.00 STWHIP P WEXIT Stalling at top of whipstock at 9790.19'. Ease mill down to 9790.17' and inc pump from 1.2 bpm to 1.3, 1.4 every 5 min to push mill onto tray. Still stalled at 1.4 bpm after 10 min. at same depth. No WOB. Ease mill down to 9790.16'. Park coil. Ease pump up from 1.2 bpm in 0.1 bpm increments., every 4 min Stalled at 1.5 bpm after 15 min. No WOB. Ease down to 9790.17'. Circ 1.16 bpm, inc pump in 0.1 bpm increments, every 4 min. Stalled at 1.52 bpm at 9790.17' after 15 min parked. Ease down to 9790.17'. Circ. 1.06 bpm, inc pump in 0.1 bpm increments, every 4 min. Stalled again. 16:00 - 18:00 2.00 STWHIP P WEXIT Time mill down onto whipstock very slowly. Parked mill at 9790.15', RIH 0.01' every 4 min. Mill took 100# WOB at 9790.17'. Milled off for the first time. Time mill at 0.01' every 2 min. 1.52 bpm, 3150 psi free spin. 50-100# WOB Milled to 9790.8`. Time mill at 0.8 FPH, 1.5 bpm, 3150-3350 psi, 1000# WOB. No stalls. Milled to 9791'.' Total of 24 stalls so far. 18:00 - 21:00 3.00 STWHIP P WEXIT Time mill at 0.8 FPH, 1.5 bpm, 3300-3400 psi, 1.3k-1.9k# DHWOB Mill to 9792.4'. 21:00 - 00:00 3.00 STWHIP P WEXIT Time mill at 0.8 FPH, 1.6 bpm, 3650-3900 psi, 1.8-2.3k# DHWOB Mill to 9792.6'. PU due to high WOB. PU Wt 31 k#. 3300 psi FS C~3 1.6 bpm. Time mill at 0.4-0.8 FPH, 1.6 bpm, 3600-3800 psi, 1.8k# DHWOB Mill to 9792.8'. 4/7/2009 00:00 - 04:00 4.00 STWHIP P WEXIT Mill from 9792.8', 1.6 bpm, 3450-3600 psi, 1.8k-2.Ok# DHWOB Mill to 9793.8'. 04:00 - 06:00 2.00 STWHIP P WEXIT Mill 1.6 bpm, 3450-3500 psi, 2.Ok-2.1k# DHWOB, 0.2 FPH Mill to 9794.1'. 06:00 - 10:00 4.00 STWHIP P WEXIT Mill 2.80" window, 1.54 bpm, 3150-3400 psi, 2.OK wob, 0.2 FPH Milled to 9794.8'. 10:00 - 12:30 2.50 STWHIP P WEXIT Mill 2.80" window, 1.54 bpm, 3150-3300 psi, 2.OK wob, 0.15 FPH Picked up clean and reamed down clean thru window. Milled to 9795.2'. 12:30 - 15:00 2.50 STWHIP P WEXIT Mill 2.80" window, 1.52 bpm, 3150-3350 psi, 2.2K wob, 0.1 FPH Very slow ROP, not milling off, still getting motor work, no overpull picking up off bottom. 20 milling hours on mills and motor. Printed: 4/27/2009 10:14:52 AM BP EXPLORATION Page 3 of 12 Operations Summary Report Legal Well Name: 18-26 Common Well Name: 18-26 Spud Date: 2/3/1993 Event Name: REENTER+COMPLETE Start: 3/3/2009 End: 4/16/2009 Contractor Name: NORDIC CALISTA Rig Release: 4/16/2009 Rig Name: NORDIC 1 Rig Number: Date I From - To Hours Task '~, Code ~ NPT `~ Phase Description of Operations __ _ i_ _ _ _!_ __. __ 4/7/2009 12:30 - 15:00 2.50 STWHIP P WEXIT Milled to 9795.5'. 15:00 - 16:45 1.75 STWHIP P WEXIT POH to check mill and motor. 16:45 - 17:00 0.25 STWHIP P WEXIT SAFETY MEETING. Review procedure, hazards and 17:00 - 17:45 I 0.751 STWHIPI P 17:45 - 19:40 1.921 STWHIPI P 19:40 - 22:40 I 3.001 STWHIPI P 22:40 - 00:00 I 1.331 STWHIPI P 4/8/2009 100:00 - 02:00 I 2.00 I STWHIPI P 02:00 - 03:30 1.501 STWHIPI P 03:30 - 03:45 0.25 STWHIP P 03:45 - 04:40 0.92 STWHIP P mitigation for C/O mill and motor of milling BHA. WEXIT Lay out CoilTrak, L/O mills and motor. Window mill still in gauge at 2.80" NoGo. 40% uniform wear across face of mill and gauge. Good condition for 20 hrs of milling. Pics of mill sent by E-mail. Motor was still tight. M/U new 2.80" HCC window mill and 2.79" string reamer and new Xtreme motor. M/U 2 jts 2-1/16" CSH and CoilTrak. BHA OAL = 108.17'. WEXIT RIH with 2.80" window milling BHA #3. New mill and motor. Circ. 0.3 bpm, 900 psi. Log GR down from 9,715 ft. Correct +2 ft. WEXIT Bring pump to 1.52 bpm C~ 3020 psi Free spin. Tag at 9,795.9 ft. Mill 2.80" window at 1.51 bpm, 3000-3100 psi. DWOB = 1-2 Klbs. PVT = 294 bbls. 20:30 9796.3 ft DWOB = 1.83 Klbs 21:30 9796.6 ft DWOB = 1.92 Klbs 22:00 9796.9 ft DWOB = 2.65 Klbs 22:00 Sample is all cement and metal. Mill to 9797.2 ft with 3.4 Klbs DWOB. WEXIT Pick up to re-establish milling parameters. Up wt is 30K, Free Spin is 2950 psi at 1.49 bpm. 23:00 Mill at 9797.2 ft at 3200 psi, 3.4 Klbs DWOB 00:00 9797.4 ft DWOB = 3.60 Klbs. WEXIT Continue milling window. Extremely slow ROP. 00:00 9797.4 ft DWOB = 3.6 Klbs 01:00 9797.65 ft DWOB = 3.92 Klbs 01:30 Clean pickup to 30K, run back down to 9797.7 ft with 4 Klbs DWOB, about 200 psi motor work. Sit at this depth for 30 min, no change in any milling parameters. Progress since 23:00 is around 0.1 ft/hr or less. WEXIT POOH to check mill. Sample at 02:10 and at 03:00 had several grains of sand and pyrite, 99% metal and cement. WEXIT SAFETY MEETING. PJSM for change out BHA. WEXIT L/D BHA #3. Mill is 2.80" No-Go, has moderate wear on the motor, without the string reamer. A #4. 04:40 - 06:45 2.08 STWHIP N DPRB WEXIT 06:45 - 07:10 0.42 STWHIP N DPRB WEXIT 07:10 - 10:15 3.08 STWHIP N DPRB WEXIT 10:15 - 11:45 1.50 STWHIP N DPRB WEXIT RIH. Log GR tie-in. Added 2' CTD. RIH and tag bottom at 9796.0'. Mill 2.80" window, 1.5 bpm, 3000-3200 psi, 2.5-3K wob Milled 0.1'. very slow ROP. Milled to 9796.1'. POH with milling BHA. Nnrnea: aie n~oua 1U:14:SL HM ~ ~ BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Name: 18-26 Common Well Name: 18-26 Spud Date: 2/3/1993 Event Name: REENTER+COMPLETE Start: 3/3/2009 End: 4/16/2009 Contractor Name: NORDIC CALISTA Rig Release: 4/16/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task ~~ Code . NPT ~ Phase ',~ Description of Operations 4/8/2009 11:45 - 12:00 0.25 STWHIP N DPRB WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for changing out the window mill. 12:00 - 12:45 0.75 STWHIP N DPRB WEXIT Lay out CoilTrak. Stand back 2 jts CSH, M/U new 2.80" HCC, 12:45 - 14:15 1.50 STWHIP N DPRB WEXIT 14:15 - 14:30 0.25 STWHIP N DPRB WEXIT 14:30 - 18:30 4.00 STWHIP N DPRB WEXIT 18:30 - 20:00 1.50 STWHIP N DPRB WEXIT 20:00 - 00:00 I 4.001 STWHIPI N I DPRB I WEXIT 4/9/2009 100:00 - 01:20 I 1.331 STWHIPI N I DPRB I WEXIT 01:20 - 04:00 I 2.671 STWHIPI N I DPRB I WEXIT ~ 04:00 - 06:30 2.50 STWHIP N DPRB WEXIT \ ~~ ` ~v v 06:30 - 08:00 1.50 STWHIP N DPRB WEXIT 08:00 - 08:15 0.25 STWHIP N DPRB WEXIT 08:15 - 09:00 0.75 STWHIP N DPRB WEXIT 09:00 - 10:45 1.75 STWHIP N DPRB WEXIT 10:4 - 11:00 0.25 STWHIP N DPRB WEXIT 11:00 - 16:20 5.33 STWHIP N DPRB WEXIT diamond window mill. H and CoilTrak tools. BHA OAL = 108.17'. RIH with 2.80" window milling BHA #5. Circ at 0.4 bpm, 1200 psi. Log GR tie-in, added 3.5' CTD. RIH and tagged bottom at 9795.9'. Milled 2.80" window, 1.51 bpm, 1-1.8K WOB. Milled to 9797.0'. Continue milling from 9797.0 ft at 1.50 bpm, 3170 psi. DWOB = 2.45 Klbs. 19:00 9797.10 ft DWOB = 2.40 Klbs 3135 psi 20:00 9797.25 ft DWOB = 2.51 Klbs 3105 psi Pick up to check wt, 32K clean pickup. Free spin is 2900 psi. Mill at 9797.07 ft DWOB = 2.18 Klbs 3073 psi 21:00 9797.30 ft DWOB = 2.31 Klbs 3070 psi 22:20 9797.45 ft DWOB = 2.35 Klbs 3149 psi 23:00 9797.55 ft DWOB = 2.35 Klbs 3259 psi 00:00 9797.88 ft DWOB = 2.39 Klbs 3149 psi Continue milling window. 00:00 9797.88 ft DWOB = 2.39 Klbs 3149 psi 01:00 9798.15 ft DWOB = 1.98 Klbs 3127 psi Nothing across shakers except metal fragments. Stall at 9798.3 ft, up wt is 3K overpull. Work back down slowly to stall point, get periodic motor work on the way down. Stall again at same spot, pick up clean and work back down 02:00 ample has some sand in it. Stall at 9798.48 ft. Continue working past stall point slowly. After 9798.5 ft ROP is 5-6 ft/hr, DWOB around 1 K. Window is from 9790 - 9798.5' Sample from 9800 ft is 10% formation. Drilled rathole to 9808~ft. 2K WOB, 5-10 fph Back ream up thru window clean. POH with milling BHA. SAFETY MEETING. Review procedure, hazards and mitigation for adding string reamer to milling BHA. Lay out CoilTrak, Stand back CSH, M/U 2.79" HCC diamond string reamer between mill and motor. M/U CSH and CoilTrak tools. BHA OAL = 108.1 T. RIH with 2.79" window reaming BHA #6. Circ 0.4 bpm, 1200 psi. Log tie-in, add 3.5' to CTD. RIH, ream window, it was clean down to 9796'. several stalls at 9796'. Swap to new GeoVis while reaming. 1.4 bpm, 2100 psi. Printed: 4/27/2009 10:14:52 AM ~ ~ BP EXPLORATION Page 5 of 12 Operations Summary Report Legal Well Name: 18-26 Common Well Name: 18-26 Spud Date: 2/3/1993 Event Name: REENTER+COMPLETE Start: 3/3/2009 End: 4/16/2009 Contractor Name: NORDIC CALISTA Rig Release: 4/16/2009 Rig Name: NORDIC 1 Rig Number: Date j From - To Hours Task .Code NPT Phase Description of Operations 4/9/2009 11:00 - 16:20 5.33 STWHIP N DPRB WEXIT Ream down slow and stall at bottom of window at 9798.5'. Back ream, Ream down stall at 9798.6'. Backream clean. Ream down past bottom of window. Ream formation down to 9808'. Backream clean to above whipstock. 16:20 - 18:00 1.67 STWHIP N DPRB WEXIT POOH. 18:00 - 18:15 0.25 STWHIP N DPRB WEXIT SAFETY MEETING. Discuss hazards and mitigations for change out BHA. 18:15 - 19:00 0.75 STWHIP N DPRB WEXIT Tag stripper and UD BHA #6. Mill is 2.79" No-Go, string reamer 2.78" No-Go. 19:00 - 19:50 0.83 DRILL P PROD1 - P/U BHA #7 -New HYC SRX bit, 1.5 deg Xtreme, 2.375" CoilTrak with Res. BHA OAL = 67.95 ft. 19:50 - 22:40 2.83 DRILL P PROD1 RIH BHA #7. Log GR down from 9670 ft, correct +4 ft. 22:40 - 00:00 1.33 DRILL P PROD1 Pass through window at 180E TF, turn on pump and tag at 9809 ft. Drill at 1.66 / 1.63 bpm, Free Spin 2350 psi. Initial ROP is 70-100 ft/hr with DWOB 1-3 Klbs. Start with 150R TF to drop angle. Drill to 9,882 ft. 4/10/2009 00:00 - 01:10 1.17 DRILL P PROD1 Continue drilling from 9882 ft to 9950 ft. 01:10 - 01:25 0.25 DRILL P PROD1 Wiper trip from 9950 ft to window. Clean pass up and down. 01:25 - 03:40 2.25 DRILL P PROD1 Drill from 9950 ft. Continue RH turn. 1.62 / 1.65 bpm ~ 2400 - 2600 psi. ROP is 40-70 ft/hr with DWOB 1-2 Klbs. PVT = 318 bbls, ECD = 9.50 ppg. Drill to 10,090 ft. 03:40 - 03:50 0.17 DRILL P PRODi Wiper trip from 10,090 ft to window. 03:50 - 04:40 0.83 DRILL P PROD1 Drill from 10 090 ft to end of build at 10,150 ft. 04:40 - 06:15 1.58 DRILL P PROD1 POOH. Pull through window and open EDC. POH. 06:15 - 06:30 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for UO build BHA, function test BOPE and M/U lateral /RES BHA. 06:30 - 07:00 0.50 DRILL P PROD1 Lay out CoilTrak tools. 07:00 - 07:30 0.50 BOPSU P PROD1 Function tested BOP's. 07:30 - 08:30 1.00 DRILL P PROD1 M/U Lateral /RES BHA #8 with HYC BC Bit #2, 1.1 deg motor, RES and CoilTrak. BHA OAL = 67.95'. Test tools at surface. 08:30 - 10:15 1.75 DRILL P PROD1 RIH with Lateral CoilTRak /RES BHA #8. Circ 0.2 bpm, 700 psi. 10:15 - 10:30 0.25 DRILL P PROD1 Log GR tie-in at RA tag. Add 4' CTD. 10:30 - 10:45 0.25 DRILL P PROD1 RIH clean to bottom. Tag at 10150' 10:45 - 12:00 1.25 DRILL P PROD1 Drill Z1A lateral, 1.6 bpm, 2500-2700 psi, 1-2K WOB, 100R, 89 deg incl, 130 fph, Drilled to 10300'. 12:00 - 12:40 0.67 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. 12:40 - 14:20 1.67 DRILL P PRODi Drill Z1A lateral, 1.6 bpm, 2500-2700 psi, 1-2K WOB, 80R, 89 deg incl, 110 fph, Drilled to 10450'. 14:20 - 15:00 0.67 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. Printed: 4/27/2009 10:14:52 AM BP EXPLORATION Page 6 of 12 Operations Summary Report Legal Well Name: 18-26 Common Well Name: 18-26 Spud Date: 2/3/1993 Event Name: REENTER+COMPLETE Start: 3/3/2009 End: 4/16/2009 Contractor Name: NORDIC CALISTA Rig Release: 4/16/2009 Rig Name: NORDIC 1 Rig Number: Date I From - To .Hours Task Code NPT Phase Description of Operations 4/10/2009 15:00 - 16:20 1.33 DRILL P PROD1 Drill Z1A lateral, 1.6 bpm, 2500-2700 psi, 1-2K WOB, 80R, 90 deg incl, 120 fph, Drilled to 10600'. 16:20 - 16:45 0.42 DRILL P PROD1 Wiper trip to window. Clean hole. 16:45 - 17:00 0.25 DRILL P PROD1 Log GR tie-in at RA tag. Added 1' CTD. 17:00 - 17:20 0.33 DRILL P PROD1 RIH clean to bottom. 17:20 - 18:25 1.08 DRILL P PROD1 Drill Z1A lateral, 1.6 bpm, 2500-2700 psi, 1-2K WOB, 80R, 91 deg incl, 150 fph, Drilled to 10,750 ft. 18:25 - 19:30 1.08 DRILL P PROD1 Wiper trip from 10,750 ft to window. Clean pass up and down. 19:30 - 20:40 1.17 DRILL P PROD1 Drill Z1A lateral. Hold 88-89 deg for now to go down 1 ft TVD. 1.52 / 1.53 bpm ~ 2400-2600 psi. ROP is 120-150 ft/hr with 1-2 Klbs DWOB. PVT = 298 bbls, ECD = 9.63 ppg. Drill to 10,900 ft. 20:40 - 21:50 1.17 DRILL P PROD1 Wiper trip from 10,900 ft to window. Clean pass up and down. 21:50 - 23:20 1.50 DRILL P PROD1 Drill from 10,900 ft. Hold this TVD for now and follow planned well trajectory. 1.51 / 1.51 bpm C~ 2300-2550 psi. ROP is 150 Whr with 1-2 Klbs DWOB. PVT = 300 bbls, ECD = 9.66 ppg. In /Out is 8.55 / 8.65 ppg. Drill to 11,050 ft. 23:20 - 00:00 0.67 DRILL P PROD1 Wiper trip from 11,050 ft to window, and tie-in log. No correction. 4/11/2009 00:00 - 00:55 0.92 DRILL P PROD1 Continue wiper trip and tie-in from 11,050 ft. 00:55 - 02:50 1.92 DRILL P PRODi Drill from 11,050 ft. Hold 20L TF to_ uickl re ain 4 ft TVD indication of shale on Res. 1.68 / 1.68 bpm @ 2500-3 00 psi. ROP is 150 ft/hr with 2-3 Klbs DWOB. PVT = 300 bbls, ECD = 9.75 ppg. 8.58 / 8.66 ppg In /Out. Drill to 11,200 ft. 02:50 - 04:30 1.67 DRILL P PROD1 Wiper trip from 11,200 ft to window. Start mud swap from 11,200 ft. 04:30 - 05:30 1.00 DRILL P PROD1 Drill from 11,200 ft. Try to maintain 8925 ft TVD for now. 1.64 pm ~ 250 -2800 ft. ROP is 150 ft/hr with 1.2 Klbs DWOB. Mud swap in progress. Drill to 11,350 ft. 05:30 - 07:00 1.50 DRILL P PROD1 Wiper trip from 11,350 ft to window. RIH clean to bottom. 07:00 - 08:45 1.75 DRILL P PROD1 Drill Z1A lateral, 1.6 bpm, 2300-2700 psi, 1-2K wob, 80R TF, 130 fph, 90 incl, Drilled to 11500'. 08:45 - 09:55 1.17 DRILL P PROD1 Wiper trip to window. 09:55 - 10:10 0.25 DRILL P PRODi Log GR tie-in at RA tag at 9796'. Added 1.5'. 10:10 - 11:00 0.83 DRILL P PROD1 RIH. Sat down in shale at 11050'. Reamed down easy. RIH clean to bottom. 11:00 - 11:40 0.67 DRILL P PROD1 Drill Z1A lateral, 1.6 bpm, 2300-2700 psi, 1-2K wob, 80R TF, 120 fph, 88 incl, Drilled to 11575'. 11:40 - 12:20 0.67 DRILL P PROD1 Drill Z1A lateral, 1.6 bpm, 2400-2700 psi, 1-2K wob, 80L TF, 110 fph, 88 incl, Printed: 4/27/2009 10:14:52 AM BP EXPLORATION Operations Summary Report Page 7 of 12 Legal Well Name: 18-26 Common Well Name: 18-26 Spud Date: 2/3/1993 Event Name: REENTER+COMPLETE Start: 3/3/2009 End: 4/16/2009 Contractor Name: NORDIC CALISTA Rig Release: 4/16/2009 Rig Name: NORDIC 1 Rig Number: Date From - To .Hours Task Code NPT Phase Description of Operations 4/11/2009 11:40 - 12:20 0.67 DRILL P PROD1 Drilled to 11650'. 12:20 - 14:15 1.92 DRILL P PROD1 Wiper trip to window. Clean hole up to shale at 11050'. Ream 14:15 - 15:30 1.251 DRILL ~ P 15:30 - 15:45 I 0.251 DRILL I P 15:45 - 17:45 I 2.001 DRILL I P 17:45 - 19:00 I 1.251 DRILL I P 19:00 - 22:00 I 3.001 DRILL I P 22:00 - 23:05 I 1.081 DRILL I P 23:05 - 00:00 I 0.921 DRILL I P 4/12/2009 100:00 - 02:50 I 2.831 DRILL I P 02:50 - 03:50 I 1.001 DRILL I P 03:50 - 06:45 2.92 DRILL P 06:45 - 07:00 0.25 DRILL P 07:00 - 08:00 1.00 DRILL P 08:00 - 08:15 0.25 CASE P 08:15 - 10:00 1.75 CASE P thru shale. Wiper up to window clean, RIH clean to shale at 11050', ream down at 10 fpm. RIH clean to bottom. PROD1 Drill Z1A lateral, 1.6 bpm, 2550-2900 psi, 1-2K wob, 80L TF, 120 fph, 89 incl, Drilled to 11760'. PROD1 Drill Z1A lateral, 1.6 bpm, 2600-3000 psi, 1-2K wob, 80L TF, 120 fph, 88 incl, Drilled to 11800'. PROD1 Wiper trip to window. Clean hole up to shale at 11050'. Ream thru shale easy. Clean up to window and back to 11100'. Ream down thru shale. RIH clean to bottom. PROD1 Drill Z1A lateral, 1.6 bpm, 2600-3000 psi, 1-2K wob, 80L TF, 120 fph, 88 incl. Plan is to drift down slightly and try and find lower API sand. Drill to 11,950 ft. PROD1 Wiper trip from 11,950 ft to window. Overpulls through shale at 11200-11050 ft. Tie-in log from 9810 ft. Correct +2.5 ft. Set down in shale at 11,070 ft, pull 60K to get free.. Work through at 10 ft/min. PROD1 Drill from 11,950 ft. 1.53 / 1.52 bpm (~3 2500-3000 psi. ROP is 150-160 ft/hr with 1-2 Klbs DWOB. PVT = 275 bbls, ECD = 10.16 ppg. 8.60 / 8.69 ppg In /Out. Drill to 12,060 ft. Call TD here, drilling conditions deteriorating and there is already about 1100 ft of perfable interval. PROD1 Wiper trip back through shale zone to 11030 ft, then back down through it to 11,160 ft. Pull back up through it at 10 ft/min, then back down again to 11,160 ft. PRODi Continue cleaning up shale zone from 11,050 - 11,150 ft. Pull back through a third time, getting cleaner. Pull back to window for tie-in. Correct +1.7 ft. Run back to bottom. Pass shale cleanly. Tag at 12,061 ft, official TD. PROD1 Pull back through shale for final cleanout pass, only slight weight bobbles up and down. RIH to bottom to lay in liner pill. PROD1 Lay in liner pill, POOH. Flag CT at 9370 ft and 7200 ft EOP. POH. PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for laying out drilling BHA. PROD1 Lay out CoilTrak, motor and bit #2. Bit graded at (1,1,1 ). RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for C/O CTC and pumping out E-Line slack. RUNPRD Cut off Kendal connecter, M/U BOT CTC, pull and press test Printed: 4/27/2009 10:14:52 AM BP EXPLORATION Page 8 of 12 Operations Summary Report Legal Well Name: 18-26 Common Well Name: 18-26 Spud Date: 2/3/1993 Event Name: REENTER+COMPLETE Start: 3/3/2009 End: 4/16/2009 Contractor Name: NORDIC CALISTA Rig Release: 4/16/2009 Rig Name: NORDIC 1 Rig Number: Date I From - To Hours Task Code NPT Phase Description of Operations 4/12/2009 08:15 - 10:00 1.75 CASE P RUNPRD CTC. M/U 1 jt 2-1/16" CSH and pump out slack at 4200 psi, 3.3 bpm, 4 times. Cut off 250' of E-Line. 10:00 - 10:15 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for running 2-3/8" liner. 10:15 - 15:00 4.75 CASE P RUNPRD Run 2-3/8", 4.43#, L-80, STL Liner as per program. M/U Indexing guide shoe, Flt Cllr, 1 jt, Flt Cllr, pup, Landing Cllr and 39 jts of 2-3/8" STL Liner. Stop and fill liner with water. M/U a total of 78 its of 2-3/8" liner with 1 ten ft pup It for tie-in. Liner total length = 2466.32' BHA OAL = 2593.41' Circ. at surface. 15:00 - 16:30 1.50 CASE P RUNPRD RIH with 2-3/8" liner on CT. Circ 0.3 bpm, 950 psi. Coil flag was on depth. Up wt at 9800' = 33.5K. 16:30 - 17:05 0.58 CEMT P RUNPRD RIH clean thru window. RIH at 65 fpm, 0.3 bpm, 1400 psi. Dwn wt = 19K at 10100' Dwn wt = 17K at 10600' RIH thru shales at 11,050-11,100' clean. Dwn wt = 14K at 11300', RIH 65 fpm, 0.2 bpm, 1550 psi Dwn wt = 13K at 11800'. Dwn wt = 12K at 12000' Lower flag was on depth. Up wt = 35.5K. Sat down at 12,010, Pick up and RIH clean to TD. Landed liner at TD at 12062'. Corrected TD is 12 061'. 17:05 - 18:10 1.08 CEMT P RUNPRD Pull to ball drop position. Launch 5/8" AL Ball with 1000 psi. Circ 1.0 bpm with GeoVis, heard ball go over guide arch. slow to 0.6 bpm, 1600 psi, at 23 bbls. Ball not on seat at 40 bbls. Surge pump up to 1.0 bpm, Ball on seat at 40.5 bbl. Sheared at 3000 psi, Pick up free from liner at 32K. 18:10 - 20:30 2.33 CEMT P RUNPRD Circ well to 2% double slick KCL water. Mix 70 bbls 2# biozan in Pit #3. SLB cement crew on location and rigging up. Circ KCI water at 1.46 / 1.42 bpm ~ 1390 psi. 20:30 - 20:50 0.33 CEMT P RUNPRD SAFETY MEETING. PJSM with rig crew and SLB cementers to discuss procedure, hazards and mitigations for pumping cement. 20:50 - 21:40 0.83 CEMT P RUNPRD Batch up 11.7 bbls pum able cement. Cement up to weight, send sample to SLB lab. 21:40 - 23:00 1.33 CEMT P RUNPRD Send SLB KCI water for PT. PT cement line to 6,500 psi, good. Open cement line back up. Pump 11.7 bbls 15.8 ppg cement. Zero In /Out MM on density c ange. At 11.7 bbls In MM, shut down SLB pump. Zero In /Out MM. Displace cement with 70 bbls biozan then KCI water. At 33.8 bbls In MM cement is at shoe. Zero Out MM, leave In Printed: 4/27/2009 10:14:52 AM ~ • BP EXPLORATION Page 9 of 12 ~ Operations Summary Report Legal Well Name: 18-26 Common Well Name: 18-26 Spud Date: 2/3/1993 Event Name: REENTER+C;OMPLETE Start: 3/3/2009 End: 4/16/2009 Contractor Name: NORDIC CAILISTA Rig Release: 4/16/2009 Rig Name: NORDIC 1 Rig Number: Date '~ From - To Hours Task ,Code NPT , Phase I Description of Operations 4/12/2009 121:40 - 23:00 __ _ ~ _ -- - _ _ 1.33 CEMT P RUNPRD MM running. At 34.0 bbl In MM there is 2 bbls cmt left inside CT, pick up on Get wt back and pick up another 13 ft to 12,042 ft. Pump 5 bbls to exhaust remaining cement + 3 bbls Ooen choke. sting back into deployment sleeve. Stack back down to 12,063 ft. Close choke and pressure up, launch dart at 39.7~b1s In MM 2,500 psi. In /Out MM (bbls) 39.7 / 1.6 40.0 / 1.7 42.0 / 3.0 Displace at 1.2 / 1.1 bpm 44.0 / 4.8 46.0 / 6.6 1.28 / 1.17 bpm 48.0/8.4 1.2/0.95 bpm Bump plug at 49.1 / 9.5 bbls. Pressure up to 1000 psi over circ pressure, plug is holding. Open Baker choke and check floats, holding good. Close choke and Pressure up to 900 psi, pull out of seals. 23:00 - 00:00 1.00 CEMT P 4/13/2009 00:00 - 00:10 0.17 CEMT P 00:10 - 00:25 0.25 CEMT P 00:25 - 01:30 1.08 CEMT P 01:30 - 04:00 I 2.501 CEMT I P 04:00 - 04:30 0.50 CEMT P 04:30 - 08:00 3.50 CEMT P 08:00 - 09:00 I 1.001 CEMT I P 09:00 - 10:30 I 1.501 CEMT I P 10:30 - 13:15 2.75 CEMT P 13:15 - 13:30 0.25 CEMT P Total of 9.5 bbls cement behind pipe._ All parameters of cement job were normal. RUNPRD POOH replacing coil voidage. RUNPRD Continue POOH. RUNPRD SAFETY MEETING. Discuss hazards and mitigations for l1D cementing BHA and P/U CSH. RUNPRD Tag stripper and UD cementing BHA. About 12 ft of cable hanging out. Tool has functioned normally. Send liner running tools outside, prep rig floor to run CSH. RUNPRD M/U BHA #10 for liner cleanout. 1.875 Diamond Speed mill, 1.69 PDM, 1/2" ball Circ Sub, 5/8" Ball Disconnect, 84jts 1" CSH, 3/4" Ball Disconnect, DBPV, 2 jts 2-1/16" CSH, BTT Quick Connect. BHA OAL = 2,656.81 ft. RUNPRD Cement has reached 500 psi compressive at 03:00. Cable has been kinked when M/U riser, cut it off and re-boot. RUNPRD RIH BHA #10. Cement is at 1000 psi compressive at 04:30. Tag at 9445 ft, pick up and wash through it. Wash down past 9562 ft, some hard cement seen. Tag profile at 9580'. Ream up to 20' above top of liner. Ream down to profile. RUNPRD Mill BTT profile at bottom of deployment sleeve. 1.0 bpm, 2400 psi, 5 stalls to get started. 8 stalls total. Milled thru profile with 1.875" mill. Reamed area up/down twice. RUNPRD RIH to PBTD. 1.0 bpm, 3000 psi, circ 30 bbl 2# Biozan sweep to carry out any cement. Tag PBTD at 12,003' CTD, Calculated PBTD = 12,022'. RUNPRD wit 1.8 5 c eanout BHA, circ 1.0 bpm, 3100 psi. RUNPRD SAFETY MEETING. Review procedure, hazards and Printed: 4/27/2009 10:14:52 AM ,~ • BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: 18-26 Common Well Name: 18-26 Spud Date: 2/3/1993 Event Name: REENTER+COMPLETE Start: 3/3/2009 End: 4/16/2009 Contractor Name: NORDIC CALISTA Rig Release: 4/16/2009 Rig Name: NORDIC 1 Rig Number: Date. From - To Hours Task Code NPT Phase Description of Operations 4/13/2009 13:15 - 13:30 0.25 CEMT P RUNPRD mitigation for standing back CSH and UO mill and motor. 13:30 - 17:15 3.75 CEMT P RUNPRD Stand back 42 stds 1"CSH. Lay out 1.87" mill and motor. 17:15 - 18:45 1.50 BOPSU P RUNPRD M/U swizzle stick and jet stack. 18:45 - 20:20 1.58 BOPSU P RUNPRD Stand back injector o en lower BOP doors for ins ection. BOPs are clean. Close doors and bod test to 250 / 3500 si, good. 20:20 - 20:35 0.25 EVAL P LOWERI SAFETY MEETING. PJSM for working with logging tools and running CSH. Time, distance, shielding were discussed. 20:35 - 23:00 2.42 EVAL P LOWERI M/U Memory logg BHA #11 - MCNL, 5/8" Disconnect, 42 stds 1" CSH, 3/4" Disconnect, DBPV, 2 jts 2-1/16" CSH. BHA OAL = 2,670.24 ft. 23:00 - 23:40 0.67 EVAL N WAIT LOWERI Not able to M/U Quick Connect in BHA, the threads have been damaged. Request a new one from BTT shop in Deadhorse. 23:40 - 00:00 0.33 EVAL P LOW ER1 New disconnect arrives. M/U BHA and M/U CT riser. 4/14/2009 00:00 - 01:10 1.17 EVAL P LOWERI RIH BHA #11. 01:10 - 03:20 2.17 EVAL P _ LOWERI Log down from 8,500 ft at 30 ft/min. Find PBTD at 11,999 ft, uncorrected. 03:20 - 04:20 1.00 EVAL P LOWERI Log up from 11,999 ft at 60 fUmin. Lay in pert pill. 04:20 - 05:00 0.67 EVAL P LOW ER1 Done logging, POOH. 05:00 - 05:15 0.25 EVAL P LOWERI SAFETY MEETING. PJSM for UD CSH. 05:15 - 07:00 1.75 EVAL P LOWERI Tag stripper, stand back injector and UD 2-1/16" CSH, Stand back 42 stds of 1"CSH workstring. 07:00 - 07:15 0.25 EVAL P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for laying out the SWS memory CNUGR logging tools. 07:15 - 08:00 0.75 EVAL P LOWERI La out SWS Memo CNUGR/CCL to in tools. Down load data and send logs to Anc Geo. 08:00 - 08:45 0.75 CEMT P RUNPRD Pressure test liner lap with 2000 psi. Failed pressure test. ~,. . Press to 2000 psi, press leaked off, checked for surface leaks, Press to 2000 psi, press leaked off, no surface leaks. Press to 2000 psi, double blocked. Chart test. Liner lap pressure fell from 2000 psi to 1350 psi in 5 min. Press fell to 1200 psi at 10 min. Failed liner lap pressure test. 08:45 - 09:00 0.25 PERFO P LOWERI Load SWS pert guns into pipe shed. Lay out guns in order. Prep rig floor to run pert guns. 09:00 - 10:00 1.00 PERFO N WAIT LOWERI Wait on orders from Anc. Office. Decide to run pert guns and ream cement from 3-1/2" tubing later. 10:00 - 10:15 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for running SWS 1.56" pert guns. 10:15 - 15:20 5.08 PERFO P LOWERI M/U SWS 1.56" PJ perf guns, loaded at 6 spf. 28 joints 1" CSH and 2 joints 2-1/16" CSH for a total of 2745.29'. MU injectior. 15:20 - 17:30 2.17 PERFO P LOWERI RIH to PBTD. 17:30 - 18:30 1.00 PERFO P LOWERi Launch 1/2" STL ball with 20 bbl pill with 1000 psi. Displace at .9 bpm 1850 psi. Slow rate to 0.44 bpm / 1100 psi at 25 bbls away. After 38 bbls ball not on seat, increase rate to 0.7 bpm / 1300 psi. Try moving reel up and down a few feet to get ball on seat, no sign of it. Try rocking pump on and off, various rates, no luck. 59 bbls away at this point. 18:30 - 20:30 2.00 PERFO N LOWERI Shut down pump and open ball drop port, no ball seen. Printetl: 4/27/2009 10:14:52 AM BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Name: 18-26 Common Well Name: 18-26 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To I Hours ' Task Code NPT - _ __ _ __ 4/14/2009 18:30 - 20:30 2.00 PERFO N 20:30 - 20:50 I 0.33 20:50 - 21:40 0.83 21:40 - 22:10 0.50 22:10 - 23:10 1.00 23:10 - 23:40 0.50 23:40 - 00:00 0.33 4/15/2009 00:00 - 04:00 4.00 P 04:00.- 04:30 0.50 P 04:30 - 05:20 0.83 P 05:20 - 10:15 4.92 P P P P P P P P P X X Spud Date: 2/3/1993 Start: 3/3/2009 End: 4/16/2009 Rig Release: 4/16/2009 Rig Number: Phase Description of Operations LOWERI Pressure up against reel valve to 3,000 psi to re-launch it. Ball is heard rolling. Maintain pump rate at 1.40 bpm / 3000 psi. Drop rate to 1.12 bpm / 1820 psi after ball goes over gooseneck. Drop it further to 0.69 bpm / 880 psi after 20 bbls away. After 38 bbls away not on seat. Surge pump on and off, various rates. Try moving CT up and down. LOWERI Mix another viscous pill and pump 4 bbls down CT. Try launching again with 4,000 psi. Ball is on seat. Shears at 3,700 psi. Good shot indication from acoustic and fluid loss. Bottom shot at 12,010.7 ft. Perforated Intervals: ~ 10,220 - 10,350 10,400 - 10,940 10,990 - 11,030 11,120 - 11,170 11,350 - 11,530 11,640 - 11,780 11,870 - 12,010 LOWERI POOH, hold 250-300 psi WHP while pert guns are inside liner. Keep running speed < 50 fUmin. LOWERI Park at 9,380 ft for 30 min, flow check well. No flow after 30 min. LOWERI POOH. LOW ER1 Tag stripper and flow check well. SAFETY MEETING. PJSM for stand back CSH. LOWERI Fill well with 0.5 bbls. Break off CT riser and stand back injector. Stand back 14 stds of 1"CSH. PJSM then pull 84 pert guns out. LOWERI Continue L/D perf guns. LOWERI Send perf running tools outside. LOWERI M/U BHA #13 - 2.80" mill + String Reamer, Circ Sub, Disconnect, DBPV, 2 jts 2-1/16" CSH. BHA OAL = 78.34 ft. LOWERI RIH. to be aettina aassv return water based on Out 10:15 - 12:00 1.75 PERFO X 12:00 - 12:45 0.75 PERFO X 12:45 - 14:45 2.00 PERFO X 14:45 - 15:15 0.50 PERFO X 15:15 - 17:00 I 1.751 PERFOBI X stop and flow check, well is not flowing but in choke, s ut in pressure is zero. Hold 200-300 psi WHP while RIH.Open choke no gas. Continue to RIH. Circulate 1.67 bpm C~3 2280 psi seem peroidic motor work starting C~ 9370'. Stall 9417 continue to RIH 100 psi MW. Continuus cement reaming from 9420+. 150 psi MW. 120 fph. 9460 losing returns, 1.8/1.23. Clean out to 9585 LOWERI POH. LOWERI BHA swap LD cleanout bha and PU polish mill assy. LOWERI RIH with polish mill LOWERI Polish 9585 uncorrected to 9689.4 Stall.. UP retag 9689.4 1.5 bpm 2050 psi. stall. LOWERI POH. Printed: 4/27/2009 10:14:52 AM ~ ~ BP EXPLORATION Page 12 of 12 ~ Operations Summary Report Legal Well Name: 18-26 Common Well Name: 18-26 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date I From - To Hours Task Code NPT 4/15/2009 17:00 - 17:50 0.83 CASE X 17:50 - 20:10 2.33 CASE C 20:10 - 21:40 I 1.50 I CASE I C 21:40 - 22:15 I 0.58 I CASE I X 22:15 - 23:15 I 1.00 I CASE I C Spud Date: 2/3/1993 Start: 3/3/2009 End: 4/16/2009 Rig Release: 4/16/2009 Rig Number: Phase .Description of Operations RUNPRD BHA. LD polish mill and PU liner top packer assy. RUNPRD RIH with liner top Packer. Set down at 9355 ft, pick up and get past at slower speed. Pump at low rate and sting into deployment sleeve at 9585 ft. Pick up is heavy, try again to get a good up wt. Pick up to 9583 ft is 40 Klbs. Unsling and move CT to a good ball drop position, at 9580 ft. RUNPRD Drop 5/8" steel ball, launch with 1200 psi. Chase with a viscous pill at 1.33 / 1,550 psi. Ball is heard rolling. Slow down to 0.5 bpm / 580 psi at 26 bbls away. After 40 bbls ball not on seat, try surging the pump at various rates, no luck. Try launching with 4,000 psi, no luck. Pull up hole 100 ft and cycle pump again, launch again with 4000 psi, no luck. RUNPRD Pull up hole 400 ft while pumping, ball goes on seat while pulling up. Open Baker choke and RIH to setting depth. Sting in to sleeve and set 10K down, to 9593 ft. Pick up to get wt back, and 1 more ft, to 9582.6 ft. Close Baker choke and pressure up to 2500 psi. Slack 12K back down to 9587 ft, no movement. O en Baker choke and PT CT x tbg annulus to 2,000 psi. 0 min / 2029 psi 5 min / 1978 psi 10 min / 1974 psi Good test. RUNPRD Pressure up to 3,000 psi to shear off of packer. 23:15 - 23:30 I 0.251 CASE I P 23:30 - 00:00 I 0.501 CASE I P 4/16/2009 00:00 - 00:20 0.33 WHSUR P 00:20 - 01:20 1.00 WHSUR P 01:20 - 03:00 1.67 RIGD P ~. 03:00 - 04:30 I 1.501 RIGD I P RUNPRD SAFETY MEETING. Discuss hazards and mitigations for L/D BHA, and freeze protect well. RUNPRD L/D LTP running tools and send outside. Tool has functioned normally. POST M/U nozzle and check valves for freeze protect. POST RIH and freeze protect from 2,200 ft. POST Hook up air to CT and blow back 2 bbls into pits, to freeze protect CT over pipe shed. Blow down surface lines with air. Start to vac out pits. Rig down SSSV panel. POST PJSM then set BPV. Start N/D BOPs. Install tree cap and test, good. '* Rig released at 0430, all further information on 04-35A ** Printed: 4/27/2009 10:14:52 AM • ~~ ~~ ~~ BAKER N~~S INTEQ North America -ALASKA - BP Prudhoe Bay PBDS18 18-26 -Slot 26 18-26B 500292232902 Design: 18-26B Survey Report -Geographic 13 April, 2009 by ~ s Survey Report -Geographic 1NTE Q Company: North America -ALASKA - BP Local Go-ordinate Reference: Well 18-26 -Slot 26 Project: Prudhoe Bay 'TVt7 Reference: Mean Sea Level Site: PB DS 18 ' MD Reference: 49:26 2/3/1993 00:00 @ 52.OOft (generic drilling Well: 18-26 North Reference: True Wellbore: 18-26B 500292232902 r Survey Calculation Method: Minimum Curvature Design: 18-26B Database: EDM .16 - Anc Prod - WH24P Project Prudhoe Bay, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 18, TR-11-14 Site Position: Northing: 5,959,213.15ft Latitude: 70° 17' 35.252 N From: Map Easting: 691,583.44ft Longitude: 148° 26' 55.555 W Position Uncertainty: 0.00 ft Slot Radius: O.000in Grid Convergence: 1.46 ° Well 18-26 -Slot 26, 18-26 Well Position +N/-S 0.00 ft Northing: 5,961,120.78ft Latitude: 70° 17' 53.892 N +E/-W 0.00 ft Easting: 692,050.70 ft Longitude: 148° 26' 40.520 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground level: O.OOft Wellbore 18-266 500292232902 Magnetics Model Name Sample Date Declination Dip Angle Field Strength bggm2007 4!20/2009 22.83 80.96 57,703 Design 18-26B Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,636.59 Vertical Section: Depth From (7VD) +N/-S +Ef-W Direction lft) (ftl Ift) (°) -16.00 0.00 0.00 349.62 Survey Program Date 4/13!2009 From To (ft) (ft) Survey (Wellbore) Tool. Name Description 500.06 9,636.59 1 : MWD -Standard (18-26P61) MWD MWD -Standard 9,790.50 12,061.00 MWD (18-266 500292232902) MWD MWD -Standard 4/13!2009 10:13:30AM Page 2 COMPASS 2003.16 Build 70 •~>f Survey Report - Geographic 1(NTE Q Company: North America -ALASKA - BP Local Co-ordinate Reference: Well 18-26 -Slot 26 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB DS 18 MD Reference: 49:26 2/3/1.993 00:00 @ 52.OOft (generic drilling Well: 18-26 North'Refen;nce: True Wellbore: 18-26B 500292232902 Survey Calculation Method: Minimum Curvature Design: 18-26B - Database: EDM .16 - Anc Prod - WH24P 'Survey Measured TVD Below Map Map Depth Inclination Azimuth System +N/-S +E/=W ' Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,636.59 73.12 324.48 8,496.83 2,805.79 -2,191.37 5,963,869.49 689,788.47 70° 18' 21.483 N 148° 2T 44.423 W TIP 9,790.50 77.03 325.91 8,536.47 2,927.88 -2,276.22 5,963,989.36 689,700.53 70° 18' 22.684 N 148° 27' 46.899 W KOP 9,811.43 73.26 328.50 8,541.83 2,944.88 -2,287.18 5,964,006.08 689,689.14 70° 18' 22.851 N 148° 27' 47.219 W 9,841.13 68.70 332.29 8,551.51 2,969.27 -2,301.05 5,964,030.11 689,674.65 70° 18' 23.091 N 148° 2T 47.624 W 9,871.03 67.03 336.28 8,562.78 2,994.22 -2,313.07 5,964,054.74 689,662.00 70° 18' 23.336 N 148° 27' 47.974 W ~, 9,902.21 68.95 344.28 8,574.48 3,021.40 -2,322.80 5,964,081.66 689,651.58 70° 18' 23.603 N 148° 27' 48.258 W 9,932.73 70.84 352.09 8,584.99 3,049.43 -2,328.66 5,964,109.53 689,645.01 70° 18' 23.879 N 148° 2T 48.429 W j 9,963.37 72.30 358.59 8,594.69 3,078.39 -2,331.01 5,964,138.41 689,641.92 70° 18' 24.164 N 148° 2T 48.498 W'i 9,996.87 74.03 5.33 8,604.40 3,110.41 -2,329.90 5,964,170.45 689,642.21 70° 18' 24.479 N 148° 2T 48.466 W 10,032.09 76.61 11.67 8,613.33 3,144.08 -2,324.86 5,964,204.24 689,646.39 70° 18' 24.810 N 148° 2T 48.319 W 10,062.77 81.65 15.39 8,619.12 3,173.36 -2,317.81 5,964,233.68 689,652.69 70° 18' 25.098 N 148° 2T 48.114 W 10,094.01 87.51 17J1 8,622.07 3,203.15 -2,308.95 5,964,263.70 689,660.78 70° 18' 25.391 N 148° 2T 47.856 W ~~ 10,126.70 88.19 20.96 8,623.29 3,233.97 -2,298.13 5,964,294.78 689,670.80 70° 18' 25.694 N 148° 2T 47.541 W'I 10,158.58 89.20 26.49 8,624.02 3,263.14 -2,285.32 5,964,324.26 689,682.87 70° 18' 25.981 N 148° 2T 47.167 W i 10,191.58 88.80 25.16 8,624.60 3,292.84 -2,270.94 5,964,354.32 689,696.48 70° 18' 26.273 N 148° 27' 46.748 W 10,222.38 88.59 21.47 8,625.30 3,321.11 -2,258.76 5,964,382.89 689,707.94 70° 18' 26.551 N 148° 27' 46.393 W 10,255.66 88.56 17.44 8,626.13 3,352.47 -2,247.68 5,964,414.53 689,718.21 70° 18' 26.860 N 148° 27' 46.070 W 10,286.52 88.47 18.05 8,626.92 3,381.86 -2,238.28 5,964,444.14 689,726.86 70° 18' 27.149 N 148° 27' 45.796 W ' 10,315.72 89.26 23.12 8,627.50 3,409.18 -2,228.02 5,964,471.71 689,736.42 70° 18' 27.417 N 148° 27' 45.497 W 10,346.70 89.72 26.94 8,627.78 3,437.24 -2,214.91 5,964,500.10 689,748.80 70° 18' 27.693 N 148° 27' 45.115 W 10,378.22 90.03 31.23 8,627.85 3,464.78 -2,199.59 5,964,528.02 689,763.41 70° 18' 27.964 N 148° 27' 44.669 W 10,408.60 89.97 35.62 8,627.85 3,490.13 -2,182.86 5,964,553.78 689,779.49 70° 18' 28.214 N 148° 27' 44.181 W 10,439.80 89.75 40.14 8,627.92 3,514.75 -2,163.71 5,964,578.88 689,798.00 70° 18' 28.456 N 148° 27' 43.623 W 10,471.14 89.05 37.41 8,628.25 3,539.18 -2,144.09 5,964,603.80 689,816.99 70° 18' 28.696 N 148° 2T 43.051 W 10,506.98 89.97 33.70 8,628.56 3,568.33 -2,123.25 5,964,633.48 689,837.08 70° 18' 28.983 N 148° 27' 42.443 W 10,538.34 89.72 31.75 8,628.64 3,594.71 -2,106.30 5,964,660.28 689,853.35 70° 18' 29.242 N 148° 2T 41.949 W I, ~ 10,574.26 90.58 36.29 8,628.55 3,624.47 -2,086.21 5,964,690.55 689,872.67 70° 18' 29.535 N 148° 27' 41.363 W ~ 10,607.58 91.29 41.48 8,628.01 3,650.40 -2,065.30 5,964,717.00 689,892.91 70° 18' 29.790 N 148° 2T 40.754 W', 10,640.52 90.12 44.94 8,627.60 3,674.40 -2,042.75 5,964,741.56 689,914.83 70° 18' 30.026 N 148° 2T 40.096 W 10,671.90 90.58 49.48 8,627.41 3,695.71 -2,019.73 5,964,763.46 689,937.30 70° 18' 30.236 N 148° 27' 39.425 W :, 10,703.62 88.83 53.85 8,627.57 3,715.38 -1,994.86 5,964,783.75 689,961.66 70° 18' 30.429 N 148° 27' 38.700 W 10,736.86 87.91 58.02 8,628.52 3,733.99 -1,967.34 5,964,803.06 689,988.70 70° 18' 30.613 N 148° 27' 37.898 W I 10,769.76 88.04 62.85 8,629.68 3,750.21 -1,938.75 5,964,820.00 690,016.86 70° 18' 30.772 N 148° 2T 37.064 W i, A ' 10,801.60 89.17 68.22 8,630.46 3,763.38 -1,909.79 5,964,833.91 690,045.47 70° 18' 30.902 N li 148° 2T 36.219 W I 10,831.60 89.05 72.79 8,630.92 3,773.39 -1,881.52 5,964,844.64 690,073.48 70° 18' 31.000 N 148° 2T 35.395 W'~, 10,862.96 89.79 77.61 8,631.24 3,781.40 -1,851.21 5,964,853.42 690,103.57 70° 18' 31.079 N 148° 2T 34.511 W' 10,893.16 90.43 83.36 8,631.18 3,786.39 -1,821.44 5,964,859.17 690,133.20 70° 18' 31.128 N 148° 27' 33.643 W 10,929.58 90.21 88.64 8,630.98 3,788.93 -1,785.12 5,964,862.63 690,169.44 70° 18' 31.153 N 148° 27' 32.583 W 10,961.46 90.43 94.36 8,630.80 3,788.09 -1,753.26 5,964,862.61 690,201.31 70° 18' 31.145 N 148° 27' 31.654 W 10,992.22 90.68 99.06 8,630.50 3,784.50 -1,722.72 5,964,859.80 690,231.93 70° 18' 31.110 N 148° 27' 30.764 W 11,023.08 ~ 89.72 96.42 8,630.40 3,780.35 -1,692.15 5,964,856.43 690,262.60 70° 18' 31.069 N 148° 27' 29.872 W I 11,057.10 91.38 94.21 8,630.07 3,777.19 -1,658.28 5,964,854.14 690,296.53 70° 18' 31.038 N 148° 2T 28.884 W 11,092.02 91.57 86.91 8,629.17 3,776.85 -1,623.40 5,964,854.69 690,331.41 70° 18' 31.035 N 148° 2T 27.867 W ~, ~ 11,127.32 93.41 85.84 8,627.64 3,779.08 -1,588.20 5,964,857.82 690,366.53 70° 18' 31.057 N 148° 2T 26.840 W 11,159.16 94.86 83.60 8,625.34 3,782.00 -1,556.58 5,964,861.55 690,398.07 70° 18' 31.086 N 148° 2T 25.918 W 11,192.36 91.99 81.78 8,623.36 3,786.22 -1,523.72 5,964,866.61 690,430.81 70° 18' 31.127 N 148° 27' 24.960 W% 11,223.18 90.58 79.34 8,622.66 3,791.27 -1,493.33 5,964,872.43 690,461.06 70° 18' 31.177 N 148° 2T 24.073 W 11,254.92 88.80 77.61 8,622.84 3,797.62 -1,462.23 5,964,879.57 690,491.99 70° 18' 31.239 N 148° 2T 23.166 W'', 11,290.64 88.59 77.88 8,623.65 3,805.20 -1,427.33 5,964,888.04 690,526.68 70° 18' 31.314 N 148° 2T 22.149 W ~, 11,329.94 87.14 84.04 8,625.12 3,811.36 -1,388.57 5,964,895.19 690,565.27 70° 18' 31.375 N 148° 2T 21.018 W I, 11,359.92 88.86 87.63 8,626.16 3,813.54 -1,358.69 5,964,898.13 690,595.08 70° 18' 31.396 N I 148° 27' 20.147 W 11,390.14 90.03 91.91 8,626.45 3,813.66 -1,328.48 5,964,899.02 690,625.27 70° 18' 31.398 N 148° 27' 19.266 W 11,425.68 90.61 96.41 8,626.26 3,811.08 -1,293.04 5,964,897.35 690,660.76 70° 18' 31.372 N 148° 27' 18.232 W 4/13/7009 10:13:30AM Page 3 COMPASS 2003.16 Build 70 ' Survey Report -Geographic bP 1NTEQ Company: North America -ALASKA - BP t.ocal Go-ordinate Reference: Well 18-26 -Slot 26 Project: Prudhoe Bay ND Reference: Mean Sea Level Site: PB DS 18 AAD Reference: 49:26 2/3/1993 00:00 @ 52.OOft (generic drilling Well: 18-26 North Refe rence: True Wellbore: 18-26B 500292232902 Survey Gaiculation Method: Minimum Curvature Design: 18-266 .Database: EDM .16 - Anc Prod - WH24P Survey Measured TVD Below Map Map Depth Inclination Azimuth System +NI-S +E/-yy Northing Easting (ft) (°) (°) lft} (ft) (ft) (ft) (ft) Latitude Longitude 11,458.74 89.85 101.67 8,626.12 3,805.89 -1,260.40 5,964,893.00 690,693.52 70° 18' 31.321 N 148° 27' 17.280 W ~ 11,488.40 88.16 106.97 8,626.64 3,798.56 -1,231.68 5,964,886.40 690,722.42 70° 18' 31.249 N 148° 27' 16.442 W 11,531.66 88.44 114.13 8,627.92 3,783.39 -1,191.22 5,964,872.27 690,763.25 70° 18' 31.100 N 148° 27' 15.262 W 11,565.88 88.80 119.20 8,628.75 3,768.04 -1,160.66 5,964,857.71 690,794.20 70° 18' 30.949 N 148° 27' 14.371 W 11,594.08 88.62 117.21 8,629.38 3,754.72 -1,135.81 5,964,845.03 690,819.37 70° 18' 30.818 N 148° 27' 13.646 W j 11,626.50 89.23 114.20 8,629.99 3,740.66 -1,106.61 5,964,831.72 690,848.92 70° 18' 30.680 N 148° 2T 12.794 W 11,659.70 88.31 110.27 8,630.70 3,728.10 -1,075.89 5,964,819.95 690,879.95 70° 18' 30.556 N 148° 27' 11.898 W 11,693.54 88.16 106.57 8,631.75 3,717.42 -1,043.81 5,964,810.09 690,912.30 70° 18' 30.451 N 148° 27' 10.963 W 11,732.34 89.69 102.50 8,632.48 3,707.68 -1,006.26 5,964,801.32 690,950.07 70° 18' 30.356 N 148° 27' 9.868 W 11,761.80 88.50 99.53 8,632.94 3,702.06 -977.35 5,964,796.44 690,979.12 70° 18' 30.300 N 148° 27' 9.024 W 11,813.10 88.43 95.29 8,634.32 3,695.44 -926.51 5,964,791.13 691,030.11 70° 18' 30.235 N .148° 27' 7.542 W 11,846.12 87.42 92.00 8,635.51 3,693.35 -893.59 5,964,789.87 691,063.07 70° 18' 30.215 N 148° 2T 6.581 W 11,877.58 87.70 89.14 8,636.85 3,693.03 -862.16 5,964,790.36 691,094.50 70° 18' 30.212 N 148° 27' 5.665 W 11,909.14 87.57 85.70 8,638.15 3,694.45 -830.66 5,964,792.58 691,125.94 70° 18' 30.226 N 148° 27' 4.746 W ~'~ 11,940.04 87.63 82.61 8,639.45 3,697.60 -799.95 5,964,796.51 691,156.56 70° 18' 30.257 N 148° 2T 3.851 W 11,971.46 90.28 80.18 8,640.02 3,702.30 -768.90 5,964,802.00 691,187.49 70° 18' 30.303 N 148° 27' 2.945 W 12,002.28 90.43 76.94 8,639.83 3,708.41 -738.70 5,964,808.88 691,217.52 70° 18' 30.363 N 148° 2T 2.064 W 12,022.66 90.61 74.62 8,639.65 3,713.41 -718.94 5,964,814.39 691,237.14 70° 18' 30.412 N 148° 27' 1.488 W 12,061.00 90.61 74.62 8,639.24 3,723.58 -681.98 5,964,825.50 691,273.83 70° 18' 30.512 N 148° 27' 0.410 W TD Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/S +E/-W Northing Easting -Shape ( °) (°) (ft) (ft) (ft) (ft) lft) Latitude Longitude 18-266 Target 2 0.00 0.00 8,630.00 3,808.01 -1,969.14 5,964,877.00 689,985.00 70° 18' 31.341 N 148° 27' 37.951 W - actual wellpath misses target cente r by 65.31ft at 10769.76ft MD (8629.68 TVD, 3750.21 N, -1938.75 E) - Point 18-26B Target 3 0.00 0.00 8,630.00 3,731.86 -829.65 5,964,830.00 691,126.00 70° 18' 30.594 N 148° 27' 4.717 W - actual wellpath misses target cente r by 38.14ft at 11913.61ft MD (8638.34 TVD, 3694.81 N, -826.21 E) - Point 18-26B Target 1 0.00 0.00 8,630.00 3,212.58 -2,313.49 5,964,273.00 689,656.00 70° 18' 25.484 N 148° 27' 47.988 W - actual wellpath misses target cente r by 10.51ft at 10101.69ft MD (8622.39 TVD, 3210.45 N, -2306.57 E) - Point Design Annotations Measured Vertical Local Coord inates Depth Depth +N/-S +E/-W (ft) (ft} (ft) (ft) Comment 9,636.59 8,496.83 2,805.79 -2,191.37 TIP 9,790.50 8,536.47 2,927.88 -2,276.22 KOP 1 2,061.00 8,639.24 3,723.58 -681.98 TD Checked By: Approved By: Date: 4/13/2009 10:13:30AM Page 4 COMPASS 2003.16 Build 70 TREE= ~ 4-1/16"CAN WELLHEAD= FMC ACTUATOR = AXELSON KB. ELEV = 52' BF. ELEV = NA KOP = 2075' Aix Angk! = 95 ~ 11159' Datum MD = Datum TVD = 9981 8600' SS DRLG DRAFT 1 H-26B I~rf ~ 41/2" TBG, 12.6#, 1-80, .0152 bpf, ID = 3.958" ~ ~ 13-3/8" CSG, 68!72#, K-55/L-80, ~ = 12.347" ~ Minimum ID =1.81" a~ 9586' 'LlflO!' TOT.7 s~DC)(f'f 9-5/8" X 7" TAN S PACKER H 8658" 9-5/8" CSG, 47#, NT-805, ID = 8.681" PERFORA TION SUMMA RY REF LOG: GR-CGL ON 06/19/98 A NGL E A T TOP PERF: 89 ~ 10220' Note: Refer to Roduction DB for historical perf data SQE SPF INTERVAL Opn/Sgz OWTE 1.56" 6 10220 - 10350 O 04/14/09 1.56" 6 10400 - 10940 O 04/14/09 1.56" 6 10990 - 11030 O 04/14/09 1.56" 6 11120 - 11170 O 04/14!09 1.56" 6 11350 - 11530 O 04/14/09 1.56" 6 t 1640 - 11780 O 04!14109 1.56" 6 11870 - 12010 O 04/14/09 TOP OF 2-3/8" LNR, ID = 1.941" 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" SAF IOTES: OA NOT ARCTIC PACK®021 TOP ~ -i S OF 13-3/8" CSG ARE 68#/K-'S5. WELL ANGLE > 70° (ril 9500' 8 > 90° (dt 11170'. ~ 41 /2 CA MCO TROP-4A, TRSSSV, ID = 3.812" ~ /2"X3-1 /2" XO, ~ = 2.992" GA S LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3257 3206 21 AAvIG DOME RK 16 04!20/09 2 5497 5258 23 A11MG SO RK 20 04/20/09 3 7673 7250 27 AM1G DMY RK 0 02/16/93 4 8338 7811 37 MMG DAAY RK 0 02/16/93 5 8456 7904 40 A11vIG DAAY TGE 0 02/16!93 $i sOT I~ 3-1 /2" OT1S X NIP, ID = 2.813" 8549" 9-5/8" X 3-1 /2" BKR SB-3 PKR, ID = 3.875" 8593" 3-1/2" PARKER SWN NIP, MA_LED TO 2.80" (04112/98) 8663' 9-518" X 7" TAN DTH-S HGR 9586' Liner Top Packer 35KB 9590' 2.70" BKR DEPLOYMENT SLV, ID = 1.969" 9700" tbg punch above KOP g7g0' 3.5" BKR PKR WHIPSTOCK 10468' tbg punch bebw KOP 2-318" LNR, 4.6#, L-$0, .0039 bpf, ID = 1.941" 12056 RTTI=19ntA' 9~ ~CIBP Weatherford 9860' leaking HES cement retainer 10496' leaking CIBP 0528" 2.70" BKR DEPLOYMENT SLV, ID = 1.969" ~ 10635 ~~7" X 41/2" TAN SS PKR ASSY (BEHIND LNR', 10651" ~-{41!2" PORTED JOINT (37.98') (BEHIND LNR) 7" LNR, 29#, NT-805, ID = 6.184" ~--1 10se 4112" LNR SIDETRACK WINDOW 10898' - 10907 (OFF CArfT PLUG) /2" LNR, 12.6#, NT-80, .0152 bpf, ID = 3.958" 1185 2-3/8" LNR, 4.6#, L-80, .0039 bpf, 10= 1.941" DATE REV BY COMMENTS DATE REV BY COMMENTS 02116!93 ORIGINAL COMPLETION 06/21/98 CTD SIDETRACK (18-26A) 01/28/02 CH/KAK CORRECTIONS 04!15109 NORDICI CTD SIDETRACK (18-26B) 04!20/09 TFA/TLH GLV GO 04/23/Q9 TLH CORRECTIONS 11.75" BKRCIBP(10/?0100) ELM 1 PRUDHOE BAY UNfT WELL: 18-268 PERMfT No: API No: 50-029-22329-02 SEC 19, T11 N, R14E, 755' SNL 8298' EWL BP Exploration (Alaska) ALASS-A OIL A1~TD GAS COI~TSER~A'TIO1~T COMI~IISSIOrT John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-26B BP Exploration Alaska Inc. Permit No: 209-017 Surface Location: 755' FNL, 296' FWL, SEC. 19, T11N, R15E, UM Bottomhole Location: 297'T FSL, 534' FEL, SEC. 13, T11N, R14E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, ~~ aniel T. Seamount, Jr. Chair DATED this ~ day of February, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~'~w~l~r°~L1 STATE OF ALASKA ALASI~IL AND GAS CONSERVATION COMMI~N ~ ~_ -~ ~ Z0~9 PERMIT TO DRILL 20 AAC 25.005 ~lasiCa c~ M':~x irons. Commiss:~n 1 a. Type of worfc ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if isiaF8p8sed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 18-26B 3. Address: P.O. Box 196612, Anchorage, Afaska 99519-6612 6. Proposed Depth: MD 1193T TVD 8629'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028321 & 028307 Oil Pool FWL, SEC. 19, T11N, R15E, UM 755 FNL, 296 Top of Productive Horizon: T11N R14E UM 3111' FSL 2603' FEL SEC. 13 8. Land Use Permit: 13. Approximate Spud Date: March 1, 2009 , , , , , Total Depth: 297T FSL, 534' FEL, SEC. 13, T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 32,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-692051 y-5961121 Zone-ASP4 10. KB Elevation (Hsi ht above GL): 52' feet 15. Distance to Nearest Well Within Pool: 39' 16. Deviated Wells: Kickoff Depth: 8800 feet Maximum Hole An le: 90 d rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3475 Surface: 2595 18. in Pr m: 'i T - '`' -B am ni fC m n .f. r Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 1 g. PRESENT WELL CONDITION S UMMARY (To be cxrmpleted for Redr ill and Re-entry Operations) Total Depth MD (ft): 12650' Total Depth TVD (ft): Plugs (measured): 8 5' 12265' Effective Depth MD (tt): 12573' Effective Depth TVD (ft): 8689' Junk (measured}: None Casing Length Size Cement Volume MD TVD Conductor /Structural I Surface / " 141 x III t x 11 7 ' ' Intermediate / " 1 I 4 ' P Liner T' 1 ' - 04T - 77' i t 27T 4-1 4 x I 'n r f r 1- 1 ' -1 '- 7T , , Perforation Depth MD (tt): 11450' - 12250' Perforation Depth TVD (tt): 8690' - 8679' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ~ 20 AAC 25:050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Mel Rixse, 564-5620 Printed Name Joh c II r Title En ineerin Team Leader Prepares By Ham~Number: Si nature Phone 564-4711 Date ~ 3d G Terris Hubble, 564-4628 Commission Use On! Permit To Drill ~~O APt Number. so-o29-a23a~-0z-oo Permit Approval See cover letter for i n Conditions of Approval: It box is checked, well may not be used to explore for, test, or produce coalbeci methane, gas hydrates, or gas contained shales: ~aSOC~„ P5~ ~-e~.~y~s~-~- Samples Req'd: Yes ~No Mud Log Req'd: ^ ~/es L~No ~ 5C~© ~S. ~5r` ~Z~~ r-~ GnhJ~ ~~-~~ HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No Other: ^7 APPROVED BY THE COMMISSION L ~ Date COMMISSIONER Form 10-01 `Rev'rseFf 12/005 ~ ~ !~ Submit Fn Duplicate • 18-26B - Coiled Tubing Drilling To: Tom Maunder Petroleum Engineer ~.l~ Alaska Oil & Gas Conservation Commission IJ From: Mel Rixse CTD Engineer Date: January 29, 2009 Re: 18-26B Application for Permit to Drill Request CTD Drill and Complete 18-26B program: Spud in March 1, 2009 Pre-Rig Operations 1. O Dummy GLVs 12/08/2008 DONE 2. O MIT-OA - 2000 psi, MIT-IA - 3000 psi .Passed 12/14/2008 DONE 3. C Drift to 10,528' (top 2-3/8" liner) for Halliburton cement retainer and BTT 3-1/2" Dummy WS/packer assembly (2.65" OD) 4. C Run MCNVCCL 10,528' ELMD - 8507' ELMD 5. C Set CIBP at 10,500' (mid first full joint above 2.70" liner deployment sleeve 6. C Punch holes in tubing at 10,468' ELMD(mid first full joint above CIBP). 7. C Punch holes in tubing at 9700' ELMD. 8. C Set Halliburton EZ drill Squeeze Packer/Retainer at 9850' ELMD 9. C Stab into retainer and establish returns through lower pert to upper perfs and out to surface. 10. C Circulate 31.0 bbls cement through lower tubing punch holes while taking returns. 11. O MIT-Tubing 3000 psi 12. O AC-LDS; AC-PPPOT-IC, T 13. O PT tree (MV,SV,WV), function LDS 14. O Bleed gas lift and production flowlines down to zero and blind flange 15. O Remove S-Riser, Remove wellhouse, level pad -Complete ?~®~_ ~~~ Rig Sidetrack Operations: (Scheduled to begin on March 1, 2009) 1. NU 7-1/16" CT Drilling BOPE and test to 250 psi low and 3500 psi high 2. Pull BPV. 3 Set 3-1/2" monobore whipstock at 9790' ELMD - 4. Mill 2.80" window through 3-1/2" tubing and 7" liner at 9790' ELMD. 5. Drill build/turn section with 3" bicenter bit, and land well. 6. Drill lateral section to 11,937' MD w/ resistivity log. 7. Run 2-3/8" solid liner w/cementralizers to TD. Place liner top at 9600' MD. 8. Cement liner from TD to TOL (9590'MD) with 15.8ppb cement. 9. Clean out liner/Run MCNUGR/CCL log. 10. Test liner lap to 2000 psi. 11. Perforate per geologist. 12. Set liner top packer (if fails liner lap test) 13. Freeze protect well to 2500' with methanol. 14. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 15. RDMO Nordic 1. January 26, 2009 18-26B - Coiled Tubing Drilling Post Rig: 1. Re-install wellhouse and FL's 2. Pull BPV 3. Install GLV 4. Re-install well house and attach production lines 5. RU test separator, flow test well. NOTES: • Max angle in 18-26B above the CIBP set depth is 87° deg at 10,500' ELMD • Max DLS is 4.9°/100ft at 8843'. Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or Biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3" Casing Program: • 2-3/8", 4.7#, L-80, STL connection solid liner - 11,937'MD - 9590' MD. • A minimum of 13 bbls 15.8 ppg cement will be used for liner cementing. (TOC 9590'MD) Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 90 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line - 32,000' • Distance to nearest well in the pool - 18-186 - 39.2' Anticollision Summary • 18-18 - 20' ctr-ctr, Status: Abandoned • 18-18B - 39.2' ctr-ctr, Status: Producing • L2-29 - 598' ctr-ctr, Status: Shut in Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole GR/CCVCNL log will be run. Hazards • The maximum recorded H2S level on DS18 is 20 ppm on 18-03 (11-28-2008). DS 18 is not considered an H2S pad. January 26, 2009 18-26B - Coiled Tubing Drilling • Lost circulation risk is low. No fault crossings are expected. Reservoir Pressure • Res. press. is estimated to be 3,475 psi at 8,800'ss (7.7 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 2595 psi. Mel Rixse - CTD Engineer cc. John McMullen, Terrie Hubble, Sondra Stewman January 26, 2009 18-26B - Coiled Tubing Drilling P~HOE BAY V~Nf VIIEl.L: 1B•Z!A P@11lf No:'~971944 A~tn-s: saoz~ax~s.oa ~- m[piantkln {Alasky January 26, 2009 ~tH~-a; FMC sA~ertt rw~ oA Mir Ar~enc PACItm 07tINl3. ~„~ = AXEL90N 'I 8 2 fiA TOP: J7! OP t7-~1!' CMG ANE M/IIFS.'i. . aw s sz ~ we.E. ANCLB~ w ~ aoe~ s • ~ @ ~4trn. 18-268 - Coiled Tubing Drilling °- ~ 1 S-ZSB T=om „ ~~~~-~ >R = Ax~LSON wdl. w~^• To- ~ ' a ~. 66~ O 11176'. ' Sr Proposed CTD Sidetrack w- c3A.s Lurr MANDRELS N~nimum iD = f.941" ~ it3533' TOP OF 2-3f8" LNR PERFORATIDN SUMAMRY ReF loo: cR-co! a~ o6n arse AAK3lE ATTOP PERF: 8T ~ 11450' Nato: R afar to Ptoduetiort DB for historical p art data S¢E SPF NTERVAL Opn/Sgz DATE 1-11/18' 6 11450-11530 O 05113!04 1-11M8" 6 11810-11710 O OSM3/04 1-11118' 4 11782-11880 O 08r20r98 1-11M8" 4 11885-12250 O 08/20198 ':-t?!?8" 4 ?'3C15- 1?57? G ?0110/00. ST -AID TVD DEV TYPE VLV LATCH PDRT DATE 1 3257 3206 21 A6N6 Oti{Y tiK 0 12/08108 2 5467 5258 73 A6MCi D4Y RK D 12A8t08 3 7873 7250 27 MMq DMY RK D 0?H 8183 4 BS38 7611 97 MMIi DW RK D 02!18193 S 8458 79D4 40 A6iiKi DMY TGE 0 02/18193 9590' I--12.T0"9KRDER.DYM81Cr~V,D=1 73° $7~ _,_.. ~~a~.b,..Y _. _.~~. 2 318" lNR, 4.85,1-60, .0039 6pf, D a 1.94t' 11937' Da 1.641' H 10533' i~~ ~ 10528' ZT0" sKR DEfi.dYMBJfSLV. e=1.969' 4112' LIW SIDETRACiI YYNDOYV 10~ -1090Q' (OFF CA1T PLLK3j PI3JDii~ BAY tAVtT tiVE7-L: 18268 PERAIiT Ns: API Ns: 56~D26.2232802 6f 6)~pNAr~lon (Alaalca~ January 26, 2009 ~ BP Alaska ~ ~`~ by Baker Hughes INTEQ Planning Report ~rrE ~mpany: BP Amoco Date: 1/28/2008 Time: 10:28:33 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 18-26, True North Site: PB DS 18 Vertical (TVD) Reference: 49:26 2/3/1993 00:00 52.0 Well: 18-26 Section (VS) Reference: Well (O.OON,O.OOE,65.OOAzi) Wetlpath: Plan 4, 18-266 Survey Calculation Method: Minimum Curvature Db: Sybase Targets Map Map <---- Latitude ----> <--- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 18-26B Fault 2 52.00 3692.63 -3951.86 5964711.00 688006.00 70 18 30.198 N 148 28 35.776 W -Polygonl 52.00 3692.63 -3951.86 5964711.00 688006.00 70 18 30.198 N 148 28 35.776 W -Polygon 2 52.00 3505.84 -3219.35 5964543.00 688743.00 70 18 28.364 N 148 28 14.410 W 18-266 Polygon 52.00 3456.93 -2519.33 5964512.00 689444.00 70 18 27.886 N 148 27 53.994 W -Polygonl 52.00 3456.93 -2519.33 5964512.00 689444.00 70 18 27.886 N 148 27 53.994 W -Polygon 2 52.00 3974.72 -1720.79 5965050.00 690229.00 70 18 32.981 N 148 27 30.709 W -Polygon 3 52.00 3809.06 -523.56 5964915.00 691430.00 70 18 31.353 N 148 26 55.790 W -Polygon 4 52.00 3560.54 -584.94 5964665.00 691375.00 70 18 28.909 N 148 26 57.579 W -Polygon 5 52.00 3724.15 -1702.19 5964800.00 690254.00 70 18 30.516 N 148 27 30.164 W -Polygon 6 52.00 2923.83 -2327.88 5963984.00 689649.00 70 18 22.644 N 148 27 48.405 W 18-26B Fault4 52.00 2443.14 -3990.80 5963461.00 687999.00 70 18 17.909 N 148 28 36.892 W -Polygonl 52.00 2443.14 -3990.80 5963461.00 687999.00 70 18 17.909 N 148 28 36.892 W -Polygon 2 52.00 2419.46 -2242.74 5963482.00 689747.00 70 18 17.684 N 148 27 45.918 W -Polygon 3 52.00 2383.73 -845.11 5963482.00 691145.00 70 18 17.335 N 148 27 5.163 W -Polygon 4 52.00 2419.46 -2242.74 5963482.00 689747.00 70 18 17.684 N 148 27 45.918 W 18-266 Fault 1 52.00 3905.91 -2942.02 5964950.00 689010.00 70 18 32.300 N 148 28 6.326 W -Polygon 1 52.00 3905.91 -2942.02 5964950.00 689010.00 70 18 32.300 N 148 28 6.326 W -Polygon 2 52.00 4208.00 -1571.77 5965287.00 690372.00 70 18 35.275 N 148 27 26.364 W -Polygon 3 52.00 4044.15 -914.71 5965140.00 691033.00 70 18 33.665 N 148 27 7.198 W -Polygon 4 52.00 3958.93 -46.55 5965077.00 691903.00 70 18 32.827 N 148 26 41.878 W -Polygon 5 52.00 4044.15 -914.71 5965140.00 691033.00 70 18 33.665 N 148 27 7.198 W -Polygon 6 52.00 4208.00 -1571.77 5965287.00 690372.00 70 18 35.275 N 148 27 26.364 W 18-266 Fault 3 52.00 3531.86 -3141.65 5964571.00 688820.00 70 18 28.621 N 148 28 12.144 W -Polygon 1 52.00 3531.86 -3141.65 5964571.00 688820.00 70 18 28.621 N 148 28 12.144 W Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2007 Site: PB DS 18 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5959213.15 ft Latitude: 70 17 35.252 N From: Map Easting: 691583.44 ft Longitude: 148 26 55.555 W Position Uncertainty: 0.00 ft Ground Level: 0.00 ft North Reference: Grid Convergence: True 1.46 deg Well: 18-26 Slot Name: 26 18-26 Well Position: +N/-S 1895.21 ft Northing: 5961120.78 ft Latitude: 70 17 53.892 N +E/-W 515.76 ft Easting : 692050.70 ft Longitude: 148 26 40.520 W Position Uncertainty: 0.00 ft Wetlpath: Plan 4, 18-266 500292232902 Drilled From: Tie-on Depth: 18-26PB1 9636.59 ft Current Datum: 49:26 2/3/1993 00:00 Hei ght 52.00 ft Above System Datum: Mean Sea Level Magnetic Data: 4/20/2009 Field Strength: 57715 nT Vertical Section: Depth From (TVD) +N/-S Declination: Mag Dip Angle: +E/-W 22.86 deg 80.94 deg Direction - ft ft ft deg 36.00 0.00 0.00 65.00 Plan: Plan #4 Date Composed: 1/20/2008 move well into center of polygon Principal: Yes Version: Tied-to: 7 From: Definitive Path BP Alaska ~ by Baker Hughes INTEQ Planning Report °~ ~~EQ Company: BP Amoco Date: 1/28/2008 - - -~ Time: 10:28:33 Page: 2 Field: Prudhoe Bay l Co-ordinate(NE) Reference: Well: 18-26, True North i Site: PB DS 18 Vertical (TVD) Reference: 49:26 2!3/1993 00:00 52.0 Well: 18-26 Sectio n (VS) Reference: Well (O.OON,O.OOE,65.OOAzi} ', Wellpath: Plan 4, 18-266 Survey Calculation Method: Minimum Curvature Db_ Sybas e Targets _ Map Ma p <---- Latitude ----> <--- Longitude ---> '; Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft -Polygon 2 52.00 3152.43 -3404.45 5964185.00 688567.00 70 18 24.888 N 148 28 19.803 W 18-266 Target 1 8682.00 3212.58 -2313.49 5964273.00 689656.00 70 18 25.484 N 148 27 47.989 W 18-26B Target 2 8682.00 3808.01 -1969.15 5964877.00 689985.00 70 18 31.341 N 148 27 37.951 W 18-266 Target 3 8682.00 3731.86 -829.65 5964830.00 691126.00 70 18 30.594 N 148 27 4.717 W Annotation ~MD TVD --- - - ft ft 9636.59 8548.83 TIP 9800.00 8590.57 KOP 9820.00 8595.28 End of 9 Deg / 100 ft DLS 9875.00 8614.75 4 10137.84 8681.33 End of 24 Deg / 100 ft DLS 10288.00 8681.33 6 10688.00 8681.33 7 10788.00 8681.33 8 10888.00 8681.33 9 11238.00 8681.33 10 11443.00 8681.33 11 11781.00 8681.33 12 11937.00 8681.33 TD Plan Section Information -- ~ MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target I ft deg deg ft ft ft degl100ft deg/100ft deg/100ft deg J 9636.59 73.12 324.48 8548.83 2805.79 -2191.37 0.00 0.00 0.00 0.00 9800.00 77.28 326.00 8590.57 2935.56 -2281.40 2.70 2.55 0.93 19.66 9820.00 75.48 326.00 8595.28 2951.67 -2292.27 9.00 -9.00 0.00 180.00 9875.00 62.98 330.54 8614.75 2995.27 -2319.33 24.00 -22.73 8.26 162.00 10137.84 90.00 30.00 8681.33 3235.83 -2310.25 24.00 10.28 22.62 74.99 10288.00 90.00 11.98 8681.33 3375.45 -2256.69 12.00 0.00 -12.00 270.00 10688.00 90.00 59.98 8681.33 3689.75 -2028.49 12.00 0.00 12.00 90.00 10788.00 90.00 71.98 8681.33 3730.38 -1937.32 12.00 0.00 12.00 90.00 10888.00 90.00 59.98 8681.33 3771.01 -1846.15 12.00 0.00 -12.00 270.00 11238.00 90.00 101.98 8681.33 3824.66 -1508.16 12.00 0.00 12.00 90.00 11443.00 90.00 77.38 8681.33 3825.79 -1304.73 12.00 0.00 -12.00 270.00 11781.00 90.00 117.94 8681.33 3781.67 -976.70 12.00 0.00 12.00 90.00 11937.00 90.00 99.22 8681.33 3732.18 -829.49 12.00 0.00 -12.00 270.00 Survey _-- _- ~! MD Incl Azim SS TVD N/S E/W NIapN MapE DLS VS TFO Too ft deg deg ft ft ft ft ft deg/100ft ft deg -~ _ 9636.59 73.12 324.48 __ 8496.83 2805.79 -2191.37 5963869.49 689788.47 0.00 -800.28 0.00 MWD 9650.00 73.46 324.61 8500.69 2816.25 -2198.82 5963879.75 689780.76 2.70 -802.61 19.66 MWD 9675.00 74.10 324.84 8507.67 2835.84 -2212.68 5963898.99 689766.40 2.70 -806.89 19.62 MWD 9700.00 74.73 325.08 8514.39 2855.56 -2226.51 5963918.34 689752.08 2.70 -811.09 19.55 MW D 9725.00 75.37 325.31 8520.84 2875.39 -2240.29 5963937.82 689737.79 2.70 -815.20 19.49 MWD 9750.00 76.01 325.54 8527.02 2895.34 -2254.04 5963957.40 689723.54 2.70 -819.23 19.43 MWD 9775.00 76.64 325.77 8532.93 2915.40 -2267.75 5963977.10 689709.32 2.70 -823.18 19.37 MWD 9800.00 77.28 326.00 8538.57 2935.56 -2281.40 5963996.91 689695.15 2.70 -827.03 19.32 MWD 9820.00 75.48 326.00 8543.28 2951.67 -2292.27 5964012.74 689683.88 9.00 -830.07 180.00 MWD 9825.00 74.34 326.39 8544.58 2955.68 -2294.96 5964016.68 689681.09 .24.00 -830.81 162.00 MWD 9850.00 68.65 328.38 8552.51 2975.64 -2307.74 5964036.30 689667.81 24.00 -833.96 161.90 MWD 9875.00 62.98 330.54 8562.75 2995.27 -2319.33 5964055.62 689655.72 24.00 -836.17 161.26 MWD BP Alaska by -'~` Baker Hughes INTEQ Planning Report >~~~~ Company: BP Amoco Date: 1/28/2008 Time: 10:28:33 Page: 3 Field: Prudhoe Bay Co-ord inate(NE) Reference: Well: 18-26, True North Site: PB DS 18 Vertical (TVD) Reference: 49:26 2/3/1993 00:00 52.0 Well: 18- 26 Section (VS) Reference: Well (O. OON,OAOE ,65.OOAzi) Welipath: Pla n 4, 18-266 Survey Calculation Method: Minimum Curvature Db: Sybase Survey MD lncl Azim SS TVD N/S E/W MapN MapE DLS VS TFO 'Poo ft deg deg ft ft ft ft ft deg/100ft ft deg 9900.00 64.68 336.96 8573.79 3015.38 -2329.24 5964075.48 689645.30 24.00 -836.65 74.99 MWD 9925.00 66.64 343.18 8584.10 3036.78 -2336.99 5964096.67 689637.01 24.00 -834.63 72.16 MWD 9950.00 68.85 349.21 8593.58 3059.24 -2342.49 5964118.98 689630.93 24.00 -830.13 69.59 MWD 9975.00 71.26 355.05 8602.11 3082.50 -2345.70 5964142.15 689627.13 24.00 -823.20 67.31 MWD 10000.00 73.85 0.73 8609.61 3106.33 -2346.57 5964165.94 689625.65 24.00 -813.93 65.31 MWD 10025.00 76.59 6.25 8615.99 3130.44 -2345.09 5964190.09 689626.51 24.00 -802.39 63.61 MWD 10050.00 79.44 11.65 8621.19 3154.58 -2341.28 5964214.32 689629.70 24.00 -788.74 62.20 MWD 10075.00 82.38 16.94 8625.14 3178.49 -2335.19 5964238.37 689635.19 24.00 -773.11 61.08 MWD 101.00.00 85.39 22.17 8627.80 3201.90 -2326.87 5964261.99 689642.90 24.00 -755.67 60.24 MWD ' 10125.00 88.43 27.35 8629.15 3224.56 -2316.42 5964284.91 689652.77 24.00 -736.63 59.68 MWD 10137.84 90.00 30.00 8629.33 3235.83 -2310.25 5964296.32 689658.64 24.00 -726.28 59.40 MWD 10150.00 90.00 28.54 8629.33 3246.43 -2304.31 5964307.08 689664.31 12.00 -716.41 270.00 MWD 10175.00 90.00 25.54 8629.33 3268.70 -2292.95 5964329.62 689675.10 12.00 -696.70 270.00 MWD 10200.00 90.00 22.54 8629.33 3291.53 -2282.76 5964352.70 689684.70 12.00 -677.83 270.00 MWD 10225.00 90.00 19.54 8629.33 3314.86 -2273.79 5964376.25 689693.08 12.00 -659.83 270.00 MWD 10250.00 90.00 16.54 8629.33 3338.62 -2266.05 5964400.21 689700.21 12.00 -642.77 270.00 MWD 10275.00 90.00 13.54 8629.33 3362.76 -2259.56 5964424.51 689706.08 12.00 -626.69 270.00 MWD 10288.00 90.00 11.98 8629.33 3375.45 -2256.69 5964437.26 689708.62 12.00 -618.73 270.00 MWD 10300.00 90.00 13.42 8629.33 3387.15 -2254.05 5964449.02 689710.96 12.00 -611.39 90.00 MWD 10325.00 90.00 16.42 8629.33 3411.30 -2247.61 5964473.33 689716.78 12.00 -595.35 90.00 MWD 10350.00 90.00 19.42 8629.33 3435.09 -2239.92 5964497.31 689723.86 12.00 -578.33 90.00 MWD 10375.00 90.00 22.42 8629.33 3458.44 -2231.00 5964520.87 689732.18 12.00 -560.37 90.00 MWD 10400.00 90.00 25.42 8629.33 3481.29 -2220.86 5964543.97 689741.73 12.00 -541.53 90.00 MWD 10425.00 90.00 28.42 8629.33 3503.58 -2209.54 5964566.54 689752.47 12.00 -521.85 90.00 MWD 10450.00 90.00 31.42 8629.33 3525.24 -2197.07 5964588.52 689764.38 12.00 -501.39 90.00 MWD 10475.00 90.00 34.42 8629.33 3546.22 -2183.49 5964609.84 689777.43 12.00 -480.21 90.00 MWD 10500.00 90.00 37.42 8629.33 3566.47 -2168.82 5964630.45 689791.57 12.00 -458.37 90.00 MWD 10525.00 90.00 40.42 8629.33 3585.92 -2153.12 5964650.29 689806.77 12.00 -435.92 90.00 MWD 10550.00 90.00 43.42 8629.33 3604.52 -2136.42 5964669.31 689822.99 12.00 -412.92 90.00 MWD 10575.00 90.00 46.42 8629.33 3622.22 -2118.77 5964687.46 689840.18 12.00 -389.44 90.00 MWD 10600.00 90.00 49.42 8629.33 3638.97 -2100.21 5964704.68 689858.30 12.00 -365.55 90.00 MWD 10625.00 90.00 52.42 8629.33 3654.73 -2080.81 5964720.93 689877.29 12.00 -341.30 90.00 MWD 10650.00 90.00 55.42 8629.33 3669.45 -2060.61 5964736.16 689897.11 12.00 -316.77 90.00 MWD 10675.00 90.00 58.42 8629.33 3683.09 -2039.66 5964750.33 689917.70 12.00 -292.02 90.00 MWD 10688.00 90.00 59.98 8629.33 3689.75 -2028.49 5964757.27 689928.70 12.00 -279.08 90.00 MWD 10700.00 90.00 61.42 8629.33 3695.62 -2018.03 5964763.41 689939.00 12.00 -267.12 90.00 MWD 10725.00 90.00 64.42 8629.33 3707.00 -1995.77 5964775.35 689960.96 12.00 -242.14 90.00 MWD 10750.00 90.00 67.42 8629.33 3717.20 -1972.95 5964786.13 689983.51 12.00 -217.15 90.00 MWD 10775.00 90.00 70.42 8629.33 3726,19 -1949.63 5964795.71 690006.60 12.00 -192.21 90.00 MWD 10788.00 90.00 71.98 8629.33 3730.38 -1937.32 5964800.22 690018.80 12.00 -179.28 90.00 MWD 10800.00 90.00 70.54 8629.33 3734.23 -1925.96 5964804.36 690030.05 12.00 -167.36 270.00 MWD 10825.00 90.00 67.54 8629.33 3743.17 -1902.61 5964813.89 690053.16 12.00 -142.42 270.00 MWD 10850.00 90.00 64.54 8629.33 3753.33 -1879.77 5964824.62 690075.74 12.00 -117.43 270.00 MWD 10875.00 90.00 61.54 8629.33 3764.66 -1857.49 5964836.52 690097.72 12.00 -92.45 270.00 MWD 10888.00 90.00 59.98 8629.33 3771.01 -1846.15 5964843.16 690108.90 12.00 -79.48 270.00 MWD 10900.00 90.00 61.42 8629.33 3776.88 -1835.68 5964849.30 690119.21 12.00 -67.52 90.00 MWD 10925.00 90.00 64.42 8629.33 3788.26 -1813.43 5964861.24 690141.16 12.00 -42.53 90.00 MWD 10950.00 90.00 67.42 8629.33 3798.46 -1790.60 5964872.02 690163.72 12.00 -17.54 90.00 MWD 10975.00 90.00 70.42 8629.33 3807.45 -1767.28 5964881.60 690186.80 12.00 7.40 90.00 MWD 11000.00 90.00 73.42 8629.33 3815.21 -1743.52 5964889.96 690210.36 12.00 32.21 90.00 MWD 11025.00 90.00 76.42 8629.33 3821.71 -1719.38 5964897.08 690234.32 12.00 56.84 90.00 MWD 11050.00 90.00 79.42 8629.33 3826.94 -1694.94 5964902.93 690258.62 12.00 81.20 90.00 MWD 11075.00 90.00 82.42 8629.33 3830.89 -1670.25 5964907.51 690283.19 12.00 105.24 90.00 MWD BP Alaska by Baker Hughes INTEQ Planning Report iN'TEQ Company: BP Amoco Date: 1!28/2008 Time: 10:28:33 Page: 4 Field: Prudhoe Bay Co-ord inate(NE} Reference: Well: 18-26, True N orth i Site: PB DS 18 Vertical (TVD) Reference: 49:26 2/3!1993 00:00 52.0 ~ Well• 18- 26 Section (VS) Reference: Well (O. OON,O.OOE,65.OOAzi) ~ Wellpath: Pla n 4, 18-268 Survey Calculation Method: Minimum Curvature Db: Syba se Survey _ _ !~ MD Intl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Too ft deg deg ft ft ft ft ft deg/100ft ft deg 11100.00 90.00 85.42 8629.33 3833.53 -1645.40 5964910.79 690307.97 12.00 128.89 90.00 MWD 11125.00 90.00 88.42 8629.33 3834.88 -1620.44 5964912.77 690332.89 12.00 152.08 90.00 MWD 11150.00 90.00 91.42 8629.33 3834.91 -1595.44 5964913.44 690357.87 12.00 174.75 90.00 MWD 11175.00 90.00 94.42 8629.33 3833.64 -1570.47 5964912.81 690382.86 12.00 196.83 90.00 MWD 11200.00 90.00 97.42 8629.33 3831.06 -1545.61 5964910.87 690407.78 12.00 218.28 90.00 MWD 11225.00 90.00 100.42 8629.33 3827.18 -1520.91 5964907.62 690432.57 12.00 239.02 90.00 MWD 11238.00 90.00 101.98 8629.33 3824.66 -1508.16 5964905.42 690445.38 12.00 249.51 90.00 MWD 11250.00 90.00 100.54 8629.33 3822.31 -1496.39 5964903.38 690457.20 12.00 259.19 270.00 MWD 11275.00 90.00 97.54 8629.33 3818.39 -1471.71 5964900.09 690481.98 12.00 279.90 270.00 MWD 11300.00 90.00 94.54 8629.33 3815.75 -1446.85 5964898.09 690506.90 12.00 301.32 270.00 MWD 11325.00 90.00 91.54 8629.33 3814.43 -1421.89 5964897.40 690531.88 12.00 323.38 270.00 MWD 11350.00 90.00 88.54 8629.33 3814.41 -1396.89 5964898.03 690556.87 12.00 346.03 270.00 MWD 11375.00 90.00 85.54 8629.33 3815.70 -1371.93 5964899.95 690581.79 12.00 369.20 270.00 MWD 11400.00 90.00 82.54 8629.33 3818.30 -1347.06 5964903.18 690606.58 12.00 392.83 270.00 MWD 11425.00 90.00 79.54 8629.33 3822.19 -1322.37 5964907.70 690631.16 12.00 416.85 270.00 MWD 11443.00 90.00 77.38 8629.33 3825.79 -1304.73 5964911.75 690648.70 12.00 434.36 270.00 MWD 11450.00 90.00 78.22 8629.33 3827.27 -1297.90 5964913.41 690655.50 12.00 441.18 90.00 MWD 11475.00 90.00 81.22 8629.33 3831.73 -1273.30 5964918.50 690679.97 12.00 465.36 90.00 MWD 11500.00 90.00 84.22 8629.33 3834.90 -1248.50 5964922.30 690704.68 12.00 489.17 90.00 MWD 11525.00 90.00 87.22 8629.33 3836.76 -1223.58 5964924.80 690729.55 12.00 512.55 90.00 MWD 11550.00 90.00 90.22 8629.33 3837.32 -1198.59 5964925.99 690754.51 12.00 535.43 90.00 MWD 11575.00 90.00 93.22 8629.33 3836.57 -1173.60 5964925.88 690779.51 12.00 557.76 90.00 MWD 11600.00 90.00 96.22 8629.33 3834.51 -1148.69 5964924.46 690804.46 12.00 579.47 90.00 MWD 11625.00 90.00 99.22 8629.33 3831.15 -1123.92 5964921.74 690829.31 12.00 600.50 90.00 MWD 11650.00 90.00 102.22 8629.33 3826.50 -1099.36 5964917.72 690853.98 12.00 620.80 90.00 MWD 11675.00 90.00 105.22 8629.33 3820.58 -1075.07 5964912.41 690878.41 12.00 640.30 90.00 MWD 11700.00 90.00 108.22 8629.33 3813.38 -1051.13 5964905.83 690902.52 12.00 658.96 90.00 MWD 11725.00 90.00 111.22 8629.33 3804.95 -1027.60 5964898.00 690926.26 12.00 676.72 90.00 MWD 11750.00 90.00 114.22 8629.33 3795.29 -1004.54 5964888.94 690949.55 12.00 693.54 90.00 MWD 11775.00 90.00 117.22 8629.33 3784.45 -982.02 5964878.67 690972.34 12.00 709.36 90.00 MWD 11781.00 90.00 117.94 8629.33 3781.67 -976.70 5964876.03 690977.73 12.00 713.01 90.00 MWD 11800.00 90.00 115.66 8629.33 3773.10 -959.75 5964867.90 690994.90 12.00 724.76 270.00 MWD 11825.00 90.00 112.66 8629.33 3762.87 -936.94 5964858.26 691017.96 12.00 741.10 270.00 MWD 11850.00 90.00 109.66 8629.33 3753.85 -913.63 5964849.83 691041.49 12.00 758.42 270.00 MWD 11875.00 90.00 106.66 8629.33 3746.05 -889.88 5964842.65 691065.44 12.00 776.65 270.00 MWD 11900.00 90.00 103.66 8629.33 3739.52 -865.75 5964836.73 691089.72 12.00 795.75 270.00 MWD 11925.00 90.00 100.66 8629.33 3734.25 -841.31 5964832.09 691114.28 12.00 815.67 270.00 MWD 11937.00 90.00 99.22 8629.33 3732.18 -829.49 5964830.33 691126.15 12.00 825.51 270.00 2.375 ' BP Alaska WELLIATX OETAIIA 60on 9 1E-ME 020~222W2 Ponnt Wallpolh: 1E-2EPE1 ila on M0: a2ae.H vw. e.~...s_ u-202I9MBY]OOAO 82.OOIt C L 0 8 x' a a~ Y 2 F by LEGEND - 1&26(16-26) --- 18-26 18-26Ai - 18-26(18-26APBiJ - 18-26(18-26APB2) - 18-26(18-26P87) - Plan 4, i8-268 ---- Plan #4 Cmtacl nlormx: on &e M r n il: (90]1301->J5llt E ,air, nai m~ci,ameai®~~mn.wm LEGEND BP Alaska I -_ ~z-;;~ WELLIATX DETAI4A lioos9a4iu~94oz ' fam:l WellpnM: 10.26PH 110 en MD: 0838.88 wr. wmDm: a9:2n van043 oo:aA S1.omt v.9.9u9n on9m Drym ng Arg10 NIi rEI.W Froro TVD 66A0' O.pO o.o0 9sao L2-111 L2-21 "_-_...~ L2-21 L2-29 "'"-'- 18-01 18-01 -- - - 18-02 - ---- 1 B-02 -"- 18-02 -- - - 18-03 ----- 18-03 REFERENCE INFORMATION _ 18-03 __ 18-04 Co-ordinate (N/E Reference: Well Centre: iB-26, True NorN --- -- 18_04 Vertical (TVD Reference: 49: 26213/199300:D052.00 -.... 18_04 Section (VS Reference: Sbt-26 (O.OON.O.OOE) Measured Depth Reference:49:262/3/199300:00 52.00 18-04 Calculation Method: Minimum Curvature - - 18-05 _ .. _- - 18-05 _ __ _.~ _ -__v m ---- --~ Bea)IDx DE4Alu ~~ "-' -- 18-08 iac MO -. Ppe TVD .W-6 1Fi-W My TFacn VMC i+rybt. 18-05 1 -9636.98 T].i3 84.40 ®SOH.OP 2806.)4 .2 Y9.ST O.Otl 0.00 41AA.16 U] 46 J1 40 2 i0 98 89 39Eb bb 8201 d ~~ -- 18'O5 --- 18_O] . . U- . . . , 2 A800.00 .19.90 J36.00 S9 ] 80 000 5.48 00 338. 51 8) 392.2} 9.00 W 00 00 96100 s58 ti1 7]18 ]] 4 b }i YH T ' _„_- 18-07 . . . - .N 310 a b f a 9 Y .W v .331018 34.b0 489 ]4.24 f 9P3)a6 98.00 OB.BE8i.3E 333E 8E 18-07 . -1258.59 ix 00 390.90 698.13 6 +A26B.00 00.08 1+.98 8809.93 ]398.46. .3038 09 -3rY.Ui 49 91 a8B1 ]E 3800 13 88 69 53 > -__. 18-07 . . . . . . 70088.00 Po ,10]1.]9 13.00 40.W. -199.98 0186.04 00.00 11.48 ~6Bt.93 3930.]8 -- 18 OB i4es9.ao .oo. 9.09 9+.3]. Sn9.m -teab.ta 1x.oo 390.00 -re.4d .99199]8.06 60.00 101Ab ~64t.]3 3894.64. 5M.96 t3-OA 08.00 i .It - -- 18-08 9t +iM1.W 90,00 )3.30 09.33 9815.98 -9]84 )3 12AA 9.00 494.36 .00 W.DO )t3A9 69 BTb )b t 99 8481 ]] 9171 911}87 80 90 00 1 ) 18-08 y . . , . . 1 t] t1RTi 00 W.W Y 32 BB9t.]3 ]999.91 82944 1 AA Y b.40 834.bA --. 18-09 -- 18-09 - 18-09 - 18-10 :.. . l -- 18-10 __..-_ 18-10 ---- 18-10 - 18-10 1) T M AzBnuths to Trua No:1h Maeneric Ngg h'. 32.86° Plan: Plan #4 (18-261PWn 4, 18-26B) Created By: BP Dala: 129/2009 Checketl: Date: SVeM th'. 6]]15nT DIP ~rw~a. eo.94• Date'. 412012003 Maaar. ae4mzoo] ~wenn:auon: .one I BN Mldiaolson cn5. t9o])Sm.]6]n En~air. 4ill.mx:haulsonl{~Inluq.mm BP Alaska WF4PeTN DETl1118 Ian 4 18~2fiR 60029~Y9S902 Iannt WeIIMIk: 18-3fiPR1 rw on MD: aeab.ea Rat. Datum: 49.28 3/9HBBD OOAO 53.OMt v.sacmn or~j oNn~1 ~wr11~D w nn 1 . a - A„9 88A0' OAO O.DD 38A0 REFERENCE INFORMATION Co-ordinate (NIE Reference: Well Centre: 18-26, True NorN Vertical (TVD Reference: 49:26 2/3/1993 D0:00 52.D0 Section (VS Reference: Slot-26 (O.OON,O.OOE) D0 49: 2fi 2!3/1993 DD:00 52 th R f n d D . e ere ce: Measure ep Calculation Method: Minimum Curvature -. _.._.-.._._._ .._-.-_.____. _._..__ __-~.___e-~. BBCYION D£4AiL8 --_.,--__.-- Sac MD inc Au TVD iMl.3 +F1-W DL.y T6ace Y8a0 Tarear. $38.82 X005.>9 ~21 t.]1 .00 0.00 8 t 9638.!9 >S.9S 3Y 4 400.2@ Q 8 2 98W:a0. Y>38 D20 b99.b> 0}6.SB -22@9.40 Y.>0 18.88. 5.{8. SE6.00. 94,78 4951.61 -3S92.Y) 0.00 180.00 ] 9@30.Ob 1 8 i3>.03 #90.01 6 14.)5 29853) 2318.39 2-0.00 184.00. { 80]b,00 E.98 9]0.83 8 0931.@{ 90.00 90.00 687.3] 3538,83 ~2310.Y$ .DO )4.88 ! 738.17 •)26.48 ; 8 038B.OD .90.00 9.08 0N5i.3} 1378.48 3466.88 y2.60 179.00 ' 1 40858.00 99.90 88.98 9.99 ]889.1$ -YOYB.{9 .00 ~.~ 90>Itl.W 9000 1.98 0GB9.3} }730.38 -993r.3E 13.06 .610.1} -219-DO -1)8.28 088!.09 BOAO 59.98. 689.39 3TT9.01 -1849.95 .90 270.00 9 9619298.00 1A 7.98 0885.93 3824.66 -A808.t5 14.00 .00 -19.4@ 239.Sf i1 tt493.90 80.00 > • 8889.33 3816.>A -1304.71 i2 00 3)0.00 93 91 51.00 90-00.1 868939 3)89.61 -815.)0 42.@0. W.OQ 0.94.M >92.Of 13 9193).00 90.00 9932 8681.19 9)31.98 •0Y9M 12.00 240.00 itf.89 LEGEND - L2-11 (L2-11 - L2-11 PB1 (L -71481) - L2-11P62(L2-71482) - L2-21 (L2-21) --- L2-21 (L2-21 A) - L2-29 (L2-29) ---- 18-18 (18-18) --- 18-18 18-18A) ~- 18-18 18-18AP81) - 18-18 18-188 ---- 18-18 (18-188 B1) - 18-26 (18-26) ---- 18-26 18-26A) - 18-26 18-26APB1) - 18-26 (18-26AP82) ----- 18-26 (18-26481) '- Plan 4, 18-268 -- Plan #4 T Plan: Plan #4 (18-26/Plan 4, 18-266) M Azimuths r9 Tme IiOM Created By: BP Date: 7/29/2009 Maen9lic NOrlh: 22.66° GhBCketl: Dale: Map etlO Fleltl o~p ~nhgle'ei. aT comza mrom,anon: Dara:anon6o9 a~u Mld,a01co9 Motlel: bOgm200] Call: (90]7301-35]0 E-mall: Dlll.micha01son1(QIn109.cOm WELL DETAILS ANTI-COLLISION SETTINGS Name +W-S rFJ-W NoMing Bat'ling Lnlitmk Longitude Slot Intopolalion Me0~odMD Interval: 50.00 DopN Range From: 9636.59 To: 11937. W Ifl-26 1895,21 515.76 5961110.7fl W2WU.70. 70"17'S3.fl91N 148"26'4U.52UW 26 MaBimum Rmge: 13YU.IU Refinence: Plan: Plan N4 13 IJ COMPANY DETAILS SURVEY PROGRAM BY AnNK9 Ucpth Fm UepOt 7'u Survry/Plun Culculmion Mmhml: Minimum CLrvamrc 9636.59 11937.00 PlannW: Ylau lt4 V7 Ertm Sys4m: ISCWSA 5<mt Method: Trev Cylinder NaM Erter Surface: Elliptical+Cnaing Warning Method: Rules Based _ tIC i t\ I l...ai' i. ~ . + `w~ ` \ ~\ 4~ \~ n .a \ lu; 1 t ``I„ \ ~m/ ~~, 27L, ~~]Ii .+I~ 1`1\11~Puv1[111~j! 241 ~.\\. ~ \\\~ .t.-F ~.~... r .`4``t - ~~. I\„ , ~ ,; ,~`\ R,; ~~` ~r ~ ~4 ~~ ~ ~M ~ r n' i J ~ ~ ~ J ~ . r - J rf _ ~ b~ ~. eI~P ~yi -. - --. 'y .1 - _ ~Ll~~\ ,, 1 ~~ ~ ,;+i:'• \, tl," ~ ~~, ,~~ ,, t, :1 i L1V!.Z ~. -,C _. ~ ,0~ \~ `~ alv ~~ JIUi9 ._u IdU _tl1 -- Travelling CyluWer AzinnW (TFO+~AZp [dagJ vs CenOC m Centre Sepmolion [ISfI/in] 9 I~.,A1~11~~1~~i ,.w 0 m~~l iirul~ r/ 29 WELLYA'fll DETAILS Twl Plvt 9, 18-26N 500192232902 MWD Pnrem Wellpalh: IS-261'DI Tie an MU: 963fi.59 Rig'. Rcf. Umum: 49: 262/]/199300:W 52 Wft V.S,rctiou Origin Origin Starling Angle +N/-S +Fl-W Fmm NU 65.W° 0.00 O.OU 3fi.W LEGEND ---- L2-ll(L2-11), Major Risk - L2-1IP61 (L2-11PB1), Major Risk - L2-21 (L2-21), Major Risk - L2-21 (L2-21A), MaJor R]sk --- L2-29 (L2-29), Major Risk 18-18 (18-I8), MaJor Rlsk - - 18-IS (18-I8A), MaJor Risk --- IS-18 (18-18APBl), Major R]sk - 18-I8 (IS-IRB), Major Risk -- IS-IS (18-ISBPBI), MaJor Rlsk -- I8-26 (18-26PB1), MaJor Rlsk -~---- IR31 (1831), Major Risk - 18-31(18-31PB1), Major Risk -- Plan 4, IS-26B _......_. Plan N4 PWV. PW, w (IF+1/Plw, , Itl Mm d y bP Oa rzY2e99 .iN- Bw --... W..-- -_.... Ik,e _._ by it' INTEQ SECTION UETAII,S Sec MU Inc AW 7VD +N/-S +IJ-W Ul.eg TFace VSee 'far8ut 1 9636.59 13.12 329.44 8548.83 2605.]9 -2191.37 O.W O.W -800.24 98W.U0 77.26 R6.W 6590.51 X915.56 -'_'-81.40 2.70 19.66 -827.U3 3 9d20.W ]546 326.W 8595.28 2951.67 -2^_92.27 9.00 ISO.W -830.07 4 96]S.W 62.98 330.54 8619.75 2995.27 -2319.31 X4.00 162.W -436.17 5 101]7.84 W.W 30.00 8fi81.33 3235.43 X310.25 24.W 74.99 -726.28 6 10266.00 90.W 11.98 8681.33 3375.45 -2256.69 12.W 270.W -614.73 7 10684.00 90.W 59.98 Sfi81.33 ]689.75 -2028.49 12.W 90.W -279.08 8 10788.00 90.00 71.98 6681.]3 3770.38 -1937.32 12.W W.W -179.24 9 IWSB.W 90.00 59.94 8681.13 3711.01 -1846.15 12.00 T70.W -79.48 10 11278.W 90.00 101.98 d6d1.33 3824.66 -1508.16 12.00 W.W "49.51 II 11441.W 90.W 77.14 Nfi81.33 3825.]9 -13W.71 12.W 270.W 474.36 12 11781.W 90.W 117.94 868133 3781.67 -976.70 12.W 9U.W 713.01 13 11977.W W.W 99.22 8681.33 37]2.18 -829.49 12.W 270.W 425.51 • BP Alaska by Anticollision Report ~~~ BAN~GR~~ INTEQ ~~ Comp :any BP Amow Date: 1/28!2009 Time: 14:13:00 Page: 1 Field: P rudhoe Bay Reference Site: P B DS 18 Co-ordinate(NE) Reference: Well: 18-2 6, True North Reference Well: 1 8-26 Vertical (TVD) Reference: 49:26 2/3!1993 00:00 52.0 Reference Wellpath: Plan 4, 18-266 _ Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are'I~}ddi$eeells in this~Iahlfipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 9636.59 to 11937.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1390.10 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 1/20/2008 Validated: No Version: 0 Planned From To Survey Toolcode Tool Na me ft ft 500.06 9636.59 1 : MWD -Standard (500.06-107 MWD MWD -Standard 9636.59 11937.00 Planned : Plan #4 V7 MWD MWD -Standard Casing Points MD TVD Diameter Hole Size Name _ ft ft in in 11937.00 8681.33 2.375 3.000 2.375" Summary ------- Offset Wellpath - --> Reference MD Offset Ctr-Ctr MD Distance No-Go Area Allowable Deviation Warning ~ Site WeII Wellpath ft ft ft - ft ft --- - - Lis DS 02 L2-11 L2-11 V2 Out of range Lis DS 02 L2-11 P61 L2-11 PB1 V1 Out of range Lis DS 02 L2-11 PB2 L2-11 P62 V2 Out of range Lis DS 02 L2-21 L2-21 V2 Out of range Lis DS 02 L2-21 L2-21A V6 Out of range Lis DS 02 L2-29 L2-29 V1 11509.09 9325.00 598.38 162.90 435.48 Pass: Major Risk PB DS 18 18-18 18-18 V6 10995.61 10975.00 20.62 139.62 -119.00 FAIL: Major Risk PB DS 18 18-18 18-18A V1 10856.19 11025.00 52.14 130.07 -77.93 FAIL: Major Risk PB DS 18 18-18 18-18APB1 V1 10856.19 11025.00 52.14 129.98 -77.84 FAIL: Major Risk PB DS 18 18-18 18-188 V4 10856.19 11025.00 52.14 130.07 -77.93 FAIL: Major Risk PB DS 18 18-18 18-18BP61 V1 10856.19 11025.00 52.14 129.98 -77.84 FAIL: Major Risk PB DS 18 18-26 18-26 V1 9800.00 9800.00 0.01 223.50 -223.50 FAIL: Major Risk PB DS 18 18-26 18-26A V4 9800.00 9800.00 0.01 223.50 -223.50 FAIL: Major Risk PB DS 18 18-26 18-26AP61 V2 9800.00 9800.00 0.01 223.50 -223.50 FAIL: Major Risk PB DS 18 18-26 18-26APB2 V2 9800.00 9800.00 0.01 223.50 -223.50 FAIL: Major Risk PB DS 18 18-26 18-26PB1 V1 9800.00 9800.00 0.01 223.50 -223.49 FAIL: Major Risk PB DS 18 18-31 18-31 V4 Out of range PB DS 18 18-31 18-31 P61 V3 Out of range Site: Lis DS 02 Well: L2-29 Rule Assigned: Major Risk Wellpath: L2-29 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Ma}or Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD lief Offset TFO+AZI TFO- HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11920.26 8681.33 8125.00 7429.76 35.08 16.62 91.48 350.25 1269.91 97.10 1172.81 Pass 11896.80 8681.33 8150.00 7450.43 36.69 16.83 93.87 349.82 1250.57 97.66 1152.91 Pass 11872.62 8681.33 8175.00 7471.22 38.35 17.03 96.36 349.41 1231.07 98.26 1132.81 Pass 11847.87 8681.33 8200.00 7492.15 40.05 17.22 98.93 349.02 1211.36 98.91 1112.45 Pass 11822.68 8681.33 8225.00 7513.19 41.76 17.40 101.58 348.64 1191.47 99.62 1091.85 Pass 11797.05 8681.33 8250.00 7534.33 43.46 17.58 104.30 348.28 1171.41 100.37 1071.04 Pass 11777.70 8681.33 8275.00 7555.52 44.31 17.69 105.48 347.93 1151.24 101.08 1050.16 Pass 11769.16 8681.33 8300.00 7576.75 43.82 17.71 104.08 347.56 1131.12 101.74 1029.37 Pass 11760.75 8681.33 8325.00 7598.02 43.33 17.72 102.67 347.16 1111.07 102.46 1008.62 Pass 11752.48 8681.33 8350.00 7619.33 42.85 17.74 101.25 346.73 1091.12 103.24 987.89 Pass 11744.31 8681.33 8375.00 7640.64 42.36 17.78 99.81 346.27 1071.29 104.09 967.20 Pass 11736.21 8681.33 8400.00 7661.94 41.86 17.84 98.35 345.78 1051.61 105.05 946.55 Pass 11728.18 8681.33 8425.00 7683.21 41.36 17.93 96.86 345.26 1032.09 106.11 925.98 Pass 11720.20 8681.33 8450.00 7704.43 40.85 18.01 95.35 344.70 1012.78 107.24 905.55 Pass 11712.28 8681.33 8475.00 7725.59 40.34 18.10 93.81 344.11 993.70 108.42 885.28 Pass 18-268 - Coiled Tubing Dri ing i N BtindfShears 2" combi ramfslips Mud Cross 2 3f8" pipefslip Flow Tee 18-2~~3 BAG. TOTS Mud Cross January 26, 2009 Alaska Department of Natural Resources Land Administration System Page 1 0~` • _«~ ~~,~:~f~~€ ~ ;~-,: ~h state Cabins ~ ,~ ~5r~41C S IBS a r° 1_A, Menu ~ Case_Abstract ~ Case Detail ~ Land Abstract ~- File: ADL 2R3~ 1 ' ' Search for ~ tatu s Play ~;~ z12~t~_~~s Ct~stojner: 000107377 BP EXPLORA"I~1ON (ALASKA) iNC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA. ANCHORAGE AK 995196612 Circe Type: 7134 OIL & GAS LEASE COMP DNR Unil: 780 OIL AND GAS File Locution: DOG DIV OIL AND GAS Ca.ce,S'tutus:3~ ISSUED Status Date: 09/14/1965 1'otul _~CTeS: 280.000 Dale IYllllalBa'' 05/28/1965 Office of I'~°i~na~y Responsibilil~~: DOG DIV OI L AND GAS Lust Tf°ansuction Date: 12/04/2006 Case Subtype : s NORTH SLOPE Last Transaction: AA-NRB ASSIGNMEN"C APPROVED AIe1'IChan: U TOli'T1SI11I7: 01 IN RUTlge.` O1JE, ,SEC'II077: ~7 Si'~~I7u11 ,~CYE'S: 6~O ~aB~S'CFl F~la~s ~lIer~z~lia~a: U Totivnslrr/>.~ Il l IN I~u~~,~~~: O1 ~I~ ~'~ctios~: 18 ~~~~~~~r~~ir I~ rc~: ~~>~) ll9cf°icliun: UI'otivt7slty~.~ 0l 1 V~ l~~nr~c~ U I SE Section: 19 Section acres: {>(J I ~Lfericlian: U Totiarr~hil~~ (~ I I ~ I~~m.,~~: 015E Section: 20 Section Acf•es: 640 Legal Description 0~-?b'-19<~ *~' ,S':~11,EA'OTIC'E LEG:9L DESC7UPTIOA C'I-I-I ~I TIIA'. RISE, Z"III', l-S'. 19. ?0?-l~S'0.00 Last updated on 02/04/2009. http://dnr.alaska.gov/projects/las/Case_Summary.cfm?FileType=ADL&FileNumber=28321... 2/4/2009 Alaska Department of Natural Resources Land Administration System Page 1 of~~ . - <r.~ ~ .a;-~: _, .~ ,~~arch Stag Cabins ~tRtl ~u~' S aka ~V CaE', ark ^~ nn„°+ I Case Abstract i Case Detail i Land Abstract /~rlc~: ~llL 25307 ~~~~~~rch ter Staf;3s Plat UNdates Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995 1 966 1 2 Case The: 784 O[L & GAS LEASE COMP DNR Uui1: 780 OlL AND GAS File Loccrtiora: DOG DIV OIL AND GAS Cuse Stult~s: 33 ISSUED Stalrrs D~rte: 09/l4/1965 Totul Acres: 2560.000 Dote hzitiuted : 05/28/1965 Office of Priiuarv Rc>spojtsibiliiy: DOG DIV OIL AND GAS Lust Truftsuc°tion Dale: 12/04/2006 Cuse Strbtv~e : ~ NORTH SLOPE I~rst 7i~cursacliort: AA-NRF3 ASSIGNMENT nPPROVED Il1E'1'l[~1CX71: U TOlP31SI?lj~: O1 1N Rul?~e: 014E SPC't1071: 13 SL'CtZO77 ACYC'.S': 640 Search ;,jiS ~l~~~i~i~li~n~~ I' "f'o~rnshi~~: O11N Rczj~gE:: 014E Sectioj~: 14 Sectioj~a_~crc°~- ~~~~1 ~leridran: U Toinrrshi~: 01 IN Rc~rt,rc_ 014E Section: 23 Secliofa Acres: (~ GO ~1leric~iur~: U Tox~n~hir~: U I I N 1~'~rnge. 014E Section: 24 Section Acres: 644 Leal Description ll~-?b'-1 yG~ '~S 91,E A'OIIC'E LFG.~t I DL'~S'C'RIPTIO:'~- CI-1-128 l IN 1~/E U~lt J3, l=/,23.?~J 260.00 U 3- 7 h t~ t.. m tl ~ t" Last updated on 02/04/2009. http://dnr.alaska. gov/projects/las/Case_Summary.cfm?FileType=ADL&FileNumber=28307... 2/4/2009 TRANSMITTAL LETTER CHECKLIST WELL NAME __ ~,~~ ~~?~~ PTD# ~O~OI~ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~.e.°C/,dyOE' ~ y POOL: ~.E'l/l~.~O~ ~i9y ~G Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS VVHgT (OPTIONS) APPLIES TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existin g well (If last two digits in API number me Permit No. ,API No. 50- - _ between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and togs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH SAMPLE 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 throw h tar et zones. Non-Conventional Well Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for name of welly until after (Comnanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Comaany Name must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: I / 11 /2008 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 18-268 Program DEV Well bare seg ^ PTD#:2090170 Comp any BP EXPLORATION (ALASKA) INC Initial Class/Type DEV 1 PEND GeoArea 890 __ Unit 11650 On/Off Shore On Annular Disposal ^ Administration 1 PeCmit_fee attached- NA_ 2 Lease_number appropriate- Yes . 3 Unique well- name and number - - - Yes 4 Welllocat_edin.a_defnedpool_________________________ _Yes_ ___._ 5 Well locatedp[operdistancefromdrillingunit_boundary_______ __________ ___ __ Yes_ ___________.._.-__---- -.. _.. 6 Well located proper distance from other wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ . 7 Sufficient acreage_ayail_able in_drilling un_it_ _ Yes 8 !!-deviated, is.wellbore plat_included Yes 9 Operator only affected party- .. _ . _ _ _ Yes 10 Operator has_appr_opriate_ bond in force Yes ..... Blanket Bond # 6194193. _ 11 Permit- can be issued without conservation order. _ _ ... _ _ _ _ _ Yes _ _ .. _ - _ _ _ _ _ _ _ _ _ _ . r ae pP 12 Permit_can be issued without administrative_approval , Yes ----------------- i 13 Can permit be approved before 15-day wait_ _ _ _ _ _ _ _ _ _ __ __ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes , . _ _ _ ACS 2!412009 14 Well located within area and_strata authorized by Injection Order # (put Ip# in_comments)_ (For- NA_ 15 All wells_within 114_mile area_of review identified (For Service well only)- _ . - , .. NA_ _ , x, 16 Pre-produced injector; duration_of pr_e-production less than 3 months- (For_se[vice well only) NA_ 17 Nonconven. gas conforms to AS31,05,030Q.1-.A).Q2.A-D) - - - - - - - - - - - - - - - - - - - - - NA- - - - - - - - - 18 Conductor string. provided -- NA_ _ .. _ _ _ .Conductor set in DS 18-26 (193-005)._ Engineering 19 Surface caSingprotects altknown USDWS . _ _ - - NA. _ _ _ _ No aquifers, A10 4B,_conclusion 5, 1 20 CMT_v_ol adequate. to circulate_o_n conductor & surf_csg _ NA_ _ .. _ _ .Surface casing set in DS 18-26. x; 21 CMT_vol adequate_to tie-inJong string to surfcsg - - NA Production,casin set in_DS 18.26, 9- 22 CMT_will coyer_all known_productive horizons- _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23 Casing desgns adequate for C,_T, B &_ permafrost- Yes 24 Adequate tankage_or reserve pit . .... - . - Yes . . _ . _ - -Rig equipped with Steel pits. No reserve pit planned.. All waste to approved disposal well(s). 25 If_a_re-drill,has.a.10-403 for abandonment been approved Yes 309-043 26 Adequate wellbore separation_proposed Yes Proximity analysis performed, Traveling cylinder path- calculateed._ Close approach identi_fied_ in reservoir. 27 If.diverter required, does it meet regu_lations_ NA_ BOP stack will alread _be_in -lace: . y p Appr Date 28 -Drilling fluid- program schematic_& equip list_adequate_ Yes Maximum expected formation pressure 7:7_ EMW, MW planned 8.6 ppg. _ . _ . . TEM 2/6/2009 29 BOPEs,dotheymeetregulation_______..._ Yes_ __________ _ _________ ___ _------_-- .. _ . /t X 30 BOPE_press rating appropriate; test to (put prig in comments)- _ _ _ Yes _ _ _ _ _ . MASP calculated at 2595psi. 3500_pst BOP test planned, _ 11 i 31 Choke-manifold complies w/APt RP-53 (May 84) _ _ .Yes _ _ _ _ 32 Work will occur without operation shutdown_ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ - _ _ . ~ ,33 Is presence-of H2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ Yes _ _ _ _ _ _ H2S is reported at DS 1$._ Mud should preclude H2S on_rig, Rig_has sensors and alarms._ __ 34 Mechanicalcondition of wells within AOR verified (For service well only) _ . NA_ 35 Permit-can be issued wlo hydrogen-sulfide measures _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ , _ Max level H2S on_ pad DS18 is 20ppm for well_18-03 (1.1!28/08). _ . _ , _ Geology 36 Data_presented on potential overpressure zones NA_ Appr Date 37 Seismic_analys_is_4fshollow gas z_ones_ _ ... _ NA_ ACS 2!4/2009 38 Seabed condition surrey (if off-shore) _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ _ ____ _ _ _ _ _ _ _ _ _ _ _____ __ _ _ _ _ ~39 _C_ontact namelphone fo_r weekly. progress reports-[exploratory gnly] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ McLRixse - 564.5.620. _ _ _ _ _ _ . _ _ _ . _ _ Geologic Engineering Public Date Date ~ Date: Commissioner: er Commissioner: ~~~ z.6-~ a~6^ o~ r~ iNelt History File APPENDIX Information of detailed nature that is not • particularly germane to the We11 Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. tapescan.txt '~'~*~ REEL HEADER **'~* MWD .09/07/01 BHI O1 LIS Customer Format Tape **** TAPE HEADER '~*** MWD 09/04/12 2539510 O1 2.375" CTK **~` LIS COMMENT RECORD '"~* !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 9643.0000: Starting Depth STOP.FT 12063.5000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 18-26B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 17'.53.892"N 148 deg 26' 40.520"W CNTY. COUNTY: North Slope Borough STAT. STATE: AlaSkd SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 12 Apr 2009 API API NUMBER: 500292232902 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 19 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 52 DMF DF EKB .F 0 EDF .F 52 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVD55) are subsea corrected. (4) All Formation Evaluation data is realtime data. Page 1 tapescan.txt (5) Baker Hughes INTEQ util„i zed coilTrak downhole tools and the Advantage surface system to loy this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated 14 Apr 2009 per Doug Stoner with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from 18-26 through a milled window in a 7 inch liner. Top of window 9790.5 ft.MD (8536.5 ft.TVDSS) Bottom of window 9780.0 ft.MD (8538.2 ft.TVDSS) (9) Tied to 18-26 at 9636.6 feet MD (8496.8 feet TVDSS). <10) The interval from 12061 feet to 12029 feet MD (8639.2 feet to 8639.6 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP~VG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHZ-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHZ-Compensated Borehole Corrected (OHMM) RPCLx -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHZ-Compensated Borehole Corrected (OHMM) TVDSS -> True vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, 9661.4, 9664.4, 9670.64, 9675.05, 9681.23, 9685.28, 9713.17, 9718.63, 9794.4, 9796.17, 9798.28, 9800.57, 9810.27, 9812.39, 9824.38, 9827.56, 9834.26, 9837.96, 9839.16, 9840.75, 9849.22, 9850.45, 9853.63, 9854.51, 9858.04, 9860.5, 9875.14, 9877.79, 9877.26, 9880.26, 9880.79, 9883.08, 9888.37, 9890.66, 9894.46, 9896.75, 9908.21, 9910.68, 9916.32, 9917.74, 9938.69, 9941.16, 9942.57, 9944.33, 9944.51, 9946.45, 9945.74, 9947.86, 9950.57, 9952.16, 10009.7, 10011.5, 10014.9, 10017.5, 10023, 10024.2, 10034.1, 10035.1, 10043.7, 10046, 10049.7, 10052, 10059.6, 10063.3, 10067.2, 10069.4, 10109.3, 10111.5, 10113.9, 10115.9, 10140, 10142.8, 10189, 10191.3, 10198.7, 10199.7, 10214.7, 10217.9, 10220.4, 10224.1, 10421.7, 10424.7, 10428.6, 10430.9, DISPLACEMENT 2.99805 4.40918 4.05664 5.4668 1.76367 2.29199 2.11719 3.1748 3.70312 1.58691 1.23438 0.881836 2.46875 2.64551 2.99805 2.29297 2.29297 2.29199 2.46973 1.41113 2.46875 1.76367 1.93945 2.11621 1.58789 1.76367 2.64551 1.23438 1.05859 2.29297 2.29199 3.7041 2.29297 2.11621 1.93945 2.82129 2.29297 1.05859 3.17383 3.70312 2.99805 2.29199 Page 2 • 10431.9, 10433.7, 10436.1, 10438.3, 10438.8, 10440.6, 10440.4, 10442.5, 10443.4, 10445.8, 10475.2, 10476, 10501.4, 10502.3, 10510.4, 10513.9, 10515.7, 10516.2, 10589.9, 10591.8, 10592.2, 10593.4, 10593.2, 10595, 10594.3, 10596.6, 10630.2, 10633.6, 10633.6, 10636.9, 10641.7, 10644.7, 10716.7, 10718.5, 10722, 10724.5, 10731.5, 10733.8, 10782.1, 10784, 10787.2, 10789, 10790.6, 10792.2, 10803.3, 10804.7, 10806.6, 10808, 10814.7, 10816.5, 10823.6, 10825.7, 10934.9, 10935.4, 10956.7, 10957.1, 11017.7, 11018, 11033.4, 11032, 11038.3, 11038.5, 11049.9, 11049.3, 11059.2, 11057.6, 11063.6, 11063.3, 11067.3, 11066.4, 11076.3, 11077.2, 11080.9, 11079.9, 11091.2, 11091.9, 11102.4, 11102.6, 11110.2, 11112, 11188.4, 11191, 11506, 11503.3, 11815.4, 11816.3, 11914.9, 11918.5, 11937.9, 11941..4, EOZ END ! BASE CURVE: GROH, Tape Subfile: 1 Minimum record length: Maximum record length: *~~~ FILE HEADER ~`**~` MWD .001 1024 tapescan.txt 1.76367 2.11719 1.76367 2.11621 2.46875 0.881836 0.881836 3.52734 0.529297 1.94043 1.23438 1.76367 2.29297 3.35156 3.35059 2.99805 1.76367 2.46973 2.29199 1.93945 1.76367 1.58789 1.41016 1.41113 1.76367 2.11621 0.529297 0.353516 0.352539 -1.41113 0.175781 -0.529297 -1.58789 -0.352539 -0.881836 0.881836 -1.05859 0.706055 0.175781 1.76367 2.64551 -2.64551 0.881836 3.52734 3.52734 OFFSET CURVE: GRAX 162 records... 10 bytes 132 bytes ~~~ LIS COMMENT RECORD ~** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth shifted to a PDCL from schlumberger GR CNL dated 14 Apr 2009 per Doug Stoner with Page 3 BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) tapescan.txt Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) Optical Lod Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM Total Data Records: 135 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 -----24 Tape File Start Depth = 9643.000000 Tape File End Depth = 12063.500000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet ~~** FILE TRAILER **** Tape Subfile: 2 148 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **~~ FILE HEADER '~'~** MWD .001 1024 *'~~ LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) optical Log Depth Scale Units: Feet Page 4 tapescan.txt Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub-ty pe is: 1 FRAME SPACE _ 0. 250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 269 Tape File Start Depth = 9640.000000 Tape File End Depth = 12060.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 282 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 09/04/12 2539510 O1 **** REEL TRAILER **** MWD 09/07/01 BHI O1 Tape Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Page 5 ~ ~ tapescan.txt 0 Tape subfile 1 is type: LIS - 0 Tape subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9643.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9643.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9700.0000 42.6945 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9800.0000 31.8097 -999.2500 1508.9131 2.6962 2000.0000 2000.0000 9900.0000 25.5942 52.6837 62.2548 74.2400 136.8304 258.2180 10000.0000 39.5818 70.4628 146.1353 288.0535 288.4580 576.8130 10100.0000 75.1598 96.8201 81.5327 232.1563 203.0020 346.4700 10200.0000 67.6623 127.9160 85.1134 207.2660 195.4015 329.2342 10300.0000 72.1204 144.0000 94.1832 209.2681 189.6802 314.0180 10400.0000 70.3867 105.9755 77.5249 202.0014 194.5448 369.8127 10500.0000 63.1171 109.7809 100.5337 145.2164 203.0020 365.0933 10600.0000 32.2767 173.9043 51.5309 93.6439 190.4572 689.8209 10700.0000 39.1188 144.0000 63.3530 127.7531 239.0040 849.5470 10800.0000 31.7611 151.0920 48.7401 89.4845 146.9170 347.3310 10900.0000 31.1802 150.6481 53.6842 108.8373 188.9900 527.3285 11000.0000 57.8828 125.6394 31.8160 67.6407 98.6809 264.1740 11100.0000 181.8311 132.9892 30.8093 81.9665 163.8200 2000.0000 11200.0000 63.6637 158.5682 66.4132 190.6808 188.9900 386.8660 11300.0000 68.9988 142.9504 68.5576 216.5544 203.2790 347.3310 11400.0000 57.7295 123.6464 50.4845 131.1853 122.5180 216.2953 Page 6 tapescan.txt 11500.0000 69.5367 138.7809 63.6062 155.6780 270.8725 11600.0000 79.8295 114.6062 67.2395 176.4930 314.7330 11700.0000 74.6592 124.8000 67.3288 184.1575 347.3310 11800.0000 88.4424 144.6336 82.8422 188.9900 314.7330 11900.0000 57.7871 147.8088 46.6755 114.1390 198.1590 12000.0000 56.3000 154.9000 62.3520 139.0410 244.1960 12063.5000 -999.2500 133.7000 -999.2500 -999.2500 -999.2500 Tape File start De th = 9643.000000 Tape File End Depth = 12063.500000 Tape File revel Spacing = 0.500000 Tape File Depth Units = feet D Tape subfile 3 is type: LIS DEPTH GR ROP RPD RPS 9640.0000 -999.2500 -999.2500 -999.2500 -999.2500 9640.2500 -999.2500 -999.2500 -999.2500 -999.2500 9700.0000 34.8000 -999.2500 -999.2500 -999.2500 9800.0000 40.3000 -999.2500 39270.0000 314.0180 9900.0000 25.3000 59.0000 155.5130 286.7980 10000.0000 44.4000 70.8000 288.4580 576.8130 10100.0000 79.0000 97.8000 203.0020 346.4700 10200.0000 77.1000 125.3000 114.0480 165.6090 10300.0000 66.3000 119.3000 203.0020 314.0180 10400.0000 70.2000 106.1000 188.7490 363.6810 10500.0000 71.4000 111.4000 203.0020 385.8100 10600.0000 29.6000 124.4000 176.4930 497.8530 10700.0000 40.5000 145.5000 239.0040 849.5470 Page 7 RAD -999.2500 -999.2500 -999.2500 1.8900 67.5370 140.9490 86.1520 86.1520 94.3090 80.4340 96.8030 51.9710 64.2250 122.9639 172.6797 176.5836 189.6413 101.3074 121.4130 -999.2500 RAS -999.2500 -999.2500 -999.2500 12.1880 91.5360 259.6680 202.7670 132.0020 200.5350 256.9760 148.7630 99.6700 171.1150 tapescan.txt 10800.0000 31.1000 254.4000 47.2240 146.9170 347.3310 10900.0000 32.2000 147.9000 54.7600 197.0010 579.0840 11000.0000 56.5000 131.5000 31.1680 98.3760 264.1740 11100.0000 183.5000 135.3000 30.9640 150.9830 53821.6953 11200.0000 62.6000 123.1000 71.2770 203.2790 386.8660 11300.0000 69.2000 141.3000 73.3350 203.2790 347.3310 11400.0000 51.6000 120.1000 52.7880 116.9960 196.4540 11500.0000 66.5000 138.1000 69.4090 155.6780 275.7880 11600.0000 80.3000 114.6000 71.2770 176.4930 314.7330 11700.0000 77.2000 124.8000 65.8350 176.4930 347.3310 11800.0000 90.9000 159.0000 80.4400 188.9900 314.7330 11900.0000 58.6000 147.2000 44.7010 109.1690 198.1590 12000.0000 58.5000 141.9000 61.2620 139.0410 244.1960 12060.0000 -999.2500 133.7000 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9640.000000 Tape File End Depth = 12060.000000 Tape File revel Spacing = 0.250000 Tape File Depth Units = feet D Tape Subfile 4 is type: LIS 85.9190 94.6970 65.6000 81.7380 174.4580 218.3580 169.5790 176.3600 218.3580 151.1850 167.9120 101.6990 121.9020 -999.2500 Page 8