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209-139
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 03-37 PRUDHOE BAY UNIT 03-37 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/12/2024 03-37 50-029-23421-00-00 209-139-0 W SPT 8470 2091390 2118 1751 1752 1748 1746 258 448 438 434 4YRTST P Sully Sullivan 11/6/2023 Operator tested to 2485 for 500 psi diff using 110deg diesel 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 03-37 Inspection Date: Tubing OA Packer Depth 550 2485 2448 2445IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS231108130640 BBL Pumped:1.4 BBL Returned:1.3 Friday, January 12, 2024 Page 1 of 1 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Monday, November 25, 2019 3:03 PM To: AK, GWO Well Integrity Engineer, AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; G GPB FS2 Drillsites; Summers, Matthew; Wallace, Chris D (CED) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHI LLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (CED); AK, GWO Well Integrity Well Information Subject: OPERABLE: Injector 03-37 (PTD #2091390) TxIA communication mitigated with rig work over All, Injector 03-37 (PTD #2091390) was made under evaluation on 10/28/2019 in order to monitor for TxIA communication post rig work over. The well was brought on MI injection 10/28/19 and has shown no signs of inner annulus pressurization during the 28 day UE period. At this time the well is reclassified as Operable. A request to cancel the administrative approval 4E.039 will be submitted to the AOGCC within the coming week. Plan Forward/ Completed work: 1. Operations— Place on MI Injection —Done 10/28/19 2. DHD —AOGCC MIT -IA once on stable injection —Passed 11/2/2019 3. DHD— Monitor IA pressure 4. Well Integrity Engineer— Progress AA cancelation Please respond if in conflict, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 21 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill D Perforate New Pool ❑ Repair -Well 0 Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to DO Number: 209-139 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service RI 6API Number: 50-029-23421-00-00 7 Property Designation (Lease Number): ADL 028328 & 028331 8. Well Name and Number: PBU 03-37 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 10740 feet Plugs measured None feet true vertical 9301 feet Junk measured None feet Effective Depth: measured 10650 feet Packer measured 9529, 9717 feet true vertical 9223 feet Packer true vertical 8332.8470 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 30-110 30-110 1530 520 Surface 3524 9-5/8" 29-3553 29-3389 5750 3090 Intermediate 9966 7" 29 26-9992 26-8678 8160 7020 Production Liner 905 4-1/2" 9833-10738 8557-9299 8430 7500 Perforation Depth: Measured depth: 10155 -10330 feet True vertical depth: 8805-8950 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 9635-9845 8409-8566 Packers and SSSV (type, measured and 4-1/2" HES TNT Perm Packer 9529 8332 true vertical depth) 4-1/2' HES TNT Perm Packer 9717 8470 4-1/2" HES MCX 2194 2124 12. Stimulation or cement squeeze summary: RECEIVED Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 1 NOV NOV 3 2U019 1 J 13. Representative Daily Average Production or Injection Da Oil -B01 Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 12727 555 1700 Subsequent to operation: 12270 674 3067 14. Attachments: Iregmrsd per 20 MC 25.o7o.2do71, &25,283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service RI Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG RI GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-168 Authorized Name: Lastufka, Joseph N Contact Name: Hyatt, Trevor Authorized Title: S Specialist Contact Email: Trevoc1-1yatt0bp.com Authorized Signature: Date: 11 ?. Contact Phone: +1 907 564 4627 Form 10-404 Revised 04/2017 4 007 P / r N 19� 9BDMSL�NOV 14 2019 Submit Original Only Daily Report of Well Operations PBU 03-37 T/I/O = 1500/450/250 TEMP = 105* PPPOT-T Eval TxIA (PASS) PPPOT-IC Eva[ IAxOA comm (PASS) PPPOT-T: Stung into test void 200 psi on THA, bled to 0 psi. Monitored for 15 min, no change in pressure. R/U test equipment Pump though test void good returns. Pressure test void to 5,000 psi for 30 min test. Lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bleed THA to 0 psi. PPPOT-IC: Stung into test void 100 psi, bled IC void to 0 psi. Monitored for 10 min. No 3/25/2019 change in pressure. Pump though test void, good returns of fluid. Pressure test void to 3,500 T/I/O= 999/191/5 Temp=Sl (Assist SLB SL) Pumped 160 bb[s 180*f DSL down TBG to assit 5/16/2019 with brush and flush. ***WSR coninued on 05-17-2019*** ***WELL INJECTING UPON ARRIVAL*** (rwo expense) LRS FREEZE PROTECTED INJECTON LINE B&F W/ 3.80" GAUGE RING, 4 1/2" BRUSH TO XN NIPPLE @ 9,832' MD (160bbls diesel) SET 4 1/2" PXN PLUG @ 9,822' SLM / 9,832' MD 5/16/2019 ***CONT WSR ON 5/17/19*** T/I/O= 1900/500/300. Assist Slickline. Freeze protect tbg and f[owline. Pumped 2 bbls 60/40, followed by 40 bbls crude down tbg for freeze protection. Pumped 7 bbls 60/40 down 5/16/2019 flow[ine freeze protection. Slickline getting on well at LRS departure. FWHP=1100/232/12 ***WSR Continued from 05-16-2019*** CMIT-TxIA PASSED to 4050/4147 psi ***PASSED***, Max Applied Pressure=4250 Target Pressure=4000 psi. Pressured TAA to 4250/4227 psi with 5.44 bb[s DSL. CMIT-TxIA lost 23/19 psi in 1st 15 minutes and 18/16 psi in 2nd 15 minutes for a total of 41/35 psi during 30 minute test. Bled back 6.5 bbls DSL MIT -OA PASSED to 1205 psi, Max Applied Pressure=1250 Target Pressure=1100 psi. Pressured OA to 1250 psi with 1.41 bbls DSL. MIT -OA lost 26 psi in 1 st 15 minutes and 19 psi in 2nd 15 minutes for a total of 45 psi during 30 minute test. Bled back 1bbl DSL. Notify SL WSL. Hung tags on WV,IA,OA. AFE sign hung on MV ***FLUID PACKED WELL*** 5/17/2019 Valve PositinM V, WV, SSV closed MV open CV's OTG. FWHP=630/118/5 *** CONT FROM 5/16/19 WSR *** (rwo expense) LRS PERFORMED PASSING CMIT-TxIA TO 4050/4147psi (see log) LRS PERFORMED PASSING MIT -OA TO 1205psi (see Irs log) 5/17/2019 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** T/I/O = SSV/50/0 TEMP = SI, Function LDS Pre Rig (PASS) Tubing Head: Stung into test void 150 psi on void, bled to 0 psi. Monitored for 15 min, no change in pressure. Function all LDS, all moved freely. Torque all LDS to 450 ft/lbs. R/D bleeder tools. 6/10/2019 Casing Head: Stung into test void 0 psi on void. Monitored for 10 min, no change in TWO = LOTO/100/0. Temp = SI. IA & OA FL (Pre MIT). IA FL @ 90'(1.6 bbls). OA FL @ near surface. 6/29/2019 SV, WV, SSV = LOTO. MV = O. IA, OA = OTG. 20:00 Daily Report of Well Operations PBU 03-37 ***WELL SHUT IN ON ARRIVAL*** SLB E -LINE UNIT #2362 MIRU, PERFORM PASSING PT RIH W/ FX 1.56" SMALL CHARGE TUBING PUNCHER. PUNCH TUBING FROM 9624'-9629'. RIH W/ POLLARD 4.5" MCR RCT CUT TUBING @ 9636'. CORRELATED TO 4.5" TUBING TALLY 15 -FEB -2010. RIG DOWN SLB E -LINE UNIT 7/10/2019 ***JOB COMPLETE, WELL LEFT S/I*** T/1/0=504/43/3 temp=Sl LRS unit 46 CMIT-TxIA/ Circ out (RWO EXPENSE) CMIT-T/IA PASSED to 4146/4153 psi (TEST #7) Max Applied Pressure =4250 psi Target Pressure=4000 psi. Pressured T/IA to 4185/4191 psi with 6 bbls DSL. CMIT-T/IA lost 20/20 psi in the 1st 15 minutes and 19/18 psi in the 2nd 15 minutes for a total loss of 39/38 psi during a 30 minute test. Bled T/IA to 142/148 psi recovering - 5 bbls. Pumped a total of 13 bbls crude down T/IA in attempt to do CMIT-T/IA (SEE LOG FOR DETAILS) Circ'd out TxIA to OTT with 5 bbls 50/50 followed by 462 bbls FW followed by 82 bbls DSL to FP TxIA. U - Tube TxIA for 1 HR. Pad -Op notified of well status upon LRS departure. Tags hung. 7/13/2019 SV/SSVNW=C MV=O CV's=OTG. HLV's=C Tags Hung. FWHP's 142/144/8 T/I/O = 200/150/0 Pre AAO -111 Set 4" "H" TWC #294 @100", LTT TWC (PASS), R/U Temp Valve #40 as dryhole SV. PT Dryhole tree against TWC 350 psi (PASS) 5000 psi (PASS), Pull TWC #294, Rig down lubricator, PT Tree cap to 4000 psi (PASS), Install Integrals on working IA and OA with block valve and tee. PT IA 350 psi (PASS) 3500 psi (PASS), PT OA 8/17/2019 350 psi (PASS) 3500 psi (PASS). RDMO Final T/1/0 100/150/0. ***Job Complete*** See T/1/O = 110/110/Vac. Temp = SI. Bleed WHP's to 0 psi (pulling unit). IA FL @ surface. Dry hole tree installed hardline block valves installed on IA/OA. Bled TP/IAP to BT to 0 psi in 30 min (.75 bbl). Monitored for 30 min. TP/IAP unchanged. Final WHPs = 0/0/Vac. 8/28/2019 SV = C. MV = O. IA, OA = OTG. 10:30. T/I/0 = 10/10/0. Temp = SI. WHPs (post bleed). Dry hole tree installed. Integral with block valve & Tee installed on IA & OA. TP &IAP increased 10 psi and OAP went off a Vac since 08/28/09. 9/3/2019 SV = C. MV = O. IA, OA = OTG. 19:30 INITIAL T/I/0= 200/200/0 SET 4" HP-BPV #HP4-3 PRE ALL AMERICAN PULLING UNIT. RU LUB AND PT TO 350/3500 (PASS). RD, SET HP-BPV @ 85" THRU DRY -HOLE. LTT PLUG (PASS). RD LUB, INSTALL TREE CAP. PT TO 500 (PASS). RDMO, ***JOB 10/4/2019 COMPLETE***. SEE LOG FOR DETAILS Final T/I/O = BPV/200/0 Release off V-227 @ 09:00 hrs 10/7/2019 / PJSM with Rig Crews on rigging down. Move flow back and U/R tanks and stage. Move pulling unit support equipment, V -Door and 10/7/2019 catwalk, Prep Sub to move off well. Continue moving support modules to DS -3. Spot sub base and rig down all lines. Remove upper dog house, fuel and water tanks. PJSM with Rig Crews and Peak Operators. Remove 10/8/2019 carrier from sub. T/I/O = BPV/130/0. Temp = SI. Bleed WHPs (Pre Pulling Unit). Dry hole tree installed. Integrals w/ block valve and Tee installed on IA & OA. IA FL @ surface, OA FL @ near surface. Bled IAP from 130 psi to 0 psi in 6 min (0.13 bbls). Monitored for 30 min. WHPs unchanged. Final WHPs = BPV/0/0. 10/8/2019 SV = C. MV = O. IA, OA = OTG. 09:45 Continue rig move. Prep carrier and sub base to take to Bell's weighing station. Complete removing Sub and remaining equipment off trailer. Move trailer to PBOC scale Trailer w/ Ponies weighed 190k Lbs. No permit required. Continue moving equipment to DS 3. Pre - lifting Risk Assesment. Move sub base and carrier to DS -3. PJSM with Rig and Crane 10/9/2019 Crews on picking sub base components. Daily Report of Well Operations PBU 03-37 Continue rigging up on DS3-37. Set sub base modules with cranes. Rig up carrier and stand up derrick. Set wind walls and roof sections. Stand BOP's behind rig. Spot sub over well and 10/10/2019 level. Set in suport module Lower Equipment Room Continue to rig up on DS3-37 - Set Support modules - Boiler, Generator, Trip Tank, Koomey and Catwalk -Beaver Slide. Test gas monitoring alarm system. Test BPV 300/3,500 psi. 10/11/2019 Nipple down dry hole tree. Inspect tubing hanger and install test dart, Nipple up BOP. Complete nipple up BOP, Choke, Kill and koomey control lines. WS test hardline to 4200 psi. Rig up test equipment. Test BOP per plan. Test witness waived by Matt Herrera. Pull blanking plug and BPV. Rig up and displace diesel with 9.8 brine. Make up landing joint Accept Pulling Unit @ 21:00 Hrs 10/12/2019 Make up hanger and confirm make up. Pull tubing free at 140K. String weight 100k up. Lay down hanger and safety joint. Level the derrick. POOH laying down 4.5" tubing. Well control 10/13/2019 drill. Lay down stub and per joint. R/U and run 4.5" VT tubing per program. Continue running 4.5" VT 12.6# tubing Per plan. Monitor well with trip tank. Well Control Drill while tripping (with safety joint) Checked all equipment for NORM and all hauled off (pipe to cold storage and hanger to TS).MU hanger and land tbg, no spaceout pups required. Unique overshot no-go 4' above stub (stub @ 9637' AAO RKB) and mule shoe @ 10/14/2019 9647'. Set TWC and test. Flush out trip tank and choke line and valves. Clear rig floor of tubing equipment. Hard line crew rig down choke hoses and lines. R/U and suck out stack. ND BOPE, NU and test tree. Release pulling unit @ 1500 hrs. Move URs 10/15/2019 and fluid to DS 9. RD. T/I/O = TWC/0/0. Post AAO Tree conversion. Remove 4" Temp #40. Install Original 4" Upper production tree with Baker actuator and torque to API specs. Torque MV x THA to API specs. RU CIW lubricator and PT to 350/5000psi (PASS) Run down and pull TWC at 130". RD lubricator and install Tree cap PT to 500psi (PASS) Remove OA integrol flange and install 2" Tapped blind flange. Torque to API specs and PT to 2500psi (PASS) RDMO 10/16/2019 ***Job Complete*** SEE LOG FOR DETAILS Final T/I/O = 0/0/0. MV = Open SSV/WV/SV T/I/0= 0/5/0 (LRS Unit 46: Circ Out 9.8 ppg brine, Set Packer) Pumped the following down the IA, taking returns up the Tubing to Open Top Tank: 2 bbls of 60/40 and 171 bbls of 2% KCL. ***Clean returns taken to OTT 73098*** 10/16/2019 ***WSR Continued on 10/17/2019*** ***WSR Continued from 10/16/2019*** (LRS Unit 46 - Circ Out 9.8 ppg Brine, Set Packer) Continue to pump the following down the IA, taking returns up the Tubing to Open Top Tank: Pumped 167 bbls of 110* Inhibited 2% KCL, followed by 1 bbls of 60/40 spacer, and an additional 82 bbls of 90* Diesel for a TxIA U -Tube freeze protect _****Drop Ball & Rod*** MIT -T ***PASSED*** to 4129 psi (2nd attempt) Max Applied Pressure= 4250 psi Target Pressure= 4000 psi. Pressured TBG to 4167 psi with 1.86 bbls of diesel to test and set packer. MIT -T lost 20 psi in the first 15 minutes and 18 psi in the 2nd 15 minutes for a total loss of 38 psi during a 30 min test.Bled TBG to 1500 psi recovering — 1.5 bbls. MIT -IA **PASSED** to 4179 psi. Max applied 4250 psi/Target = 4000 psi. Pumped 3.6 bbls dsl into IA to reach test pressure. 15 min IA lost 45 psi. 30 min IA lost 17 psi. Total loss of 62 psi in 30 mins. Bleed tbg and IA back to 0/5 psi. Bled back 4 bbls. **AFE sign in place on arrival** / **Fluid packed tags hung on IAV/MV** 10/17/2019 FWHP= 0/5/0. ****WELL S/I UPON ARRIVAL**** (RWO Expense) PULLED BALL & ROD FROM RHC -M @ 9,560' SLIM (9,562' MD) 10/23/2019 ****CONT JOB ON 10/24/19**** Daily Report of Well Operations PBU 03-37 T/I/O = VacNac/1. Temp = SI. AOGCC MIT - IA PASSED to 2711 psi, Max Pressure = 2750 psi, Target Pressure = 2500. AOGCC state witness waved. IA FL @ surface. Used 1.8 bbis of DSL to pressure up IAP from a Vac to 2751 psi. IAP lost 33 psi in the 1 st 15 minutes & 7 psi in the 2nd 15 minutes for a total loss of 40 psi in 30 minutes. Bled IAP to 0 psi (1.7 bbls). Hung tags & AFE sign. Used 5.2 bbis of DSL to freeze protect PWI flowline. 10/23/2019 Final WHPs = 0/0/0. ****CONT. JOB FROM 10/23/19**** (IRWO expense) PULLED 4-1/2" RHC -M PLUG BODY FROM 9,563' SLM / 9,562' MD RAN 3.60" BELL GUIDE, 2-1/2" JDC, S/D @ 9,816' SLM (Unable to latch p -prong) RAN 10'x 3" PUMP BAILER TO 9,818' SLM (3 cups thick schmoo, Metal marks) 10/24/2019 ***CONT ON 10-25-19 WSR*** ***CONT FROM 10-24-19 WSR***(rwo) PULLED 4 1/2" PXN PLUG BODY FROM 9832' MD. (SCHMOO INSIDE, HYDRATES OUTSIDE). BRUSHED SVLN AT 2179' SLM WITH 3.80" G -RING, 4 1/2" BL -BRUSH. SET 4-1/2" MCX ISSSV(BPX-473) IN SVLN @ 2194' MD.(tools hung up while pooh) LRS FREEZE PROTECTED TBG W/ 50 BBLS OF HOT CRUDE. 10/25/2019 ICONFIRMED GOOD SET W/ 4-1/2" CHECK SET.(sheared) = CNV HFAD= FAK'. A(:IUAILJK= 13AK[=KU KB. E LLV = 55.6' BF. E LEV = 29.87' KOP= 366' Max Angle = 50° @ 8999' 20"X34" CORD— DatumMD= 10216' 215.5#, A-53, Datum ND= 8800'SS D= 1 9-5/8" CSG, 40#, L -8o RTC, ID = 8E35° 3553 - Minimum ID = 2.36" @ 10021' 9 CHROME SNAP LATCH 412' MG, 12.6#, l3CR46 VA M TOP 9632' .0152 bpt, ID = 3.958" TBG CUTw/RCT wflo19) 9836' 4 -12 -TBG, 12.6#, L-80 TCl/, 9845' .0152 bpf, ID = 3.958" 7" PERFORATION SIRAMRY tiff LOG: SLB MJVD ON 01/28/10 ANGLEATTOPP32F:40" @ 10008' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3(8" 6 10008- 10033 C 02!11111 3-318" 6 10155-10170 O 02111/11 3-3/8' 6 10178 - 10188 O 02/11/11 3-3/8" 6 10198- 10223 O 02/10/11 3-3/8" 6 10236 - 10256 O 02/10/11 33/8" 6 10256 - 10276 O 02110/11 3318" 6 10306 - 10316 O 04/24/10 3318" 6 10320 - 10330 O 0424/10 lPBTD 10650' - 4-112" LNR, 12.6#, L-80 TCH, .0152 bpf, ID = 3.958' 10738' SAFETY NOTES: H2S READINGS AVERAGE 125 WHEN ON Mi. WELL REQUIRES 03-217 Min* CHROME NIPPLES & TBG*K A SSSV ON 594' 9-5/8' TAM PORT COLLAR 2194' 4-12" HES X NP (9 -CR), D = 3.813' 9502' 9529' T X 4-12' HES TNT PKR, D 33.88" 9562' 4-12' HES X NP (9-0R), D = 3.813" 9647' -tTX4-12'UNIQUE OVERSHOT 9691'4-12' HES X NP (9 -CR), D = 3.813° 02119110 NSES 971T TX4-12'HESTNTPKR,D=3.8� 10/15/19 AAO -111 9759'4-12" HES X NP (9 -CR), D = 3.813" 10/29/19 MH/JMD 983T744 -11T HES XN NP (9 -CR), D = 3.7'e 1 10124' 1 DATE REV BY COMMENTS DATE REV BY I COMMENTS 02119110 NSES ORIGINAL COMPLETION 10/15/19 AAO -111 INTERVENTIONS RWO 10/29/19 MH/JMD PULLED PXN PLUG 1025/19 X 5" 4-M" ALE G, D = 3.958" 7" X 5" HMC LNR HGR D = c1x. 1:61f'b11L0(i-:7 aE = 2.38" PRUDHOE BAY UNIT WELL '73-37 PERMITNo: #2091390 API No: 50-029-23421-00 TI ON, RI 5E, 1424' FSL & 115 BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday, November 8, 2019 �p� P.I. Supervisor l l F�/I'j I t SUBJECT: Mechanical Integrity Tests 11 i I BP Exploration (Alaska) Inc. 03-37 FROM: Guy Cook PRUDHOE BAY UNIT 03-37 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 03-37 API Well Number 50-029-23421-00-00 Inspector Name: Guy cook Permit Number: 209-139-0 Inspection Date: 11/2/2019 - IDSp Num: mitGDC191102134128 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 03-37 Type Inj G TVD 8470 -Tubing 2961 2954 2968" 2981 " PTD 2091390 Type Test sPT Test psi 2118 IA 895 2760 2723 - 2724 " BBL Pumped: 9 BBL Returned: 13 OA 445 636 639 - 640 ' Interval OTHER PIF P Notes: Post rig MIT -IA. Job performed with a triplex pump, bleed trailer and calibrated gauges. s�(n� Nil -IGS C h, Y`j rCFt!-i'YCt�_c� Friday, November 8, 2019 Page 1 of 1 Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Monday, October 28, 2019 7:34 AM To: AK, GWO Well Integrity Engineer Cc: AK, GWO Well Integrity Well Information Subject: RE: WAG Injector 03-37 (PTD #2091390) Permission to bring on MI injection post RWO Joshua, The plan described below is approved. I may suggest you wait to submit the cancellation request until after the 10-404 is received by AOGCC. With the 10-404, the MITIA, and a longer duration stabilized TIO, the cancellation request can be evaluated with more confidence. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7" Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallacePalaska.eov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or ch(is.wallace@alaska.gov. From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, October 27, 2019 2:34 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Subject: WAG Injector 03-37 (PTD #2091390) Permission to bring on MI injection post RWO Hi Chris, WAG Injector 03-37 currently has an AA (4E.039) for slow TAA on MI and has been restricted to water service only. The well was worked over on 10/15/2019 under sundry #319-168 and passed a witnessed waved MIT -IA to 2711psi on 10/23/19. The final reconnect is currently being wrapped up and the well is planed to go online in the next couple of days. BPXA is requesting permission to place the well on MI injection immediately with the intention of submitting an AA cancelation later this week. Please let me know if you need any further information to make a decision, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, October 28, 2019 9:14 AM To: AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr, AKOpsProdEOCTL, G GPB FS2 Drillsites; Summers, Matthew, Wallace, Chris D (CED) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, lames B (CED) Subject: UNDER EVALUATION: Injector 03-37 (PTD #2091390) Permission to bring on MI injection post RWO All, WAG Injector 03-37 (PTD #2091390) recently underwent a rig work over to mitigate TxIA communication on MI injection. The well was previously operated as a water only injector under AOGCC administrative approval AID 4E.039. The AOGCC has granted permission to bring the well on MI injection post RWO in order to monitor for IA repressurization. At this time the well is reclassified as Under Evaluation and permitted to bring on MI injection. Plan Forward: 1. Operations — Place on MI Injection 2. DHD—AOGCC MIT -IA once on stable injection 3. DHD— MonitorIApressure 4. Well Integrity Engineer— Progress AA cancelation Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, July 11, 2019 2:58 PM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, G GPB FS2 Drillsites; Rupert, C. Ryan; Summers, Matthew Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A, Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R, Tempel, Joshua;.Worthington, Aras 1 Subject: NOT OPERABLE: Injector 03-37 (PTD #2091390) tubing cut prior to rig work over All, Injector 03-37 (PTD #2091390) is currently being prepared for a tubing swap. On 07/10/19 Eline performed a tubing cut which means the well no longer has primary barrier integrity. The well is now classified as NOT OPERABLE until the primary barrier has been restored. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 03-37 Permit to Drill Number: 209-139 Sundry Number: 319-168 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a o g c c. a l a s k a. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / �^ Je sie L. Chmielowski Commissioner DATED this 12 -day of April, 2019. RBDMSi��/APR 16 200 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 HECEIVED APR 0 3 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 OpQ¢(�a Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change AppYdOcrtl g Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 209-139 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 0 • 6. API Number: 50-029-23421-00-00 . 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 03-37 , 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028328 8 028331 PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ff): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10740 930110650 9223 • 2470 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" x 34" 30-110 30-110 Surface 3524 9-5/8" 29-3553 29-3388 5750 3090 Intermediate 9 1 7" 26-9992 26-8678 8160 7020 Production Liner 905 1 4-1/2" 9833-10738 8557-9299 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD III): 1 10155- 10330 8805 - 8950 4-1/2" 128# 24-9845 Packers and SSSV Type: 4-1/T HES TNT Perm Packer Packers and SSSV MD (it) and TVD (ft): 9717/8470 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ StraBgraphic ❑ Development ❑ Service 0 , 14. Estimated Date for Commencing Operations: April 15. 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 0 • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hyatt, Trevor be deviated from without prior written approval. Contact Email: Trevor.HyaO@bp.com Authorized Name: Mdaughlin, Sean M Contact Phone: +1907 564 4627 Authorized Title: Engineering Team Lead - CTD Authorized Signature: Date: 3 20i 9 .7t71rM �#11, ! COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number ,r' 01 ^{J' ' �b Plug Integrity ❑ Test Mechanical Integrity Test Location Clearance ❑ pSOP Other:GJs��t' iJc3QE1'�L3r�ZP 3Es}�S) lv`.,riv'ersaD ro 2.�0 Post Initial Injection MIT Req'd? Yes No ❑J/ yo-r�w.Ct•{v 2DAQGZS`���ol�-�PcDVed).. Spacing Exception Required? Yes 11No ld Subsequent Form Required: /D —.Vo y APPROVED BYTHE I Approved by: COMMISSIONER COMMISSION Date: D RBM1 APR 16 2019 ORIGINAL y �: �✓�t2•a�l/ Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attach ents in Duplicate Af 0 s! =s0 To: Alaska Oil & Gas Conservation Commission by From: Trevor Hyatt RWO/CTD Engineer AV11L 0+0 Date: April 2, 2019 Re: 03-37i Sundry Approval Sundry approval is requested to perform a tubing swap on 03-37i. - History and current status: 03-37i was drilled in early 2010 to be a grass roots central injector for the 03-07 pattern with a 4 1/2" monobore completion from Jan 21 -Feb 17th, 2010. The well has been providing PWI central injection supporting wells 03-02, 03-19, 03-21, 03-08, 03-34B, 17-11, 17-14, and 17-07B since then. 03-37i was initially perforated in a short interval (10306'-10316', 10320'-10330') that showed hydrocarbon on the OH Log & was put on Mt to try and mobilize this oil. Shortly after POI in 2010 the well began to demonstrate TxIA to gas while on MI with a BUR of 100-1500 psi/day (passing MITs). Due to this an AA was requested and granted on 9/6/2011. In 2011 03-37i was switched to PWI & additional perforations were shot in Feb 2011 due to low injectivity. In 2014 Brightwater was pumped as a Reservoir Sweep Modifier & had minimal effect on injectivity. After this a Baker patch was set in 2015 across Sag perforations (shot 2011) to isolate the Sag & Inject solely into Z4 of the Ivishak. As part of the pattern rotation program several new wells have been drilled in the area of 03-37i and are accessing Z4 including 03-21A & 17-11 B with more wells being planned for 2019. Due to this it is once again increasingly appealing to put 03-37i on MI. Due to the IA BUR of -150 psi/day in 03-37 with MI an AA based on the new acceptable BUR guidelines cannot be requested. A RWO is considered the most feasible option to obtain EOR value from this well. Scope of Work: The primary objective of this RWO is to replace the 4-1/2" tubing, with a passing MIT -IA, and place the well on MI without IA pressure buildup. The MASP for the Ivishak is 2470 psi. Pre -Pulling Unit Prep Work: 1. PPPOT-T and IC to 5,OOOpsi and 3,500psi function all LDS 2. Set PXN plug @ 9,832' MD 3. CMIT-TxIA to 4,OOOpsi 4. RCT Tubing 5. Post cut combo, circ out and freeze protect 6. Prep tree and TWC Proposed RWO Procedure: 1. MIRU A�C 2. NU BOPE and test— Zy �,,,+r ns '� ♦ d r 3. Pull tubing 4. Dress off if necessary 5. Run new 4-1/2" L-80 VamTop tubing with stacker packer 6. ND BOPE, NU Tree Post rig Work 1. Circ in inhibited fluid and FP 2. Drop ball -n -rod, set packer, 3. Pull ball -n -rod, RHC, PXN Trevor Hyatt ROW/CTD Engineer 564-4627 CC: Well File Joe Lastufka MIT -T and MIT-IA--,Zrt 7 - Jr TREF= C1w WELLHEAD= FMC ACTUATOR= BAKERC KB. E_B/ = 55.6' BF. R = 29.87' KOP= 366' Max Angle = 50' Q 8999' Datum MO= 10216' Datum ND= 8800'SS 7 SAFETY NOTES: H2S READINGS AVERAGE 125 03-3 • ppmML *** HROM NPPLESWHEN ON IREQUIRES A SSSV ON 20-X�� 110' 215.5#, A-53, 594' 9-5/8' TAM PORE COLLAR D= ti I LL 9993' 4-1/T HF3 X NP l9_CR1 n= I9-5/8' CSG, 40#. L-80 BTC. D = 8.835' 1- 3553' Minimum ID = 2.36" @ 10021' 9 CHROME SNAP LATCH /2" LNR, 12.6#, L-80 TCR 52 bpf, D = 3.958' PERFORATION SUMMARY REFLOG: SLB MND ON 01/28/10 ANGLE AT TOP PERF: 40" @ 10008' Note: Refer to Production DB for historical perf data SIZE SPF MERVAL OPNSgz DATE 3-3/8' 6 10008-10033 C 02/11/11 3-3/8' 6 10155- 10170 O 02/11/11 3-3/8' 6 10178- 10188 O 02/11/11 3-3/8' 6 10198- 10223 O 02/10/11 3-3/8' 6 10236- 10256 O 02/10/11 3-3/8' 6 10256- 10276 O 02/10111 3-3/8' 6 10306 - 10316 O 0424/10 3-3/8' 6 10320 - 10330 O 0424/10 L PBTD 12.6#, L-80 TCR .0152 bpf, D = 3.958' 9691' 1-14-1/2- HES X NIP (9 -CR), D = 3.813- 4-1/2- HES X NP (9 -CR), D = 3.813' 14-12' HES XN NP (9 -CR), D = 3.725' I 9833' 117' X 5- HRD-E ZXPN LTP w /11.08' X 5.25' D TEBK II 9845' 4-12' WLEG, D=3.958' 9856' 7- X 5- HMC LNR HGR ID )6' - 10021BKR 45 FLO GUA RD PATCH, D = 2.36- 10124- 114-1/2' MARKER JT DATE REV BY COMMENTS DATE REV BY COMMENTS 02/19/10 N9ES ORIGINAL COMPLETION 02/11/11 M3/JMO ADDED SSSV SAFETY NOTE 01/10/12 TM WJMO ADDED H2S SAFETY NOTE 07/31/15 JCANJMD SET LOWER PATCH (06/07115) 07/31/15 MGS/JMD SET UPPER PATCH (07/01/15) 04/03/19 JNJJIvD ADDED BF & COPD INFO ✓`1 PRUDHOE BAY LUT VVELL: T03-37 R3iMT No: '`2091390 ARM 50-029-23421-00 T1 ON, RI 5E, 1424' FSL & 115' FA SP Exploration (Alaska) TREE= CNJ WELLHEAD= FMC ACTUATOR= aAKHRC KB. ELEV = 55.6' BE. ELEV = 26.6' KOP= 366' Max Angle = 50" @ 8999' Datum MD= 10216' Datum TVD= 8800' SS I9-5/8" CSG, 40#, L-80 BTG, D = 8.835' I 3553' Minimum ID = 2.36" @ 10021' 9 CHROME SNAP LATCH 4.5" 12.6# 13Cr VamTop Tubing - Unique Overshot - 9641' PXN Plug LHR 126#, L-80 TCI, bpf, D = 3.958" PERFORATION SUMMARY REFLOG: SLB MWD ON 01/28/10 ANGLE AT TOP PEZF:40'@ 10008' Note: Refer to Production DB for historical pert data SIZE SPF MERVAL OpNSgz DATE 3-3/8" 6 10008-10033 C 02/11/11 3-3/8" 6 10155 - 10170 O 02/11111 3-3/8" 6 10178 - 10188 O 02/11111 33/8" 6 10198 - 10223 O 02/10111 33/8" 6 10236 - 10256 O 02/10/11 33/8" 6 10256 - 10276 O 02/10/11 3318" 6 10306 - 10316 O 0424/10 33/8" 6 10320 - 10330 O 0424/10 LNR 12.6#, L-80 Tat .0152 bpf, D = 3.958' I -- i 0736' _/S 7 SAFETY NOTES: 1-12S READINGS AVERAGE 125 O v �� ■ ML **WHEN ON i. WELL REQUIRES A SSS V ON X NIP - ID=3.813" X NIP - ID=3.813" 7 x 4-1/2 13Cr HES TNT Packer - 9565' X NIP - ID=3.813" ® 9691' —j4-V2"HESXNP(9-CFQ,D=3.813" 9717' 7"x4 -v2" HES TNr PKR, ID=3.BW 9759' 4-1/-HESXNP(9-CFq,ID=3.813" 9832' 4-112' FES XN NP (9 -CR), 9833' 7' X 5" HRD-E ZXPN LTP w /11.08' X 525" D T)'EBK 9845' 4-1/2' WLEG, D=3.958' 9856' 1-17- X 5" FMC LNR HGR D = 4.430- I 10124' I DATE REV BY COMMENTS DATE REV BY ODM E?frS 02119/10 N9ES ORIGINAL COMPLETION 02/11/11 M8/J11VD ADD®SSSV SAFETY NOTE 01110/12 TMTYJMD ADDED H2S SAFETY NOTE 07/31/15 JCWJMD SET LOWER PATCH (06107115) 07/31/15 MGS/JMD SEr LPPER PATCH (07101/15) BKR 45 FLO GUARD PATG-t D = 2.36' (7/1115) 1 PRUCHOE BAY FNIT WELL 10337 PERMIT No- 12091390 AR No: 50.029-23421-00 SEE 10, T10K R15E, 1424' FSL & 115 FEL BP Exploration (Alaska) 1 2 3 4 4'-2" o G D G A A T-815/16" SHENKAI SL 13-5M ANNULAR 8'-103/15" SHENKAI SL 13-5M DOUBLE RAM B B 9'-17/16,, 4'"8t 1� Sn V-41/16" 3'-25/" 5-1/2' C 1--93 /4 o 010 o C. 0(@0 o o 10'-4" 1'1 -4/2' 00 G D ZMINPEN GIG 5'-31/2" CLOSING / OPENNING VOLUME (GAL) ITEMS CLOSING VOL OPENNING VOL 30° ANNULAR 23.59 17.41 RAM 4.39 3.91 O D HCR 0.40 0.40 THE CONTENTS OF THIS ORAWING PROJECT BDP TITLE NOTES: INFORMATION IN THIS ARETHEPROPERTYOFKESTERN ENERGY SERVICES CORP. ANY E�AERO 13-5M BOP STACK D'�NO DRANANG IS FOR REPRODUCTION OF THIS ADDU-15-002 OW1NN TY MTE 28/FBb/2D78 ' N.T.S. K£IDHT REV REFERENCE ONLY AND IS NOT FOR DRAWNO WITHOUT THE EXPRESS PERMISSIONOFVIESTERN 'n ^'I^ar"^T° 0 INITIALRELEASE TY MJP Ot/Mer¢OtS APPROVED DATE SIZE SHEET O CONSTRUCTION. ENERGYSERVICESCORPIS REV DESCRIPTION BY M"DATE STRICTLY PROHIBITED. MdP 01/Mar/2015 A 1 OF1 1 1 3 4 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: gg DATE: Wednesday,August 16,2017 Jim Re P.I.Supervisor � y "t ZI(I 7 SUBJECT: Mechanical Integrity Tests 1�'( BP EXPLORATION(ALASKA)INC. 03-37 FROM: Bob Noble PRUDHOE BAY UNIT 03-37 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 03-37 API Well Number 50-029-23421-00-00 Inspector Name: Bob Noble Permit Number: 209-139-0 Inspection Date: 8/15/2017 Insp Num: mitRCN170815141205 Rd Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 03-37 - Type Inj W TVD 8470 Tubing 1755 , 1754 1736 1735 - PTD 2091390 Type Test SPT Test psi 2400 - IA 72 2400 - 2363 2355 • BBL Pumped: 2.5 BBL Returned: 2,1 OA 368 • 583 - 570 - 563 Interval REQVAR P/F P v Notes: AA 4E.039 for T x IA communication on MI to 1.2 times max injection pressure of 1700 psi. SCANNED 2 , Wednesday,August 16,2017 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,August 2, 2017 2:49 PM To: Wallace, Chris D (DOA) Cc: AK, GWO SUPT Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Well Integrity Well Information Subject: Injector 03-37 (PTD#2091390) operating under AA 4E.039 will miss MIT anniversary date Mr.Wallace, Injector 03-37 (PTD#2091390)operates under AIO 4E.039 for water only injection due to TxIA communication when on MI. The well was scheduled for its 2 year AOGCC witnessed MIT-IA today but was canceled due to being taken off line after an unexpected shut down at flow station 3. The anniversary date for the AA is 08/02/11 and the test was due 08/02/17 (last AOGCC MIT-IA 7/11/15). The plan forward is to reschedule the test after the well is back on stable injection;the current estimate is approximately a week. Please respond if this is not permissible or if any further work/information is needed before returning the well to injection with a lapsed test date. Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 ANNE® �;r P ()H i,' .M••.weds r.•'r+•••• 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM )N REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 .— Plug for Rednll 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 7 mob+n 7 eff 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 209-139 3 Address: P O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service El 6 API Number: 50-029-23421-00-00 7 Property Designation(Lease Number): ADL 0028331 8. Well Name and Number: PBU 03-37 9 Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 10740 feet Plugs measured None feet true vertical 9301 feet Junk measured None feet )I 1 I c L r 2J 1 Effective Depth: measured 10650 feet Packer measured 9716 61,9844.38 feet true vertical 9223 feet Packer true vertical 8469.8.8566.02 feet A.G C C Casing: Length: Size MD: TVD. Burst: Collapse. Structural Conductor 80 20"91.1#H-40 29-109 29-109 1530 520 Surface 3524 9-5/8"40#L-80 29-3553 29-3388 5750 3090 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 905 4-1/2"12.6#L-80 9833-10738 8557-9299 8430 7500 Perforation Depth: Measured depth: 10008-10033 feet 10155-10170 feet 1 01 78-1 01 88 feet 10198 10223 feet 10236-10256 feet 10256-10276 10306-10316 feet 10320-10330 feet True vertical depth: 8690-8709 feet 8805-8817 feet 8824-8832 feet 8841-8861 feet 8872-8888 feet 8888-8905 8930-8938 feet 8942-8950 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 23-9844 23-8566 Packers and SSSV(type,measured and 4-1/2"HES TNT 9716 61 8469.8 true vertical depth) 5"zxP LTP 9844 38 8566.02 12 Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation. 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25 070 25 071,a 25 283) 15.Well Class after work: Daily Report of Well Operations I3 Exploratory 0 Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16 Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG Il GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C.O.Exempt: 315-248 Contact Summerhays,Nita M(i IPRO Technologies) Email Nita.Summerhays@bp.com Printed Name /Summerhays ita (WIPRO TechnologieJ/ Title Petrotechnical Data Manager Si.•:,t•L%/ , i "' `'TL R�2 !11111111111,,r— Phone +1 907-564-4035 Date 07/31/2015 Form 10-404 Revised 5/2015 /� Sutomit OnginaiOnly ,,i( 'V�f-- RBDMS AUG 1 4 2015 Daily Report of Well Operations PBU 03-37 ACTIVITYDATE SUMMARY ***WELL FLOWING ON ARRIVAL***(profile mod) ATTEMPT TO DRIFT W/30'45KB PACKER DRIFT, UNABLE TO PASS 4200'SLM DELAY-JOB SCOPE CHANGE 6/4/2015 ***WSR CONTINUED ON 06/05/15*** T/I/0=400/82/0 Assist SL(Profile Mod) FP FL to lateral with 5 bbls neat. FP s-riser to wing with 1 6/4/2015 bbl neat. Rig up to lubricator. (continued on 6-5-15) (continued from 6-4-15) Pump 5 bbl neat spear followed by 160 bbls SBG mix and 5 bbls neat soak for 3 hrs Pump123 bbls 1% kcl flush and 2 bbls meth. let soak for 5 hrs.while SL made a drift run. Pumped 40 bbls diesel down tubing to freeze protect. Final WHP-800/70/0 FP tags 6/5/2015 hung, SSL rigging down on departure. ***WSR CONTINUED FROM 06/04/15***(profile mod) LRS LOAD TBG W/ 157bbls SCHMOO-B-GONE(soak 3 hrs) LRS PUMP 125bbls KCL FOR TBG OVERFLUSH(soak 3 hrs) BRUSH & DRIFT W/4-1/2" BLB& 3.25" GAUGE RING, CLEAR DRIFT TO 10100' SLM DRIFT TO 10,200' SLM W/30'x3.70"45 KB PACKER DRIFT 6/5/2015 ***WELL LEFT S/I UPON DEPARTURE*** ***WELL SHUT IN ON ARRIVAL*** (SLB E-LINE SET LOWER PACKER) INITIAL T/I/O=500/0/0 RIH W/4-1/2" BAKER LOWER FLO-GUARD PACKER TOOLSTRING. SIT DOWN AT 2940. PULL 600 LBS OVER TO GET FREE. WORK TOOL&ABLE TO GET PAST SET LWR PKR @ 10038' MID ELEMENT(TOP @ 10021') (LWR PKR SPECS=21.79'OAL/3.70" MAX OD/2.45" MIN ID) TIED INTO SLB JEWELRY LOG DATED 24-APR-2010 ****SL TO SET UPPER SECTION OF PATCH AT LATER DATE**** FINIAL T/I/O=400/0/0 WELL LEFT SHUT IN UPON DEPARTURE- NOTIFIED PAD OP OF WELL STATUS 6/7/2015 ***JOB COMPLETE*** ***WELL S/I ON ARRIVAL SWCP 4521***(tbg patch/liner) RAN 3.70"CENT TO 9,997' SLM. RAN 3.7"CENT, 3.5" LIB, TO 9,996' SLM (10,021' MD) IMPRESSION OF LOWER PATCH SNAP LATCH. RAN 30' 3.7" PATCH DRIFT TO 9,997' SLM SET UPPER BAKER PATCH W/SNAP LATCH (oal-18.78', min id of 2.36")TOP© 10,005' MD. SET LTTP @ 9980'SLM. 7/1/2015 ***CONTINUE WSR TO 7/2/15*** T/I/0=97/85/vac Temp= SI Assist Slickline(Set TBG patch) Pumped 5 bbls of 60/40 methanol to reach test pressure of 1000 psi. First 15 minutes TBG lost 12 psi, Second 15 minutes TBG lost 7 psi, for a total of 19 psi. Bled back—5 bbls SLB SL in control of well upon LRS departure. Job complete 7/2/2015 FWHP= 160/90/0 ***CONTINUE WSR FROM 7/1/15 SWCP 4521***(tbg patch/liner) SET LTTP @ 9980'SLM&GET PASSING TEST. PULL LTTP FROM 9980' SLM. 7/2/2015 ***WELL LEFT S/I ON DEPARTURE*** Fluids Summary Bbls Type 18 METH 42 _DIESEL 160 SBG MIX 123 1% KCL 343 Total a) 0 N 0 N - N O0 O O O O N- to C M to I,- 1.0 Is• I,- N- C.) ML COD COD M M • L.0N- N ' N m IC) C— CO I- CO CO CO 0OD co O M LO N- N 0 CD co co to CD N 1.0 M CO CO CO CD CO I I I I I I I N N- O) CD CO O M CO 10 M N N N M to to to N CO CO CO CO O CO N 0 tto O N N 0)) CD M co co CA O lA O O t C.) Ci CO i i i i i i i Q M CO C) CO O N COCO V CS) M a) Q7 N N N C'') N- N N N C CL O O O O co CJ J J J CD co N �$ *k O CO N ,± *k4t4t NN /� N N N N V - O - N CA 4 NIt C 0▪ 00 L CD N CD O CO lU CO CA O C1) J W W W W Q Q Q c� 0000 U w w w w w o• rou_ ce cc ce cc w Z ZQwwwwwm 0 u) Z Z Z Z J 1_ TREE= CAN ' S IY NOTES:H2S READINGS AVERAGE 125 • 1/1413_LI-EAD= FMC 7 ppm WHEN ON MI.WELL REQUIRES A SSSV ON ACTUATOR= BAKER C03-3MI. ***CHROME NIPPLES*** KB.ELEV= 55.6' - BF.R FV= zss' J I KOP= 366' Max Angle= 50'@-11(469; 20"CONDUCTOR H 60' Datum MD= 10216' 594' 1—9-5/8"TAM PORT COLLAR Datum TVD= 8800'SS ' 2223' H4-12"HES X NP(9-CR),D=3.813' 9-5/8'CSG,40#,L-80 BTC,D=8.835" H 3663' HA , Minimum ID =2.36" @ 10021' 9 CHROME SNAP LATCH • ' 9691' H4-12'I$X rip(9-CR),D=3.813' 9717' Hr X 4-l/2'HES TNT PKR D=3.88" ' 9769' I--I4-12-HES X NP(9-CFt),D=3.813' ' 9832' —14-1/2"HES XN M'(9-CR),D=3.725" 9833' Hr X 5'HRD-E ZXPN LTP w/11.08'X 5.25'0 T1 BK l 4-1/2"LMR, 126#,L-80 TCR H 9645' .0152 bpf,D=3.958' / \ 9646' H4-1/2"WLEG,D=3.958" 7"CSG,29#,L-80 VAM TOP,D=6.184' H 9997 9866' Hr X 5-FMC LNR I-$GR,0=4.430' PERFORATION SUMMARY REF LOG: SLB NAND ON 0128/10 10006'-10021' —1BKR 45 FLO GUARD PATCH,D=2.36'(7/1/15) ANGLE AT TOP PERF:40'42 10008' Note:Refer to Production DB for historical perf data ' S¢E SPF MBZVAL C n/Sgz BATE 3-3/8" 6 . 10008-10033 C 02/11/11 10124' --14-12'MARKER JT 3-3/8' 6 10155-10170 0 02/11/11 I 3-3/8" 6 10178-10188 0 02/11/11 t 3-3/8' 6 10198-10223 0 02/10/11 ' 3-3/8' 6 10236-10256 0 02/10/11 3-3/8' 6 10256-10276 O 02/10/11 ' 3-3/8' 6 10306-10316 O 04/24/10 ' 3-3/8' 6 10320-10330 0 04/24/10 I PBTD —1 10650" 0•.�1�.11111 I4-12"LMR,12.6#,L-80 TCR.0152 bpf,D=3.958" H 10738' DATE REV BY COMuEN S �l DATE REV BY COMNB�ITS PRUDHOE BAY INT 02119/10 NOES ORIGINAL COMPLETION WELL:113-37 02/11/11 1.43/JM) ADDED SSSV SAFETY NOTE FERMfT No:'2091390 01/10/12 TMJWJMD ADD®1-25 SAFETY NOTE API No: 50-029-23421-00 07/31/15 JCM/JMD SET LO? PATCH(06/07/15) SEC 10,T10N,R15E,1424'FSL&115'FEL 07/31/15 MSS/JAM SET UFVE t PATCH(07/01/15) BP etploratbn(Alaska) • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,July 14,2015 TO: Jim Regg@@`` P.I.Supervisor L, l ) z-/iS SUBJECT: Mechanical Integrity Tests t BP EXPLORATION(ALASKA)INC 03-37 FROM: Chuck Scheve PRUDHOE BAY UNIT 03-37 Petroleum Inspector %JA�� " ) a Src: Inspector Reviewed By: P.I.Supry 33e--- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 03-37 API Well Number 50-029-23421-00-00 Inspector Name: Chuck Scheve Permit Number: 209-139-0 Inspection Date: 7/11/2015 Insp Num: mitCS150712055108 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 03:37 -,Type Inj W'TVD r 8470 - Tubing[ 1429 - 1486 ' 1475 - 1410 - -a PTD 2091390 Type Test SPT Test psi 2118 - IA 1 391 2629 - 2604 " 2590 - Interval REQVAR P/F P '- OA t 234 454 ' 451 - I 449 - Notes: Tested per AA - AJo 4E,t 361 Tuesday,July 14,2015 Page 1 of 1 of Tye e THE STATE Alaska Oil and Gas ofLASKA. Conservation Commission ; wi__AF333 West Seventh Avenue F GOVERNOR BILL WALKER Anchorage, Alaska k909509 3572 1 e' 572 Arfri Main. oF ALAS" Fax: 907 276 7542 www aogcc.alaska.gov Ralph Sinnok d9 .... ,3 /9 Production Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-37 Sundry Number: 315-248 Dear Mr. Sinnok: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ;6(.4 Cathy . Foerster Chair DATED this 7- day of May, 2015 Encl. SEAMED M/- ' 4 201.; RECEIVED • STATE OF ALASKA APR 2 3 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION Ors' S I¢`/S APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug PerforationsE • Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casmg❑ Other. ,Sep t 2.Operator Name. 4 Current Well Class: 5.Permit to Drill Number: BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 209-139-0 • 3.Address: Stratigraphic ❑ Service E 6.API Number: P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23421-00-00 • 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU 03-37 . Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10 Field/Pool(s): ADL0028331 P PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured). 10740 . 9301 • 10650 9223 ' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.1#H-40 29.04-109.04 29.04-109.04 Surface 3524 9-5/8"40#L-80 28.54-3552.88 28.54-3388.31 5750 3090 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 905 4-1/2"12.6#L-80 9832.61 -10737 54 8557.14-9298.72 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/7 12.6#L-80 L-80 23.46-9844.13 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program (] BOP Sketch ❑ Exploratory ❑ Development ❑ Service [ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 0 ' GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ralph Sinnok Email Ralph.Sinnok@BP.Com Printed Name Ralph Sinnok Title Production Engineer Signature �' - Phone 564-4630 Date Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3%5- 2'-E Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No El Subsequent Form Required: `Q -4a 1f // APPROVED BY Approved by: 2ila (r�� COMMISSIONER THE COMMISSION Dater_4,_/," rft30115-- se\> 2..el/S- Form 10-403 Revised 10/2012 0 RAtre is 'o is valid for 12 months from the date of approval. Submit Form and Attachments in D licate I RBDMS3 MAY - 6 2015 `r/ • 0 0 0 0 0 0 0 0 a) V 0o 00 co 0o 00 00 00 • I J J J J J J J a) • N 2.7. O CV N O O) O — p Ln LO N- N- N- CO N- 0 0 0 0 0 0 0 0 0 s- M tt (0 CO co LO M D LO N N •cr N- CO CO CO CO LO CO co co N O) co CO CO a1 LO O f— M O) 00 CO (0 co co LO N co LO CO121 CO CO O) CO CO I- C2 0 N �t N O) CO CO LO O LO O7 CO N LO N LO CO LO N • 0o 00 00 L I- � r E Dcr) ao \ m O 0N0 OM rn 0 LLO 0co U) O Q (ID O) O) c) co O) O O 2 6) O) co CU I— O O CO N O co O) co O Q N I` N CO CO CO N • O O 0) CD O O O V O co co O CO CO = CO CO CO CO J J a) 4 J J J J co �$ N .- *k *k It *k NN (n O CO O) O1 ,— O N N N N _ bo _ O N N N 4 CA 4 .�.. • OO) co Cfl C N N 00 N N- CD LO 00 J O) O co O) W W LU LU H I— H I— < Q Q Q Q F1_0 12101121121 wwww LU caD 222 QCT 0 Q tY CC CC Ctu Z Z w w W w w m O E— F— H D D 0 Z Z Z Z W Perforation Attachment ADL0028331 Well Date Perf Code MD Top MD Base TVD Top TVD Base 03-37 ' 2/11/11 APF 10008 10033 8690 8709 03-37 2/11/11 APF 10155 10170 8805 8817 03-37 - 2/11/11 ' APF 10178 10188 8824 _ 8832 03-37 2/10/11 APF 10198 10223 8841 8861 03-37 2/10/11 APF 10236 10256 8872 8888 03-37 2/10/11 APF 10256 10276 8888 8905 03-37 4/24/10 PER _ 10306 10316 8930 8938 03-37 4/24/10 PER 10320 10330 8942 8950 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028331 Well Facility Type MD Top Description TVD Top 03-37 PACKER 9717 4.5" HES TNT Prod ▪ 8470 03-37 PACKER 9844 5" Baker ZXP Top Packer • 8566 ALASKA WELL AG..✓ITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15) General Information Well Name: 03-37 Well Type: Water Injection Well API Number: 50-029-23421-00 Well Activity Conventional 4 Classification: Activity Description: Isolate Perforations Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE SAG RIVER 12 Month Avg IOR, bopd: Job Type: Mech-Patch Estimated Cost, $K: AWGRS Job Scope: PATCH TUBING/LINER Other regulatory requirements? Sundry Form 10-403 Required? Yes — Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Ralph Sinnok Contact numbers: (907) 564-4630 (907) 304-252 Well Intervention Engineer: Ryan Thompson Contact numbers: (907)301-1240 (907) 564-453 Lead Engineer: Bernhard Stechauner Contact numbers: (907) 564-4594 (907)360-748 Date Created: April 8, 2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injectic Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Cut(%) (Mscf/Day) (psi) 4/7/2015 0 -4 Current Status: Operable Shut In Inclination>70°at Depth (ft) N/A NA 0 Maximum Deviation (Angle and Recent H2S (date, ppm) ppm Depth) 50° 8,999' MD — Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 5° 7,183' MD Reservoir pressure(date, psig) 4/24/2010 3,794 psi Minimum ID and Depth 3.725"@ 9,832' MD;4-1/2"XN-NIP Reservoir Temp, F 156° F Shut-in Wellhead Pressure Vac. Known mech. integrity None. problems(specifics) Last downhole operation (date, operation) 6/9/2014 FB-Brightwater treatment. Most recent TD tag (date,depth, 2/9/2011 10,320' MD 3-3/8"x10' dmy gun &2.50"sample bailer. toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? N/A. Comments,well history, 03-37 was completed in April of 2010 as a central PW injector. The injection rates range between 9,000- background information, 14,000 bwpd and it currently injects into the SAG and Ivishak formation. End of April 2015, 03-15B will be etc: completed in the SAG as a producer which will be in close proximity of where 03-37 is completed in the SAG. The goal of this job is to isolate the SAG perforations in 03-37 to minimize the risk of watering out the 03-15B producer. Objective: set patch over SAG perforations for isolation. Well Intervention Details Suspected Well Problem: SAG injection will water out producer 03-15B perforations. Specific Intervention or Well Objectives: 1 Isolate SAG perforations at 10,008'- 10,033' MD 2 3 Key risks,critical issues: Mitigation plan: 1 2 3 Summary Service Line Activity Step# 1 S Drift for Patch (contingent B&F if unable to make it past -10,050' MD) 2 E Set lower patch 3 S Set top section of patch. Pressure test patch. Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 S Drift for patch with 3.70"x 30' (contingent B&F if unable to make it past-10,050' MD) 2 E Set lower patch section (Element Depth = 10,036' MD)Tie into SLB jewelry log dated 24 April 2010. 3 S Set top section of patch (Top element to set at 10,005' MD) Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: Post job POP instructions: Turn over to pad operator for injection. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: TREE= CAN °° 1 rY NOTES:H2S READINGS AVERAGE 125 WELLHEAD= FMC ACTUATOR BAKER C Q 3-3? ppm WHEN ON MI. WELL REQUIRES A SSSV ON ....._. ML CHROME NIPPLES KB. ELEV= 55.6' — BF. ELEV_ 26.6 KOP= 366' Max Angle= 50"@ 8999' 20"CONDUCTOR 80' Datum MD= 10216' Datum TVD= 8800'SS = 594' H9-5/8"TAM PORT COLLAR ' ' 2223' —14-1/2"HES X NIP(9-CR),ID=3.813" 9-5/8"CSG, 40#,L-80 BTC,ID=8.835" N 3553' I--4 , Minimum ID = 3.725" @ 9832' 4-1/2" HES XN NIPPLE I 9691' —14-1/2"HES X NIP(9-CR),ID=3.813" R x 9717' —17'X 4-1/2"HES TNT PKR,ID=3.88" ' 9759' —14-1/2"HES X NIP(9-CR),ID=3.813" I I 9832' --I4-1/2"HES XN NIP(9-CR), ID=3.725" 9833' 1-17'X 5"HRD-EZXPN LTPw/11.08'X 5.25"ID T1EBK j I 4-1/2"LNR,12.6#, L-80 TGI, H 9845' .0152 bpf,ID=3.958" / ki._ 9845' H4-1/2"WLEG, ID=3.958" 7"CSG,29#,L-80 VA TOP,ID=6.184" — 9992' \ IL 9856' —1T'X 5"I-v1C LNR HGR, ID=4.430" PERFORATION SUMMARY REF LOG: SLB MAOON 01/28/10 ANGLE AT TOP PERF:40" 44 10008' Note: Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10008- 10033 0 02/11/11 10124' -�4-112"MARKER JT 3-3/8" 6 10155-10170 0 02/11/11 ' 3-3/8" 6 10178-10188 0 02/11/11 ' 3-3/8" 6 10198- 10223 0 02/10/11 , 3-3/8" 6 10236- 10256 0 02/10/11 3-3/8" 6 10256- 10276 0 02/10/11 I 3-3/8" 6 10306-10316 0 04/24/10 ' 3-3/8" 6 10320- 10330 0 04/24/10 PBTD H 10650' 111111111i1 4-1/2"LNR,12.6#,L-80 TCII,.0152 bpf, ID=3.958" H 10738' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/19/10 N9ES ORIGINAL COMPLETION 02/11/11 1V113/JIM ADDED SSSV SAFETY NOTE WELL.'b3-37 02/20/10 SV DRLG HO CORRECTIONS 01/10/12 TMC/JM) ADDED H2S SAFETY NOTE PERMIT'No:`2091390 02/23/10 Mt1R/JMD DRLG DRAFT CORRECTIONS(12/20/10) API No, 50-029-23421-00 04/29/10 JGF/PJC PERFORATING(04/24/10) SEC 10,T1ON,R15E,1424'FSL&115'FEL 10/23/10 WEC/PJC SET XXN PLUG(10/07/10) 12/06/10 MI3NYPJC PULLXXN PLUG(12/01/10) BP Exploration (Alaska) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q 1 - 13 Y Well History File Identifier Organizing (done) Two -sided 111111111111111111 ❑ Rescan Needed Hill 111111 III III RES AN DIGITAL DATA OVERSIZED (Scannable) I Color Items: ❑ Diskettes, No. ❑ Ma . /Greyscale Items: Other, No/Type: ➢ VP "C). I Other Items Scannable by a Large Scanner i_pq$ Poor Quality Originals: ( P d OVERS ( - S can na ble) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: 0. /3 /s/ 14 1 1 Project "ect Proofing 1111111111111111111 i BY: Maria Date: 3 /s/ 1 it Scanning Preparation x 30 = 1 a.° + = TOTAL PAGES / c24 (Count does not include cover sheet) I BY: ; - Date: /s/ n Scanning 111111111111111111 Product�o g Stage 1 Page Count from Scanned File: I ct, 7 (Count does include cover sheet) Pa•e Count Matches Number in Scanning Preparation: t/ Y ES NO BY: Date: !3 ,s, f ► t Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 111111111111111111 ReScanned 111111111111111M BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111 1111111 III 12/22/2011 Well History File Cover Page.doc • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,August 29,2013 TO: Jim Regg P.I.Supervisor 2 c It t(Z4 f(3 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 03-37 FROM: Bob Noble PRUDHOE BAY UNIT 03-37 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 03-37 API Well Number 50-029-23421-00-00 Inspector Name: Bob Noble Permit Number: 209-139-0 Inspection Date: 8/26/2013 Insp Num: mitRCN130826132616 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 03-37 Type Inj W ITVD 8470 IA j 640 2506 7 2470 2461 - PTD . 'Type Test SPT Test pst Inte RE VAR 2200 J OA j 390 570 - 563 557 rval l Q ----------I P/F � P Tubing t 1665 1668 �--1665 1645 -d Notes: AA T x IA comm,2 Year MIT-IA n-v - 1, 3`l "�T't®®-qq-1-� g� • SCANNED DE 4_ 2. �j L.. i f �i, p Thursday,August 29,2013 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] Sent: Monday, August 19, 2013 11:19 AM To: AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A;AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; Wallace, Chris D(DOA); Dos Santos, Higino W; Regg, James B(DOA) Cc: AK, D&C Projects Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Injector 03-37(PTD#2091390) Due for AOGCC Compliance MITIA All, Injector 03-37 (PTD#2091390) has been reclassified as Under Evaluation for AOGCC testing as facility maintenance has been completed,and is currently on a 28 day evaluation clock. Thank you, Laurie Climer is Illcrnalc 1a A Disbrow) BP Alaska - Well Integrity Coordinator GW SCANNED r " WIC Office: 907.659.5102 WIC Email: AKDCWelllntegritvCoordinator @BP.com From: AK, D&C Well Integrity Coordinator Sent:Thursday,July 25, 2013 3:14 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; 'chris.wallace @alaska.gov'; Dos Santos, Higino W Cc: AK, D&C Projects Well Integrity Engineer; Parks, Kevin D; 'jim.regg @alaska.gov' Subject: NOT OPERABLE: Injector 03-37 (PTD #2091390) Due for AOGCC Compliance MITIA All, Injector 03-37(PTD#2091390)operates under Administrative Approval 4E.039,and is due for its biannual AOGCC compliance MIT-IA on 08/02/2013. The well is currently shut in and will not be placed on injection prior to the AOGCC MIT-IA anniversary date due to planned facility maintenance. The well is reclassified as Not Operable and will be added to the Quarterly AOGCC Not Operable Injector Report. Plan forward: 1. DHD/Fullbore: Perform Pre-AOGCC MITIA 2. DHD/Fullbore: Perform AOGCC witnessed MITIA once well is injecting and thermally stable Please call with any questions. 1 Thank you, Jack Disbrow BP Alaska-Well Integrity Coordinator GWGlobal Wells Orgarnzatior Office: 907.659.5102 WIC Email:AKDCWellIntegritvCoordinator@bp.com 2 DATA SUBMITTAL COMPLIANCE REPORT 8/10/2012 Permit to Drill 2091390 Well Name /No. PRUDHOE BAY UNIT 03 -37 Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 23421 -00 -00 MD 10740 TVD 9301 Completion Date 4/24/2010 Completion Status WAGIN Current Status WAGIN 41, - REQUIRED INFORMATION Mud Log No Samples No Directional Sury Yes DATA INFORMATION Types Electric or Other Logs Run: DIR / GR, DIR / GR / RES / PWD, NEU / DEN, SCMT / USIT, DIR /GR/ (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr • Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Log 1--- Sonic 5 Col 4851 10733 Case 3/10/2010 Sonic, Cali, GR, MSIP, PPC Rpt — Report: Final Well R 0 10740 Open 4/1/2010 End of Well Rep, Op Overview, Morn Reps ED C Pds 19443 Sonic 4851 10733 Case 3/10/2010 Sonic, Cali, GR, MSIP, PPC Log- Sonic 5 Col 100 9990 Case 3/10/2010 Sonic, Cali, GR, Anal behind Casing, CBL ED C Pds 19444 Sonic 100 9990 Case 3/10/2010 Sonic, Cali, GR, Anal behind Casing, CBL ED--e' 19502 Report: Final Well R 3586 10740 Open 4/1/2010 End of Well Rep, Op Overview, Morn Reps Log C/ Mud Log 1 Col 3586 10739 Open 4/1/2010 MD Gas Ratio ED --C Lis 19522 Induction /Resistivity 317 10739 Open 4/9/2010 OH LIS GR, ROP, FET, • RPM, RAM, DRHO Plus PDS Graphics Log .-- Induction /Resistivity 25 Blu 313 10700 Open 4/6/2010 MD Vision Service Log Induction /Resistivity 25 Blu 261 9245 Open 4/6/2010 TVD Vision Service Log --- Pressure 5 Blu 9950 10395 Case 5/10/2010 SPS, Pres, Temp, GR, CCL ED - ---- C Pds 19638 Pressure 9950 10395 Case 5/10/2010 SPS, Pres, Temp, GR, CCL ED ^ G 0 10740 Open Asc Directional Survey p Rpt .---- Directional Survey 0 10740 Open Log - Injection Profile 5 Blu 9900 10314 Case 5/11/2011 IPROF, Spin, PILS, Temp, Pres 1 ED ' Pds 14613 Injection Profile 9900 10314 Case 5/11/2011 IPROF, Spin, PILS, Temp, Pres DATA SUBMITTAL COMPLIANCE REPORT 8/10/2012 Permit to Drill 2091390 Well Name /No. PRUDHOE BAY UNIT 03 -37 Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 23421 -00 -00 MD 10740 TVD 9301 Completion Date 4/24/2010 Completion Status WAGIN Current Status WAGIN UIC Y Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y N Daily History Received? N Chips Received? — TM - - Formation Tops Y N Analysis N `'t1c r Received? Comments: Compliance Reviewed By: Date: • • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 December 30, 2011 ao 3 7 a3-- 3 7 9F-CPIVED Mr. Tom Maunder Alaska Oil and Gas Conservation Commission JAN fi 6 7017 333 West 7 Avenue 9 Anchorage, Alaska 99501 }leska 011 : tu^ lab •u?tpat15° . GommissIon Subject: Corrosion Inhibitor Treatments of DS -03 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -03 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS-03 10/26/11 Corrosion Initial top of Vol. of cement Final top of Cement top Corrosion inhibitor/ Well Name PTD # API it cement pumped cement off date inhibitor sealant date ft bbls ft gal 03 1750750 50029200930000 Sealed conductor NA NA NA NA NA 03-02 1760240 50029202030000 Sealed conductor NA NA NA NA NA 03-03 1760390 50029202110000 Sealed conductor NA NA NA NA NA 03-04 1760510 50029202180000 Sealed conductor NA NA NA NA NA 03-05 1760570 50029202220000 Sealed conductor NA NA NA NA NA 03-06 1760600 50029202240000 Sealed conductor NA NA NA NA NA 03-07A 2040430 50029202200100 Sealed conductor NA NA NA NA NA 03-08 1760730 50029202310000 Sealed conductor NA NA NA NA NA 03-09 1790220 50029203620000 Sealed conductor NA NA NA NA NA 03-10 1790210 50029203610000 Sealed conductor NA NA NA NA NA 03-11 1790470 50029203830000 Sealed conductor NA NA NA NA NA 03-12 1790580 50029203920000 Sealed conductor NA NA NA NA NA 03-13 1790710 50029203990000 Sealed conductor NA NA NA NA NA 03-14B 2090020 50029204070200 Sealed conductor NA NA NA NA NA 03-15A 1930150 50029204140100 Sealed conductor NA NA NA NA NA 03-16A 1970330 50029204150100 Sealed conductor NA NA NA NA NA 03-17 1791020 50029204200000 Sealed conductor NA NA NA NA NA 03 -18A 1930420 50029204210100 Sealed conductor NA NA NA NA NA 03-19 1830920 50029209710000 0.3 NA 0.3 NA 1.7 7/31/2010 03-20A 1930470 50029209800100 6.2 NA 6.2 NA 40.8 8/2/2010 03-21 1831120 50029209900000 6.6 NA 6.6 NA 49.3 8/3/2010 03-22 1831230 50029210000000 0.0 NA 0 NA 7.7 10/26/2011 03 -23 1831270 50029210040000 >25 21.0 0.8 7/15/2011 5.1 7/18/2011 03-24A 1980060 50029210150100 1.3 NA 1.3 NA 8.5 9/16/2010 03-25A 1930230 50029210210100 >25 12.0 2.25 7/12/2011 13.6 7/17/2011 03-26 1831510 50029210270000 0.2 NA 0.2 NA 0.85 8/2/2010 03-27 1840620 50029211090000 23.5 5.0 0.4 7/12/2011 3.4 7/17/2011 03-28 1840720 50029211140000 55.0 17.0 0.4 7/12/2011 3.4 7/17/2011 03-29 1840790 50029211180000 6.0 NA 6 NA 20.4 8/3/2010 03-30 1840830 50029211220000 4.4 NA 4.4 NA 22.5 8/3/2010 03-31 1840920 50029211290000 10.0 NA 10 NA 113.9 8/3/2010 03-32B 2090050 50029211410200 1.5 NA 1.5 NA 8.5 7/30/2010 03-33B 2050180 50029211420200 7.8 NA 7.8 NA 57.0 7/30/2010 03-34B 2000110 50029211320200 0.2 NA 0.2 NA 9.4 10/26/2011 03-35 1910800 50029221840000 5.8 NA 5.8 NA 39.1 7/28/2010 03-36A 2070200 50029223400100 1.5 NA 1.5 NA 3.4 7/28/2010 . 03-37 2091390 50029234210000 2.5 NA 2.5 NA 16.2 8/2/2010 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, September 09, 2011 TO: Jim Regg i C� 1 - A It P.I. Supervisor ( SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 03 -37 FROM: Bob Noble PRUDHOE BAY UNIT 03 -37 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J6P-- NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 03 - 37 API Well Number: 50 029 - 23421 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110803052903 Permit Number: 209 - 139 - 0 Inspection Date: 8/2/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well; 03 -37 - Type Inj. 1 w ITV ! 8470 LA 1435 1 2508 j 2507 ! 2514 - 1 P.T.Dj 2091390 •TypeTest ! SPT i Test psi I 2117 " OA 1 480 610 1 610 . 1 610 P - T j 1612 _ 1632 1 1610 I 1620 Interval P/F — — Notes: 1 Page 1 of 1 Friday, September 09, 2011 • sirairif o[F ALAsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 4E.039 Mr. Douglas Cismoski, P.E. Wells Intervention Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 RE: PBU 03 -37 (PTD 2091390) Request for Administrative Approval Prudhoe Bay Oil Pool Dear Mr. Cismoski: Pursuant to Rule 9 of Area Injection Order (AIO) 4E.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby GRANTS BP Exploration (Alaska) Inc. (BPXA)'s request for administrative approval to continue water injection in the subject well. BPXA notified the Commission of inner annulus (IA) repressurization affecting PBU 03- 37 while injecting miscible injectant (MI). Diagnostic mechanical integrity testing confirms the well exhibits competent tubing and production casing. Attempts to locate the source of pressure communication using a leak detect log and a tubing caliper survey were unsuccessful. BPXA has elected to perform no corrective action at this time on PBU 03 -37. The Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety, if the well's operation is subject to certain constraints. AOGCC' s administrative approval to continue water injection only in PBU 03 -37 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates, and shall flag the well's periodic pressure bleeds on the report; 3. BPXA shall limit the well's IA pressure to 2000 psi. 4. BPXA shall perform an MIT - IA every 2 years to 1.2 times the maximum anticipated injection pressure; • AIO 4E.039 September 6, 2011 Page 2 of 2 5. BPXA shall immediately notify the AOGCC and shut in the well if there is any continued deterioration in well integrity, indicated by increased inner or outer annulus pressure, increased repressure rate, or increased bleed frequency; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 7. The MIT anniversary date is August 02, 2011. DONE at Anchorage, Alaska and dated Septe P9 - 2011. 0i Daniel T. Sea ount, Jr. J orman Cathy '. Foerster Chair Commis ' : er Comi iissioner 0 OIL AN cc: BPXA Well Integrity Coordinator, PRB -20 P.O. Box 196612 f Anchorage, AK 99519 -6612 p o i �. c (PA, RECONSIDERATION AND APPEAL NOTICE +4L 411ON CO As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of re- consideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Com- mission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by in- action, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on re- consideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on re- consideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the pe- riod; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, August 05, 2011 TO: Jim Regg � / P.I. Supervisor ' ef 6(/1 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 03 -37 FROM: Bob Noble PRUDHOE BAY UNIT 03 -37 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 03 - 37 API Well Number: 50 029 - 23421 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110803052903 Permit Number: 209 - 139 - Inspection Date: 8/2/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 03 -37 ' Type Inj. W - TVD 8470 - IA 1435 2508 , 2507 � 2514 - P.T.D 20913900 TypeTest SPT Test psi L 2117 - OA 480 610 610 _ 610 Interval 4YRTST p/F P ,Tubing 1612 1632 1610 1620 Notes: Friday, August 05, 2011 Page 1 of 1 Clarification on Administrative Approvals Page 1 of / Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Tuesday, May 31, 2011 9:26 PM To: Maunder, Thomas E (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: RE: Clarification on Administrative Approvals - -DS 03 -37 (209 -139) Attachments: Injector 03 -37 (PTD #2091390) TIO and Injection Plot.doc Tom, Here is the TIO and Injection plot you requested for 03 -37 (PTD #2091390). I will begin working on the justification for the AA. Please let me know if I can provide anything further. Thank you, Jerry Murphy BPXA Well Integrity Coordinator From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, May 31, 2011 3:25 PM To: AK, D &C Well Integrity Coordinator Subject: RE: Clarification on Administrative Approvals - -DS 03 - 37 (209 - 139) Torin, Jerry or Mehreen, I owe you all an apology; it appears I did not get a final reply to you all on this well matter. After discussion with Jim, it is our consensus that YES, an Administrative Approval should be secured for the continued operation of this well. If you would, please send a copy of the latest TIO plot. Based on the last TIO information I had seen, it appeared that the well was operating satisfactorily on water. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, April 18, 2011 8:20 AM To: AK, D &C Well Integrity Coordinator Subject: RE: Clarification on Administrative Approvals Torin or Jerry, Did you get a reply on this ?? Tom From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIIIntegrityCoordinator @bp.com] Sent: Thursday, March 31, 2011 11:33 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: AK, D &C Well Integrity Coordinator; Roschinger, Torin T. 8/15/2011 • • Injector 03 -37 (PTD #2091390) TIO Plot 05/31/2011 • Welt 03-37 • 4,000 3,000 - f Tbg — M- 2,000 - OA 00A - -a- 000A 1,000 - •••■■ 03/05/11 03/12/11 03/19/11 03/26/11 04/02/11 04/09/11 04/16/11 04/23/11 04/30/11 05/07/11 05/14/11 05/21/11 05/28/11 Injector 03 -37 (PTD #2091390) Injection Plot Welt 03-37 - 12,000 1.500 - 10,000 F — WHIP - 8,000 0 = 1,000 - PW - 6,000 n MI 4,000 01 500 0 — Other ,,. - 2,000 — On • 03/12/11 03/26/11 04/09/11 04.'23/11 05/07/11 05;21/11 05/06/11 Sctdumberger NO. 5738 Alaska Data 8. Consulting Services Company: State of Alaska 2525 GambeII Street, Suite 400 Alaska Oil 8. Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 8 Log Description Date BL Color CD P2 -16 BBSK -00061 USIT /9,, — 1a3 04/04/11 1 1 1- 35/0.25 BBKA -00101 PRODUCTION PROFILE / fife / (� 04/04/11 1 1 P2 -52 BJGT -00027 CROSS FLOW CHECK 1 �'} ° S4 04/14/11 1 C! r 1 03 -37 BJGT -00028 INJECTION PROFILE (j [„, 13C) 04/16/11 1 (.. / 1 2.42/P -13 BAUJ -00076 MEM LDL / /II-- / .s �] 04/15/11 1 jj � 1 N -11C BH4H -00048 PRODUCTION PROFILE (-./ --/ v- 04/19111 1 , Elf "Y(� 1 ID 02 -12C BD88 -00098 MEM CBL ,. / I " d 04/21/11 /C.("(o /Cj 1 1 S -120 BD88 -00100 MEM INJECTION PROFILE - 1 - 0 �, -.(Qb,- 04/25/11 1 �(®( , 1 P1 -09 BJOH -00024 PRODUCTION PROFILE `QL — / , 05/01/11 1 144'0 ' 1 P1 -09 BJOH -00024 SCMT Oa, , --1 g 5/02 0/11 (pd� 1 1 fir P243 _ BG4H -00049 SCMT 465 — /76(-f 04/28/11 I 4 1(01 . 5 — 1 1 16 -21 BJGT -00030 - PRODUCTION PROFILE /75 �S ` ;,t 04/28/11 1 7<'(a /., 1 *'t',_ n 09 -26 BD88 -00104 MEM LDL S 3 ? 04/30111 1 j ( 1 04 -33A BLPO -00095 MEM PRODUCTION PROFIL �OGj,- ("3'{f- 04/30/11 1 / 1! 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 e. .. . . .. , . „. . ... .. . , , . , , . . . r :, ,,,, , . . . i , - Monthly Injection Report for GPB•MA, Northstar, Milne Point & Endicl,,for March ... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Sunday, April 03, 2011 8:00 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Engel, Harry R Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for March 2011 Attachments: AOGCC Inj Report 04- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the March 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 04- 11.zip» Notes on wells: Added to Report: 03 -37: Added to evaluate TxIA communication while on water injection. The Well Integrity Coordinator will apply for an administrative approval pending IA repressurization. Taken off Report: AGI -05: Taken off report after slickline changed out the SSSV on 3/8/11 that mitigated the IA repressurization. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 4/18/2011 Well 03 -37 Injection Plot TxIA o Pressure vs. Rate O TIO Plot MIT IA P comm while MI 09 20/10 0 - ---- ----- ._.- -- - - -- ° N N Tbg • • w IA Will pursue an AA for PWI only • o • • • • o o n pending IA repressurization. 0 0 LO CO 0 o d o 0 a o a ° ° o 0 0 u, • • Last 90 days • Last Month o t • • , o 0 2,000 4,000 6,000 8,000 10,000 12,000 14,000 9/8/10 11/29/10 2/19/11 5/12/11 Injection Rate, MCFPD • Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 04/01/11 12,336 1,816 04/01/11 1,788 1,200 250 03/31/11 12,500 1,816 03/31/11 1,814 1,200 250 03/30/11 12,450 1,800 03/30/11 1,777 1,200 250 03/29/11 12,701 1,801 03/29/11 1,805 1,200 250 03/28/11 12,835 1,798 03/28/11 1,803 1,200 300 03/27/11 13,032 1,799 03/27/11 1,814 1,200 300 03/26/11 13,092 1,793 03/25/11 1,739 1,200 300 03/25/11 13,087 1,780 03/23/11 1,787 1,220 380 03/24/11 13,161 1,789 03/21/11 1,787 1,020 320 03/23/11 12,955 1,803 03/20/11 1,787 800 160 03/22/11 12,595 1,763 03/19/11 1,787 800 160 03/21/11 11,350 1,683 03/18/11 1,787 860 160 03/20/11 10,122 1,615 03/17/11 1,787 860 160 03/19/11 10,686 1,664 03/16/11 1,787 1,000 260 03/18/11 10,612 1,666 03/15/11 1,787 920 220 03/17/11 10,674 1,660 03/14/11 1,787 800 180 03/16/11 9,946 1,621 03/13/11 1,787 800 180 IF 03/15/11 10,058 1,652 03/12/11 1,787 890 220 03/14/11 10,024 1,647 03/11/11 1,787 890 220 03/13/11 9,181 1,638 03/10/11 1,787 800 200 03/12/11 9,398 1,691 03/09/11 1,675 700 200 03/11/11 9,715 1,753 03/08/11 1,690 700 150 03/10/11 8,961 1,744 03/07/11 1,500 600 200 03/09/11 7,295 1,673 03/06/11 1,500 750 200 03/08/11 6,293 1,678 03/05/11 1,500 750 200 03/07/11 3,322 1,716 03/04/11 1,500 700 150 03/06/11 6,700 1,811 03/03/11 1,500 700 150 03/05/11 6,400 1,786 03/02/11 1,500 700 200 03/04/11 6,000 1,763 03/01/11 1,500 700 200 03/03/11 6,200 1,791 02/27/11 1,500 690 200 03/02/11 6,000 1,842 02/23/11 1,500 500 10 1Q2011 Not Operable Injectorrt Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, April 03, 2011 7:30 AM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 1Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 1Q2011.zip Tom, Jim, Phoebe and Guy, Attached is the 10 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 1Q2011.zip» Notes on wells: Removed from Quarterly Injection Report: 03 -37: TxIA comm. when on MI. Well placed on production to eval TxIA comm. while on water injection. NGI -14: RWO repaired TxIAxOA comm. on 01/05/11 U -04A: Startinghead leak mitigated with Furmanite wrap on 02/12/11 Added to Quarterly Injection Report: S -101: MIT -IA failed on 03/01/11. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 II I 4/17/2011 Clarification on Administrative Approvals Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Thursday, March 31, 2011 11:33 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: AK, D &C Well Integrity Coordinator; Roschinger, Torin T. Subject: Clarification on Administrative Approvals Attachments: 03 -37 TIO & Injection Plot 03- 31- 11.doc Jim/Tom, Injector 03 -37 (PTD # 2091390) is a WAG injector with known TxIA communication while on MI. However, when on water injection the well does not exhibit the communication. I would like to get clarification as to whether an Administrative Approval is required if the well will remain on water injection only. I have provided a TIO plot and injection plot for your reference. «03 -37 TIO & Injection Plot 03- 31- 11.doc» Thank you for your time. Torin Roschinger Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 8/15/2011 • • 03 -37 (PTD# 2091390) 03/31/2011 TIO Plot Wet 03-37 4.000 -,- r. 3.000 �. —0— Tbg --O— IA 2. 000 —4.--- OA •.-"•• OOA OnOA — On 1,000 I I t A _ iffitiiiiiii _ _ 09/25/10 10/09/10 10/23/10 11/06/10 11/20/10 12/04/10 12/10/10 01/01/11 01)15/00 _ 01/29/11 02/12/11 02/26/11 03/12/11 03/26/11 Injection Plot We! 03-37 3,400 r„) 3.200 3,000 - - 12,000 • . - - 11 -000 • 2,600 -. - 10,000 • 2,400 - - .. - 9.aaa 2,200 - - 2.000 - :8.000 p SW a 1,800 - - 7,000 ° — pW 3 — M1 1.600 - - 6,000 r — GI 1 400 - ° — OUro1 — On 1.200 - 1.000 - _ a,000 800 - -3.000 • 600 400 • .2,000 200 - • 09/25/10 10/09/10 10/23/10 11/06/10 11/20/10 12/04/10 12/18/10 01/01/11 01/15/11 01/29/11 02/12/11 02/26/11 03/12/11 03 /26/11 1 • • • FW: OPERABLE: Injector 03•(PTD #2091390) Tubing Integrity Coed on PWI I... Page 1 of 3 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator @bp.com] Sent: Sunday, March 20, 2011 12:31 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Huebel, Ross Cc: AK, D &C Well Integrity Coordinator Subject: FW: OPERABLE: Injector 03 -37 (PTD #2091390) Tubing Integrity Confirmed on PWI Injection - MIT -IA Date Correction Attachments: Injector 03 -37 (PTD #2091390) TIO and Injection Plot.doc All, To correct a misstatement; the passing MIT -IA date was 10/16/2010, not 10/16/2011. Gerald Murphy BPXA Well Integrity Coordinator From: AK, D &C Well Integrity Coordinator Sent: Sunday, March 20, 2011 11:11 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; Schwartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Huebel, Ross Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Winslow, Jack L (ASRC) Subject: OPERABLE: Injector 03 -37 (PTD #2091390) Tubing Integrity Confirmed on PWI Injection All, WAG injector 03 -37 (PTD #2091390) began produced water injection on 03/01/2011 and has exhibited no TxIA communication during that time. With the passing MIT -IA on 10/16/2011, the well has two competent barriers to fluid. The well has been reclassified as Operable and may remain on injection while an Administrative Approval for PWI only is pursued. A copy of the TIO plot and injection plot are included for review. «Injector 03 -37 (PTD #2091390) TIO and Injection Plot.doc» Please call if you have questions. Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 4/18/2011 FW: OPERABLE: Injector 03•(PTD #2091390) Tubing Integrity Coed on PWI I... Page 2 of 3 From: AK, D &C Well Integrity Coordinator Sent: Monday, February 21, 2011 1:53 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Huebel, Ross Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Winslow, Jack L (ASRC) Subject: UNDER EVALUATION: Injector 03 -37 (PTD #2091390) Begin Injection On PWI to Evaluate for AA for PWI only All, WAG injector 03 -37 (PTD #2091390) was completed in February 2010. During the first injection cycle of M -I in June, 2010, the well exhibit slow TxIA communication. The well passed an MIT -IA to 4000 psi on 10/16/2010 indicating the presence of two competent barriers to fluid. The well is being placed on injection to evaluate if an AA should be pursued for PWI only. The well is reclassified as Under Evaluation. Plan forward: 1. WIE: Monitor wellhead pressures for communication for 14 days after well reachs temperature stabilization 2. WIC: Pursue AA for PWI if appropriate Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, October 08, 2010 1:56 PM To: 'Regg, James B (DOA)'; Schwartz, Guy (DOA)'; 'Maunder, Thomas E (DOA)'; 'Brooks, Phoebe L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, OPS FS2 Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB East Production Optimization Engineer; AK, OPS PCC EOC TL Cc: Janowski, Carrie; Sinyangwe, Nathan; AK, D &C Well Integrity Coordinator Subject: NOT OPERABLE: Injector 03 -37 (PTD #2091390) Secured with a downhole plug All, Injector 03 -37 (PTD #2091390) was secured with a downhole plug on 10/07/10 due to rapid TxIA communication while on MI. The production and reservoir engineers are currently evaluating whether an administrative approval for water injection should be pursued or if remediation work should be completed for continued gas injection. The well has been reclassified as Not Operable and will remain shut -in until further diagnostic work is determined. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 4/18/2011 FW: OPERABLE: Injector 03S(PTD #2091390) Tubing Integrity Coed on PWI I... Page 3 of 3 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, September 10, 2010 8:34 AM To: 'Regg, James B (DOA) ; 'Schwartz, Guy (DOA)'; 'Maunder, Thomas E (DOA)'; 'Brooks, Phoebe L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, OPS FS2 Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; AK, OPS PCC EOC TL Cc: AK, D &C Well Integrity Coordinator; Janowski, Carrie; Sinyangwe, Nathan Subject: UNDER EVALUATION: Injector 03 -37 (PTD #2091390) IA repressurization while on MI All, Injector 03 -37 (PTD #2091390) has been noticed to have IA repressurization while on MI as seen on the attached TIO plot. The plan forward is to keep the well on MI while diagnostics are completed at which time the well will need to be shut -in or swapped to water injection. The well has been reclassified as Under Evaluation and placed on a 28 day clock for the diagnostics. The plan forward is as follows: 1. Wellhead: Pack -off test on the tubing 2. WIE: Eval for LDL and remedial plan forward A TIO plot and wellbore schematic have been included for reference. « File: 03 -37 TIO Plot 09- 10- 10.doc » « File: 03- 37.pdf » Please call with any questions. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 4/18/2011 • Injector 03 -37 (PTD #2091390) TIO Plot Well: 03 -37 • 4,000 3,000 —�— Tbg —U— k 2,000 — A — OA OOA t 000A — On 1,000 01/22/11 01/29/11 02/05/11 02/12/11 02/19/11 02/26/11 03/05/11 03/12/11 03/19/11 Injector 03 - (PTD #2091390) Injection Plot Wd. 03 -37 1600 14000 1.800 - 9.000 1.400 - 8.000 1.200 - 7,000 5 WHIP 1.000 _ 6,000 pW - 5,000 MI 800 GI - 4A00 - OOie - On 600 - 3.000 400 2A00 200 111111111111111■ _ 11:000 01/22/11 01/29/11 02/05/11 02/12/11 02/19/11 02/26/11 03/05.11 03112/11 STATE OF ALASKA ALASKAPIL AND GAS CONSERVATION COMMISSI N • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate I Other U Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development ❑ Exploratory ❑ - 209 -139 -0 3. Address: P.O. Box 196612 Stratigraphic Service 0 6. API Number: Anchorage, AK 99519 -6612 . 50- 029 - 23421 -00 -00 7. Property Designation (Lease Number):. 8. Well Name and Number: ADL 028328 & 028331 - PBU 03 -37 9. Field /Pool(s): PRUDHOE BAY, PRUDHOE OIL 10. Present Well Condition Summary: Total Depth measured 10740 feet Plugs measured None feet true vertical 9300.87 feet Junk measured None feet Effective Depth measured 10650 feet Packer measured 9717 feet true vertical 9222.52 feet true vertical 8470.09 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.1# H -40 30 - 110 30 - 110 1530 520 Surface 3524 9 -5/8" 40# L -80 29 - 3553 29 - 3332.82 - 5750 3090 Intermediate None None None None None None Production 9966 7" 29# L -80 26 - 9992 26 - 8622.43 8160 7020 Liner 905 4 -1/2" 12.6# L -80 9833 - 10738 8557.44 - 9243.52 8430 7500 Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 24 - 9845 24 - 8510.89 Packers and SSSV (type, measured and true vertical depth) 4.5" HES TNT Prod 9717 8470.09 Packer None None None SSV 11. Stimulation or cement squeeze summary: RECEIVEC Intervals treated (measured): Treatment descriptions including volumes used and final pressure: FEB �� 12. Representative Daily Average Production o�r nfeLRidri4 # ta CaRiniSsils Oil -Bbl Gas -Mcf Water -Bbl Casing Pill �„At(u Tubing Pressure Prior to well operation: SI Subsequent to operation: 13. Attachments: 14. Well Class after work: I Copies of Logs and Surveys Run Exploratory0 Development 0 Service Ei Stratigraphic ❑ Daily Report of Well Operations 15. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP ❑ SPLUG ❑ 16. 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: NA Contact Joe Lastufka Prepared by Joe Lastufka 564 -4091 Printed N 21. A at,. Lastufka Title Data Manager Signature�ii ∎ , , IL ; Phone 564 -4091 Date 2/16/2011 'W r RBVMS FEB 18 MI , Form 10 -404 Revised 10/2010 Y 2 ( 74" Z — Subm't Original Only a 03 -37 . 209 -139 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03 -37 4/24/10 PER 10,306. 10,316. 8,930.09 8,938.44 03 -37 4/24/10 PER 10,320. 10,330. 8,941.79 8,950.16 03 -37 10/7/10 BPS 9,812. 10,330. 8,541.59 8,950.16 03 -37 12/1/10 BPP 9,812. 10,330. 8,541.59 8,950.16 03 -37 , 2/10/11 APF 10,198. 10,223. 8,840.5 8,861.13 03 -37 2/10/11 APF 10,236. 10,256. 8,871.88 8,888.46 03 -37 2/10/11 APF 10,256. 10,276. 8,888.46 8,905.08 03 -37 2/11/11 APF 10,008. 10,033. 8,690.26 8,709.4 03 -37 2/11/11 APF `� 10,155. 10,170. 8,805.19 8,817.47 03 -37 2/11/11 APF / 10,178. 10,188. 8,824.04 8,832.27 AB ABANDONED PER PERF • APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 03 -37 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 2/9/20111* *WELL SHUT -IN ON ARRIVAL* ** (ELINE- PERFORATING) 'INITIAL T /I /O = 550/560/160, RIG UP ELINE TO PERFORATE WITH 3 -3/8" HSD 'POWER JET. '***JOB IN PROGRESS, CONTINUED ON 10- FEBRUARY - 2011 * ** 2/10/2011 ***JOB IN PROGRESS, CONTINUED FROM 9- FEBRUARY - 2011 * * *(ELINE - PERFORATING) PERFORATE 10256'- 10276' 10236'- 10256', 10198'- 10223', WITH 3 -3/8" HSD POWER JET 3406 HMX, 6 SPF, 60 DEGREE PHASING, DEP ' ` D TO SLB JEWELRY LOG DATED 24- APRIL -2010. ** *JOB IN PROGRESS, CONTINUED ON 11- FEBRUARY - 2011 * ** 2/11/2011 ** *JOB IN PROGRESS, CONTINUED FROM 10- FEBRUARY - 2011 * ** (ELINE - PERFORATING) • ; _ 1 :' s ::' _a155' -1s 170' AND 10008'- 10033', WITH 3 -3/8" HSD POWER JET 3406 HMX, 6 SPF, 60 DEGREE PHASING, DEPTHS REFERENCED TO SLB JEWELRY LOG DATED 24- APRIL -2010. FINIAL T /I /O = 780/550/150 ** *JOB COMPLETE, WELL SHUT -IN ON DEPARTURE * ** FLUIDS PUMPED BBLS 3 DIESEL 2 METH 5 TOTAL TREE = CM/ 0 S Milk ES : WELL REQUIRES A SSSV ON WELLHEAD = FMC ACTUATOR = BAKER C 03-37 ML ***CHROME NIPPLES*** KB. ELEV = 55.6' BF. ELEV = 26.6' I KOP = 366' Max Angle = 50° @ 8999' Datum MD = 10216 20° CONDUCTOR I 80' ' –.- I 594' H9-5/8" TAM PORT COLLAR Datum TV D = 8800' SS — — I I I 2223' I-I4-1 /2" HES X NIP (9-CR), ID = 3.813" I 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835 H 3553' 1- ■ , Minimum ID = 3.725" @ 9832' 4-1/2" HES XN NIPPLE • • 9691' H4-1/2" HES X NIP (9-CR), ID = 3.813" I Z 9717' H7" X 4-1/2" HES TNT PKR, D = 3.8F I • • 9759' H4-1/2" HES X NIP (9-CR), D = 3.813" I I I 9832' H4-1/2" HES XN NIP (9-CR), ID = 3,725" I 9833' HT X 5" HRD-E ZXPN LTPw /11.08' X 5.25" ID TIEBK I 4-1/2" LNR, 12.6#, L-80 TCII, --I 9845' 1 , \ 9845' H4-1/2" WLEG, D = 3.958" .0152 bpf, ID = 3.958" ;.., 9856' H7" X 5" HMC LNR HGR, D = 4.430" I 7" C,SG, 29#, L-80 VAM TOP, ID = 6.184" H 9992' I IL PERFORATION SUMMARY REF LOG: SLB MWD ON 01/28/10 ANGLE AT TOP PERE: 33° © 10360' I 10124' H4-1/2" MARKER JT I Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10306 - 10316 0 04/24/10 I 3-3/8" 6 10320 - 10330 0 04/24/10 I PBTD H 10650' rff. 4001 WO* 14-1/2" LNR, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" H 10738' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/19/10 N9ES ORIGINAL COMPLETION 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE WELL. r 03-37 02/20/10 SV DRLG HO CORRECTIONS PERMIT No: ° 091390 02/23/10 MR/JMD DRLG DRAFT CORRECTIONS (12/20/10) API No: 50-029-23421-00 04/29/10 JGF/PJC PERFORATING (04/24/10) II SEC 10, T1ON, R15E, 1424' FSL & 115' FEL 10/23/10 WEC/PJC SET XXN PLUG (10/07/10) II 12/06/10 MBM/PJC PULLXXN PLUG (12/01/10) - BP Exploration (Alaska) FW: AOGCC MITIA Forms for END103 (1811170), 03 -37 (2091390), 13- 36451670), AGI -0... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] id k (tD Sent: Friday, October 01, 2010 9:15 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: FW: AOGCC MITIA Forms for END5 -03 (1811170), 03 -37 (2091390), 13 -36 (1951670), AGI -05 (1930020), B -34 (1930370), GC-1D (1871280), L -105 (2020580), L -217 (2060750), V -225 (2091180), X- 28 (1931140) Attachments: Sept 2010 MIT Forms.zip Jim, Tom and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: END 5 -03 PTD #1811170 03 -37 PTD #2091390 1 • • AGI -05 PTD #1930020 B -34 PTD # 1930370 GC-1D PTD #1871280 L -105 PTD #2020580 L -217 PTD #2060750 V -225 PTD #2091180 X -28 PTD #1931140 «Sept 2010 MIT Forms.zip» Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 10/6/2010 6 If STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.recogralaska.aoy ; doa .aoacc.grudhoe.bayaralaska.cov; phoebe.brooksCrDalaska.gov; tom.maunderc alaska.cov OPERATOR: BP Exploration (Alaska), Inc. 'gefl )016(10- FIELD /UNIT / PAD: Prudhoe Bay! PBU / DS -03 DATE: 09/20/10 OPERATOR REP: Jerry Muphy AOGCC REP: Packer Depth Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min. Well 03 -37 , Type Inj. G ' TVD ^ .. 8,470' Tubing 3310 3310 3310 3310 Interval ID P.T.D. 2091390 ' Type test P Test psi ' 2117.5 Casing 350 2500 2480 -' 2480 P/F P Notes: MIT -IA to 2500 psi to evaluate TxIA communication OA 110 320 330 330 Well Type In). TVD Tubing Interval P.T.D. Tyre test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test T Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test dunng Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU 03 - 37 09 20 10.xls NOT OPERABLE: Injector 03 -3 i PTD #2091390) Secured with a dole plug Page 1 of 2 IP Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Friday, October 08, 2010 1:56 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, OPS FS2 Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB East Production Optimization Engineer; AK, OPS PCC EOC TL Cc: Janowski, Carrie; Sinyangwe, Nathan; AK, D &C Well Integrity Coordinator Subject: NOT OPERABLE: Injector 03 -37 (PTD #2091390) Secured with a downhole plug All, Injector 03 -37 (PTD #2091390) was secured with a downhole plug on 10/07/10 due to rapid TxIA communication while on MI. The production and reservoir engineers are currently evaluating whether an administrative approval for water injection should be pursued or if remediation work should be completed for continued gas injection. The well has been reclassified as Not Operable and will remain shut -in until further diagnostic work is determined. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, September 10, 2010 8:34 AM To: 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA)'; 'Maunder, Thomas E (DOA)'; 'Brooks, Phoebe L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, OPS FS2 Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; AK, OPS PCC EOC TL Cc: AK, D &C Well Integrity Coordinator; Janowski, Carrie; Sinyangwe, Nathan Subject: UNDER EVALUATION: Injector 03 -37 (PTD #2091390) IA repressurization while on MI All, Injector 03 -37 (PTD #2091390) has been noticed to have IA repressurization while on MI as seen on the attached TIO plot. The plan forward is to keep the well on MI while diagnostics are completed at which time the well will need to be shut -in or swapped to water injection. The well has been reclassified as Under Evaluation and placed on a 28 day clock for the diagnostics. The plan forward is as follows: 1. Wellhead: Pack -off test on the tubing 2. WIE: Eval for LDL and remedial plan forward A TIO plot and welibore schematic have been included for reference. 10/8/2010 NOT OPERABLE: Injector 03 -3iTD #2091390) Secured with a dove plug Page 2 of 2 « File: 03 -37 TIO Plot 09- 10- 10.doc» « File: 03- 37.pdf» Please call with any questions. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 10/8/2010 UNDER EVALUATION: Injector z o 3 -37 (PTD #2091390) IA repressurin while on MI Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Friday, September 10, 2010 8:34 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, OPS FS2 Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; AK, OPS PCC EOC TL Cc: AK, D &C Well Integrity Coordinator; Janowski, Carrie; Sinyangwe, Nathan Subject: UNDER EVALUATION: Injector 03 -37 (PTD #2091390) IA repressurization while on MI Attachments: 03 -37 TIO Plot 09- 10- 10.doc; 03- 37.pdf All, Injector 03 -37 (PTD #2091390) has been noticed to have IA repressurization while on MI as seen on the attached TIO plot. The plan forward is to keep the well on MI while diagnostics are completed at which time the well will need to be shut -in or swapped to water injection. The well has been reclassified as Under Evaluation and placed on a 28 day clock for the diagnostics. The plan forward is as follows: 1. Wellhead: Pack -off test on the tubing 2. WIE: Eval for LDL and remedial plan forward A TIO plot and wellbore schematic have been included for reference. «03 -37 TIO Plot 09- 10- 10.doc» «03- 37.pdf» Please call with any questions. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 i 10/8/2010 WdF 03-37 4 00u 3.000. •.-. —4♦-- I6 2. 000 - �- OA 00A • 000A On 1.000 • - I 08/12/10 06/19/10 06/26/10 07/03/10 ,..10/10 07/17/10 07/24/10 07/31/10 08/07/10 08/1 4/10 08,'21/10 00/28/10 09/04/10 This lot reflects the transition of two pressure recording systems, SCADA and TIO Entry. For a short period of time in late August P p g Y rY p g and early September pressures were being recorded in the new system (TIO Entry), but the plots were being uploaded from the old system (SCADA). This lead to the late reporting of injector 03 -37, the bug has since been worked out and plots now reflect the current WHP recording system. AOGCC MITIA Forms for 03- 30760600), 03 -12 (1790580), 03 -37 (21,90), 04 -10 (... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] Sent: Thursday, July 01, 2010 5:06 PM To: AK, D &C Well Integrity Coordinator Cc: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Subject: AOGCC MITIA Forms for 03 -36 (1760600), 03 -12 (1790580), 03 -37 (2091390), 04 -10 (1760420), 04 -43 (1940130),04 -44 (1940100),09 -16 (1770370),09 -19 (1770400), 09 -31C (1960640), 09 -36C (1951140), 09 -37 (1940280) Attachments: June 2010 MIT Forms GPB part 1.zip Jim, Tom and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: 03 -06 (PTD #1760600) 03 -12 (PTD #1790580) - enclosed are 2 tests; original test from 6/12 /2010 and retest on 6/29/2010. 03 -37 (PTD #2091390) 04 -10 (PTD #1760420) 04 -43 (PTD #1940130) 04 -44 (PTD #1940100) 09 -16 (PTD #1770370) 09 -19 (PTD #1770400) 09-31C (PTD #1960640) 09 -36C (PTD #1951140) 09 -37 (PTD #1940280) «June 2010 MIT Forms GPB part 1.zip» Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 7/2/2010 • 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; phoebe.brooks @alaska.gov; tom.maunder @alaska.gov; doa.aogcc.prudhoe.bay @alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU / DS 03 DATE: 06/01/10 OPERATOR REP: Jerry Murphy AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. Well 03 -37 Type Inj. G TVD 8,470' Tubing 2,950 2,950 2,950 2,950 Interval, I P.T.D. 2091390 Type test P Test psi 2117.5 Casing 240 2,500 2,450 2,450 P/F Notes: AOGCC MIT -IA to 2500 psi OA 330 580 560 530 R r)_ Pumped 1.8 bbls MEOH Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA \ TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU 03 -37 06- 01- 10.xls • • Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble @bp.com] Sent: Thursday, June 10, 2010 9:28 AM To: Saltmarsh, Arthur C (DOA) Subject: PBU 03 -37 / PTD # 209 -139 Hi Art, Please reference the following well: Well Name: PBU 03 -37 Permit #: 209 -139 API #: 50- 029 - 23421 -00 -00 Top Perf MD: 10306' Bottom Perf MD: 10330' This well began Injection on May 31, 2010 Method of Operations is: Gas Injection Date of Test: Not Applicable 6/10/2010 I . ilD MEMORANDUM S tate of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 03, 2010 TO: Jim Regg a P.I. Supervisor l � � t (1 `) SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 03 -37 FROM: Chuck Scheve PRUDHOE BAY UNIT 03 -37 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry — )t -- NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 03 - 37 API Well Number: 50 029 - 23421 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS 100602072255 Permit Number: 209 - 139 - Inspection Date: 6/1/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 03 -37 'Type Inj. G 'TVD 1 8470 / IA 1 240 2500 2450 2450 P.T.D 2091390 lTypeTest SPT Test psi 1 2118 / OA 330 580 560 530 Interval INITAL d P/F P '" Tubing 2950 2950 2950 2950 Notes: Thursday, June 03, 2010 Page 1 of 1 � ' STATE OF ALASKA RECEIVED ALASKA AND GAS CONSERVATION COMMIS ON WELL COMPLETION OR RECOMPLETION REPORT AN MAY 201n la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 1, 104 Qi &:U92 VJ• + jnnju$SI011 20AAC 25.105 20AAC 25.110 U DeVelOpgyfeholtEXDIOratOry ❑ GINJ ❑ WINJ ® WAG ❑ WDSPL ❑ Other No. of Completions One ® Service Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 4/24/2010 209 -139 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 1/28/2010 50 - 029 - 23421 - - 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 2/14 /2010 PBU 03 -37 1425' FSL, 115' FEL, SEC. 10, T1 ON, R15E, UM 8. KB (ft above MSL): 55.6' 15. Field / Pool(s): Top of Productive Horizon: 989' FNL, 3583' FEL, SEC. 15, T1ON, R15E, UM GL (ft above MSL): 27.1' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 1258' FNL, 3896' FEL, SEC. 15, T1ON, R15E, UM 10650' 9223' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 713143 y - 5937461 Zone- ASP4 10740' 9301' ADL 028328 & 028331 TPI: x- 709748 y- 5934952 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 709443 y - 5934674 Zone- ASP4 None 18. Directional Survey: Yes ❑ No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) _ N/A ft MSL 1916' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill/Lateral Top Window MD/TVD: DIR / GR, DIR / GR / RES / PWD, NEU / DEN, SCMT / USIT, DIR / GR / RES / NEU / DEN, DPS / Sonic, SCMT / USIT N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 215.5# A - 53 Surface 108' Surface 108' •: :41 -260 sx Arcticset 9 - 5/8" 40# L - 29' 3553' 29' 3388' 12 " 965 sx AS Lite, 403 sx 'G'; Top Job of 809 AS Lite y- 7" 26# L -80 26' 9992' 26' 8678' , 8- " 184 sx Class 'G' 4 -1/2" 12.6# L -80 9833' 10738' 8557' 9299' 6- " 125 sx Class 'G' 24. Open to production or injection? ® Yes ❑ No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 3 -3/8" Gun Diameter, 6 spf 4 -1/2 ", 12.6#, L -80 9845' 9717' / 8470' MD TVD MD TVD 10306' - 10316' 8930' - 8938' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10320' - 10330' 8942' - 8950' 1 aiiiiH4lair DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED -. I' a 2260' Freeze Protected w/ 80 Bbls of Diesel 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS-MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: 1 Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ 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 20 AAC 250.071. None Form 10-407 Revised 12r ` MA 1 2 A 200 CONTINUED ON REVERSE � /4. te) Submit Original Only a If ► f 94 / G 29. GEOLOGIC MARKERS (List all formations and marencountered): 30. •MATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base 1974' 1916' results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Ugnu 5163' 4894' None West Sak 6756' 6379' Colville Mudstone 7395' 6887' Top HRZ 9634' 8408' Base HRZ 9894' 8604' LCU 9931' 8632' Sag River 9992' 8678' Shublik A 10037' 8712' Shublik B 10062' 8732' Shublik C 10085' 8749' Sadlerochit / Zone 4B 10133' 8787' Zone 4A 10258' 8890' 42N 10280' 8908' Zone 3 10352' 8969' 22N 10509' 9102' Formation at Total Depth (Name): 22N 10509' 9102' 31. List of Attachments: Summary of Daily Drilling Reports and Post -Rig Work Summary, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. OS ([ 444ff C i Signed: Terrie Hubble Title: Drilling Technologist Date: / 0 PBU 03 - 209 - 139 Prepared By Name/Number. Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: John Rose, 564 - 5271 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. Item la: 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. Item 4b: TPI (Top of Producing Interval). Item 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. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50 -029- 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: 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. Item 30: 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 12/2009 Submit Original Only . 1 , GRAPHIC SCALE ' � � � � ` �j ' — � � 0 250 500 800 7 i N , ( IN FEET) I -,� mom' ,, f _ ' . i 1 17, _. i I 1 inch = 500 ft. I I? �� � • ", . / L ii--1.1, / 44, , I -� �J ,,.. . Tcn /,-- 9 , i At: - -.0" /, ;: .._, ,0 . n 'drill dd 9 ` z /nilltiain 1 9 �� --_, DS3 ( a I 1 I j1 ( 35 0 s _ q . Ater ° I 1 I 1 - -i � - ti � 1 I I 1811--1 — _. i / I N 3 7i 171— - -- ,1 115 / I 's F 1 t6' 6 l A ✓ : 6 15 I I II 7 ,(' ` IDS ' 71 ZL1 '. + a • V* • n, (-------------C4- 1 291— 8 t _ ! d 25 ; 11 VICINITY MAP I, NTS 2411— 2 12 ^ I 11 I j 36 , % %WM1%1111 1 23 / 8 : 13 `�� OF A / J.1 2211--4 L 1 iI r 14 4 ° ' ° SL 7 2111- -. •77 * 0 49 %\ . 4 z I � 31 I I 0000000000000 1911— � 32 �— X 0000000000000 . o0 —_� \ � t, " ° Leonard J. OHanley ° °�P > 33 �i 11 386 ° °��� I U /111 j1111����� S � ` // I SURVEYOR'S CERTIFICATE / I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN NOTES: THE STATE OF ALASKA AND THAT THIS AS -BUILT REPRESENTS A SURVEY 1. DATE OF SURVEY: DECEMBER 15, 2009. MADE BY ME OR UNDER MY DIRECT 2. REFERENCE FIELD BOOK: NS09 -64 PGS. 63 -65. DUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE 3. COORDINATES ARE ALASKA STATE PLANE ZONE 4, NAD 27. CORRECT AS OF DECEMBER 15, 2009. 4. GEODETIC POSITIONS ARE NAD 27. 5. PAD MEAN SCALE FACTOR IS 0.999951378. LEGEND 6. HORIZONTAL CONTROL IS BASED ON THE AS -BUILT POSITIONS ♦ AS -BUILT CONDUCTOR OF EXISTING WELLS W16 AND W17. • EXISTING WELLS I LOCATED WITHIN PROTRACTED SECTION 10, T. 10 N., R. 15 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS 03 -371 Y= 5,937,460.85 S= 1,910.57 70'13 70.2321350' 27 1 1,425' FSL X= 713,142.88 E= 415.45 148'16'45.379 148.2792719' 115' FEL F. Robert „ � , BARNHART /! CHECKED: �� 0/� ' II( DATE: N � 12/18/09 "'• 1j ' AWING: �RRB09 DS3 03 -00 SHEET: EOA DRILL SITE 3 ISM. JOB ND. AS —BUILT CONDUCTOR 00 12/15/09 ISSUED FOR INFORMATION 1FB .12 nom rn ,xn s.nC' SCALE: 1 1 Mm We 1 = see• WELL 03 -371 °F NO. DATE REVISION BY CHK /+ .z MAIM .IrJ 1 BP Page 1 of 1 • Leak -Off Test Summary Legal Name: 03 -37 Common Name: 03 -37 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 2/6/2010 LOT 3,553.0 (ft) 3,389.0 (ft) 8.80 (ppg) 767 (psi) 2,316 (psi) 13.16 (ppg) 2/12/2010 LOT 3,553.0 (ft) 3,389.0 (ft) 10.50 (ppg) 905 (psi) 2,754 (psi) 15.64 (ppg) • • Printed: 5/24/2010 3:33:45 PM • BP Page 1 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/24/2010 21:00 - 00:00 3.00 MOB P PRE PREPARE RIG TO MOVE OFF OF V -1231 BY SUCKING OUT CELLAR & SECURING WELL - BRIDLE UP, SECURE TOP DRIVE - DISCONNECT HARD LINES & ELECTRICAL LINES -BLOWN DOWN PITS -PJSM W/ PEAK & RIG HANDS ON MOVING PITS - SEPARATE PITS AWAY FROM RIG SUBSTRUCTURE -START GENERATOR #1, FUNCTION TEST MOVING SYSTEM - PREPARE SATELLLITE CAMP FOR MOVEMENT - MOVEMENT ORDER WILL BE: - SATELLITE CAMP ESCORTED BY SECURITY; SECURITY WILL RETURN TO V -PAD - SUBSTRUCTURE -PIT SYSTEM AND TRUCK - WRANGELL CAMP WILL MOVE ON TUESDAY AFTER OTHER UNITS ARE STAGED 1/25/2010 00:00 - 08:00 8.00 MOB P PRE SATELLITE CAMP MOVED TO DS -3. 08:00 - 12:00 4.00 MOB P PRE DERRICK DOWN. STAGE SUB AT V -PAD ACCESS ROAD FOR SECURITY ESCORT TO DS -3. RD AND MOVE DIVERTER ASSEMBLY WITH CRANE, PREPARE FOR MOVEMENT. STAGE PIT COMPLEX AWAY FROM SUB. 12:00 - 00:00 12.00 MOB P PRE RIG MOVING FROM V -PAD TO DS -3. MOVED 14 MILES OUT OF TOTAL DISTANCE OF 32.5 MILES. 1/26/2010 00:00 - 12:00 12.00 MOB P PRE CONTINUE TO MOVE RIG SUBSTRUCTURE FROM PRICE PAD TO SAG RIVER SECURITY SHACK. 12:00 - 18:00 6.00 MOB P PRE MOVE RIG SUBSTRUCTURE FROM SAG RIVER SECURITY SHACK THRU ICE ROAD TO DS 3. 18:00 - 00:00 6.00 MOB P PRE STAGE MATS AROUND WELL 03 -371. STAGE SATELLITE CAMP. TRUCK AND WELDING SHOPS ON LOCATION AT 22:00 HRS. REMOVE JEEP FROM PITS MODULE AND STAGE NEAR RIG SUBSTRUCTURE. LAY HERCULITE UNDER PITS MODULE. SECURE CROWN SAVER LINER TO THE CROWN. 1/27/2010 00:00 - 03:00 3.00 RIGU P PRE ATTEMPT TO SPOT PIT MODULE. NOT ENOUGH ROOM. JOCKEY SUB TO ALLOW SPOTTING OF PIT MODULE. 03:00 - 04:30 1.50 RIGU P PRE POSITION PITS, LAY RIG MATTING, SPOT PITS. 04:30 - 06:00 1.50 RIGU P PRE RAISE DERRICK AND CATTLE SHOOT. ACCEPT RIG AT 05:00 HRS. �. 5 r• k1pJC�MdV NOTE: RIG ACCEPT TIME PUSHED BACK THREE HOURS DUE TO WORK BEING COMPLETED ON V -123 AFTER RIG HAD BEEN RELEASED. 06:00 - 08:00 2.00 RIGU P PRE TAKE ON WATER IN PITS. 08:00 - 10:00 2.00 RIGU P PRE RIG UP SURFACE STACK AND RIG FLOOR. 10:00 - 11:00 1.00 RIGU P PRE SAFETY STAND DOWN WITH DIRECTOR OF ALASKA DRILLING AND WELLS. REVIEW SAFETY PLAN AND GOALS. 11:00 - 12:00 1.00 RIGU P PRE RIG UP HYDRAULIC SERVICE LOOP 12:00 - 19:00 7.00 RIGU P PRE BRIDAL DOWN, SECURE DERRICK. HOOK UP KELLY HOSE, REMOVE A -LEG BRACE, HANG TONGS, SECURE RIG FLOOR. NIPPLE UP SURFACE STACK AND SECURE CELLAR. BURM FLOW LINE AREA. STRAP 99 JOINTS OF Printed: 5/6/2010 10:43:33 AM i t • • BP Page 2 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/27/2010 12:00 - 19:00 7.00 RIGU P PRE 4" DP. 19:00 - 21:00 2.00 RIGU N HMAN PRE MOBILIZE SPEAR TO RETRIEVE INSULATION IN CONDUCTOR. RIH ON 4" DP AND POOH WITH SOME INSULATION RECOVERED. ROTATED IN INSULATION ON 2ND RUN WITH NO INSULATION RECOVERED. ROTATED ONLY ON BOTTOM WITH 3RD RUN AND MINIMAL INSULATION RECOVERED. BOTTOM OF CONDUCTOR TAGGED AT 108'Mn 21:00 - 22:00 1.00 RIGU P PRE - PJSM ON PICKING UP 4" DRILL PIPE. PICK UP ROTARY TABLE MOUSE HOLE AND FIVE SINGLES OF 4" DP RACKING IN DERRICK. 22:00 - 00:00 2.00 RIGU P PRE FUNCTION TEST DIVERTER AND ACCUMULATOR SYSTEM. TEST WITNESSED BY LOU GRIMALDI WITH AOGCC, BP WSL JOSHUA MALLERY AND ELI VAZQUEZ, NABORS TOUR PUSHER BRIAN TIEDEMANN. 1/28/2010 00:00 - 04:30 4.50 RIGU P PRE CONTINUE TO PICK UP 4" DP FOR A TOTAL OF 99 JOINTS OF 4" DP PICKED UP TO BUILD 33 STANDS AND STAND BACK IN DERRICK. 04:30 - 05:00 0.50 RIGU P PRE CONDUCT 03 -371 PRE SPUD MEETING WITH HOLCOM'S CREW AND THIRD PARTY PERSONNEL. 05:00 - 06:00 1.00 RIGU P PRE LOAD PIPE SHED AND PREPARE 4" HWDP AND BHA 06:00 - 08:30 2.50 RIGU P PRE PU 21 JOINTS OF 4" HWDP AND STAND BACK IN DERRICK. 08:30 - 09:30 1.00 RIGU P PRE SERVICE TOP DRIVE, DRAWWORKS, AND CROWN. CALIBRATE RIG AND MWD BLOCK POSITION. 09:30 - 13:00 3.50 RIGU P PRE READY RIG FLOOR AND MAKE UP BHA #1 AS FOLLOWS: 12 1/4" MXL -1 HUGHES, 9 5/8" 1.83 DEG BENT MUD MOTOR, NMLC, NM STAB, MWD, UBHO, NM STAB, NMDC, NM STAB, NMDC, 5" HWDP, JARS, 5" HWDP. 13:00 - 15:30 2.50 RIGU N RREP PRE CHANGE OUT ENCODER ON DRAWORKS. CALIBRATE ENCODER TO NEW EPOCH SYSTEM. 15:30 - 18:00 2.50 RIGU P PRE CONTINUE TO MAKE UP BHA #1. 18:00 - 18:30 0.50 RIGU P PRE CONDUCT 03 -371 PRE SPUD MEETING WITH HAUG'S CREW AND THIRD PARTY PERSONNEL 18:30 - 19:00 0.50 RIGU P PRE CONDUCT H2S DRILL CRT = 120 SEC 19:00 - 20:30 1.50 RIGU P PRE TEST STANDPIPE MANIFOLD, CIRCULATE DRILPLEX MUD SYSTEM AND CHECK FOR LEAKS. PRESSURE TEST LINES TO 3000 PSI. 20:30 - 23:30 3.00 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE FROM 108' MD TO 255' MD WITH THE FOLLOWING PARAMETERS: - PUMP AT 440 GPM WITH 400 PSI - ROTATE AT 40 RPM WITH 1K FT -LBS. WOB 5K -10K LBS. - ROTATE 100 %, ART 1.55 HRS. - MW IN / OUT 8.6 PPG. - WIPE 15' TO 30' ON CONNECTION AS HOLE DICTATES 23:30 - 00:00 0.50 DRILL N DFAL SURF TROUBLESHOOT MWD SIGNAL LOSS. ATTEMPT TO DOWNLINK TO TOOL TO CHANGE COMMUNICATION FREQUENCY FROM 12HZ TO 24 HZ WITH NO SUCCESS. 1/29/2010 00:00 - 01:00 1.00 DRILL N DFAL SURF TROUBLESHOOT MWD SIGNAL LOSS. ATTEMPT TO DOWNLINK TO TOOL TO CHANGE COMMUNICATION FREQUENCY FROM 12HZ TO 24 HZ WITH NO SUCCESS. Printed: 5/6/2010 10:43:33 AM • BP Page 3 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/29/2010 00:00 - 01:00 1.00 DRILL N DFAL SURF THIN DRILPLEX FROM 58 TO 40 LSYP. IN ATTEMPT TO REGAIN SIGNAL TO MWD TOOL. 01:00 - 02:00 1.00 DRILL N DFAL SURF RIH WITH GYRO, STING INTO UBHO AT 185'MD AND TAKE SURVEY. POH WITH GYRO. 02:00 - 04:00 2.00 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE FROM 272' MD TO 367' MD WITH THE FOLLOWING PARAMETERS: - PUMP AT 590 GPM WITH 720 PSI ON - ROTATE AT 40 RPM WITH 1.5K FT -LBS TORQUE. WOB 35K LBS. - ROTATE 100% 04:00 - 05:30 1.50 DRILL N DFAL SURF POOH FROM 367 'MD. CHANGE OUT MWD. 05:30 - 07:00 1.50 DRILL N DFAL SURF PICK UP BHA #2. RIH TO BOTTOM. TAG UP ON 7' OF FILL. 07:00 - 14:00 7.00 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE FROM 367' MD TO 755' MD WITH THE FOLLOWING PARAMETERS: - PUMP AT 500 GPM WITH 1130 PSI ON, 830 PSI OFF. - AST 2.8 FIRS, ART 1.12 HRS, BIT 3.92 HRS - ROTATE AT 40 RPM WITH 4K FT -LBS TORQUE ON AND 1K FT -LBS TORQUE OFF. WOB 20K -35K LBS. GYRO AS PER DD 14:00 - 15:30 1.50 DRILL N WAIT SURF TRIP OUT FROM 755' MD DUE TO WAITING ON TRUCKS. WORK PIPE FROM 670' MD TO 300' MD WITH 25- 40K OVER. WAIT ON TRUCKS TO RESUME OPERATIONS. TRUCKING STOP DUE TO POOR VISIBILITY IN WEATHER PHASE 2 LEVEL 2. 15:30 - 00:00 8.50 DRILL N WAIT SURF WAIT ON TRUCKS TO RESUME OPERATIONS. WEATHER IN PHASE 2 LEVEL 2 CONDITION. 1/30/2010 00:00 - 01:00 1.00 DRILL N WAIT SURF WAIT ON TRUCKS TO RESUME OPERATIONS. WEATHER IN PHASE 2 LEVEL 2 CONDITION. 01:00 - 03:00 2.00 DRILL N WAIT SURF RESUME TRUCKING. RIH WITH SURFACE DRILLING BHA #2 FROM 280' MD TO 387' MD WITH NO ISSUES. PUW 70K, SOW 70K. ENCOUNTER TIGHT SPOT AT 387' M. ATTEMPT TO WORK DRILL STRING THROUGH OBSTRUCTION WITH 25K DOWN WEIGHT, NO SUCCESS. KELLY UP, WORK THROUGH OBSTRUCTION BY PUMPING AT 250 GPM WITH 235 PSI OFF, 435 PSI ON, ROTATING AT 20 RPM, 700 FT -LBS TORQUE OFF, 4.6K FT -LBS TORQUE ON. CONTINUE TO WORK THROUGH OBSTRUCTION WITH SAME PARAMFTFRS TO 41(1' Mn., CONTINUE TO RIH FROM 410' MD TO 447' MD WITH NO ISSUES. ATTEMPT TO PASS OBSTRUCTION WITH PUMPS OFF, NO SUCCESS. WORK THROUGH OBSTRUCTION BY PUMPING AT 250 GPM AND ROTATING FROM 447' MD TO 473' MD. CONTINUE TO RIH FROM 473' MD 707' MD WITH NO ISSUES. PUW 74K, SOW 74K. ENCOUNTER OBSTRUCTION AT 707' MD, WORK THROUGH Printed: 5/6/2010 10:43.33 AM } i • BP Page 4 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/30/2010 01:00 - 03:00 2.00 DRILL N WAIT SURF OBSTRUCTION WITH PUMPS OFF AND 29K DOWN WEIGHT, NO SUCCESS. WORK THROUGH OBSTRUCTION WHILE PUMPING AT 250 GPM AND ROTATING AT 20 RPM, NO SUCCESS. INCREASE FLOW RATE TO 500 GPM WITH 753 PSI OFF, INCREASE ROTATION TO 40 RPM WITH 1.7K OFF. PASSED THROUGH OBSTRUCTION IMMEDIATELY. NO FURTHER ISSUES WHILE RIH FROM 707'MD TO BOTTTOM OF HOLE AT 755' MD. NO FILL FOUND ON BOTTOM. 03:00 - 12:00 9.00 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE FROM 755' MD' TO 959' MD - PUMP AT 600 GPM WITH PSI 1260 ON, 950 PSI OFF - AST 4.57 HRS, ART .22 HRS - PUW 76K, SOW 75K, RTW 75K - 35 RPM, WOB 35K, TORQUE ON 3K -4K FT -LBS, TORQUE OFF 2K FT -LBS - MW IN / OUT 8.7 PPG - FLUID LOSS RATE -60 BPH. - WIPE 30' ON CONNECTION WITH PUMPS ON - GYRO SURVEY AS PER DD 12:00 - 12:30 0.50 DRILL P SURF RIG DOWN GYRO DATA AND E -LINE UNIT. 12:30 - 00:00 11.50 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE FROM 959' MD' TO 1684' MD - PUMP AT 570 GPM WITH PSI 1380 ON, 1270 PSI OFF - AST 4.57 HRS, ART 2.87 HRS - PUW 90K, SOW 83K, RTW 84K - 40 RPM, WOB 25K, TORQUE ON 4K FT -LBS, TORQUE OFF 2K FT -LBS - MW IN/ OUT 8.8 PPG - FLUID LOSS RATE -60 BPH. - WIPE 30' ON CONNECTION WITH PUMPS ON TOTAL LOSSES FOR DAY: 997 BBLS OF nRII PI FX Mt in SYSTEM 1/31/2010 00:00 - 03:00 3.00 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE FROM 1684' MD TO BASE OF PERMAFROST AT 1938' MD. - MW IN / OUT 8.8 PPG - WIPE 30' ON CONNECTION WITH PUMPS ON 03:00 - 04:00 1.00 DRILL P SURF CIRCULATE THREE BOTTOMS AT 550 GPM WITH 1290 PSI. FIRST BOTTOMS UP NO SIGNIFICANT CHANGE IN CUTTINGS RETURNS. SECOND BOTTOMS UP NO SIGNIFICANT CHANGE IN CUTTINGS RETURNS. THIRD BOTTOMS UP SLIGHT DECREASE IN CUTTINGS RETURNS. 04:00 - 06:00 2.00 DRILL P SURF POOH ON ELEVATORS FROM 1684' MD TO 279' MD WITH NO ISSUES. 06:00 - 09:00 3.00 DRILL P SURF LAY DOWN BHA #2. BREAK BIT AND LAY DOWN MUD MOTOR. BIT GRADE: 5- 7- WT- A- E -3 -FC -BHA 09:00 - 12:00 3.00 DRILL P SURF PICK UP BHA #3 WITH NEW BIT AND 1.5 DEGREE MUD MOTOR AND RUN IN HOLE TO 1833 MD WITH NO ISSUES. 12:00 - 12:30 0.50 DRILL P SURF WHILE RUNNING IN THE HOLE AT 1833' MD. TOOK 40K WEIGHT. WORK PIPE ON DOWN FROM 1833' MD TO BOTTOM OF HOLE AT 1938' MP WHILE PUMPING AT 550 GPM WITH 1520 PSI, 60 RPM AND 3K -4K FT -LBS OF TORQUE. Printed: 5/6/2010 10:43:33 AM • • BP Page5of23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/31/2010 12:30 - 14:00 1.50 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE FROM 1938' TO 2066' MD. - PUMP AT 550 GPM WITH 1550 PSI ON, 1440 PSI OFF - AST 0.0 HRS, ART 0.6 HRS - PUW 102K, SOW 80K, RTW 93K - 60 RPM, WOB 10K -20K, TORQUE ON 5K FT -LBS, TORQUE OFF 3K FT -LBS - MW IN / OUT 8.8 PPG - BACKREAM 30' ON CONNECTION - TOTAL FLUID LOSS FROM MIDNIGHT TO NOON 255 BBLS DRILPLEX MUD SYSTEM. 14:00 - 15:30 1.50 DRILL N FLUD SURF WHILE BRINGING PUMPS ONLINE FOLLOWING A CONNECTION, NOTE PRESSURE LOSS. LOST CIRCULATION MATERIAL IN MUD CAUSING SUCTION SCREENS IN PUMP TO PACK OFF. SHUT DOWN PUMPS AND WORK PIPE. STARTED TAKING WEIGHT AND OVER PULL. WORK STRING WHILE PACKING OFF AND TORQUE AT 15K FT -LBS. CONTINUE TO WORK PIPE AND ESTABLISH CIRCULATION. RACK BACK STAND BY PULLING WITH NO PUMPS. OVER PULL OF 20K - 30K TO 2030' MD. ESTABLISH CIRCULATION AND ROTATE 3K -4K, REMOVE PUMP SCREENS. WASH BACK TO BOTTOM AT 600 GPM WITH 2100 PSI.. 15:30 - 00:00 8.50 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE FROM 2066' TO 3018' MD. - PUMP AT 600 GPM WITH 2100 PSI ON, 1870 PSI OFF - AST 0.47 HRS, ART 4.48 HRS - PUW 108K, SOW 82K, RTW 95K - 60 RPM, WOB 25K, TORQUE ON 5K FT -LBS, TORQUE OFF 5K FT -LBS - MW IN / OUT 9.0 PPG - BACKREAM 30' ON CONNECTION OR AS HOLE DICTATES TOTAL FLUID LOSS FROM NOON TO MIDNIGHT 506 BBLS DRILPLEX MUD SYSTEM. TOTAL FLUID LOSS FOR DAY 761 BBLS DRILPLEX MUD SYSTEM. 2/1/2010 00:00 - 04:00 4.00 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE FROM 3018' TO 3585' MD. - PUMP AT 640 GPM WITH 2520 PSI ON, 2350 PSI OFF - 60 RPM, WOB 15K, TORQUE ON 6.8K FT -LBS, TORQUE OFF 5.5K FT -LBS - MW IN / OUT 9.0 PPG - BACKREAM 30' ON CONNECTION 04:00 - 07:00 3.00 DRILL P SURF ON REACHING TD, CIRCULATE THREE BOTTOMS UP. RECIPROCATE IN 90' STROKES OFF OF TD AT 640 GPM WITH 2350 PSI AND 100 RPM. 07:00 - 12:00 5.00 DRILL P SURF BACKREAM OUT OF HOLE FROM TD AT 3,585' MD TO BASE OF PERMAFROST AT 1968' MD. Printed: 5/6/2010 10:43:33 AM • BP Page 6 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/1/2010 07:00 - 12:00 5.00 DRILL P SURF -PUMP AT 550 GPM WITH 1680 PSI -100 RPM 5.5K FT -LBS TORQUE TOTAL FLUID LOSS FROM MIDNIGHT TO NOON: 610 BBLS DRILPLEX AR MUD SYSTEM 12:00 - 13:30 1.50 DRILL P SURF TRIP OUT OF HOLE FROM BASE OF PERMAFROST AT 1968' MD TO 277' MD. - PUW 100K, DWT 100K 13:30 - 16:00 2.50 DRILL P SURF LAY DOWN BHA #3. THREE STABILIZERS UNDERGAUGE. 12" STABILIZER CAME OUT 1 -1/4" UNDERGUAGE BIT GRADE: 3- 4- WT- A- E- 2 -NO -TD 16:00 - 16:30 0.50 DRILL P SURF LAY DOWN TOOLS, CLEAN AND CLEAR RIG FLOOR. 16:30 - 19:00 2.50 CASE P SURF RU TO RUN 9 -5/8" 40# SURFACE CASING. PERFORM DUMMY RUN WITH MANDREL HANGER AND CONFIRM RKB ELEVATION OF 29'. 19:00 - 21:30 2.50 CASE P SURF RU TESCO CASING RUNNING TOOL. SPOT 350 TON CASING SLIPS. 21:30 - 00:00 2.50 CASE P SURF MU 9 5/8" 40# L -80 BTC SURFACE CASING SHOE TO 15,000 FT -LBS AND BAKER -LOK. FILL PIPE AND TEST FLOATS - GOOD. RIH AT 2 MINUTES PER JOINT. FILL EACH JOINT. CIRCULATE EVERY 10 JOINTS. LOSING 12 BBLS EVERY 10 JOINTS. - MW IN / OUT 9.0 PPG TOTAL FLUID LOSS FROM NOON TO MIDNIGHT: 55 BBLS DRILPLEX AR MUD SYSTEM TOTAL FLUID LOSS FOR WELL: 2478 BBLS DRILPLEX AR MUD SYSTEM 2/2/2010 00:00 - 12:00 12.00 CASE P SURF RUN 9 5/8" 40# L -80 SURFACE CASING. FROM 378' MD TO 3,500' MD. TORQUE EACH JOINT TO 15K FT -LBS. FILL EACH JOINT. CIRCULATE EVERY 10 JOINTS AND RECORD PU AND SO WEIGHTS. RIH AT 2 MINUTES PER JOINT. ADJUST RUNNING SPEED TO 4 MINUTES PER JOINT AS HOLE CONDITIONS DICTATE. FLUID LOSS RATE 15 -20 BPH PRIOR TO ADJUSTING RUNNING SPEED, 10 -15 BPH AFTER. -MW IN /OUT8.9PPG TOTAL FLUID LOSS MIDNIGHT TO NOON: 110 BBLS DRILPLEX AR MUD SYSTEM 12:00 - 13:00 1.00 CASE P SURF WHILE RUNNING 9 -5/8" CASING, STRING TOOK WEIGHT AT 3,500' MD. WORK PIPE AND WASH DOWN 10' OF JOINT #85 TO 3,510' MD. - 223 GPM WITH 370 PSI MAKE UP JOINT #86, WORK PIPE WITH PUMPS AND ROTATION USING TESCO TOOL TO 3,557' MD. - 223 GPM WITH 370 PSI - 30 RPM, 10K FT -LBS TORQUE 13:00 - 14:30 1.50 CASE P SURF LAY DOWN JOINTS #86 AND #85. MAKE UP 20' PUP JOINT AND LANDING JOINT. LAND STRING ON LANDING RING. SHOE DEPTH 3.553' Mr . - PU 210K, SO 120K Printed: 5/6/2010 10:43:33 AM I • BP Page 7of23 Operations Summary Report Legal Well Name: 03 -37 Common Wcll Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/2/2010 1'4:30 - 00:00 9.50 CEMT N WAIT SURF WAITING ON WEATHER. PHASE THREE WEATHER CONDITION. CONTINUE TO CIRCULATE WITH NO RECIPROCATION. -107 GPM WITH 233 PSI DECREASE PUMP RATE DUE TO LACK OF TRUCK AVAILABILITY. REDUCE PUMPING TO 15 MINUTES ON, 15 MINUTES OFF. - 44 GPM WITH 180 PSI CUTTINGS TANK CAPACTIY BECOMING MINIMAL. REDUCE PUMPING TO 15 MINUTES ON, 30 MINUTES OFF. - 44 GPM WITH 200 PSI - MW IN /OUT 8.9 PPG TOTAL FLUID LOSS NOON TO MIDNIGHT: 160 BBLS_ DRILPLEX AR MUD SYSTEM TOTAL FLUID LOSS FOR WELL: 2748 BBLS DRILPLEX AR MUD SYSTEM 2/3/2010 90:00 - 10:30 10.50 CEMT N WAIT SURF WAITING ON WEATHER. PHASE THREE WEATHER CONDITION. CONTINUE TO CIRCULATE WITH NO RECIPROCATION. DUE TO REDUCED TRUCKING, PUMPING 15 MINUTES ON, 30 MINUTES OFF. - 44 GPM WITH 215 PSI 10:30 - 12:00 1.50 CEMT N WAIT SURF INCREASED TRUCKING AVAILABILITY. STAGE PUMPS UP TO 250 GPM: -50 GPM WITH 195 PSI -125 GPM WITH 238 PSI -150 GPM WITH 263 PSI -180 GPM WITH 297 PSI -210 GPM WITH 327 PSI -250 GPM WITH 372 PSI TOTAL FLUID LOSS MIDNIGHT TO NOON: 60 BBLS DRILPLEX AR MUD SYSTEM 12:00 - 16:30 4.50 CEMT N WAIT SURF WAIT ON CEMENTERS TO ARRIVE ON LOCATION. -PUMP AT 50 GPM WITH 160 PSI 16:30 - 19:30 3.00 CEMT N WAIT SURF WAIT ON CEMENTERS TO ARRIVE ON LOCATION. INCREASE CIRCULATION RATE IN PREPARATION FOR CEMENT JOB -250 GPM WITH INITIAL CIRC PRESSURE OF 374 PSI, FINAL CIRC PRESSURE OF 303 PSI 19:30 - 00:00 4.50 CEMT P SURF PJSM WITH SLB CEMENTERS, TRUCK PUSHERS, CREWS, MUD ENGINEERS FOR CEMENT JOB. CEMENT 9 5/8" SURFACE CASING WITH NO RECIPROCATION. 19:33 PUMP 10 BBLS MUD PUSH II AT 3.5 BPM, TEST LINES TO 3900 PSI - GOOD. Printed: 5/6/2010 10:43:33 AM • • BP Page 8 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/3/2010 19:30 - 00:00 4.50 CEMT P SURF 19:56 PUMP 93.8 BBL 10.2 PPG MUD PUSH II AT 5 BPM WITH 67 PSI 20:12 UNSTING TESCO TOOL, DROP BOTTOM PLUG MANUALLY, STING BACK IN WITH TESCO TOOL 20:20 START PUMPING 10.7 PPG ASL LEAD AT 3.5 BPM 20:44 36 BBL LEAD CEMENT AWAY, 3.5 BPM, 16 PSI 21:01 172 BBL LEAD CEMENT AWAY, 6.4 BPM, 120 PSI MUD PUSH AT SHOE 21:20 272 BBL LEAD CEMENT AWAY, 5 BPM, 630 PSI BOTTOM PLUG SHEARED 21:52 467 BBL LEAD CEMENT AWAY, 6.3 BPM, 181 PSI 22:16 626 BBL LEAD CEMENT AWAY, 6.4 BPM, 221 PSI 22:40 775 BBL MENT AWAY, 6.4 BPM, 229 PSI AP OVER TO 15.8 PPG AIL 22:49 15 BBL TAIL CEMENT AWAY, 4.6 BPM, 209 PSI 22:59 60 BBL TAIL CEMENT AWAY, 3.9 BPM, 207 PSI 22:03 84 BBL TAIL CEMENT AWAY, END OF SLURRY 23:04 UNSTING TESCO TOOL, DROP TOP PLUG, STING BACK IN WITH TESCO TOOL, AND KICK OUT WITH 10 BBL H2O. ISOLATE SLB AND DISPLACE WITH RIG PUMPS. 23:10 CHASING CEMENT WITH RIG PUMPS, 9.2 PPG DRILPLEX MUD SYSTEM 7 GOOD RETURNS DURING CEMENT JOBv PLUG BUMP AT 3530 STROKES, 251 BBLS DISPLACED. FINAL PUMP PRESSURE AT BUMP 1550 PSI AND HELD FOR 5 MINUTES. CEMENT IN PLACE AT 5 MINUTES PAST MIDNIGHT. CHECK FLOATS - HOLDING. FULL RETURNS THROUGHOUT JOB. I AFTER PLUG BUMP, BLEED PRESSURE TO ZERO. CEMENT JOB VOLUME: 775 BBLS ASL LEAD PUMPED; 955 SACKS AT 4.51 CUFT/SX 84 BBLS CLASS G TAIL PUMPED; 407 SACKS AT 1.17 CUFT /SX TAIL COMPRESSIVE STRENGTH: 500 PSI: 12:45 HRS 1000 PSI: 17:59 HRS TOTAL FLUID LOSS NOON TO MIDNIGHT: 73 BBLS DRILPLEX AR MUD SYSTEM TOTAL FLUID LOSS FOR WELL: 2881 BBLS DRILPLEX AR MUD SYSTEM 2/4/2010 00:00 - 00:30 0.50 CEMT P SURF CEMENT IN PLACE AT 00:05 HRS CHECK FLOATS - HOLDING. NO CEMENT TO SURFACE. FULL RETURNS THROUGHOUT JOB. Printed: 5/6/2010 10:43:33 AM • S BP Page 9 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/4/2010 00:00 - 00:30 0.50 CEMT P SURF AFTER PLUG BUMP, BLEED PRESSURE TO ZERO. CEMENT JOB VOLUME: 775 BBLS ASL LEAD PUMPED; 955 SACKS AT 4.51 CUFT /SX 84 BBLS CLASS G TAIL PUMPED; 407 SACKS AT 1.17 CUFT /SX TAIL COMPRESSIVE STRENGTH: 500 PSI: 12:45 HRS 1000 PSI: 17:59 HRS 00:30 - 02:30 2.00 CEMT P SURF BACK OUT LANDING JOINT PUP. BLOW DOWN TOP DRIVE. RIG DOWN TESCO CASING SYSTEM. CLEAN AND CLEAR RIG FLOOR. 02:30 - 04:00 1.50 CEMT P SURF PICK UP TAM PORT COLLAR OPENING TOOL AND RUN IN HOLE WITH 4" HWDP TO TAM PORT COLLAR DEPTH AT ( 594' MD. STING INTO TAM PORT COLLAR. ESTABLISH CIRCULATION THROUGH TAM PORT COLLAR. STAGE PUMPS UP TO 173 GPM WITH 77 PSI. CIRCULATE 2 BOTTOMS UP. 04:00 - 08:00 4.00 CEMT P SURF CIRCULATE THROUGH TAM PORT COLLAR IN PREPARATION FOR TOP JOB. WAIT FOR SCHLUMBERGER TO ARRIVE WITH ADDITIONAL CEMENT. -44 GPM WITH 44 PSI 08:00 - 13:30 5.50 CEMT P SURF PJSM WITH SLB CEMENTERS, TRUCK PUSHERS, CREWS, MUD ENGINEERS FOR TOP JOB. CEMENT 9 5/8" SURFACE CASING THROUGH TAM PORT COLLAR. 08:04 PUMP 5 BBLS WATER AT 2.3 BPM, TEST LINES TO 2450 PSI - GOOD. 08:14 START BATCH UP OF 10.7 PPG ASL CEMENT 08:17 START PUMPING 10.7 PPG ASL AT 2.0 BPM, 5 PSI 09:52 200 BBL CEMENT AWAY, 2.1 BPM, 0 PSI 11:29 400 BBL CEMENT AWAY, 2.0 BPM, 0 PSI 12:17 500 BBL CEMENT AWAY, 2.5 BPM, 18 PSI INCREASE RATE TO 2.5 BPM 12:36 550 BBL CEMENT AWAY, 2.5 BPM, 32 PSI MUD PUSH AT SURFACE 13:10 630 BBL CEMENT AWAY, 2.5 BPM, 32 PSI CEMENT TO SURFACE 13:15 650 BBL CEMENT AWAY, 32 PSI END OF SLURRY 13:16 CHASING CEMENT WITH WATER FROM SLB PUMPS, 2.5 BPM, 18 PSI 13:20 10 BBL WATER AWAY, END OF DISPLACEMENT FULL RETURNS DURING CEMENT JOB. Printed: 5/6/2010 10:43:33 AM • • BP Page 10 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/4/2010 08:00 - 13:30 5.50 CEMT P SURF CEMENT IN PLACE AT 13:20. CEMENT JOB VOLUME: 650 BBLS 10.7 PPG ASL PUMPED; 810 SACKS AT 4.51 CUFT /SX 13:30 - 15:00 1.50 CEMT P SURF CLOSE TAM PORT COLLAR AND RELEASE TOOL. PU 30K, SO 5K OVER, ROTATE 1/4 TURN TO RIGHT AND RELEASE OFF. SO 55K BELOW TAM PORT COLLAR AND SHEAR SHIFTING TOOL WITH 2200 PSI. CIRCULATE 3 BOTTOMS UP -414 GPM WITH 820 PSI POOH WITH TAM PORT COLLAR OPENING TOOL. LAY DOWN OPENING TOOL. 15:00 - 17:00 2.00 DIVRTR P SURF MAKE UP 9 -5/8" LANDING JOINT PUP. FLUSH SURFACE RISER AND FLOW LINE. BACK OUT AND LAY DOWN 9 -5/8" LANDING JOINT. 17:00 - 21:00 4.00 DIVRTR P SURF NIPPLE DOWN DIVERTER RISER AND STACK. PULL DIVERTER SYSTEM OFF OF 20" CONDUCTOR LANDING RING AND PLACE ON PEDESTAL AND SECURE. REMOVE FROM CELLAR. _ ANNULAR SLUMP: TOP OF CEMENT MEASURED 21 FROM TOP OF FLUTES ON MANDRFI HANCFR, 21:00 - 23:00 2.00 WHSUR P SURF INSTALL FMC GEN V CASING HEAD AND TUBING SPOOL. TORQUE SCREWS TO 430 FT -LBS. - PRESSURE TESTED WELLHEAD TO 1,000 PSI FOR 30 MINUTES; TESTED GOOD. WELLHEAD ORIENTATION APPROVED BY PAD OPERATOR MARK. 23:00 - 00:00 1.00 BOPSUF P SURF NIPPLE UP BOPE. INSTALL SECOND ANNULAR VALVES ON WELLHEAD. 2/5/2010 00:00 - 02:00 2.00 BOPSUF P SURF NIPPLE UP BOPE. PLACE ON TUBING SPOOL AND TORQUE. 02:00 - 03:00 1.00 BOPSUF P SURF MAKE UP TURN BUCKLES, INSTALL FLOW NIPPLE, BLOW THROUGH KILL KINE AND CHOKE MANIFOLD. 03:00 - 04:00 1.00 BOPSUF P SURF RIG UP 4" TEST EQUIPMENT. FILL BOP STACK AND LINES. INSTALL LOWER TEST PLUG. 04:00 - 08:00 4.00 BOPSUF P SURF PRESSURE TEST BOPE WITH 4" TEST JOINT. - PERFORM FULL BODY TEST. - TEST UPPER RAMS WITH 4" TEST JOINT 250 PSI LOW / 4,000 PSI HIGH. - TEST LOWER RAMS WITH 4" TEST JOINT 250 PSI LOW / 4,000 PSI HIGH. - TEST ANNULAR WITH 4" TEST JOINT 250 PSI LOW / 3,500 PSI HIGH. - TEST WITNESSED BY WSL JOSHUA MALLERY, ELI VAZQUEZ, BLAIR NEUFELD Printed: 5/6/2010 10'43'33 AM • . BP Page 11 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/5/2010 04:00 - 08:00 4.00 BOPSUF P SURF & TOOLPUSHERS ROY HUNT, BILL BIXBY. -BOPE TEST WITNESS WAIVED BY AOGCC REP. JEFF JONES. 08:00 - 09:00 1.00 BOPSUF P SURF RIG DOWN BOP TESTING EQUIPMENT. - BLOW DOWN CHOKE MANIFOLD AND KILL LINE. - PULL TEST PLUG. - INSTALL 9- 15/16" WEAR RING. 09:00 - 17:30 8.50 DRILL N RREP INT1 APPLY STEAM TO REMOVE ICE PLUG FROM TOP DRIVE, KELLY HOSE AND STAND PIPE. 17:30 - 18:30 1.00 DRILL N RREP INT1 SERVICE BACK -UP WRENCH ON TOP DRIVE. 18:30 - 20:30 2.00 DRILL P INT1 PJSM ON PICKING UP 4" DP. PICK UP 75 JOINTS OF 4" DP 1X1 FROM PIPE SHED AND RUN IN HOLE. 21:30 - 22:30 1.00 DRILL P INT1 STRIPPING AND WELL KILL DRILL WITH WSL, NABORS TOOLPUSHER AND ALL RIG CREW. 22:30 - 23:30 1.00 DRILL P INT1 PULL OUT OF HOLE RACKING BACK 25 STANDS OF 4" DP IN DERRICK. 23:30 - 00:00 0.50 DRILL P INT1 PICK UP AN ADDITIONAL 43 JOINTS OF 4" DP 1X1 FROM PIPE SHED AND RUN IN HOLE. 2/6/2010 00:00 - 01:00 1.00 DRILL P INT1 PICK UP AN ADDITIONAL 32 JOINTS OF 4" DP 1X1 FROM PIPE SHED AND RUN IN HOLE TO 2,387' MD. 01:00 - 02:00 1.00 DRILL P INT1 PULL OUT OF HOLE RACKING BACK 25 STANDS OF 4" DP IN DERRICK. 02:00 - 03:00 1.00 DRILL P INT1 BRING 3RD PARTY TOOLS TO RIG FLOOR. 03:00 - 05:00 2.00 DRILL P INT1 PSJM WITH SCHLUMBERGER AND RIG CREW RIG CREW ON PICKING UP BHA WITH SOURCE. PICK UP 8 -3/4" BHA #4 - 8.75" DTX- 619M -D2 HYCALOG BIT - 6 -3/4" 1.15 DEGREE BENT MOTOR - ARC, MWD, ADN - GHOST REAMERS 1200' AND 4663' BEHIND BIT. 05:00 - 06:00 1.00 DRILL P INT1 TRIP IN HOLE WITH BHA #4 TO 929' MD. 06:00 - 08:00 2.00 DRILL P INT1 PICK UP 31 JOINTS OF 4" DP 1X1 FROM PIPE SHED. SINGLE IN HOLE TO 1,985' MD. PICK UP AND PLACE 8 3/4" GHOST REAMER 1200' BEHIND BIT. NOTE: ROTATE BIT, STABILIZERS AND 8 3/4" GHOST REAMER WHEN EACH OF THEM PASSED THROUGH TAM PORT COLLAR AT 593' MD. 08:00 - 08:30 0.50 DRILL P INT1 SHALLOW TEST MWD TOOLS. -575 GPM WITH 1770 PSI PRESSURE TEST TAM PORT COLLAR TO 1000 PSI. 08:30 - 09:30 1.00 DRILL P INT1 PICK UP 38 JOINTS OF 4" DP 1X1 FROM PIPE SHED. SINGLE IN HOLE TO 3,133' MD. CONTINUE TO TRIP IN HOLE WITH 4" DP STAND TO 3,228' MD. 09:30 - 10:30 1.00 DRILL P INT1 CUT AND SLIP 72' OF DRILL LINE. 10:30 - 11:00 0.50 DRILL P INT1 SERVICE TOP DRIVE, DRAWWORKS, CROWN AND BLOCKS. 11:00 - 12:00 1.00 DRILL P INT1 PRESSURE TEST 9 -5/8" SURFACE CA Tf 3,5nn p Printed: 5/6/2010 10:43:33 AM • BP Page 12 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/6/2010 11:00 - 12:00 1.00 DRILL P INT1 FOR 30 CHARTED MINUTES. 12:00 - 12:30 0.50 DRILL P INT1 WASH DOWN TO FLOAT COLLAR. TAG ON DEPTH AT 3,465' MD. - 455 GPM WITH 1575 PSI - 42 RPM, 4K FT -LBS TORQUE 12:30 - 14:00 1.50 DRILL P INT1 DRILL FLOAT COLLAR AND CEMENT FROM 3,465' - 3,540' MD. - PU 123K, SO 90K, ROT 109K - 475 GPM WITH 1730 PSI - 40 RPM, 3.8K FT -LBS TORQUE, WOB 5 -7K 14:00 - 15:00 1.00 DRILL P INT1 CIRCULATE AND CONDITION MUD WHILE RECIPROCATING. - SWAP FROM 9.0 PPG DRILPLEX TO 8.8 PPG LSND MUD. - RECORD SLOW PUMP RATES. -MW IN / OUT 8.8 PPG LSND 15:00 - 16:00 1.00 DRILL P INT1 FINISH DRILLING SHOE TRACK AT 3,553' MD, 32' OF RAT HOLE AND 20' OF NEW HOLE TO 3,605' MD. - 475 GPM WITH 1730 PSI - 40 RPM, 3.8K FT -LBS TORQUE, WOB 5 -7K. CIRCULATE BOTTOMS UP 16:00 - 16:30 0.50 DRILL P INT1 PULL BACK INSIDE 9 5/8" CASING SHOE AT 3,553' MD. CONDUCT LOT: MW 8.8 PPG, 3388' TVD, DEVIATE FROM, STRAIGHT LINE AT 767 SURFACE PSI, EMW 13.15 PPG. 16:30 - 00:00 7.50 DRILL P INT1 DRILL AHEAD IN 8 3/4" HOLE FROM 3605' TO 4208' MD. - PU 135K, SO 111K, ROT 118K, WOB 15K - 20K LBS - PUMP AT 582 GPM WITH 1905 PSI ON, 1760 PSI OFF - 120 RPM, 4.1K FT -LBS TORQUE OFF, 5.5K FT -LBS TORQUE ON - AST 1.48 HRS, ART 2.52 HRS - BACKREAM FULL STANDS BEFORE CONNECTION AT 60 RPM, REDUCE PUMP RATE IN DOWN STROKE TO 450 GPM. - CAL ECD 8.83 PPG, ACT ECD 9.67 PPG - NO FLUID LOSS NOTED MW IN / OUT 8.8 PPG 2/7/2010 00:00 - 07:30 7.50 DRILL P INT1 DRILL AHEAD IN 8 3/4" HOLE FROM 4,208' MD TO 4,954' MD 01:44 PUMP HI -VIS SWEEP AT 4,465' MD. NO INCREASE IN RETURNS. - PUMP AT 590 GPM WITH 2300 PSI OFF, 2520 PSI ON - 120 RPM, 4.3K TORQUE OFF, 5.6K TORQUE ON, 18K WOB - PU 140K, SO 115K, ROT 130K - BACKREAM FULL STANDS BEFORE CONNECTION AT 60 RPM, REDUCE PUMP RATE IN DOWN STROKE TO 450 GPM. Printed: 5/6/2010 10:43:33 AM • • BP Page 13of23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/7/2010 00:00 - 07:30 7.50 DRILL P INT1 - CAL ECD 8.95 PPG, ACT ECD 9.84 PPG - NO FLUID LOSS NOTED WHILE DRILLING - ADD H2O AT 35 BPH - MW IN / OUT 9.0 PPG 07:30 - 09:30 2.00 DRILL N RREP INT1 REPAIR BLOWER MOTOR ON MUD PUMP #2 WHILE PERFORMING WIPER TRIP TO 4,200' MD. - PU 150K, SO 115K PUMP OUT FROM 4,380' MD TO 4,200' MD DUE TO SWABBING - 105 GPM WITH 460 PSI - MW IN / OUT 9.0 PPG 09:30 - 10:00 0.50 DRILL N RREP INT1 TRIP IN HOLE FROM 4,200' MD TO 4,954' MD WITH NO ISSUES -PU 135K, SO 110K 10:00 - 12:00 2.00 DRILL P INT1 DRILL AHEAD IN 8 3/4" HOLE FROM 4,954' MD TO 5,145' MD - PUMP AT 590 GPM WITH 2300 PSI OFF, 2520 PSI ON - 120 RPM, 4.3K TORQUE OFF, 5.6K TORQUE ON, 18K WOB - PU 140K, SO 115K, ROT 130K - BACKREAM FULL STANDS BEFORE CONNECTION AT 60 RPM, REDUCE PUMP RATE IN DOWN STROKE TO 450 GPM. - CAL ECD 9.23 PPG, ACT ECD 9.87 PPG - NO FLUID LOSS NOTED WHILE DRILLING - ADD H2O AT 35 BPH - MW IN / OUT 9.1 PPG 12:00 - 00:00 12.00 DRILL P INT1 DRILL AHEAD IN 8 3/4" HOLE FROM 5,145' MD to 6,617' MD - PUMP AT 570 GPM WITH 2645 PSI OFF, 2905 PSI ON - 120 RPM, 5.1K TORQUE OFF, 8.5K TORQUE ON, 15K WOB - PU 165K, SO 130K, ROT 145K - AST 2.45, ART 9.44 - BACKREAM FULL STANDS BEFORE CONNECTION AT 60 RPM, REDUCE PUMP RATE IN DOWN STROKE TO 450 GPM. - CAL ECD 9.37 PPG, ACT ECD 9.92 PPG PUMP 40 BBL HI -VIS SWEEP AT 6,481' MD, 10% INCREASE IN RETURNS. - NO FLUID LOSS NOTED WHILE DRILLING - ADD H2O AT 35 BPH - MW IN/ OUT 9.2 PPG 2/8/2010 00:00 - 12:00 12.00 DRILL P INT1 DRILL AHEAD IN 8 3/4" HOLE FROM 6,617' MD TO 7,819' MD Printed: 5/6/2010 10:43:33 AM • • BP Page 14 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/8/2010 00:00 - 12:00 12.00 DRILL P INT1 - PUMP AT 558 GPM WITH 2980 PSI OFF, 3100 PSI ON - 120 RPM, 6.5K TORQUE OFF, 10K TORQUE ON, 18K WOB - PU 170K, SO 145K, ROT 160K - AST 4.28, ART 3.22 - BACKREAM FULL STANDS BEFORE CONNECTION AT 60 RPM, REDUCE PUMP RATE IN DOWN STROKE TO 450 GPM. - CAL ECD 9.40 PPG, ACT ECD 10.13 PPG - NO FLUID LOSS NOTED WHILE DRILLING - ADD H2O AT 35 BPH - MW IN / OUT 9.2 PPG 12:00 - 00:00 12.00 DRILL P INT1 DRILL AHEAD IN 8 3/4" HOLE FROM 7,819' MD TO 8,488' MD - PUMP AT 502 GPM WITH 2900 PSI OFF, 3080 PSI ON - 120 RPM, 6.4K TORQUE OFF, 9.5K TORQUE ON, 15K WOB - PU 178K, SO 148K, ROT 160K - AST 1.72, ART 4.17 - BACKREAM FULL STANDS BEFORE CONNECTION AT 60 RPM, REDUCE PUMP RATE IN DOWN STROKE TO 450 GPM. - CAL ECD 9.37 PPG, ACT ECD 10.09 PPG - NO FLUID LOSS NOTED WHILE DRILLING - ADD H2O AT 35 BPH - MW IN / OUT 9.2 PPG 2/9/2010 00:00 - 03:00 3.00 DRILL N SFAL INT1 TROUBLE SHOOT MWD TOOLS DUE TO WEAK SIGNAL. BEGIN CIRCULATING AND RECIPROCATING AT 515 GPM WITH 2910 PSI. DOWNLINK DATA RATE FROM 6 BITS /SEC, TO 3 BITS /SEC. DOWNLINK ACCEPTED BY TOOLS, HOWEVER, WEAK SIGNAL STILL RECEIVED FROM TOOL. DOWNLINK TOOL FREQUENCY FROM 12HZ, TO 10.5HZ. DOWNLINK ACCEPTED BY TOOLS. SATISFACTORY SIGNAL FROM TOOL RECEIVED, ABLE TO RESUME OPERATIONS. 03:00 - 12:00 9.00 DRILL P INT1 DRILL AHEAD IN 8 -3/4" HOLE FROM 8488' TO 9061' - PUMP AT 500 GPM WITH 3040 PSI OFF, 3300 PSI ON - 120 RPM, 7K FT /LBS TORQUE OFF, 10K FT /LBS TORQUE ON, 18K WOB - PUW 185K, SOW 150K, ROT 170K - NO FLUID LOSS NOTED WHILE DRILLING - AST 1.22 HRS, ART 2.98 HRS - MW IN / OUT 9.3 PPG - SPR TAKEN AND RECORDED 12:00 - 00:00 12.00 DRILL P INT1 DRILL AHEAD IN 8 -3/4" HOLE FROM 9061' TO 9668' - PUMP AT 500 GPM WITH 3400 PSI OFF, 3570 PSI ON - 120 RPM, 7K FT /LBS TORQUE OFF, 11K FT /LBS TORQUE ON, 18K WOB Printed: 5/6/2010 10:43.33 AM • • BP Page 15 of 23 Operations Summary Re Opera o y ort p Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/9/2010 12:00 - 00:00 12.00 DRILL P INT1 - PUW 199K, SOW 153K, ROT 174K - NO FLUID LOSS NOTED WHILE DRILLING - AST 3.52 HRS, ART 4.80 HRS - SLOWLY ADD SPIKE FLUID TO INCREASE MW TO 10.5 PPG TO PREPARE FOR ENTERING HRZ - MW IN / OUT 9.3 PPG AT 1300 HRS; MW IN AND OUT 10.5 PPG AT1430HRS - SPR TAKEN AND RECORDED 2/10/2010 00:00 - 00:30 0.50 DRILL P INT1 DRILL AHEAD IN 8 -3/4" HOLE FROM 9668' TO 9766' - MW IN AND OUT 10.5 PPG - GEOLOGIST BEGINNING TO HAVE TROUBLE READING GAMMA RAY 00:30 - 01:30 1.00 DRILL N DFAL INT1 TROUBLESHOOT MWD FOR ERRONEOUS GAMMA RAY READINGS. SIGNAL FROM MWD TO COMPUTER IS GOOD BUT CONVERSION FACTOR IS NOT APPLIED TO GAMMA RAY. RESET COMPUTER SETTINGS, DRILL AHEAD TO TEST SIGNAL AND GAMMA RAY READING. CONVERSION FACTOR WORKING. 01:30 - 06:00 4.50 DRILL P INT1 DRILL AHEAD IN 8 -3/4" HOLE FROM 9766' TO 9,995' - PUMP AT 500 GPM WITH 3350 PSI OFF, 3550 PSI ON - 120 RPM, 7K FT /LBS TORQUE OFF, 10K FT /LBS TORQUE ON, 10K WOB - PUW 205K, SOW 155K, ROT 180K - NO FLUID LOSS NOTED WHILE DRILLING - MW IN AND OUT 10.5 PPG 06:00 - 08:00 2.00 DRILL P INT1 CIRCULATE FOR SAMPLES AT 540 GPM, 3860 PSI, 120 RPM, 180K ROT WT, 7K FT /LBS TORQUE - MW IN AND OUT 10.5 PPG 08:00 - 10:00 2.00 DRILL P INT1 OBTAIN AND RECORD SLOW PUMP RATES. MONITOR WELL - STATIC. PUW 210K. POH FROM 9995' TO 9634' WHILE PUMPING AT 95 GPM, 430 PSI. CONTINUE TO POH ON ELEVATORS FROM 9634' TO 8392' WIITH NO PROBLEMS. 10:00 - 10:30 0.50 DRILL P INT1 RIH FROM 8392' TO 9920' 10:30 - 12:00 1.50 DRILL P INT1 WASH DOWN FROM 9920' TO 9995' AT 540 GPM, 4000 PSI, 120 RPM, 180K ROT WT, 8K FT /LBS TORQUE 12:00 - 13:00 1.00 DRILL P INT1 CBU X2 AT 540 GPM, 3725 PSI, 120 RPM, 180 ROT WT, 8.4K FT /LBS TORQUE. - WITH INITIAL BOTTOMS UP, 300% INCREASE RETURNS (CLAYBALLS, WALLCAKE AND CUTTINGS) - PUMP 40 BBL HI -VIS SWEEP WITH 10% INCREASE IN CUTTINGS RETURNS - MW IN AND OUT 10.5 PPG 13:00 - 13:30 0.50 DRILL P INT1 MONITOR WELL - STATIC. PUMP OUT OF HOLE FROM 9995' TO 9539' AT 83 GPM, 395 PSI. - PUMPS OFF: PUW 220K, SOW 155K - PUMPS ON: PUW 215K, SOW 150K 13:30 - 20:00 6.50 DRILL P INT1 POH ON ELEVATORS FROM 9539' TO 289', LAYING DOWN GHOST REAMERS, STANDING BACK 4" HWDP - UPPER GHOST REAMER HAD 2 FLUID COURSES PACKED OFF WITH CLAY - LOWER GHOST REAMER HAD ALL 3 FLUID COURSES PACKED OFF WITH CLAY Printed: 5/6/2010 10:43:33 AM • • BP Page 16 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/10/2010 20:00 - 23:00 3.00 DRILL P INT1 PJSM WITH DD, MWD ON HANDLING AND LAYING DOWN BHA - LD BHA - BIT GRADE: 2- 4- RO- S- X- 1 /16 -BU -TD 23:00 - 00:00 1.00 CASE P LNR1 CLEAR AND CLEAN RIG FLOOR OF BHA MATERIAL, DEBRIS. CLEAN SUCTION SCREENS IN PUMPS. 2/11/2010 00:00 - 03:00 3.00 CASE P LNR1 REMOVE WEAR RING. FLUSH STACK. CHANGE OUT UPPER RAMS FROM 3 1/2" X 6" VARIABLES TO 7" RAMS. TEST RAMS WITH 7" TEST JOINT TO 4000 PSI HIGH, 250 PSI LOW. - CONCURRENT ACTIVITIES: REPLACE THREE HYDRAULIC HOSES, PREVENTATIVE MAINTENANCE ON ACCUMULATOR SYSTEM 03:00 - 03:30 0.50 CASE P LNR1 PU, MAKE DUMMY RUN WITH HANGER. 03:30 - 06:00 2.50 CASE P LNR1 CONTINUE RIGGING UP FOR 7 ", 29 #, L -80 INTERMEDIATE CASING RUN. 06:00 - 12:00 6.00 CASE P LNR1 MU SHOE TRACK WITH BAKER LOK. TEST FLOATS. RIH WITH 7" 29# L -80 BTC -M SHOE TRACK WITH CROSSOVER TO 7" 29# L -80 VAM TOP HC CASING AFTER JOINT 3 ACCORDING TO RUNNING PLAN. - ONE CENTRALIZER LOCKED DOWN EACH JOINT OF SHOE TRACK - ONE CENTRALIZER FREE FLOATING ON JTS 3 -11 - TWO CENTRALIZERS FREE FLOATING WITH STOP RING IN MIDDLE ON JTS 12 -137 12:00 - 15:00 3.00 CASE P LNR1 CONTINUE RIH WITH 7" 29# L -80 VAM TOP HC CASING PER RUNNING PLAN - FILL EVERY JOINT WITH FRANKS TOOL - STING IN AND PUMP DOWN AT 5 BPM EVERY 10TH JOINT - CIRCULATE ANNULAR VOLUME AT SHOE 15:00 - 16:00 1.00 CASE P LNR1 2 1/2 BBL LOSS DURING FROM JOINT 90 TO JOINT 100. - WASH DOWN JTS 101 -105 AT 208 GPM, 615 PSI ICP, 575 PSI FCP, RETURN FLOW 23% -MW IN 10.5, MW OUT 10.6 -NO INCREASE IN CUTTINGS, MW, OR VIS AT BOTTOMS UP 16:00 - 19:00 3.00 CASE P LNR1 CONTINUE RIH WITH 7" 29# L -80 VAM TOP HC CASING PER RUNNING PLAN - FILL EVERY JOINT WITH FRANKS TOOL - STING IN AND PUMP DOWN AT 5 BPM EVERY 10TH JOINT 19:00 - 21:30 2.50 CASE P LNR1 NO DISPLACEMENT AND 1 1/2 BBL LOSS DURING CIRCULATION AFTER JT 140. MONITOR DISPLACEMENT, SOW ON JT 141. DISPLACEMENT AND SOW NOT . IMPROVED. - WASH DOWN JTS 143 -150 AT 208 GPM, 755 TO 766 PSI - RETURN FLOW INITIALLY AT 16 %, INCREASED TO 23% - INITIAL FUNNEL VIS OUT AT 50 AT 1500 HRS, INCREASED TO 180 AT 1900 HRS. ADD WATER AT 30 BBLS /HR INITIALLY, 10 BBLS /HR FINAL TO BRING DOWN FUNNEL VIS TO 50 WHILE WASHING DOWN. - MW IN 10.6 PPG, MW OUT 10.8 PPG; USE SURFACE Printed: 5/6/2010 10:43:33 AM • • • BP Page 17 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/11/2010 19:00 - 21:30 2.50 CASE P LNR1 EQUIPMENT TO GET MW IN AND OUT AT 10.6 PPG DURING WASH DOWN - NO INCREASE OR DECREASE IN RETURNS ACROSS SHAKERS 21:30 - 00:00 2.50 CASE P LNR1 CONTINUE RIH WITH 7" 29# L -80 VAM TOP HC CASING PER RUNNING PLAN - FILL EVERY JOINT WITH FRANKS TOOL - STING IN AND PUMP DOWN AT 5 BPM EVERY 10TH JOINT - MW IN AND OUT 10.6 PPG 2/12/2010 00:00 - 06:00 6.00 CASE P LNR1 RIH WITH 7" 29# L -80 VAM TOP HC CASING PER RUNNING PLAN - FILL EVERY JOINT WITH FRANKS TOOL - STING IN AND PUMP DOWN AT 5 BPM EVERY 10TH JOINT - MW IN AND OUT 10.6 PPG 06:00 - 08:00 2.00 CASE P LNR1 CIRCULATE DOWN JTS 224 -229 AT 5 BPM FOR 10 MINUTES EACH FOR BOTTOMS UP BEFORE ENTERING HRZ. - CONTINUE RIH WITH JTS 230 -240; TAG 15' HIGH, WASH DOWN LAST JT AT 220 GPM, 1167 PSI - LAND STRING; CIRCULATE BOTTOMS UP WITH FRANKS TOOL - TOTAL 240 JTS, 1 CROSSOVER, 2 PUP JTS RUN; AVG MAKEUP TORQUE 14,940 FT /LBS - TOTAL 266 CENTRALIZERS AND 126 STOP RINGS RUN - TOTAL 21 BBLS MUD LOST DURING CASING RUN 08:00 - 09:00 1.00 CEMT P LNR1 RD FRANKS TOOL, MU CEMENT HEAD 09:00 - 11:30 2.50 CEMT P LNR1 CIRCULATE AND CONDITION MUD FOR CEMENT JOB, STAGING UP FROM 2 BPM TO 6 BPM. - FCP 1000 PSI, 26% RETURN FLOW - PJSM FOR CEMENT JOB WITH SLB CEMENTERS, CH2MHILL TRUCK PERSONNEL, MUD ENGINEER, TOOLPUSHER AND WSL 11:30 - 14:30 3.00 CEMT P LNR1 CEMENT PER SLB CADE CEMENTING PLAN - PUMP 27 BBLS 10.7 PPG MUDPUSH, PT LINES TO 4500 PSI - DROP BOTTOM PLUG, PUMP 161 BBLS OF 11.0 PPG LEAD CEMENT AT 5 BPM, 760 PSI; YIELD 1.84 CU FT /SACK, 479 SACKS - PUMP 41 BBLS OF 15.8 PPG TAIL CEMENT AT 3.8 BPM, 320 PSI; YIELD 1.16 CU FT /SACK, 184 SACKS - DROP TOP PLUG AND DISPLACE WITH OLD 10.5 PPG LSND MUD AT 5 BPM, AVERAGE OF 480 PSI - PACKED OFF, PRESSURED UP TO 2000 PSI AT 3184 STROKES; INTERMITTENT RETURNS AND PRESSURE FROM 3184 STROKES TO 3597 STROKES - CONTINUE DISPLACEMENT AT 5 BPM - SLOW PUMPS TO 3 1/2 BPM AT 5000 STROKES; SLOW PUMPS AGAIN TO 2 BPM AT 6000 STROKES - BUMP PLUG AT 6230 STROKES, 2400 PSI - 10 HRS FOR LEAD CEMENT TO REACH 500 PSI COMPRESSIVE STRENGTH (FOR IA BY OA FREEZE Printed: 5/6/2010 10:43:33 AM • S BP Page 18 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/12/2010 11:30 - 14:30 3.00 CEMT P LNR1 PROTECT) - IMMEDIATELY PRESSURE UP TO 4000 PSI FOR 3 MIN - BLEED PRESSURE, CHECK FLOATS. FLOATS HELD. - CIP 1430; TOTAL 4 BBLS LSND MUD LOST DURING CEMENT JOB 14:30 - 15:30 1.00 CASE P LNR1 PRESSURE TEST 7" CASING TO 4000 PSI FOR 30 MINUTES, GOOD TEST - BLEED PRESSURE OFF 15:30 - 16:00 0.50 CEMT P LNR1 CONDUCT INJECTIVITY TEST FOR FREEZE PROTECT - BREAKOVER AT 905 PSI, 15.6 PPG EMW - BULLHEAD DOWN 5 BBLS AT 1 BPM DOWN 7" BY 9 5/8" ANNULUS - CONTINUE TO BULLHEAD DOWN 1 BBLS EVERY HOUR 16:00 - 17:00 1.00 CEMT P LNR1 RD CEMENT HEAD, CLEAR AND CLEAN RIG FLOOR 17:00 - 19:00 2.00 CASE P LNR1 INSTALL 7" CASING PACKOFF, TEST VOIDS TO 5000 PSI 19:00 - 22:00 3.00 BOPSUF P LNR1 CHANGE OUT 7" RAMS TO 3 1/2" BY 6" VARIABLE RAMS. - TEST RAMS WITH 4" AND 41/2" TEST JOINTS TO 250 PSI LOW, 4000 PSI HIGH 22:00 - 00:00 2.00 CASE P LNR1 CLEAR AND CLEAN RIG FLOOR IN PREPARATION FOR DRILLING PRODUCTION HOLE - INSTALL WEAR RING - MOBILIZE 6" BHA TO RIG FLOOR - MOBILIZE ADN SOURCE TO RIG FLOOR 2/13/2010 00:00 - 00:30 0.50 DRILL P PROD1 MOBILIZE 6" BHA TO RIG FLOOR 00:30 - 03:00 2.50 WHSUR P PROD1 BULLHEAD 100 BBLS 10.5 PPG LSND DOWN 7" BT 9 5/8" ANNULUS AT 2 -3 BPM, 810 PSI, TO OPEN ANNULUS FOR FREEZE PROTECTION INJECTIVITY - RU LITTLE RED HOT OIL SERVICES TO FREEZE PROTECT - PT LITTLE RED LINES TO 2500 PSI - PUMP 64 BBLS DEAD CRUDE FREEZE PROTECT AT 2 BPM, 800 PSI - RD LITTLE RED HOT OIL SERVICE - PJSM ON MAKING UP BHA, INSTALLING NUCLEAR SOURCE WHILE PUMPING FREEZE PROTECT - BEGIN TO MAKE UP BHA AS LITTLE RED RIGS DOWN (STOP BEFORE LOADING SOURCE) 03:00 - 04:00 1.00 DRILL P PROD1 MAKE UP 6" BHA: 6" TRI -CONE BIT, 4 3/4" MOTOR WITH 1.5 DEG BEND, STABILIZER, NM FLEX COLLAR, MWD TOOL, ADN TOOL, 3 NM FLEX COLLARS, CROSSOVER, JARS, 7 STANDS 4" HWDP 04:00 - 08:00 4.00 DRILL P PROD1 RIH WITH 6" DRILLING BHA ON 4" DP TO 950'. SHALLOW HOLE TEST MWD EQUIPMENT. CONTINUE RIH WITH 6" DRILLING BHA TO 7540' - MW IN AND OUT 10.5 PPG 08:00 - 09:30 1.50 DRILL P PROD1 CUT AND SLIP DRILLING LINE, SERVICE TOP DRIVE 09:30 - 10:30 1.00 DRILL N WAIT PROD1 SAFETY STANDDOWN REQUESTED BY BP. - DISCUSSION WITH CREW, TOOLPUSHER, SPOC, WSL REGARDING STRONG SAFETY PERFORMANCE OVER PAST MONTHS AND CONTINUED AWARENESS INTO FUTURE OPERATIONS. 10:30 - 11:30 1.00 DRILL P PROD1 STRIPPING DRILL CONDUCTED WITH MORNING TOUR CREW, TOOLPUSHER AND WSL Printed: 5/6/2010 10:43.33 AM • • BP Page 19 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/13/2010 10:30 - 11:30 1.00 DRILL P PROD1 WELL KILL DRILL CONDUCTED WITH EVENING TOUR CREW, TOOLPUSHER AND WSL 11:30 - 13:00 1.50 DRILL N WAIT PROD1 SAFETY STANDDOWN WITH EVENING CREW - DISCUSSION WITH CREW, TOOLPUSHER, SPOC, WSL REGARDING STRONG SAFETY PERFORMANCE OVER PAST MONTHS AND CONTINUED AWARENESS INTO FUTURE OPERATIONS. 13:00 - 15:00 2.00 DRILL P PROD1 CONTINUE TO RIH WITH 6" DRILLING BHA FROM 7540' TO 9832' 15:00 - 16:30 1.50 DRILL P PROD1 WASH DOWN FROM 9832' TO FLOAT COLLAR AT 9907' - DRILL OUT CEMENT TO WITHIN 30' OF SHOE AT 9960' - PUW 270K, SOW 130K, ROT WT 155K, WOB 5K - 230 GPM, 2380 PSI, 60 RPM, 10K FT /LBS TORQUE - MW IN AND OUT 10.5 PPG 16:30 - 17:00 0.50 DRILL P PROD1 DISPLACE TO 8.5 PPG FLO -PRO 17:00 - 17:30 0.50 DRILL P PROD1 DRILL FROM 9960' TO 10,015' - PUW 185K, SOW 155K, ROT WT 165K, WOB 15K - 250 GPM, 1670 PSI OFF, 1850 PSI ON - 60 RPM, 3K FT /LBS TORQUE OFF, 4K FT /LBS TORQUE ON - MW IN AND OUT 8.5 PPG 17:30 - 18:00 0.50 DRILL P PROD1 PULL INTO SHOE, CONDUCT FIT TO 11.0 PPG EMW WITH 8.5 PPG MW, 8680' TVD, 1130 PSI CALCULATED. RECORD ON CHART FOR 10 MINUTES. 18:00 - 00:00 6.00 DRILL P PROD1 DRILL AHEAD IN 6" HOLE FROM 10,015' TO 10,119' - PUW 185K, SOW 155K, ROT WT 165K, 15K WOB - 250 GPM, 1670 PSI OFF, 1850 PSI ON - 80 RPM, 3K FT /LBS TORQUE OFF, 4K FT /LBS TORQUE ON - NO FLUID LOSS NOTED WHILE DRILLING - ART 4.61 HRS - SLOW PUMP RATES TAKEN AND RECORDED - MW IN AND OUT 8.5 PPG 2/14/2010 00:00 - 12:00 12.00 DRILL P PROD1 DRILL AHEAD IN 6" HOLE FROM 10,015' TO 10,740' - PUW 195K, SOW 165K, ROT WT 175K, 15K WOB - 230 GPM, 1600 PSI OFF, 1765 PSI ON - 80 RPM, 3.3K FT /LBS TORQUE OFF, 4.2K FT /LBS TORQUE ON - ART 9.85 HRS, AST 1.02 HRS - SLOW PUMP RATES TAKEN AND RECORDED - NO FLUID LOSS NOTED WHILE DRILLING - MW IN AND OUT 8.7 PPG 12:00 - 14:00 2.00 DRILL P PROD1 CIRCULATE OPEN HOLE VOLUME AT 230 GPM, 2535 PSI. - BACKREAM FROM 10,740' TO 7" SHOE AT 9992'. - PUW 195K, SOW 165K, ROT WT 175K, 80 RPM, 3.3K FT /LBS TORQUE, 230 GPM, 1660 PSI - MW IN AND OUT 8.7 PPG 14:00 - 15:30 1.50 DRILL P PROD1 PULL INTO SHOE, PUMP 40 BBL HI -VIS SWEEP - SWEEP BROUGHT BACK 10% INCREASE IN CUTTINGS RETURNS - ROT WT 165K, 80 RPM, 3K FT /LBS TQ, 245 GPM, 1745 PSI - MONITOR WELL - STATIC Printed: 5/6/2010 10:43:33 AM • • BP Page 20 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/14/2010 14:00 - 15:30 1.50 DRILL P PROD1 - MW IN AND OUT 8.7 PPG 15:30 - 19:00 3.50 DRILL P PROD1 POH WITH 6" DRILLING BHA FROM 9928' TO 855' 19:00 - 22:00 3.00 DRILL P PROD1 POH, LAYING DOWN 6" DRILLING BHA - BIT GRADE: 2- 2- WT- A- E- 1 -HC -TD - STABILIZERS SHOW 1/16" WEAR - CLEAR AND CLEAN RIG FLOOR - CONCURRENT OPERATIONS: GIVE SAFETY BRIEF TO NEW SLB ENGINEER -PJSM ON MOBILIZING, RU OF SLB TOOLS 22:00 - 00:00 2.00 EVAL P LOWER1 ,MOBILIZE SLB E -LINE TOOLS TO RIG FLOOR - RU SLB ELINE TOOLS 2/15/2010 00:00 - 13:30 13.50 EVAL P LOWER1 LOG OPEN HOLE SECTION WITH SONIC SCANNER, LOG 7" CASING FOR CBL - OH LOG GOOD; CBL WAS POOR - POH WITH LOGGING TOOL, CHANGE TO STRAIGHT BLADE, RIGID CENTRALIZERS - RIH, ATTEMPT TO LOG 7" AGAIN 13:30 - 14:30 1.00 EVAL P LOWER1 RD SLB E -LINE UNIT 14:30 - 15:30 1.00 CASE P RUNPRD RU TO RUN 4 1/2" 12.6# L -80 TCII PRODUCTION LINER - PJSM ON RU 15:30 - 18:30 3.00 CASE P RUNPRD MU LINER - BAKER -LOK SHOE TRACK, JTS 1 -3: FLOAT SHOE, JT #1 WITH CENTRALIZER LOCKED DOWN 5' FROM SHOE, FLOAT COLLAR, JT #2 WITH CENTRALIZER LOCKED DOWN MIDDLE JT, LANDING COLLAR - MU JTS 3 -14 WITH 2 FREE FLOATING CENTRALIZERS AND STOP RING LOCKED DOWN MIDDLE JT - 20' MARKER JT WITH CENTRALIZER LOCKED DOWN MIDDLE JT - MU JTS #15 -20 WITH 2 FREE FLOATING CENTRALIZERS AND STOP RING LOCKED DOWN MIDDLE JT ON JTS #15, 16, 19 & 20 - MU PUP JT, CROSSOVER BUSHING, BAKER 5" X 7" HMC LINER HANGER, RS PACKOFF NIPPLE, 5" X 7" HRD ZXP LINER TOP PACKER WITH 11.40' 5 1/4" TIEBACK SLEEVE, HRD RUNNING TOOL - TOTAL 35 CENTRALIZERS AND 16 STOP RINGS RUN; JET LUBE SEAL GUARD USED ON THREADS - OPTIMAL MU TORQUE AT 3850 FT /LBS 18:30 - 00:00 5.50 CASE P RUNPRD RIH WITH 4 1/2" 12.6# L -80 TCII LINER ON 4" DP - PU FIRST JT DP, CIRCULATE 1 1/2X LINER VOLUME - PUW 55K, SOW 52K - CONTINUE TO RIH TO 7" SHOE AT 9992' - MW IN AND OUT 8.5 PPG 2/16/2010 00:00 - 01:00 1.00 CASE P RUNPRD RIH WITH 4 1/2" 12.6# L -80 TCII LINER ON 4" DP - CONTINUE TO RIH TO 7" SHOE AT 9992' 01:00 - 01:45 0.75 CASE P RUNPRD BREAK CIRCULATION WHILE ABOVE SHOE, PUMP ANNULAR VOLUME AT 210 GPM, 835 PSI - PUW 185K, SOW 150K 01:45 - 02:30 0.75 CEMT P RUNPRD CONTINUE TO RIH WITH 4 1/2" 12.6# L -80 TCII LINER FROM 9,992' TO 10,700' 02:30 - 03:00 0.50 CEMT P RUNPRD MU CEMENT HEAD TO JOINT OF DP; MU TO DRILL STRING Printed: 5/6/2010 10:43:33 AM I • i BP Page 21 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/16/2010 02:30 - 03:00 0.50 CEMT P RUNPRD - WASH DOWN LAST JOINT AT 2 BPM , TAG AT 10740 03:00 - 04:00 1.00 CEMT P RUNPRD STAGE PUMPS UP SLOWLY TO 5 BPM - ICP 1090 PSI, FCP 1020 PSI BEGIN RECIPROCATING PIPE 8 -12' - MW IN AND OUT 8.5 PPG - PJSM W/ SLB, BAKER & 9 ES RIG CREW ON CEMENTING 4 1/2" PRODUCTION LINER DURING CIRCULATION - SHUT DOWN PUMPS, PUW 197K, SOW 153 K 04:00 - 05:30 1.50 CEMT P RUNPRD PUMP CEMENT JOB PER SLB CADE CEMENT PLAN - PUMP 20 BBLS 12.0 PPG MUDPUSH II, PT LINES TO 4500 PSI - WHILE RECIPROCATING, PUMP 26.1 BBLS 15.8 PPG CLASS "G" TAIL CEMENT AT 5 BPM - CEMENT YIELD 1.17 CU FT /SACK, 120 SACKS - DROP DART, POSITIVE INDICATION THAT DART LEFT CEMENT HEAD - KICK OUT DART WITH 8.5 PPG FLOPRO MUD USING RIG PUMPS - DISPLACE CEMENT AT 5 BPM WHILE CONTINUING TO RECIPROCATE - SLOW DISPLACEMENT RATE TO 3 BPM AT 1575 STROKES - LATCH UP TO LINER WIPER PLUG AT 1593 STROKES, 2200 PSI - CONTINUE TO DISPLACE AT 3 BPM; SLOW TO 2.5 BPM AT 1750 STROKES - PRESSURE INCREASE TO 1295 PSI; STOP RECIPROCATING - BUMP PLUG AT 1795 STROKES, 2297 PSI; CIP 0530 HRS - CONTINUE TO PRESSURE UP TO 3010 PSI TO SET LINER HANGER, SLACK OFF 65K. DID NOT CONFIRM HANGER SET. PICK BACK UP TO SET DEPTH, PRESSURE UP TO 4300 PSI AND SET BACK DOWN TO 65K. CONFIRM HANGER SET, RELEASE HR TOOL. - BLEED OFF PRESSURE, CHECK FLOATS; FLOATS HELD - PU STRING WEIGHT +5' TO VERIFY HR TOOL RELEASED AND EXPOSE DOG SUB - SET DOWN WITH 50K TO SET PACKER WITH GOOD INDICATION AT SURFACE; REPEAT PROCEDURE WITH ROTATION TO CONFIRM PACKER SET 05:30 - 06:30 1.00 CEMT P RUNPRD PRESSURE UP TO 1000 PSI, UNSTING FROM LINER TOP PACKER - MAINTAIN CIRCULATING PRESSURE OF 1000 PSI WHILE PULLING OUT OF PACKER RECEPTACLE - ONCE OUT, CIRCULATE 30 BBLS AT 425 GPM, 1750 PSI - LD CEMENT HEAD, CONTINUE PUMPING AT 425 GPM, 1750 PSI WHILE RECIPROCATING -MW IN AND OUT 8.5 PPG - 11 BBLS CEMENT CONTAMINATED MUD BACK TC SURFACE, NO MUD LOST DURING CEMENT JOB 06:30 - 08:00 1.50 CASE P RUNPRD DISPLACE WELL TO 8.5 PPG SEAWATER - MONITOR WELL - STATIC - MW IN AND OUT 8.5 PPG Printed: 5/6/2010 10:43:33 AM • • BP Page22of23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/16/2010 08:00 - 17:00 9.00 CASE P RUNPRD POH LAYING DOWN DRILL PIPE 17:00 - 17:30 0.50 CASE P RUNPRD LD HR LINER RUNNING TOOL - INSPECT, CONFIRM ALL DOGS SHEARED AND CLEAN OF CEMENT 17:30 - 18:00 0.50 EVAL P RUNPRD CLEAR AND CLEAN RIG FLOOR, PULL WEAR RING 18:00 - 18:30 0.50 EVAL P RUNPRD PRESSURE TEST PRODUCTION LINER TO 4000 PSI FOR 30 MIN ON CHART. GOOD TEST. 18:30 - 20:00 1.50 RUNCOMP RUNCMP RU TO RUN 4 1/2" 12.6# L -80 TCII COMPLETION TUBING 20:00 - 20:30 0.50 RUNCOMP RUNCMP PJSM ON MAKING UP AND RIH WITH COMLETION ASSEMBLY - PU AND MU 4 1/2" 12.6# L -80 TCII COMPLETION ASSEMBLY PER WELL PLAN - WLEG, XN NIPPLE WITH RHC -M PLUG, 4 1/2" TUBING JT, X NIPPLE, HES TNT PRODUCTION PACKER, X NIPPLE - BAKER -LOK ALL JOINTS BELOW PACKER 20:30 - 00:00 3.50 RUNCOMP RUNCMP RIH WITH 4 1/2" COMPLETION TO 2283' - JET LUBE SEAL GUARD USED ON ALL THREADS - AVERAGE MAKEUP TORQUE 3850 FT /LBS 2/17/2010 00:00 - 10:30 10.50 RUNCOMP RUNCMP RIH WITH 4 1/2" 12.6# L -80 TCII COMPLETION TO 9755' - MU LAST X NIPPLE ASSEMBLY BETWEEN JTS 176 AND 177 - CONTINUE RIH WITH COMPLETION ASSEMBLY - JET LUBE SEAL GUARD USED ON ALL THREADS - AVERAGE MAKEUP TORQUE 3850 FT /LBS 10:30 - 12:00 1.50 RUNCOMP RUNCMP MU JOINT 226 AND 7.81', 5.79'. PUW 150K, SOW 120K. MU JOINTS 227 AND 228. RIH, TAG UP TO LINER TOP PACKER BORE RECEPTACLE. - PU, RE -TAG TO CONFIRM - CALCULATE SPACE OUT - LD JOINT 227 AND 228, INSTALL PUPS: 3.77', 2.04' - MU JT 227, LINER HANGER AND LANDING JOINT - LAND COMPLETION STRING, RILDS 12:00 - 13:00 1.00 RUNCOMP RUNCMP RD FROM COMPLETION RUN - CLEAR AND CLEAN RIG FLOOR 13:00 - 14:00 1.00 WHSUR P RUNCMP INSTALL TWC. TEST TO 1000 PSI FROM BELOW AND 3500 PSI FROM ABOVE FOR 10 MIN. 14:00 - 16:00 2.00 BOPSUF P RUNCMP ND BOP 16:00 - 18:30 2.50 WHSUB P RUNCMP NU ADAPTER FLANGE, TREE - TEST FLANGE, TREE AND PACKOFF TO 5000 PSI 18:30 - 19:30 1.00 WHSUB P RUNCMP RU DSM LUBRICATOR - PRESSURE TEST TO 500 PSI - PULL TWC 19:30 - 22:00 2.50 WHSUR P RUNCMP REVERSE CIRCULATE 160 BBLS CLEAN SEAWATER FOLLOWED BY 130 BBLS SEAWATER WITH CORROSION INHIBITOR 22:00 - 00:00 2.00 WHSUB P RUNCMP RU LITTLE RED HOT OIL SERVICES - FREEZE PROTECT WITH 80 BBLS DIESEL TO 2200' TVD, -2260' MD - USE RIG CHOKE MANIFOLD AND ALLOW TO U -TUBE (NO GLM OR SHEAR VALVES IN COMPLETION) 2/18/2010 00:00 - 01:00 1.00 WHSUR P RUNCMP ALLOW FREEZE PROTECT DIESEL TO U -TUBE THROUGH RIG CHOKE MANIFOLD WITH MANUAL CHOKE SET TO 26% Printed: 5/6/2010 10:43:33 AM 1 • S BP Page 23 of 23 Operations Summary Report Legal Well Name: 03 -37 Common Well Name: 03 -37 Spud Date: 1/28/2010 Event Name: DRILL +COMPLETE Start: 1/25/2010 End: 2/19/2010 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/19/2010 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/18/2010 00:00 - 01:00 1.00 WHSUR P RUNCMP - CONCURRENT OPERATIONS: PREPARE RIG FOR MOVE 01:00 - 03:00 2.00 RUNCOMP RUNCMP DROP BALL AND ROD TO SET PACKER - PRESSURE TEST LINES TO 4200 PSI; LINES PRESSURING UP FINE BUT SENSATOR NOT READING ON CHART - TROUBLESHOOT SENSATOR LINE, HOSE AND CHART; CONFIRM NO AIR IN LINE - STILL NO PRESSURE; REPLACE LINE; NO PRESSURE; REPLACE SENSATOR, PURGE LINE - ABLE TO RECORD PRESSURE - SET PACKER WITH 4000 PSI 03:00 - 04:00 1.00 RUNCOMP RUNCMP HOLD PRESSURE AND RECORD ON CHART FOR 30 MINUTE TUBING TEST - GOOD TUBING TEST - BLEED TUBING DOWN TO 2000 PSI - PRESSURE UP ANNULUS TO 4000 PSI, RECORD ON CHART FOR 30 MINUTE ANNULUS TEST - GOOD IA TEST, - WITNESS OF PACKER SETTING WAIVED BY AOGCC ,REP CHUCK SCHEVE 04:00 - 06:00 2.00 WHSUR P RUNCMP INSTALL TWC, TEST TO 1000 PSI FROM ABOVE FOR 10 MINUTES - GOOD TEST - INSTALL BULL PLUGS - INSPECT ALL FLANGES, VALVES AND GAUGES - SECURE WELL 06:00 - 08:00 2.00 RIGD P RUNCMP RELEASE RIG TO DS09 -44 AT 0800 HRS - CONTINUE TO PREP FOR RIG MOVE Printed: 5/6/2010 10:43:33 AM • • 03 -37, Well History (Post Rig Sidetrack) Date Summary 2/28/2010 WELL S/I ON ARRIVAL. PULL BALL & ROD FROM RHC PLUG BODY. DRIFT TO RHC PLUG BODY IN XN -NIP @ 9806' SLM ( +26'corr = 9832' MD). W/ 3.80" CENT, 3.50" LIB / PULL 4 1/2" RHC PLUG BODY @ 9806' SLM / 9832' MD. 3/1/2010 DRIFT TO TD @ 10625' SLM ( +26' corr.= 10651' MD) (no sample recovered). LEFT WELL S /I, DSO NOTIFIED ON DEPARTURE, T /I /0= 100/0/0 3/9/2010 T /I /O = Locked out/0 /0 +. Temp = SI. T & IA FL (Pre Eline). WAG (New well). Unable to get TBG FL due to MV locked out for Norcon post rig tie in. IA FL near surface. 4/11/2010 T /I /O =MV /Vac /120. Temp =SI. T & IA FL's (pre -E line). T FL unavailable due to MV lock -out for flowline instrumentation work. IA FL near surface. OA FL @ surface. 4/23/2010 WELL SHUT -IN ON ARRIVAL. INITIAL T /I /O = 0/0/100 RU ELINE, WAIT FOR PERMIT TO BE SIGNED. 4/24/2010 LOGGED JEWELRY LOG FROM 9615'- 10370'. PERFORATE INTERVAL 10320'- 10330' , 10306' -10316 WITH 3 -3/8" HSD POWER JET 3406 HMX, 6 SPF, 60 DEG PHASING, DEPTH REFERENCED TO SLB MWD DATED 28- JAN -2010. API DATA - PENETRATION = 36.5 ", ENTRANCE HOLE= 0.37" LOGGED SBHPS: STOP COUNT © 9963' PRESS = 3702 PSI, TEMP = 166 DEG F STOP COUNT © 10092' PRESS = 3747 PSI, TEMP = 158 DEG F STOP COUNT © 10216' PRESS = 3794 PSI, TEMP = 156 DEG F FINAL T/ I/ 0= 0/ 0/ 100 PSI. JOB COMPLETED. Page 1 of 1 • bp 0 DS03 -37 Survey Report Schiumberger Report Date: 15- Feb -10 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 243.810 Field: Prudhoe Bay Unit - EOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: DS -03 / 03 -37 TVD Reference Datum: Rotary Table Well: 03 -37 TVD Reference Elevation: 55.60 ft relative to MSL Borehole: 03 -37 Sea Bed 1 Ground Level Elevation: 27.10 ft relative to MSL UWIIAPI #: 5002923412100 Magnetic Declination: 22.500 Survey Name 1 Date: 03 -37 / February 15, 2010 Total Field Strength: 57689.290 nT Tort 1 AHD 1 DDI 1 ERD ratio: 134.763 / 4765.28 ft / 5.870/0.512 Magnetic Dip: 80.932 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: January 28, 2010 Location Lat!Long: N 70.23213502, W 148.27927185 Magnetic Declination Model: BGGM 2009 Location Grid NIE YIX: N 5937460.850 ftUS, E 713142.880 ftUS North Reference: True North Grid Convergence Angle: +1.61938250 Total Corr Mag North -> True North: +22.500° Grid Scale Factor: 0.99995161 Local Coordinates Referenced To: Well Head • I Comments Measured Azimuth Vertical Along Hole NS EW Inclination Sub -Sea TVD TVD Closure DLS Northing Easting Latitude Longitude Depth True () I (deg) I (deA) I (g) I ft l I Section (ft I De (ft) re (ft ) Tru( North Tru (ft ) ( deg /100 ft) _ ( ftUS) ( ftUS ) RTE 0.00 0.00 0.00 -55.60 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5937460.85 713142.88 N 70.23213502 W 148.27927185 NS Gyro SS 100.00 0.13 274.32 44.40 100.00 0.10 0.11 0.11 0.01 -0.11 0.13 5937460.86 713142.77 N 70.23213504 W 148.27927276 184.00 0.36 293.85 128.40 184.00 0.35 0.47 0.47 0.12 -0.45 0.29 5937460.96 713142.43 N 70.23213535 W 148.27927548 278.00 0.54 280.06 222.40 278.00 0.90 1.20 1.20 0.32 -1.16 0.22 5937461.14 713141.72 N 70.23213589 W 148.27928118 366.00 1.31 242.06 310.38 365.98 2.24 2.58 2.45 -0.08 -2.45 1.07 5937460.70 713140.43 N 70.23213480 W 148.27929165 462.00 2.56 249.51 406.33 461.93 5.47 5.82 5.59 -1.34 -5.43 1.33 5937459.35 713137.49 N 70.23213134 W 148.27931568 556.00 4.08 253.27 500.17 555.77 10.85 11.26 11.03 -3.04 -10.60 1.63 5937457.51 713132.37 N 70.23212671 W 148.27935741 650.00 5.24 253.62 593.86 649.46 18.38 18.90 18.66 -5.22 -17.92 1.23 5937455.13 713125.11 N 70.23212077 W 148.27941649 740.00 5.57 252.17 683.46 739.06 26.75 27.37 27.14 -7.71 -26.02 0.40 5937452.41 713117.09 N 70.23211395 W 148.27948188 832.00 7.10 250.21 774.89 830.49 36.82 37.52 37.28 -11.00 -35.62 1.68 5937448.84 713107.58 N 70.23210495 W 148.27955937 MWD +GMAG 856.10 7.60 249.21 798.79 854.39 39.89 40.61 40.36 -12.07 -38.51 2.14 5937447.69 713104.72 N 70.23210203 W 148.27958271 953.56 9.44 252.24 895.17 950.77 54.21 55.04 54.79 -16.80 -52.15 1.94 5937442.58 713091.23 N 70.23208912 W 148.27969279 1052.00 12.29 258.13 991.84 1047.44 72.35 73.58 73.30 -21.42 -70.10 3.10 5937437.46 713073.42 N 70.23207650 W 148.27983763 1147.73 15.24 260.16 1084.81 1140.41 94.30 96.35 95.97 -25.67 -92.47 3.12 5937432.58 713051.18 N 70.23206490 W 148.28001820 1240.51 19.71 259.23 1173.29 1228.89 121.10 124.21 123.73 -30.68 - 119.87 4.83 5937426.80 713023.93 N 70.23205121 W 148.2935 1336.89 20.50 257.49 1263.80 1319.40 153.17 157.33 156.83 -37.37 - 152.31 1.03 5937419.19 712991.69 N 70.23203292 W 148.28050120 1431.87 20.29 254.30 1352.82 1408.42 185.52 190.43 189.92 -45.43 - 184.40 1.19 5937410.23 712959.84 N 70.23201090 W 148.28076022 1527.47 20.18 253.09 1442.52 1498.12 218.09 223.49 222.95 -54.71 - 216.14 0.45 5937400.06 712928.39 N 70.23198555 W 148.28101635 1623.36 19.96 251.20 1532.59 1588.19 250.65 256.39 255.80 -64.79 - 247.46 0.71 5937389.09 712897.37 N 70.23195799 W 148.28126913 1717.48 20.39 247.31 1620.94 1676.54 282.95 288.84 288.08 -76.30 - 277.79 1.50 5937376.74 712867.37 N 70.23192656 W 148.28151398 1813.21 21.51 245.47 1710.34 1765.94 317.14 323.07 321.98 -90.02 - 309.14 1.36 5937362.14 712836.42 N 70.23188908 W 148.28176704 1877.36 20.64 245.54 1770.20 1825.80 340.19 346.14 344.83 -99.58 - 330.14 1.36 5937351.98 712815.71 N 70.23186295 W 148.28193646 1909.11 20.87 244.79 1799.89 1855.49 351.44 357.39 355.97 - 104.31 - 340.35 1.11 5937346.97 712805.63 N 70.23185003 W 148.28201887 2004.95 19.49 246.78 1889.85 1945.45 384.48 390.45 388.79 - 117.88 - 370.49 1.61 5937332.55 712775.89 N 70.23181294 W 148.28226214 2099.73 19.21 247.38 1979.27 2034.87 415.83 421.85 420.07 - 130.11 - 399.41 0.36 5937319.51 712747.33 N 70.23177952 W 148.28249558 2194.13 19.79 249.98 2068.26 2123.86 447.22 453.36 451.53 - 141.56 - 428.76 1.11 5937307.24 712718.31 N 70.23174825 W 148.28273248 SurveyEditor Ver SP 2.1 Bld( users) 03- 37 \03- 37 \03- 37 \03 -37 Generated 5/24/2010 3:04 PM Page 1 of 4 Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub -Sea TVD TVD Closure DLS Northing Easting Latitude Longitude, Depth True Section Departure True North True North (ft) (deg) (deg) (ft) (ft) (ft) (ft ) (ft) I (ft) (ft ) (deg1100ft ) (ftUS) (ftUS) 2290.08 22.12 250.19 2157.86 2213.46 481.33 487.67 485.83 - 153.24 - 461.02 2.43 5937294.65 712686.39 N 70.23171633 W 148.28299287 2386.32 21.96 250.05 2247.06 2302.66 517.22 523.78 521.93 - 165.52 - 494.99 0.17 5937281.41 712652.79 N 70.23168277 W 148.28326698 2481.05 21.72 250.55 2334.99 2390.59 552.24 559.02 557.16 - 177.40 - 528.16 0.32 5937268.60 712619.97 N 70.23165031 W 148.28353475 2576.23 21.49 250.23 2423.49 2479.09 587.05 594.07 592.20 - 189.17 - 561.18 0.27 5937255.91 712587.30 N 70.23161817 W 148.28380120 2671.55 21.35 250.09 2512.22 2567.82 621.65 628.88 627.01 - 200.98 - 593.92 0.16 5937243.18 712554.90 N 70.23158589 W 148.28406548 2767.18 21.28 250.01 2601.31 2656.91 656.20 663.64 661.76 - 212.84 - 626.60 0.08 5937230.40 712522.58 N 70.23155348 W 148.28432920 2861.98 21.10 250.01 2689.70 2745.30 690.27 697.91 696.02 - 224.55 - 658.80 0.19 5937217.78 712490.72 N 70.23152147 W 148.28458910 2957.64 21.27 250.07 2778.90 2834.50 724.64 732.48 730.58 - 236.35 - 691.29 0.18 5937205.07 712458.58 N 70.23148922 W 148.28485135 3052.19 21.31 250.52 2867.00 2922.60 758.75 766.81 764.91 - 247.93 - 723.61 0.18 5937192.58 712426.60 N 70.23145759 W 148.28511219 3147.74 20.93 250.54 2956.13 3011.73 792.94 801.24 799.33 - 259.41 - 756.07 0.40 5937180.20 712394.48 N 70.23142623 W 148.28537417 3244.73 20.05 250.65 3046.98 3102.58 826.65 835.19 833.28 - 270.69 - 788.09 0.91 5937168.02 712362.79 N 70.23139540 W 148.28563261 3339.72 22.31 249.13 3135.55 3191.15 860.78 869.50 867.59 - 282.51 - 820.31 2.45 5937155.29 712330.92 N 70.23136310 W 148.28589261 3436.09 22.32 249.14 3224.70 3280.30 897.21 906.10 904.16 - 295.54 - 854.50 0.01 5937141.30 712297.12 N 70.23132749 W 148.28616856 3524.25 22.38 249.79 3306.24 3361.84 930.57 939.62 937.68 - 307.30 - 885.89 0.29 5937128.66 712266.07 N 70.23129535 W 148.28 93 9 -518" Csg 3553.00 22.38 250.09 3332.82 3388.42 941.45 950.57 948.62 - 311.05 - 896.18 0.40 5937124.61 712255.90 N 70.23128509 W 148.28 92 3643.70 22.40 251.04 3416.68 3472.28 975.76 985.12 983.17 - 322.55 - 928.76 0.40 5937112.20 712223.65 N 70.23125367 W 148.28676788 3737.63 22.44 250.93 3503.51 3559.11 1011.31 1020.94 1019.00 - 334.22 - 962.63 0.06 5937099.58 712190.13 N 70.23122177 W 148.28704123 3834.19 22.56 250.80 3592.72 3648.32 1047.98 1057.89 1055.95 - 346.33 - 997.54 0.13 5937086.48 712155.58 N 70.23118867 W 148.28732297 3930.24 21.39 246.06 3681.80 3737.40 1083.77 1093.82 1091.83 - 359.50 - 1030.95 2.21 5937072.38 712122.55 N 70.23115268 W 148.28759263 4025.25 20.55 243.07 3770.52 3826.12 1117.76 1127.81 1125.63 - 374.09 - 1061.65 1.43 5937056.93 712092.27 N 70.23111283 W 148.28784042 4120.97 20.88 242.89 3860.05 3915.65 1151.62 1161.67 1159.20 - 389.47 - 1091.82 0.35 5937040.70 712062.56 N 70.23107080 W 148.28808384 4216.52 21.21 242.63 3949.23 4004.83 1185.92 1195.98 1193.22 - 405.17 - 1122.32 0.36 5937024.14 712032.51 N 70.23102788 W 148.28833004 4311.67 21.04 246.28 4037.99 4093.59 1220.20 1230.26 1227.33 - 419.96 - 1153.25 1.39 5937008.49 712002.02 N 70.23098747 W 148.28857961 4407.24 20.50 251.15 4127.35 4182.95 1253.94 1264.14 1261.19 - 432.27 - 1184.79 1.89 5936995.30 711970.83 N 70.23095383 W 148.28883420 4502.34 20.64 253.02 4216.39 4271.99 1287.00 1297.55 1294.57 - 442.54 - 1216.58 0.71 5936984.13 711939.35 N 70.23092575 W 148.28909076 4598.67 21.77 253.52 4306.20 4361.80 1321.37 1332.39 1329.36 - 452.57 - 1249.95 1.19 5936973.16 711906.28 N 70.23089834 W 148.28936006 4693.68 19.40 251.57 4395.14 4450.74 1354.37 1365.79 1362.73 - 462.56 - 1281.82 2.60 5936962.28 711874.71 N 70.23087104 W 148.28961727 4796.23 19.00 250.11 4491.98 4547.58 1387.84 1399.51 1396.45 - 473.62 - 1313.68 0.61 5936950.32 711843.18 N 70.23084080 W 148.28987436 4891.41 19.46 250.79 4581.85 4637.45 1418.98 1430.86 1427.80 - 484.11 - 1343.22 0.54 5936939.00 711813.94 N 70.23081213 W 148.29011277 4986.75 18.55 252.42 4671.99 4727.59 1449.74 1461.91 1458.83 - 493.91 - 1372.67 1.10 5936928.37 711784.78 N 70.23078533 W 148.29035048 5082.62 19.29 252.59 4762.68 4818.28 1480.47 1492.99 1489.89 - 503.26 - 1402.32 0.77 5936918.19 711755.41 N 70.23075978 W 148.29058975 5177.50 20.14 251.76 4852.00 4907.60 1512.13 1525.00 1521.88 - 513.06 - 1432.79 0.94 5936907.53 711725.23 N 70.23073299 W 148.2 3563 5273.77 19.26 251.73 4942.64 4998.24 1544.27 1557.45 1554.32 - 523.23 - 1463.61 0.91 5936896.50 711694.72 N 70.23070520 W 148. 435 5369.96 19.09 251.58 5033.49 5089.09 1575.57 1589.05 1585.91 - 533.17 - 1493.60 0.18 5936885.71 711665.02 N 70.23067802 W 148.2 636 5464.60 19.53 251.44 5122.80 5178.40 1606.58 1620.34 1617.20 - 543.09 - 1523.28 0.47 5936874.95 711635.64 N 70.23065089 W 148.29156589 5560.29 19.48 252.35 5213.00 5268.60 1638.22 1652.29 1649.13 - 553.02 - 1553.64 0.32 5936864.17 711605.56 N 70.23062375 W 148.29181095 5655.52 19.26 252.24 5302.84 5358.44 1669.45 1683.87 1680.70 - 562.63 - 1583.73 0.23 5936853.72 711575.76 N 70.23059749 W 148.29205378 5750.43 19.85 246.27 5392.29 5447.89 1701.04 1715.62 1712.42 - 573.89 - 1613.39 2.19 5936841.63 711546.43 N 70.23056671 W 148.29229315 5844.77 20.13 245.87 5480.94 5536.54 1733.27 1747.87 1744.58 - 586.97 - 1642.87 0.33 5936827.72 711517.33 N 70.23053095 W 148.29253104 5940.31 20.59 246.76 5570.51 5626.11 1766.47 1781.11 1777.74 - 600.32 - 1673.31 0.58 5936813.51 711487.28 N 70.23049446 W 148.29277669 6036.21 20.61 247.85 5660.28 5715.88 1800.15 1814.85 1811.44 - 613.34 - 1704.44 0.40 5936799.62 711456.54 N 70.23045888 W 148.29302789 6132.98 21.06 248.83 5750.73 5806.33 1834.46 1849.26 1845.84 - 626.04 - 1736.43 0.59 5936786.02 711424.92 N 70.23042416 W 148.29328604 6228.35 20.96 247.68 5839.76 5895.36 1868.55 1883.46 1880.01 - 638.71 - 1768.19 0.44 5936772.47 711393.54 N 70.23038954 W 148.29354233 6323.76 21.90 247.02 5928.57 5984.17 1903.34 1918.32 1914.83 - 652.13 - 1800.36 1.02 5936758.13 711361.76 N 70.23035283 W 148.29380193 SurveyEditor Ver SP 2.1 Bld( users) 03- 37 \03- 37 \03- 37 \03 -37 Generated 5/24/2010 3:04 PM Page 2 of 4 A Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub -Sea TVD TVD Closure DLS Northing Easting Latitude Longitude, Depth True Section Departure True North True North (ft) I (deg) (deg) (ft) (ft) I (ft) (ft ) (ft) I (ft) (ft ) (deg /100 ft) (ftUS) (ftUS) 6419.05 22.35 241.24 6016.85 6072.45 1939.19 1954.18 1950.48 - 667.79 - 1832.60 2.33 5936741.57 711329.97 N 70.23031004 W 148.29406215 6514.86 22.46 240.44 6105.43 6161.03 1975.66 1990.70 1986.54 - 685.58 - 1864.49 0.34 5936722.89 711298.60 N 70.23026141 W 148.29431948 6610.71 24.59 237.20 6193.31 6248.91 2013.75 2028.94 2024.09 - 705.42 - 1897.19 2.60 5936702.13 711266.48 N 70.23020718 W 148.29458331 6706.66 27.44 233.21 6279.54 6335.14 2055.32 2071.01 2064.84 - 729.48 - 1931.68 3.48 5936677.11 711232.68 N 70.23014143 W 148.29486165 6802.24 29.88 230.02 6363.41 6419.01 2100.10 2116.84 2108.52 - 757.98 - 1967.57 3.01 5936647.61 711197.61 N 70.23006356 W 148.29515123 6897.33 31.12 226.93 6445.34 6500.94 2146.62 2165.09 2153.78 - 789.98 - 2003.67 2.10 5936614.61 711162.43 N 70.22997611 W 148.29544254 6992.58 33.21 225.52 6525.97 6581.57 2194.95 2215.79 2200.78 - 825.07 - 2040.27 2.33 5936578.50 711126.84 N 70.22988022 W 148.29573782 7087.21 36.34 223.82 6603.69 6659.29 2245.92 2269.76 2250.43 - 863.47 - 2078.18 3.46 5936539.05 711090.03 N 70.22977529 W 148.29604372 7183.08 40.60 221.05 6678.74 6734.34 2301.41 2329.38 2304.57 - 907.51 - 2118.36 4.79 5936493.89 711051.12 N 70.22965493 W 148.29636785 7279.56 43.75 221.07 6750.23 6805.83 2361.14 2394.15 2363.07 - 956.35 - 2160.90 3.26 5936443.87 711009.97 N 70.22952148 W 148.29671108 7374.59 46.09 221.13 6817.52 6873.12 2423.03 2461.24 2424.03 - 1006.91 - 2205.01 2.46 5936392.08 710967.31 N 70.22938331 W 148.29706693 7469.92 47.28 222.30 6882.91 6938.51 2487.30 2530.60 2487.68 - 1058.68 - 2251.17 1.53 5936339.03 710922.64 N 70.22924185 W 148.29743931 7565.33 46.73 220.88 6947.98 7003.58 2551.90 2600.38 2551.96 - 1110.86 - 2297.49 1.23 5936285.56 710877.81 N 70.22909924 W 148.29781302 7660.90 46.29 219.78 7013.75 7069.35 2615.49 2669.72 2615.52 - 1163.72 - 2342.37 0.95 5936231.46 710834.45 N 70.22895481 W 148.29 03 7756.64 47.54 219.61 7079.15 7134.75 2679.31 2739.64 2679.60 - 1217.52 - 2387.02 1.31 5936176.42 710791.33 N 70.22880778 W 148.229 7852.80 47.34 220.02 7144.19 7199.79 2744.02 2810.47 2744.86 - 1271.92 - 2432.38 0.38 5936120.76 710747.54 N 70.22865911 W 148.29890114 7947.70 49.07 219.74 7207.44 7263.04 2808.69 2881.22 2810.34 - 1326.22 - 2477.74 1.84 5936065.21 710703.73 N 70.22851075 W 148.29926705 8043.47 47.90 219.41 7270.91 7326.51 2874.08 2952.93 2876.84 - 1381.49 - 2523.42 1.25 5936008.67 710659.63 N 70.22835971 W 148.29963559 8139.51 48.02 218.19 7335.23 7390.83 2938.71 3024.25 2942.86 - 1437.08 - 2568.12 0.95 5935951.85 710616.53 N 70.22820781 W 148.29999609 8235.23 48.35 217.98 7399.05 7454.65 3002.98 3095.59 3008.80 - 1493.23 - 2612.12 0.38 5935894.48 710574.13 N 70.22805436 W 148.30035105 8330.17 47.94 218.23 7462.39 7517.99 3066.70 3166.31 3074.42 - 1548.87 - 2655.76 0.47 5935837.63 710532.09 N 70.22790230 W 148.30070303 8426.38 47.47 217.76 7527.14 7582.74 3130.76 3237.47 3140.63 - 1604.95 - 2699.57 0.61 5935780.33 710489.88 N 70.22774905 W 148.30105640 8522.24 48.63 219.20 7591.22 7646.82 3195.20 3308.76 3207.38 - 1660.75 - 2743.93 1.65 5935723.30 710447.11 N 70.22759656 W 148.30141425 8617.01 48.71 219.35 7653.81 7709.41 3259.94 3379.93 3274.53 - 1715.84 - 2788.98 0.15 5935666.97 710403.64 N 70.22744601 W 148.30177762 8712.63 48.09 219.59 7717.29 7772.89 3325.09 3451.43 3342.25 - 1771.04 - 2834.44 0.68 5935610.51 710359.77 N 70.22729516 W 148.30214424 8807.86 47.55 219.61 7781.23 7836.83 3389.45 3522.00 3409.28 - 1825.42 - 2879.42 0.57 5935554.89 710316.34 N 70.22714657 W 148.30250705 8902.80 48.01 219.89 7845.03 7900.63 3453.65 3592.31 3476.26 - 1879.47 - 2924.38 0.53 5935499.58 710272.93 N 70.22699884 W 148.30286968 8999.33 49.50 222.53 7908.68 7964.28 3520.65 3664.88 3546.06 - 1934.05 - 2972.20 2.57 5935443.68 710226.67 N 70.22684968 W 148.30325540 9094.06 48.25 221.71 7970.98 8026.58 3586.96 3736.24 3615.08 - 1986.98 - 3020.06 1.47 5935389.42 710180.33 N 70.22670504 W 148.30364143 9189.77 47.14 221.51 8035.40 8091.00 3652.49 3807.02 3683.49 - 2039.90 - 3067.06 1.17 5935335.20 710134.84 N 70.22656041 W 148.30402055 9285.94 45.04 218.84 8102.10 8157.70 3715.96 3876.30 3750.06 - 2092.81 - 3111.77 2.96 5935281.05 710091.65 N 70.22641582 W 148.30438113 9380.37 44.31 222.65 8169.26 8224.86 3777.02 3942.68 3814.10 - 2143.10 - 3155.08 2.94 5935229.56 710049.78 N 70.22627838 W 148.3 3041 9476.42 44.14 225.74 8238.10 8293.70 3840.11 4009.66 3879.73 - 2191.12 - 3201.77 2.25 5935180.24 710004.47 N 70.22614713 W 148. 97 9572.08 43.30 226.70 8307.23 8362.83 3903.13 4075.77 3944.97 - 2236.86 - 3249.50 1.12 5935133.17 709958.05 N 70.22602210 W 148.3 194 9667.99 41.84 229.76 8377.87 8433.47 3965.60 4140.64 4009.32 - 2280.09 - 3297.86 2.64 5935088.59 709910.94 N 70.22590395 W 148.30588202 9761.59 41.12 231.91 8448.00 8503.60 4026.01 4202.64 4071.12 - 2319.25 - 3345.91 1.70 5935048.10 709864.01 N 70.22579692 W 148.30626964 9858.25 40.98 231.43 8520.89 8576.49 4088.06 4266.11 4134.48 - 2358.62 - 3395.71 0.36 5935007.34 709815.35 N 70.22568931 W 148.30667129 9932.78 40.58 231.56 8577.33 8632.93 4135.62 4314.79 4183.06 - 2388.92 - 3433.80 0.55 5934975.97 709778.13 N 70.22560646 W 148.30697856 9972.00 40.34 231.27 8607.17 8662.77 4160.48 4340.24 4208.45 - 2404.79 - 3453.70 0.79 5934959.54 709758.69 N 70.22556308 W 148.30713901 10069.43 39.73 230.53 8681.77 8737.37 4221.56 4402.91 4270.95 - 2444.32 - 3502.33 0.79 5934918.66 709711.20 N 70.22545504 W 148.30753129 10165.17 34.87 230.34 8757.91 8813.51 4277.99 4460.91 4328.76 - 2481.26 - 3547.05 5.08 5934880.48 709667.54 N 70.22535407 W 148.30789195 10260.65 33.86 229.97 8836.72 8892.32 4330.36 4514.81 4382.46 - 2515.78 - 3588.43 1.08 5934844.79 709627.16 N 70.22525969 W 148.30822570 10355.43 32.84 229.11 8915.89 8971.49 4380.86 4566.91 4434.34 - 2549.59 - 3628.07 1.19 5934809.88 709588.48 N 70.22516728 W 148.30854546 10451.83 31.93 228.29 8997.30 9052.90 4430.71 4618.54 4485.67 - 2583.66 - 3666.87 1.05 5934774.73 709550.67 N 70.22507414 W 148.30885833 10547.53 31.36 227.76 9078.77 9134.37 4479.02 4668.75 4535.53 - 2617.24 - 3704.19 0.66 5934740.11 709514.31 N 70.22498235 W 148.30915938 SurveyEditor Ver SP 2.1 Bld( users) 03- 37 \03- 37 \03- 37\03 -37 Generated 5/24/2010 3:04 PM Page 3 of 4 r Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub-Sea TVD TVD Closure DLS Northing Easting Latitude Longitude, Depth True Section Departure True North True North (ft ) (deg) (deg) (ft) _ (ft) (ft ) (ft ) (ft ) (ft) (ft ) (deg1100ft )_ (ftUS) (ftUS) 10642.23 30.06 228.35 9160.19 9215.79 4525.57 4717.11 4583.56 - 2649.57 - 3740.16 1.41 5934706.78 709479.27 N 70.22489398 W 148.30944945 10690.59 29.34 227.62 9202.20 9257.80 4548.62 4741.07 4607.36 - 2665.61 - 3757.96 1.67 5934690.25 709461.93 N 70.22485015 W 148.30959303 10740.00 29.34 227.62 9245.27 9300.87 4571.87 4765.28 4631.39 - 2681.93 - 3775.85 0.00 5934673.43 709444.52 N 70.22480554 W 148.30973726 Survey Error Model: SLB ISCWSA version 24 * ** 2 -D 95.00% Confidence 2.4477 sigma Surveying Prog: MD From ( ft ) MD To ( ft) EOU Freq Survey Tool Type Borehole -> Survey 0.00 27.60 Act -Stns SLB_NSG +SSHOT -Depth Only 03 -37 -> 03 -37 27.60 832.00 Act -Stns SLB_NSG +SSHOT 03 -37 -> 03 -37 832.00 3524.25 Act -Stns SLB_MWD +GMAG^^1 03 -37 -> 03 -37 3524.25 9932.78 Act -Stns SLB_MWD +GMAG^^2 03 -37 -> 03 -37 9932.78 10690.59 Act -Stns SLB_MWD +GMAG^ "3 03 -37 -> 03 -37 10690.59 10740.00 Act -Stns SLB BLIND 03 -37 -> 03 -37 Legal Description: Northing (Y) fftUSI Easting (X) IftUS. Surface : 1424 FSL 115 FEL S10 T10N R15E UM 5937460.85 713142.88 BHL : 4021 FSL 3895 FEL S15 T10N R15E UM 5934673.43 709444.52 Final Definitive Survey Verify and Sign -off I have checked to the best of my ability that the following data is correct: Surface Coordinates and Reference Elevations Declination Information Survey Tool Codes SLB DE: Client Representative: Date: • SurveyEditor Ver SP 2.1 Bld( users) 03- 37 \03- 37 \03- 37 \03 -37 Generated 5/24/2010 3:04 PM Page 4 of 4 TREE = f CIW 0 WELLHEAD = FMC x SAFETYS: ** *CHROME NIPPLES * ** ACTUATOR = BAKER C DRAFT O -37 KB. ELEV = 55.6' BF. ELEV = 26.6' I KOP = 366' Max Angle = 50° @ 8999' 20" CONDUCTOR I 80' Datum MD = 10216' -1 594' H9-5/8" TAM PORT COLLAR Datum TVD = 8800' SS ' I I 2223' 1-14 -1/2" HES X NIP (9 -CR), ID = 3.813" I I9 -5/8" CSG, 40 #, L -80 BTC, ID = 8.835" H 3553' I-41 , Minimum ID = 3.725" @ 9832' 4-1/2" HES XN NIPPLE I 9691' I- 14- 1 /2 " HES X NIP (9 -CR), ID= 3.813" I 9717 H7" X 4-1/2" HES TNT PKR, ID = 3.88" 1 9759' H4-1/2" HES X NIP (9 -CR), ID = 3.813" I I 9832' 1-14-1/2" HES XN NIP(9 -CR), ID= 3.725" 9833 I- 7" X 4-1/2" BKR FLEXLOC LNR HGR (ID = 4.430 ") /I w /ZXP LTP w /11.77' TES (ID = 5.25 ") 4 -1/2" LNR, 12.6 #, L -80 TCII, H 9845' I \ I 9845' H4 -1/2" WLEG, ID = 3.958" I .0152 bpf, ID = 3.958" 17" CSG, 29 #, L -80 VAM TOP, ID = 6.184" H 9992' I ' • s PERFORATION SUMMARY REF LOG: SLB MWD ON 01/28/10 ANGLE AT TOP PERF: 33° @ 10360' I 10124' H4 -1/2" MARKER JT I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE I 3 -3/8" 6 10306 -10316 0 04/24/10 3 -3/8" 6 10320 - 10330 0 04/24/10 I PBTD H 10650' MAW I4 -1/2" LNR, 12.6 #, L -80 TCII, .0152 bpf, ID = 3.958" H 10738' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/19110 N9ES ORIGINAL COMPLETION WELL: '03 -37 02/20/10 SV DRLG HO CORRECTIONS PERMIT No: 2091390 02/23/10 ? /JMD DRLG DRAFT CORRECTIONS API No: 50- 029 - 23421 -00 04/29/10 JGF /PJC PERFORATING (04/24/10) SEC 10, T1 ON, R15E, 1424' FSL & 115' FEL BP Exploration (Alaska) J 05/07/10 Schlumberger NO. 5514 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 # Log Description Date BL Color CD Z -30A AWJI.00077 MEMORY GLS t.n3 — R IA 1 (�6 03/06/10 1 1 P -16 AYS4 -00122 PRODUCTION PROFILE / O _ to 3 143 4.3 1 03/08/10 1 1 03-01 B9RH -00024 X -FLOW CHECK/IBP /CEMENT DUMP — . 04/21/10 1 — , 1 P2 -22 BBUO -00007 USIT / • _ ' /' (n ( 03/08/10 1 - 1 U -03 BBKA -00021 X - -FLOW CHECK/P UG /C MENT t Tel fsG/ — LC. q 04/22/10 1 /9 4,3 1 ID 03 -37 BBKA -00023 STATIC PRESSURE SURVEY • - ), 04/24/10 1 1 S -111 B5JN -00049 INJECTION PROFILE L — . I , (f 04/19/10 1 1 R -28 BCZ2 -00009 PRODUCTION PROFILE / V /y, , / WA) 04/26/10 1 1 R -04 BCZ2 -00010 PRODUCTION PROFILE / // 04/27/10 1 1 13 -23A BBSK -00016 INJECTION PROFILE( ] =a. / —LOX', et, 3 04/29/10 1 1 S -06 BBKA -00026 INJECTION PROFILE (J / et // 04/30/10 1 1 Z -31 8350 -00060 INJECTION PROFILE u m" , 1,- J1 1 ) 04/27/10 1 1 17 -22 AWJI -00085 MEM PRODUCTION PROFILE - O/ — ) / / 04/28/10 - 1 1 14 -07 AVYO -00068 PRODUCTION PROFILE / OtD 9C.,a 04/26/10 1 1 04 -29AL1 BBSK -00017 USIT a / 1 $ 11 �jJ 04/30/10 1 1 A -06 BBKA -00006 RST 9 — • Is /`�j - 4 02/09/10 1 1 A -28 AYTO -00037 RST / „ — 02/16/10 1 1 17 -09A 10AKA0128 OH MWD /L 'D EDIT — (,b / ( 02/11/10 2 1 17- 09APB1 10AKA0128 OH MWD /LWD EDIT 0_09 —e la n / 9.6 a:S 02/07/10 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services filt Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 +ry rt MA'( 1 , -,1 X01( ;A1 ft r _ 09A. r e l it 1 .7 03/25/10 Schlnaherer ., NO. 5481 Alaska Data & Consulting Services Company: State of Alaska APR P R 0 9 2 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm `e 9 1.� Anchorage, AK 99503-2838 Ann: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Commission s ` Well Job # Log Description Date 8L Color CD Anchorage 03 -37 09AKA0188 OH MWD/LWD EDIT 419E — 1 c 9 i el s- 02/14/10 2 1 07 -23B 09AKA0078 OH MWD/LWD EDIT a 5 .. N S- , q 5a..3 01/10/10 2 1 V -123 _ BBKA -00002 _ CH EDIT PDC (SCMT)a / / j 01/15/10 1 04-42 B14B -00099 INJECTION PROFILE jp m (Gi) ya , ( 1 03/23/10 1 1 06 -12A AP30 -00081 PRODUCTION PROFILE /di&_ y ay, 03/21/10 1 1 III X -04 BBSK -00012 LDL (' -D —� ( 03/14/10 1 1 03 -28 B9RH -00017 PRODUCTION LOG / WI 03/19/10 1 1 14 -11A B3S0 -00050 PERF RECORD & FLO G BHP � p 4, j . 1 1 15 -31 B AP30 -00082 LDL T fls Q (_ ("• 03/22/10 1 1 03 -10 B9RH -00018 INJEC ION PROFILE U ( -I " • I 03/21/10 1 1 14 -07 8148 -00098 PERF RECORD & FLOWING BHP =, ♦ _ 03/22/10 1 1 03 -11 B9RH -00019 INJECTION PROFILE - ZC — 0 ! 03/22/10 1 1 12 -26 ANHY -00121 PRODUCTION PROFILE G— j X 03/16/10 1 1 ^ P2 -22 BBSK -00011 USIT CORROSION DATA — ( 03/11/10 1 1 P2 -22 BBSK -00011 USIT CEMENT DATA 94 G)� r• , _ 03/11/10 1 1 ,D 03 -28 B9RH -00017 CBL W- -6'} ( r8 03/19/10 1 1 15 -30A BSJN -00045 SCMT AO`d i� Sow 03/22/10 1 1 MPS -08 BBUO -00009 USIT oh - / ' O -z, 03/12/10 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: it BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Sale 400 900 E. Benson Bivd. Anchorage, AK 99503 -2838 1 L • bp Date: 04 -01 -2010 Transmittal Number: 93138 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact Joe Lastufka at (907)564 -4091 Delivery Contents SW Name Contractor Description 03 -37 HAL END OF WELL REPORT AGI -01A HAL END OF WELL REPORT Please Sign and Return one copy of this transmittal. RECEIVED Thank You, Joe Lastufka ,, `' ; ' ,�.1fl ii: ' i ' ! 3 d Petrotechnical Data Center Maas : a ConocoPhillips Sandy Lemke Exxon File Room DNR Corazon Manaois AOGCC Christine Mahnken UT aoci -/6 !�5� Dog —/3 X95& Petrotechnical Data Center LR2 -1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519 -6612 0:1 /1n/In Schiumberger NO. 5481 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Company: State of Alaska Anchorage, AK 99503 - 2838 Alaska Oil & Gas Cons Comm ATTN: Beth Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 4 Log Description ' Date BL Color CD U - 1 0 B 3 S O - 0 0 0 4 8 CROSSFLOW DETECT /IBP UDC / gtc 1■1-4 G� � 3C, 03 /02/10 1 - AVYO -00060 CBL - - / L 02/16/10 1 " " "' AGI -01A AVYO -00056 USIT _T /M� 02/10/10 1 1 - � � 1 03 -37 BBSS -00002 SONIC SCANNER -MSIP ♦te / '9614/3 '9614/3 L/3 02/14/10 1 1 r; __ 03 -37 BBSS -00002 _ SS- ANALYSIS BEHIND CSG 410)-i e/u _ 3 - ( t 02/14/10 07 -21 83S0 -00045 _SPINNER LOG /PRE -IBP I ' j ^G 1 / 4/` 1 02/24/10 1 1 1 P2 -48 AVYO -00057 PROD PROFILE (REDO) a - / - _ AGI -01A B9RH -00014 JEWELRY LOG W /PRESS/TEMP G' I 7 u 02/ 27 /10 1 1 W -204 8148.00097 GLS 0O(o - 1. 5-,5 � / ' 4 y y 14,31( 02/27/10 1 1 09 -41 BBSK -00010 CROSSFLOW RECORD 'T 03/01/10 1 1 _ 15-27 BBUO -00006 RST GRAVEL PACK / A /� / 03/06/10_ 1 1 15-27 BBUO -00006 LDL -�' �O 03/05/10 _ 1 1 - MPC -22A ��' • 03/05/10 1 1 - - BAUJ -00007 MEM PPRO W /GLS (REVISED) . �� 02/11/10 1 05 -08 BBSK -00001 RST / "3 "3 9 / _ L, � • L 4, 1 _ 11767134 MCNL 10715393 MCNL REVISED 01/17/10 1 1 E -198 ( ) r�3 1 -1 Q l Z l Z0 04/07/04 1 1 CNL (REVISED) ab� - 0 /14//41 07/21/07 18 -30A B2NJ -00052 MCNL 9 4 /0 4 i 01/31/10 1 1 W -56 09AKA0186 OH MWD /LWD EDIT ( 'j - - G/ a j 4(,/ a s - 12/19/09 2 1 -- .. • ' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: - tit' Exploration (Alaska) Inc. I'etrutectuucal Data Center LR2 -1 Alaska Data & Consulting Services 900 E Henson HIvr1 2525 Gambell Street, Suite 400 Anchorage, AK 99503 -2838 'i DS3 -37i surface Cement job. Page 1 of 1 Regg, James B (DOA) From: Jones, Jeffery B (DOA) Sent: Sunday, February 07, 2010 9:55 AM PTb 7 -0f-139 To: Regg, James B (DOA) Pak (75-57 Subject: FW: DS3 -37i surface Cement job. FYI, I got hung up at Nordic 1 BOPE test that required my presence and I did not get over there to witness the top job. From: Neufeld, Blair (ASRC) [mailto:Blair.Neufeld @bp.com] Sent: Thursday, February 04, 2010 2:29 PM To: Jones, Jeffery B (DOA) Cc: Hobbs, Greg S (ANC) Subject: DS3 -37i surface Cement job. Jeff, Our surface cement job was as follows. Drilled 12 1/4" to 3585', set pipe @ 3553' Initial cement job we pumped 775 bbls 10.7ppg lead and 84 bbls 15.8 ppg tail with no cement returns to surface. Opened Tam Port collar at 593.82' and pumped 650' bbls 10.7ppg ASL lead cement. Mud push to surface @ — 550bbIs away. Cement to surface @ 630 bbls away, pump 20 bbls for total of 650bbIs. Good 10.6 ppg cement at surface. Blair Neufeld Nabors 9es Wellsite Leader 907 - 659 -4831 2/8/2010 0 0 � —/3? . 7 2 MECHANICAL INTEGRITY RE ORT SPUD D r. _ _ . : 6 . Z 8 /a _.__ 01' ER E, FIELD RIG REL ,i..SC . 1729// W.U.1 NUMBER PS 3— 3 , :; ALL DATA 'a:� s ND.. TVD ` ETD : ? TVD Casing : a._ •_._� . .. Shoe : MD _ TVD; DV: -MD 'TGD 7 �- – :i:lEr Shoe: SM� TVD; TOP: _..._._.... VD A Tubing: .pecker a IX TVD: Set at w, , Hole Size and ; Perfa to 'IC .AN1CAL INTEGRITY - ?ART (1 , Annulus tress Test: a 4 / 00 6 ; 15 macs 30 min ffi..� Comments : T¢ -> tiro -32 1-.3 zoos nrL es. 440 71: s 4 I rt .10 , merseft.......w. A...mr o. vrWI=..........2a.*. MECHANICAL INTEGRITY e PAP ?2, Cement Vol s.s r .ntt. L & AA_ Csg t ` S ; DV — 74 Cmt vol to cove® pe.r ,s ' e_ W 4 ,,�� ( /! 1 -amss w +se <'Y:616_ + Thecrecicc.l TOO 4' MD _ 7074 JCC41 ra t` CQz— . 3Lao' M tn Cement Bond. Log irePor No) CBL- ; In A.OGCC File___ . ___- CBL Evaluation, zone above perfa - 1 - • 64st e4. o - f , p! 'j ( 15'. (4 • • r Production Log: Type Nl/f 1 Evaluation __41,q______Ys- 4 60,Ze.1.. 'CONCLUSIONS: ? art f 2 :�,,, �±►tiP.„- exs,t. G. 44--0 ' � la • lz •/a 1 40 ._ „:-(„„ ,i_i,., .\, k' § r p i SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 / FAX (907) 276 -7542 Mr. Greg Hobbs Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03 -37 BP Exploration (Alaska) Inc. Permit No: 209 -139 Surface Location: 1433' FSL, 132' FEL, SEC. 10, T1ON, R15E, UM Bottomhole Location: 1182' FNL, 3813' FEL, SEC. 15, T1ON, R15E, UM Dear Mr. Hobbs, Enclosed is the approved application for permit to drill the above referenced service 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, �� Daniel T. Seamount, Jr. Chair DATED this t day of DECEMBER, 2009 cc: Department of Fish 86 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA RECEIVEDAK, ALASJIL AND GAS CONSERVATION COMMIOON PERMIT TO DRILL NUV 0 5 Z009 20 AAC 25.005 ( p t111SStOt1 1 a. Type of work: 1 b. Proposed Well Class: ❑ Development Oil ❑ Service - Winj ❑ Single Zone `��sit "P°'m ose or: Drill ❑ Redrill ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed c >isC1 IU Hydrates ❑ Re -Entry ❑ Exploratory ® Service - WAG ❑ Service - Disp ❑ Shale Gas 2. Operator Name: 5. Bond: ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 PBU 03 - 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 - 6612 MD 10518' TVD 9097 Prudhoe Bay Field / Prudhoe 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Bay Oil Pool Surface: ADL 028328 & 028331 1433' FSL, 132' FEL, SEC. 10, T1ON, R15E, UM (Planned) Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 986' FNL, 3579' FEL, SEC. 15, T1ON, R15E, UM January 15, 2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1182' FNL, 3813' FEL, SEC. 15, T1ON, R15E, UM 2560 13,725' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: —55.5 feet 15. Distance to Nearest Well Open Surface: x- 713126 y- 5937469 Zone- ASP4 GL Elevation above MSL: feet to Same Pool: 455 16. Deviated Wells: Kickoff Depth: 500 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 49 degrees Downhole: 3250 Surface: 2387 18. Casing Program: Specifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 215.5# A - 53 Weld 108' Surface Surface 108' 108' —260 sx Arctic Set 12 -1/4" 9 -5/8" 40# L -80 BTC 3831' Surface Surface 3831' 3656' 752 sx AS Lite. 251 sx Class 'G' 8 -1/2" 7" 26# L -80 TC -II 6900' Surface Surface 6900' 6513' (See Below) 8 -1/2" 7" 26# L -80 BTC -M 3104' 6900' 6513' 10004' 8684' 216 sx LiteCrete. 141 sx Class 'G' 6 -1/8" 4 -1/2" 12.6# L -80 TC -II 664' 9854' 8569' 10518' 9097' 121 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor / Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: ❑ Property Plat ❑ BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report Drilling Fluid Program 18120 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact John Rose, 564 -5271 Printed Name Gre.yobb- Title Engineering Team Leader Prepared By Name/Number: Signature � / . ' P hone 564-4191 Date / /�4, 7 Terrie Hubble, 564 -4628 Commission Use Only Permit To Drill API Number: Perm' p va See cover letter for Number: A? 0y /� 9 so- av?9o?314/t> /� L other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coal gas hydrates, or gas contained shales: ' Other: '� /OO° RA: SDr '" lm t L Samples Req'd: ❑ Yes No Mud Log Req'd: ❑ Yes 'No s- 2500 ps ` ^,� r 0, H Measures: [ Yes ❑ No Directional Survey Req'd: ees ❑ No — Nt.Z`� �.,,.Q �, ` �kr��- 4.rr� y L oS, ' 'I� L (. l�i M .r.�. Dpe,�v41o� i K. a,e.c.dFa� ..,,: Tom� 'n VV U o ��C Z5.a33 ej) Az° Lit P (t rfMtcX ( a c c at (d < 1000 a - J APPROVED BY THE COMMISSION / Date �' , COMMISSIONER Form 10-401 R v ised /2009 Thiser i yallf 14 o the from the date of a 0 AAC 25.005(9)) Sub it In Duplicate i�1 L // go • o? 0//40/x7 • • To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: John Rose - ODE Date: November 2, 2009 p Re: PBU 03 -37i Permit to Drill Approval is requested for the drilling of the 03 -37i grassroots Sag/Ivishak water injector. For the planned drilling of this well, 20" conductor casing will be run and cemented to -80' at this surface location which is located -60 south of the current 03- 18 surface location. From there, the basic drilling plan will include a 12 -1/4" surface hole to 3831' MD (SV3) where 9 -5/8" surface casing will be run and cemented to surface. An 8 -3/4" intermediate hole will then be drilled from the 9 -5/8" casing shoe to the top of the Sag River formation - 10,004' MD where a 7 ", 26.0# intermediate casing string will run and cemented with the proposed cement top to be -750' below the surface casing shoe. A 6 -1/4" injection interval will then be drilled with the final well TD at - 10,518' MD where a 4 -1/2", 12.6# solid liner will be run and fully cemented. The planned completion for this well will include a 4 - ", 12.6# tubing, with a single permanent packer. The 03 -37i well is currently scheduled to be drilled by Doyon 14 with a spud date of -01/15/10. Please refer to the additional data within this request for specific well details and do not hesitate to call if I additional information is required. John Rose - ODE Office - 564 -5271 Cell - 748 -5223 03 -37ii Grass -roots Ivishak Injector 11/2/2009 • 1 Well Name: 03 -37i Drill and Complete Plan Summary I Type of Well (service / producer / injector): 1 Sag /Ivishak Water Injector (w /MI potential) I Target X Y Z TVDss Township Range Section FSL FEL Surface (As- Built) 713,126 5,937,469 10N 15E 10 1433 132 TSAG 709,752 5,934,955 -8628 10N 15E 15 4294 3579 TSAD 709,688 5,934,898 -8732 10N 15E 15 4239 3645 BHL 709,524 5,934,752 -9041 10N 15E 15 4097 3813 AFE Number: 1 PBD4P3021 I I API Number: 1 I I Estimated Start Date: 1 01/15/2010 I I Operating days: 1 22.1 I 1 Rig: 1 Doyon 14 - I I TMD 1 10,518' 1 I TVD rkb: 1 9097' I I RKB /GL 27.5'/28' I I RTE 55.5' I Well Design: USH w/4 -1/2" Carbon Completion I Current Status: New Drill General Well Information: Estimated BHP: 3250 psi at 8657' TVDss (7.2 ppg) . I Estimated BHT: 190 deg F at 8800' TVDss (NOTE: Conductor pipe not yet set.) 03371 Wellplan 2 11/2/2009 • • Formation Markers: I Formation SSTVD MD TVD Thick MD Thick Angle / Pore Pressure SHL 0 0 1855 1971 0.0 Base of Permafrost ** -1855 1971 765 815 20.3 SV5 - 2620 2786 380 405 20.3 SV4 - 3000 3191 600 639 20.3 SV3 (9 - 5/8" Csg) - 3600 3830 206 220 20.3 SV2 - 3806 4050 396 421 20.2 SV1 - 4202 4471 648 692 20.3 UG4 - 4850 5163 32 34 20.2 UG4A - 4882 5197 106 114 20.2 UG3 - 4988 5311 836 890 20.3 UG1 - 5824 6201 491 534 20.3 WS2 - 6315 6735 235 277 28.8 WS1 - 6550 7012 269 356 36.8 CM3 - 6819 7368 475 715 45.2 CM2 - 7294 8083 703 1062 48.6 CM1 - 7997 9145 361 507 48.6 THRZ - 8358 9652 197 257 40.0 BHRZ - 8555 9909 32 42 40.0 TJ - 8587 9951 41 53 40.0 TSGR (7" Lnr) - 8628 10004 29 38 40 / 3250 psi * TSHA - 8657 10042 75 96 39.4 / 3250 psi * 46P TSAD - 8732 10138 121 152 38.1 / 3250 psi * 42N - 8853 10290 62 76 36.6 / 3250 psi * 31P - 8915 10366 69 84 35.1 / 3250 psi * 27P - 8984 10450 57 67 33.6 / 3250 psi * 26P TD (4 -1/2" Lnr) -9041 10517 32.7 / 3250 psi * Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Connection Length Top Btm Tbg O.D. (ft) MD/TVD MD/TVD RTE (ft) RTE (ft) 42" 20" insulated 215.5 A -53 WLD 108 GL 108/108 12 - /a" 9 -5/8" 40 L -80 BTC 3831 GL 3831/3656 8 -1/2" 7" 26 L -80 TC -II 6900 GL 6900/6513 - 8 -1/2" 7" 26 L -80 BTC -M 3104 6900/6513 10,004/8684 6 -W 4 -1/2" 12.6 L -80 TC -II 664 9854/8569 10,518/9097 Tubing 4 -1/2" 12.6 L -80 TC -II 9860 GL 9860/8575 Directional: 1 Directional Plan: Schlumberger P1 b (Ref Elev: xx.x' MD) KOP: 500' MD, begin 1.0/100 build Close Approach Wells: K03 -07 well does not pass Major Risk analysis, however, as an abandon well, ,.- it will be Minor Risk at 1:200. (See P1 b anti - collision report for details.) Survey Program: Gyro Single Shots (500'), MWD- Standard (500' - 1900'), MWD + IFR + MS (500' — 10,004') Maximum Hole Angle: 49 degrees f/7421' MD Distance to Nearest Property Line: 13,725' to IPA boundary Distance to Nearest Well in Pool: 455 Ft. to 03 -07 (Stk'ed to the 03 -07A, 1486 Ft. to 03 -07A 03 -37i W ellplan 3 11/2/2009 • . Mud Program: 12 -1/4" Surface Hole Mud Properties 1 Drilplex Interval Density PV YP PH LSYP FL 0 -1971' ( -BPRF) 8.8 -9.2 ALAP 50 - 70 10.8 35 - 50 NC 1971' -3831' (SV3) 9.2-9.5 ALAP 35 - 60 10.8 25 - 35 NC p 8 -1/2" Intermediate Hole Mud Properties I Freshwater Mud (LSND) Interval Density PV YP PH API Filtrate MBT 3831' -4472' (TSV1) 8.8 -9.3 12 -18 18 -24 9 -10 <8 < 15 F 4472' -6201' (TUG1) 9.0 -9.3 12 -18 18 -24 9 -10 <8 < 15 6201' -9651' (THRZ) 9.3 -9.4 12 -18 18 -24 9 -10 <6 < 15 9651'- 10,004' (TSAG) 10.5 12 -22 18 -28 9 -10 <4 < 18 6 -' /8" Production Hole Mud Properties 1 FloPro -SF Interval Density PV YP PH API Filtrate MBT / LGS 10,004'- 10,518' 8.4 -8.6 6 -12 22 -28 9.0 -9.5 6 -8 <4 / 3% • (Final Well TD) Survey and Logging Program: 12 -' /4" Hole Section: Surface Gyro until MWD surveys are clean. MWD / LWD: Dir /GR (real time) Open Hole: None . ` Cased hole: None 8 -1/2" Hole Section: Sample as required by well site Geologist MWD / LWD: DIR /GR /RES /PWD (real time) + Neu /Den (recorded) Open Hole: None Cased Hole: SCMT /USIT log to be run with the open -hole logging work planned for the 6 -1/8" hole. 6 -' /8" Hole Section: Sample as required by well site Geologist MWD / LWD: DIR /GR /RES /NUE /DEN (real time) ._ Open Hole: DPS /Sonic Scanner on e-line Cased Hole: SCMT /USIT log to be run post -rig prior to perforating the well if desired /needed. Cement Calculations: (CONFIRM ALL VOLUMES ASSOCIATED W /ALL CEMENT JOBS) Casin Size 1 Surface Casing - 9-%", 40 lb /ft, L -80, BTC - Single Stage Basis Lead: Open hole volume + 350% excess in permafrost and 40% excess below permafrost. TOC at surface. Tail: Open hole volume + 40% excess + 80' shoe track. TOC -500' MD above shoe to -3331' MD. Fluid Sequence and A TAM port collar may be located at 1,000' as a contingency for getting cement to Volume: surface. Wash None Spacer 100 bbls of MudPush II weighted to 10.0 ppg Lead 597 bbls (752 sks) 10.7 lb/gal ASL - 4.44 cuft/sk Tail 45 bbls (251 sks) 15.8 lb/gal Class G - 1.17 cuft/sk Temp 1 BHST - 75° F 03 -37i Wellplan 4 11/4/2009 I • 1 Casin Size 1 Intermediate Casing - 7 ", 26 lb/ft, L -80, BTC -M x TC -II - Single Stage Basis Lead: Open hole volume + 30% excess from top of tail at 9004' MD to top SV1 at 4472' MD. Tail: Open hole volume + 30% excess + 80' shoe track. TOC 1000' above 7" shoe to -9004' MD. Fluid Sequence and None Volume: Wash None Spacer 70 bbl of MUDPUSH XL Spacer weighted to 10.8 -Ib /gal Lead 132 bbl (216 sks) 11.0 ppg LiteCRETE + Latex - 3.43 cuft/sk Tail 29 bbl (141 sks) 15.8 ppg Class G cement - 1.17 cuft/sk Temp J BHST 194° F Casing Size 1 Production Liner - 4 - ", 12.6 lb /ft, L -80, IBT -M - Single Stage Basis Lead: None Tail: Open hole volume + 30% excess + 150' of liner lap + 80' shoe track + 200' of 7" x 4" DP annulus volume. TOC at liner top (10,039' MD) Fluid Sequence and Wash None Volume: ' Spacer 20 bbls of Mudpush 11 Weighted to 11 ppg Tail 25 bbls (121 sks) 15.8 lb/gal Class G Cement + Silica + Latex -1.17 cuft/sk Temp 1 BHST = 200° F Surface and Anti - Collision Issues: • With the 03 -18 well being -60' north and the 03 -17 well being -60' south, no surface shut -in's will be required to move onto this well. • Close Approach Wells: With the exception of the 03 -07 well (currently abandoned / this well is currently sidetracked to the 03 -07A BHL) which pass a Minor Risk scan at 1/200, all wells have passed the Major Risk scan, therefore, no wells will require sub - surface shut -in during drilling operations. Reference the Anti - Collision report in the directional plan for a full list of offset well paths and the Tolerable Risk Worksheet in the current wellplan folder on the S- drive. Close Approach Well List: Close Ctr -Ctr Reference Allowable Comments/Well Status Approach Distance MD Deviation Well 03 -07 252' 10,248 -633' Abandon Drilling Waste Disposal: • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS -04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class 11 wastes to DS -04 for injection. Haul Class I waste to DS -04 and /or Pad 3 for disposal / Contact the GPB Environmental Advisors (659- 5893) f /guidance. I 03 -37i Wellplan 5 10/29/2009 • Well Control Surface hole will be drilled with a diverter. The intermediate and production hole sections will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind /shear rams, and annular preventer. This equipment is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4000 psi. Notes: 1. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. 2. Full ram tests are required when rams are changed. 3. BOP test frequency will be 14 days. 4. BOP function test frequency will be 7 days. Surface Section • BOPE: A tested diverter system per AOGCC regulations • Maximum anticipated BHP: 1620 psi — SV3 (8.5 ppg EMW @ 3656 TVDss) • Maximum surface pressure: 1254 psi — Based on a full column of gas @ 0.10 psi /ft • Planned BOP test pressure: Function Test • 9 -5/8" Casing Test: 3500 psi surface pressure test • Kick Tolerance: NA Intermediate Section Kick Tolerance and Integrity Testing • BOPE: Hydril, 13 -5/8 ", 5000 psi • Maximum anticipated BHP: 3250 psi — Top Sag River (7.2 ppg EMW @ -8628' TVDss) • Maximum surface pressure: 2387 psi — Based on a full column of gas @ 0.10 psi /ft • Planned BOP test pressure: 4000 psi /250 psi Rams and 2500 psi /250 psi Annular • 7" Casing Test: 4000 psi surface pressure test • Integrity Test — 8 -1/2" hole: LOT 20' — 50' from 9 -%" shoe • Kick Tolerance: 67 bbl KT with a 9.3 ppg mud and a 10.4 ppg LOT (11.9 ppg LOT needed f /ECD management) Production Section Kick Tolerance and Integrity Testing • BOPE: Hydril, 13 -5/8 ", 5000 psi • Maximum anticipated BHP: 3250 psi — TSAD (7.2 ppg @ -8732' TVDss) • Maximum surface pressure: 2377 psi — Based on a full column of gas @ 0.10 psi /ft • Planned BOP test pressure: 4000 psi /250 psi Rams and 2500 psi /250 psi Annular • 4'h" Liner Test: 4000 psi surface pressure test • Integrity Test — 6 -'/a" hole: FIT 20' — 50' from 7" shoe • Kick Tolerance: Calculated an Infinite KT with a 8.5 ppg mud with 9.0 ppg FIT /LOT (11.0 ppg FIT /LOT needed f /ECD management) • Planned completion fluid: 8.5 ppg Seawater / 6.8 ppg Diesel Varience Request: • To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, i it is requested to drill without a flow paddle for the first portion of the surface hole. While the flow paddle is removed from the flow line, PVT alarms will be used and the pit levels accurately monitored for any pit gain. Also, a visual check will be made during connections by looking down the riser to ensure the well is not flowing. After returned debris that could plug the flow line diminishes the flow paddle will be reinstalled. 03 -37i Wellplarr & 11/22009 • • 03 -37i Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures: Normal pore pressures (8.5 ppg) are expected throughout surface hole drilling operations. Normal pore pressures (8.5 ppg) are also expected throughout the intermediate hole drilling operations, however, Cretaceous injection pressures up to 9.4 ppg may be encountered from the top of the UG1 to the base of the West Sak formation. For the production interval of the well, the Ivishak reservoir is expected to be pressured to 7.2 ppg EMW. II. Hydrates and Shallow gas: No gas hydrates or shallow gas is anticipated, however, follow good drilling practices in the regards at all times. III. Lost Circulation / Breathing: Lost circulation on the surface hole cement jobs has been a problem on this pad. Well breathing problems are a possibility in the intermediate hole after weighting -up the mud to 10.5 ppg for the HRZ. Lost circulation in the reservoir section is considered low. Follow the RP guidelines for dealing with Lost Circulation problems when /if they occur. IV. Kick Tolerance / Integrity Testing: Intermediate Section Kick Tolerance and Integrity Testing • Integrity Test — 8 -3/4" hole: LOT 20' — 50' from 9 -%" shoe • Kick Tolerance: 67 bbl KT with a 9.3 ppg mud with a minimum 10.4 ppg LOT (NOTE: Need an 11.9 ppg FIT /LOT to satisfy ECD management requirements.) Production Section Kick Tolerance and Integrity Testing • Integrity Test — 6 - %" hole: FIT 20' — 50' from 7" shoe • Kick Tolerance: Calculated an Infinite KT with an 8.5 ppg mud with 9.0 ppg FIT /LOT (NOTE: Need a 11.0 ppg FIT /LOT to satisfy ECD management requirements.) V. Stuck Pipe There will be some differential sticking tendencies across upper sands in the intermediate hole with the planned 10.5 ppg mud weight in the hole and in the production interval of the well while drilling with the 8.5 ppg plus FloPro, therefore, follow good drilling practices and good casing /liner running practices for both intervals of this well. VI. Hydrogen Sulfide DS03 is considered an H2S pad (see off -set well data below), therefore, follow Standard Operating Procedures for H2S at all times. Please review this document to confirm compliance. Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level 03 -15AL1 10 ppm 10/5/2009 #2 Closest SHL Well H2S Level 03 -25A 70 ppm 6/1/2009 #1 Closest BHL Well 112S Level 03 -21 140 ppm 11/25/2008 #2 Closest BHL Well H2S Level 03 -19 70 ppm 6/29/2009 Max. Recorded H2S on Pad/Facility 03 -32 800 ppm 11/24/2001 Other Relevant H2S Data DS 03 is an H2S area (H2S alarms from rigs, etc.) VII. Faults There is a single fault crossing in the current directional plan which encounters a fault in the CM1 (see below) and NO drilling problems are anticipated with this fault crossing. SSTVD Throw Formation Where Encounter Fault MD Intersect Intersect Est. Throw Direction Uncertainty Fault #1 - Crossed in CM1 8560 -8288 24 dk E + / -100 ft MD CONSULT THE DS3 -PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 03 -37i Wellplan 7 10/29/2009 • • 03 -37i Drill and Complete Procedure Summary (10/29/09) Pre -Rig Operations: 1. Install 20" conductor casing. 2. Weld an FMC landing ring on the conductor. 3. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MI /RU. 2. Nipple up the diverter spool and riser. P/U sufficient length of 4" drill pipe to TD the surface hole and stand back in the derrick. 3. M/U a 12 -1/4" drilling assembly with Dir /GR (real- time). Spud and directionally drill surface hole to the base of the permafrost. Gyro data will be required until clean surveys can be taken (- 500'). Circulate and condition hole. Short trip to the top of the heavy weight drillpipe and /or pull out of hole for a new bit if necessary. 4. Run back in hole and drill the remainder of the surface hole to the planned surface hole to TD in a shale member of the upper SV3 sand at -3831' MD. POOH and UD BHA. 5. Run and cement the 9-%", 40 #, BTC, L -80 casing back to surface. NOTE: A TAM port collar may be run as a contingency if hole conditions indicate a problematic primary cement job. 6. Test the 9-%" casing to 3500 psi for 30 minutes and record the test. 7. N/D the riser spool and N/U the FMC Gen 5 casing head and tubing spool. 8. N/U the BOPE and test to 4000 psi. 9. MU 8 -3/4" drilling assembly with real -time MWD /GR /Res /PWD and RIH picking -up 4" drill pipe as required to drill/TD the 8 -3/4" hole into the top of the Sag River formation. 10. Drill out cement, float equipment, and the shoe. Displace the well as required with new -8.8 ppg LSND drilling fluid. Drill approximately 20' new formation and perform the planned LOT. 11. Drill ahead in the 8 -3/4" hole per the directional plan targeting a minimum weight of 9.3 ppg by the top of the UG1 at 5924' MD and then a 10.5 ppg mud weight by the top of the HRZ at 9652' MD. 12. Continue drilling the 8 -3/4" hole to the planned TD at - 10,004' MD -5' MD below the top of the Sag River formation. 13. Condition hole as necessary to run the 7" casing and POOH. 14. Run and cement the 7 ", 26 #, L -80 intermediate casing (TC -II & BTC -M connections) to TD. NOTE: While the base -case is to land the casing on a mandrel hanger, emergency "slips" should be available if hole conditions dictate. 15. Confirm that the OA is "open" by moving small volumes of mud down the annulus as soon as possible after the cement job. Freeze - protect the 9 -%" x 7" annulus, once the tail cement has reached 500 psi compressive strength. Ensure that the mud /diesel /brine in the OA is overbalanced to formation at the 9 -%" shoe ( -8.5 ppg). 16. M/U a 6 -W MWD /LWD drilling assembly. P/U additional 4" drill pipe as required to TD the well and RIH to top of the float collar and test the casing to 4000 psi f /30 minutes and chart. 17. Displace the well to 8.5 ppg Flo -Pro mud. 18. Drill out shoe and 20' of new formation and perform the planned FIT. Drill ahead, per directional proposal and rig site geologist, to well TD at approximately 10,518' MD. 19. Condition the hole as required in preparation for the planned open -hole logs and running and cementing the 4- 'h" production liner. 20. POOH, VD excess 4" drill pipe and BHA. 21. RU E -line and run Sor is Scanner (which includes a cement bond loq capability_(CBL/VDL) log from the 6 -1/8" TD back to some point in the 7" casing per well -site eo sset (prefer running the CBL/VDL log to surface to confirm the TOC and to confirm the 9 -5/8" x 7" annulus to be clear of cement.)) 22. If hole is in good condition, R/U and run the 4'h ", 12.6 #, L -80, IBT -M liner. 23. Cement the liner per program bumping the plug with clean seawater. Release from the liner and set the packer and circulate excess cement to surface displacing the well to clean seawater above the liner top. 24. POOH and inspect and VD liner running tools. 25. After cement reaches a minimum 1000 psi compressive strength, R/U and pressure test the well to 4000 psi for 30 minutes and record the test. 26. R/U and run a 4 -1/2", 12.6 #, L -80, TC -II completion. Space and land the tubing with the tubing tail inserted into the liner tie back sleeve. RILDS. Install TWC and test. 27. N/D the BOPE. 03 p -37i Well Ian 8 10/29/2009 • • 28. N/U the adapter flange and tree. 29. RU DSM. Pull TWC. 30. Reverse circulate filtered seawater, followed by inhibited seawater, followed by diesel freeze protect down the IA and U -tube the diesel freeze protect into place through the tree. 31. Drop ball /rod through the tree pressure up on the tubing side with diesel to set the completion packer. 32. Individually test the tubing and annulus to 4000 psi for 30 minutes and record each test. 33. Test tree and adapter to 5,000 psi with diesel. 34. Install a BPV. 35. Secure well / RD and move -off well. Post -Riq Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. RU E -line and run SCMT log across the 4 -1/2" production liner if required /desired to confirm the quality of the cement job on the 4-1/2" liner. 3. With E -line, perforate well per the Asset. 4. Install the well house, instrumentation, and flow line. (NOTE: This work will be completed under a separate AFE.) 03 -37i Wellplan 9 10/29/2009 KB. = = Propceed Completion • W ' Gen 5 Br_ ELEV = KOP = 500' � CSG HEAD = 1 1 " 5M W _ / 7" MANDRE- Mai Angle = 49 deg at 7421' HANGER & PACKOFF Datum MD = TBG SPOOL = 11"X 11" SM Datum TVD= 20 " Conductor - 80`MD TBG HANGER = 11 "X4-112" AD? FLANGE = 11" X 4-1/16" 1 4 -1/2" X- Nipple at -2200 MD (3.813" ID) ® _1 3,831' H9 -518 ", 40 # /ft, L -80, BTC, ID = 8.835" TOC behind 7" Casing at -4581' MD — — Minimum ID = 3.725" @ ' 4 -1/2" HES XN- NIPPLE 1 1 9,730' H HES 4 -1/2" X NIPPLE; LD. 3.813" 1 ,o�.� I, 9,750' -- H BAKER PKR 7" X 4 -1/2" S -3, ID = 3.88 ", 1 2' TBS I 1 ; 9,780' HES 4 -1 /2" X NIPPLE; ID = 3.813" I 9850' MD - HES 4 -1/2" XN- Nipple, ID = 3.725" 4 -1/2 ", 12.6 # /ft, L -80, TC -II, — 9,$60' ID = 3.958" 7 " 7" x 4 -1/2" Baker Flex -Loc Liner Hanger (ID = 2.992 ") w/ � I 9,854 — ZXP Liner Top Pkr wt 10' TBS (ID = 5.25 ") 10,004' — 7 ", 26 #!ft, L -80, BTC -M (f110,004' to 7000' MD) & TC- II (f /7000' to Surf), ID = 6.276" [ 110,1001-14-1/2", 12.6 #, L -80, IBT -M, MARKER JT PERFORATION SUMMARY RE • LOG: CAMCO GR/SSL ON 07/12/91 ANGLE AT TOP PERF: 45 @ 11250' Note: Refer to ProduStion DB for historiSal pert data SEE' SPF INTExZi/AL ' Opn/Sqz DATE 10,438'H4 -112" PBTD ( 4 110,5181- 14 -1/2 ", 12.6 #, L -80, IBT -M, ID = 3.958 ". 0.01522 BPF J DATE REV BY COMMENTS DATE ' REV BY COMMENTS PRUDHOE BAY UNIT 10/19/09 jgr Drill & Complete WELL: DS03 -371 PERMIT No: API No: BP Exploration (Alaska) by 0 DS03 -37 (P1 b) Proposal $chlumberger Report Date: October 19, 2009 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 236.780° Field: Prudhoe Bay Unit - EOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: DS - / 03 - plan �� �d TVD Reference Datum: Rotary Table Well: Plan 03 - 37 �;�; TVD Reference Elevation: 55.5 ft relative to MSL Borehole: Plan 03 - Fe a Sea Bed / Ground Level Elevation: 28.000 ft relative to MSL UWI/API #: 50029xxxxx00 Magnetic Declination: 22.486° Survey Name / Date: 03 -37 (P1 b) / October 19, 2009 Total Field Strength: 57690.120 nT • Tort / AHD / DDI / ERD ratio: 71.471° / 4651.65 ft / 5.585 / 0.511 Magnetic Dip: 80.932° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: February 07, 2010 Location Lat/Long: N 70.23213573, W 148.27927486 Magnetic Declination Model: BGGM 2009 Location Grid N/E Y /X: N 5937461.100 ftUS, E 713142.500 ftUS North Reference: True North Grid Convergence Angle: +1.61937967 Total Corr Mag North -> True North: +22.486° Grid Scale Factor: 0.99995161 Local Coordinates Referenced To: Well Head Measured Azimuth Vertical NS EW Mag / Gray Directional Comments Depth Inclination True Sub-Sea TVD TVD Section True North True North Tool Face DLS Difficulty Northing Easting (ft ) (deg) (deg) (ft ) (ft ) (ft ) (ft ) (ft ) (deg) (deg /100ft ) Index (ftUS) (ftUS) RTE 0.00 0.00 250.14 -55.50 0.00 0.00 0.00 0.00 - -- 0.00 0.00 5937461.10 713142.50 WRP 28.50 0.00 250.14 -27.00 28.50 0.00 0.00 0.00 - -- 0.00 0.00 5937461.10 713142.50 KOP Bld 1/100 400.00 0.00 250.14 344.50 400.00 0.00 0.00 0.00 250.14M 0.00 0.00 5937461.10 713142.50 Bld 2.5/100 500.00 1.00 250.14 444.49 499.99 0.85 -0.30 -0.82 250.14M 1.00 0.00 5937460.78 713141.69 600.00 3.50 250.14 544.41 599.91 4.67 -1.63 -4.51 250.14M 2.50 1.23 5937459.34 713138.04 700.00 6.00 250.14 644.06 699.56 12.72 -4.44 -12.30 HS 2.50 1.89 5937456.31 71333 800.00 8.50 250.14 743.25 798.75 25.00 -8.73 -24.17 HS 2.50 2.34 5937451.69 71 59 900.00 11.00 250.14 841.80 897.30 41.48 -14.48 -40.10 HS 2.50 2.67 5937445.49 713102.83 1000.00 13.50 250.14 939.51 995.01 62.12 -21.69 -60.05 HS 2.50 2.94 5937437.73 713083.09 1100.00 16.00 250.14 1036.21 1091.71 86.89 -30.33 -84.00 HS 2.50 3.16 5937428.41 713059.40 1200.00 18.50 250.14 1131.71 1187.21 115.74 -40.40 - 111.89 HS 2.50 3.35 5937417.55 713031.81 End Cry 1269.97 20.25 250.14 1197.72 1253.22 138.32 -48.29 - 133.72 - -- 2.50 3.46 5937409.06 713010.21 Base Perm 1970.56 20.25 250.14 1855.00 1910.50 374.23 - 130.64 - 361.78 - -- 0.00 3.90 5937320.29 712784.57 SV4 3190.99 20.25 250.14 3000.00 3055.50 785.19 - 274.11 - 759.07 - -- 0.00 4.23 5937165.66 712391.52 9 -5/8" Csg 3830.51 20.25 250.14 3600.00 3655.50 1000.54 - 349.29 - 967.26 - -- 0.00 4.34 5937084.64 712185.55 WellDesign Ver SP 2.1 Bld( users) 03 -37 plan \Plan 03 -37 \Plan 03- 37 \03 -37 (P1 b) Generated 10/19/2009 1:50 PM Page 1 of 3 • Measured Azimuth Vertical NS EW Mag I Gray Directional Comments Depth Inclination True Sub -Sea TVD TVD Section True North True North Tool Face DLS Difficulty Northing Easting (ft) _ (deg) (deg) (ft) (ft ) (ft ) (ft ) (ft ) (deg) (deg/100ft ) Index (ftUS) (ftUS) SV3 3830.52 20.25 250.14 3600.01 3655.51 1000.54 - 349.29 - 967.26 - -- 0.00 4.34 5937084.64 712185.55 SV2 4050.08 20.25 250.14 3806.00 3861.50 1074.48 - 375.10 - 1038.73 - -- 0.00 4.37 5937056.82 712114.83 SV1 4472.17 20.25 250.14 4202.00 4257.50 1216.61 - 424.72 - 1176.14 - -- 0.00 4.42 5937003.34 711978.90 UG4 5162.86 20.25 250.14 4850.00 4905.50 1449.18 - 505.91 - 1400.98 - -- 0.00 4.50 5936915.83 711756.45 UG4A 5196.97 20.25 250.14 4882.00 4937.50 1460.67 - 509.92 - 1412.08 - -- 0.00 4.51 5936911.51 711745.46 UG3 5309.95 20.25 250.14 4988.00 5043.50 1498.71 - 523.20 - 1448.86 - -- 0.00 4.52 5936897.19 711709.08 UG1 6201.02 20.25 250.14 5824.00 5879.50 1798.77 - 627.95 - 1738.93 - -- 0.00 4.60 5936784.30 711422.09 Cry 3/100 6388.62 20.25 250.14 6000.00 6055.50 1861.94 - 650.00 - 1800.00 45.66L 0.00 4.61 5936760.53 711361.68 6400.00 20.49 249.45 6010.67 6066.17 1865.80 - 651.37 - 1803.72 45.01L 3.00 4.62 5936759.05 711358.00 6500.00 22.71 243.94 6103.65 6159.15 1902.03 - 665.99 - 1837.45 39.89L 3.00 4.69 5936743.48 7119 6600.00 25.08 239.40 6195.09 6250.59 1942.36 - 685.26 - 1873.04 35.74L 3.00 4.75 5936723.22 711289.67 6700.00 27.56 235.62 6284.72 6340.22 1986.67 - 709.12 - 1910.38 32.34L 3.00 4.80 5936698.31 711253.01 WS2 6734.30 28.44 234.46 6315.00 6370.50 2002.77 - 718.35 - 1923.58 31.32L 3.00 4.82 5936688.72 711240.09 6800.00 30.14 232.42 6372.30 6427.80 2034.85 - 737.51 - 1949.38 29.54L 3.00 4.86 5936668.84 711214.83 6900.00 32.78 229.69 6457.60 6513.10 2086.75 - 770.34 - 1989.93 27.21L 3.00 4.91 5936634.88 711175.23 7000.00 35.47 227.32 6540.38 6595.88 2142.25 - 807.53 - 2031.91 25.25L 3.00 4.95 5936596.52 711134.32 WS1 7011.84 35.79 227.06 6550.00 6605.50 2149.05 - 812.21 - 2036.97 25.04L 3.00 4.96 5936591.69 711129.40 7100.00 38.20 225.26 6620.41 6675.91 2201.18 - 848.97 - 2075.22 23.59L 3.00 5.00 5936553.87 711092.21 7200.00 40.97 223.42 6697.47 6752.97 2263.39 - 894.56 - 2119.72 22.18L 3.00 5.04 5936507.05 711049.01 7300.00 43.76 221.79 6771.36 6826.86 2328.70 - 944.16 - 2165.31 20.97L 3.00 5.08 5936456.18 711004.85 CM3 7367.02 45.64 220.78 6819.00 6874.50 2374.12 - 979.59 - 2196.40 20.26L 3.00 5.11 5936419.89 710974.77 7400.00 46.57 220.31 6841.87 6897.37 2396.94 - 997.64 - 2211.85 19.93L 3.00 5.13 5936401.40 710959.84 End Cry 7471.21 48.58 219.34 6889.90 6945.40 2447.21 - 1038.02 - 2245.50 - -- 3.00 5.15 5936360.10 710927.34 CM2 8082.02 48.58 219.34 7294.00 7349.50 2884.19 - 1392.27 - 2535.85 - -- 0.00 5.24 5935997.79 710647.13 CM1 9144.65 48.58 219.34 7997.00 8052.50 3644.39 - 2008.57 - 3040.96 - -- 0.00 5.35 5935367.50 7106 Cry 3/100 9226.17 48.58 219.34 8050.94 8106.44 3702.72 - 2055.85 - 3079.72 142.77R 0.00 5.36 5935319.14 710122.26 9300.00 46.83 221.17 8100.62 8156.12 3755.06 - 2097.53 - 3114.99 141.54R 3.00 5.39 5935276.49 710088.18 9400.00 44.51 223.84 8170.50 8226.00 3824.36 - 2150.28 - 3163.29 139.68R 3.00 5.42 5935222.40 710041.40 9500.00 42.26 226.72 8243.17 8298.67 3891.65 - 2198.63 - 3212.06 137.58R 3.00 5.45 5935172.70 709994.02 9600.00 40.09 229.87 8318.45 8373.95 3956.74 - 2242.44 - 3261.16 135.21R 3.00 5.48 5935127.51 709946.17 End Cry 9604.09 40.00 230.00 8321.58 8377.08 3959.35 - 2244.14 - 3263.18 - -- 3.00 5.48 5935125.76 709944.20 THRZ 9651.63 40.00 230.00 8358.00 8413.50 3989.70 - 2263.78 - 3286.59 - -- 0.00 5.48 5935105.47 709921.36 BHRZ 9908.80 40.00 230.00 8555.00 8610.50 4153.84 - 2370.03 - 3413.22 - -- 0.00 5.50 5934995.68 709797.79 TJB 9950.57 40.00 230.00 8587.00 8642.50 4180.51 - 2387.29 - 3433.79 - -- 0.00 5.50 5934977.85 709777.72 WellDesign Ver SP 2.1 Bld( users) 03 -37 plan \Plan 03 -37 \Plan 03- 37 \03 -37 (P1b) Generated 10/19/2009 1:50 PM Page 2 of 3 • Measured Azimuth Vertical NS EW Mag 1 Gray Directional Comments Depth Inclination True Sub -Sea TVD TVD Section True North True North Tool Face DLS Difficulty Northing Easting (ft) _ (deg) (deg) (ft ) (ft ) (ft) (ft ) (ft ) (deg) (deg /100 ft) Index (ftUS) (ftUS) TSAG 10004.08 40.00 230.00 8627.99 8683.49 4214.66 - 2409.40 - 3460.14 - -- 0.00 5.51 5934955.01 709752.01 Target 10004.09 40.00 230.00 8628.00 8683.50 4214.67 - 2409.41 - 3460.14 - -- 0.00 5.51 5934955.00 709752.00 7" Csg 10004.11 40.00 230.00 8628.01 8683.51 4214.68 - 2409.41 - 3460.15 - -- 0.00 5.51 5934954.99 709751.99 Cry 10/100 10024.09 40.00 230.00 8643.32 8698.82 4227.43 - 2417.67 - 3469.99 LS 0.00 5.51 5934946.46 709742.39 TSHA 10041.92 39.73 230.00 8657.00 8712.50 4238.78 - 2425.01 - 3478.74 LS 1.50 5.51 5934938.87 709733.85 10100.00 38.86 230.00 8701.95 8757.45 4275.31 - 2448.66 - 3506.92 LS 1.50 5.52 5934914.44 709706.35 TSAD (46P) 10138.44 38.28 230.00 8732.00 8787.50 4299.11 - 2464.06 - 3525.28 LS 1.50 5.53 5934898.53 709688.44 10200.00 37.36 230.00 8780.63 8836.13 4336.59 - 2488.33 - 3554.20 LS 1.50 5.54 5934873.45 709660.21 10300.00 35.86 230.00 8860.90 8916.40 4395.81 - 2526.66 - 3599.88 LS 1.50 5.55 5934833.85 7093 10400.00 34.36 230.00 8942.70 8998.20 4452.93 - 2563.63 - 3643.94 LS 1.50 5.57 5934795.65 709 .64 10500.00 32.86 230.00 9025.98 9081.48 4507.89 - 2599.21 - 3686.35 LS 1.50 5.58 5934758.88 709531.26 TD / 4 -1/2" Lnr 10517.86 32.59 230.00 9041.00 9096.50 4517.48 - 2605.42 - 3693.74 - -- 1.50 5.58 5934752.47 709524.04 Legal Description: Northing (Y) IftUS1 Easting (X) (ftUSl Surface : 1425 FSL 116 FEL S10 T1ON R15E UM 5937461.10 713142.50 Target : 4294 FSL 3579 FEL S15 T1ON R15E UM 5934955.00 709752.00 BHL : 4098 FSL 3813 FEL S15 T1ON R15E UM 5934752.47 709524.04 WellDesign Ver SP 2.1 Bld( users) 03 -37 plan \Plan 03 -37 \Plan 03- 37 \03 -37 (P1 b) Generated 10/19/2009 1:50 PM Page 3 of 3 by 10 • • Schiumberger WELL DS03 -37 (P1b) I FIELD Prudhoe Bay Unit - EOA I STRUCTURE DS -03 Magnetic Parameters Solace Location NAD27 Alaska State Planes. Zone 04. US Feet Miscellaneous Model: 9GGM 2009 Dip'. 80932° Date: February 07. 2010 La. N701355.649 Northing. 5937461 10 SUS Gnd C074: •161937967° Sot'. 03 -37 plan We Ref: Rotary Table (55.50 ft above MSL) Mag Dec'. •22486° FS: 57890.1 n7 Lon: W1481645.389 Easting: 713142.50 SUS Scale Fact 09999516082 Plan: 03 -37 (Fib) S.ey Data: October 19 2009 -1200 0 1200 2400 3600 4800 0 RTE 0 WRP KOP Bld 1/100 Bld 2.5/100 End Cry 1200 1200 `ase Perm 2400 • 2400 - _.._.._.._.. _.. _.._..— ..i..— ..— ..— .. —.._ V4 . —.._.. _.._..__•__•_••_••_••_• —..—.._..—..—..—..—..—..—«—..—..—. .— ..— ..— .._.._..— ..— ..— .. «. — 9-5/8" Csg 3600 ..-_..-..-..- ..- ..- ..- ....._.._..- .._.. -.. -. _ " _..- .,_.._.._..- ..- ..- ..- .._.._ _.._.._..- ..- ..- .. -.._. - - ..- ..- .. - 3600 V3: N C_ 4800 4800 ii 6.) /n a H 6000 Gi Cry 3/100 6000 ----°°_.._.._.._..-..-..-..-..-..-..-..- ..- ..- ..- ..- .. « - .._.._.._.._ S2. -- _.._.._ ..- ..------------ --- .._.._.._.. _.._.._..— .. «.— ..— ..— .. —... End Cry 7200 7200 • Cry 3/100 End Cry ,..�...�«..«...,.�,� ........ Targ 8400 RZ r Cog 8400 _ _ _ _ _ _ _ _ _ _ _ - _ Cry 10 /100 - . °_ ° °_ ° ° ° °.._.._.._. °_ _ _-°_°°...._.._.._ ° °- ° °_ ° °_ ° °_ ° °_ °._.._.._.._ ° °_. _°° _ ° °_.. °._.._.._. ° _ °.- _ _ ._.._ ° TD / 4 -112" Lnr 03-37 (P1b) 9600 • 9600 • -1200 0 1200 2400 3600 4800 Vertical Section (ft) Azim = 236.78 °, Scale = 1(in):1200(ft) Origin = 0 N / -S, 0 E / -V by • Schlumberger WELL DS03 -37 (P1b) I FIELD Prudhoe Bay Unit - EOA I STRUCTURE DS -03 Magnetic Parameters Surface Location N41227 Mesita State Planes, Zone 04, US Feet I Miscellaneous Model' M . BGG 2009 Dip 80 932° Dale February 07. 2010 Let. 1470 13 55 889 Northing 5937461.10 BUS Grid Cone +1 61937967° Slot 03-37 pen TVD Ref. Rotary Table (55 50 h above MSL) Mag Dec. +22486° FS. 576901 nT Lon. W1413 16 45.389 Easeng'. 713142.53 SUS Scale Fad'. 0.9999516082 Plan 03 -37 (PIN Stay Dale. October 19, 2009 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 • • End Cry 0 i - 0 RTE d Bld 2.5/100 • KOP Bid 1/100 -500 ery.3/100 a5/s- c`g -500 A N A I PPA End Cry Z -1000 � -1000 Tif o 0 L 0) 2 -1500 c - -1500 • -2000 -2000 Cry 3/100 End Cry TD / 4.1/2" Lnr - 2500 rar°get -2500 7" Csg Cry 10/100 • 03 -37 (p1b) -3500 -3000 -2500 -2000 -1500 -1000 -500 0 «< W Scale = 1(in):500(ft) E »> • BPPASSPORT Anticollision Report - Company: North America - ALASKA - BP Local Co- ordinate Reference: Well Plan 03-37 Project: Prudhoe Bay TVD Reference: 03 -37 plan @ 55.50ft (Nabors XES) Reference Site: PB DS 03 MIY Reference: - 03 -37 plarr@ 55.50ft (Nabors XES Site Error: 0.00ft North Reference: True Reference Well: -- -Plan- 03-37- -Survey-Calculation-Method: Error: 0.00ft Output errors are at 1.00 sigma - _ Reference Wellbore 03-37 Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan #1 03 -37 Offset TVD Reference: Offset Datum Reference Plan #1 03 -37 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer Interpolation Method interval 5.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results- Limited -by Maxim jm- center- centerdistance-of 1,248.94ft Error- Surfaee: - -El ipticaI-Conis i Survey TooIProgram - Date 10/14/2009" - From To (ft) (ft) Survey (Wetlborej - T Description 28.50 500.00 Plan #1 03-37 (Plan 03 -37) GYD -GC -SS Gyrodata gyro single shots 500.00 1,900.00 Plan #1 03-37 (Plan 03 -37) MWD MWD - Standard 500.00 3,830.00 Plan #1 03-37 (Plan 03-37) MWD +IFR +MS MWD + IFR + Multi Station 3000 5,300.00 - Plan #1 - 03-3 ) - �g . 7�(Plan 03=37 IGtWD MWD - I, 3,830.00 10,004.00 Plan #1 03-37 (Plan 03 -37) MWD +IFR +MS MWD + IFR + Multi Station 10,00400 10, 517.86 - Plan -#1 03- 37-(PIan03 -37) MWD-- - -- - -- MWD- Standard 10,004.00 10,517.86 Plan #1 03-37 (Plan 03 -37) MWD +IFR +MS MWD + IFR + Multi Station it Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Welibore - Design (ft) (ft) (ft) (ft) PB- DS -03- - 03-02 - 03 -02 - 03 -02 6,700.00 7,760.00 844.33 293.45 559.34 Pass - Major Risk 03 -07 - 03 -07 - 03 -07 10,247.91 10,895.00 251.85 996.68 - 632.52 FAIL - Major Risk 03 -07 - 03 -07A - 03 -07A 7,996.98 8,435.00 1,010.36 542.25 468.88 Pass - Major Risk 03 -07 - 03 -07A - 03 -07A wp07 7,795.15 8,220.00 1,068.36 535.23 535.85 Pass - Major Risk G3-15-- 0345 03-1-5 - - X541-6 -1- -- 5,97-0,00- 58 -1.60 335:26- 249-.08- - Pass - - -Major Risk -- - -- 03 -15A - 03-15A - 03 -15A 5,541.61 5,970.00 581.60 335.26 249.08 Pass - Major Risk 03 -15AL1 - 03 -15AL1 - 03 -15AL1 5,536.77 5,965.00 581.65 335.25 249.31 Pass - Major Risk 03 -16 - 03 -16 - 03 -16 5,107.76 5,460.00 185.05 98.61 87.73 Pass - Major Risk 03 -16 - 03 -16A - 03-16A 5,107.76 5,460.00 185.05 98.61 87.73 Pass - Major Risk j 03- 17- -03=1L- 03 -17 671 6& _ 6&0.10.- 65.8 -1_. __ 11 30 -__ 54.51 Passwlajor Risk 1 03 -18 - 03 -18 - 03 -18 640.54 645.00 61.80 11.01 50.79 Pass - Major Risk 03 -18A - 03 -18A - 03 -18A 640.54 645.00 61.80 11.01 50.79 Pass - Major Risk 03.21- 03=21 - - 0321 7,809.07 7 402:79 X6&39 191.6' Pass - MajorRisk 03 -23 - 03 -23 - 03 -23 4,604.83 4,645.00 199.60 175.48 33.54 Pass - Major Risk 03 -25 - 03 -25 - 03 -25 3,379.02 3575.00 404.52 78.43 __ -- 331.61 Pass - Major Risk 03-25A - 03 -25A - 03 -25A 3,448.53 3,645.00 361.66 81.69 284.94 Pass - Major Risk PB DS 17 17 -07 - 17 -07A - 17 -07A 10,507.20 11,675.00 1,099.66 381.88 901.00 Pass - Major Risk tW/f9/2019 2 :22 :04PM Page 2 of 3 COMPASS 2003.16 Build 71 Project: Prudhoe Bay • . _ Site - PB -DS_03 Well: Plan 03 -37 Wellbore: Plan 03 -37 Design: Plan #1 03 -37 From Surface to TD Scan interval 100 ft Scale 1:100 DS03 -07 Risk 1:200 0 350 330 30 300 22- 03- 1610316A 5381 30 ,221 5'140 2 5059 977 4896 4 814 �T , 300 / 03- 18A103 -18A X3 03-17/03-17 ■ 7 Ir --C :(0111V — Alit. Ago 1 1730 } 6 6) __ _ 4 '11 ; i I ''x42 } --.- 90 70 ;� 1 �, g 1 03-23/03-23 i 13 f 498. �� 4902 i• 1735 4819 101 1641 1.47 ,4 E0 1454 • •• ., ,,,, 1266 ' 1 1 1176 4652 .C3 240 ,4566 ° 393891 �/ 120 { J 1,11 .a / ---„, \, ;44:1 f r 43-07 %3: . ..' 03- 15AL1/03 -15AL1 46 4, J� �� `+a 4 Ph1 '� i r, 11. r I _......--....,4 4110::::. _.........- .,_ 0 . 210 ° / 150 4t Iiii lialow _. , 180 Travelling Cylinder Azimuth (TFO +AZI) [ °] vs Centre to Centre Separation [100 ft/in] EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 1 1 AEO2 6000000 1 t • / AEO 1 5950000 5900000 40 CFR 147.102 (b)(3) 3 -37i 1 1 5850000 400000 500000 600000 700000 800000 • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, November 30, 2009 9:56 AM To: 'Rose, John G (ASRC)' Subject: RE: PBU 3 -37i ( PTD 209 -139) John, The data looks good. If you could please send me a 1/4 mile surface plot map (Spider map) showing the well trajectories of 3 -37 and 3 -07 (plus any other nearby wellbores) . Should be good to go after that. Thanks, Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Rose, John G (ASRC) [mailto:John.G.Rose©bp.com] Sent: Wednesday, November 25, 2009 11:19 AM To: Schwartz, Guy L (DOA) Cc: Hobbs, Greg S (ANC); Mower, Matthew Subject: RE: PBU 3 -37i ( PTD 209 -139) Guy, Please note that attached Area of Review for the 03 -37i injector and please let me know if you have any questions or concerns. Thanks - jr John G. Rose 13P.Y- Shy) Engineer Office 907 -564 -5271 Cell 907/748 -5223 FAX 907564 -4040 Home 907/243 -8813 From: Rose, John G (ASRC) Sent: Wednesday, November 25, 2009 8:42 AM To: 'guy.schwartz @alaska.gov' Cc: Hobbs, Greg S (ANC) Subject: RE: PBU 3 -37i ( PTD 209 -139) Guy, As indicated in Section #15 on the 03 -37i PTD form, there is a well 455' from this proposed injector within the pool. That well is the abandoned 03 -07 well which upon our initial thoughts did not require an Area of Review evaluation, however, after further discussion should have been scrutinized through this process. That being the case, I will request the original drilling records and P &A records so that an AOR process can be run on this well which will be forwarded to your office ASAP. If you have any questions or concerns, please advise. Thanks - jr • • 11/30/2009 • Page 2 of 2 John G. Rose BPX - St fEngineer Office 907564 -5271 Cell 907/748 -5223 FAX 907i564 -4040 Hoare 907/243 -8813 From: Rose, John G (ASRC) Sent: Tuesday, November 24, 2009 12:53 PM To: 'guy.schwartz @alaska.gov" Subject: RE: PBU 3 -37i ( PTD 209 -139) Guy, Per my phone message, please give me a call to discuss this PTD. Also, please note my e -mail address as your initial request went to the wrong Rose. Thanks - jr John G. Rose BPX - Staff-Engineer Office 907564 -5271 Cell 907'748 -5223 FAX 907/564 -4040 Home 907/243 -8813 From: Rose, John K Sent: Tuesday, November 24, 2009 10:07 AM To: Rose, John G (ASRC) Subject: FW: PBU 3 -37i ( PTD 209 -139) Must be yours From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Tuesday, November 24, 2009 12:49 PM To: Rose, John K Subject: PBU 3 -37i ( PTD 209 -139) John, 1 have a couple of follow -up questions in regard to the PTD for this well. Can you call me at your convenience .... Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) • 11/30/2009 • Able- • pT 1.) - 03 -371 Area of Review The 03 -07 well is the only well within the 1/4 mile area for review in preparation for the drilling of the 03 -371 grass -roots well. As this well has been P&A'ed (sidetracked to the 03 -07A1 well in 03/2004), the primary cement job on the original 9 -5/8" production casing for this well (10/11/1976) and the P&A cement job on this well (03/14/2004) are detailed below: 10/11/1976 - 9 -5/8" Cement Job: With the well TD'ed at 11,695' MD (12 -1/4" hole), the 9 -5/8" production casing was run and cemented at 11,669' MD with 1075 sxs Class G cement ( -223 bbls) with no records of any lost circulation or other related operational problems which may have compromised the cement job. Therefore, assuming our standard 30% wash -out through this interval of the well 12/1/4" hole x 9 -5/8" casing ( -.072 bbls /ft), the estimated TOG on this 9 -5/8" cement job is at -8598' MD / 7118' TVDss. 03/14/2004 - P&A Cement Job: 45 bbls of Class G were pumped, squeezing -5.2 bbls of cement through the perf's and while laying the remainder of the cement from the top of the PBTD at 11,076' MD to -10,345' MD. This cement plug was tested to 3500 psi on 03/17/2004 during the pre -rig CMIT -TxIA. Conclusion: Based upon the review of this cementing data for the 03- 07/03 -07Ai well, there is no reason to suspect that the planned 03 -37i injection support for this area will result any un- planned injection pattern(s). 03 -37i Area of Review 11/30/2009 1 . 40 • • , • , -, , „ • , , ....., • AtlanticRichfieldCompany <> Drilling Report—Daily Al viol iiii,ittei . i DI.' , iiii , . '411,11 l I 17 / / ■'.'... 1 • . 1 .1 ::oitth lo:::, ::.:14' ■ -,,,ot: md:1V 1,-it.td i Co ,..q.1 11 ! . /7.% ,- >_ , r"/ , L. It. ' / 1 1,1, • e. r .". . ■. 7 t //f f: 2 --* 7 / " ' C' /.."''? /',.. / I/ ---- , / ■ 2 . , 11/.1' / ' ../ l , -- 1; /- . - Mud / 1 w'' -4 , '' ' r C. . Ts 0 5.1 .., • ' ... i .- ( / , /',, 7 , , te ,7 ; ... . .., -.--..-- -•' - .- • '''/ Sutveys • 0 rem I 1,,, .r. i. ,er 1 IV..illbt f :rY1) 1.•.41 .,-o.■ .. , , P.' I r..1•TA !,.Sor,,11, ■, t nt, I- Pit, esi ti .:1,, ,,, ,, ,,,,,„0,,•,,, Bit St ze Make Type — 1 Jet size In Out Footage HMOs Condition number _ , • • re " ■•■9 lino. .4 ;'..; 1,• : C t.m.11,11 ,01,e+0 ..,, 11M.7. / 1 r,1 14rnn .. ..c...lf.r o‘ to,I 1,11-1r. /,,,,' "/!•-• -,\ -...--- - I - 7 • _ _,.. - -- ., ...,_ , I 7 1 ....,,,;,./ ./-,/,., • ,„•,,-,/ — , i ff,: •_:- _. Z.j:/." .•: / /2 ,e - / /1/4, 2 ( 2 - //- , ----- ' 6 ,, / ' / / ' L //Z/..i•- 'i / ,'". . //,-.„ .„,:,•'/- (r."/I:/,/: • .2-..4 a r / ,:-. (7 7')-,-.. • 77 - . - 64, '; i / (.',/ .-;--.. , Tr '7 '4. -'"/ / 4.:..1,titk11 tem:: c.3ii.iniii rmiiiirt ii,iiiieet,it ieLf. elf. 1 //,'• ,........."'-- / / <11.(/ ../ : '' 47 t -'' (' ' f 1 Z e/1 • ...1 4 '..:,; l'' ' .- / _21 '''' ' / '• r '_. '2' . ' • ,.:-.'- ( ,- . ..' .. Y.1.'. //41 "."_ „,,,..... -v /".' ', 27,1 / . t • 6--- : ' '.. ) 7-'/ / • .' -- ,/' - ,. " ' C . / _.:" , ... */• , e //:. ' ./.', ,//-. /,j,/ ..,, , . (1 / ' /./ / .... ../. ty (i ..,:" ./.: /.. ''i: t . /:''' A< //,. ''''...;` //'....' '. ..- ,'.%:-.. — .,-:_... •,., 4 .z ff /, --/,',/ •'/-.„,/;‘, - Cumulative 0"'Q , / 7/ 0 4 . "' costs ' I g / r - "." o,, . ' , it/ .. E ,O.C.4“/1144 ' 1 ' . / //,';', ,e/ . /-: ' . '. / . ' ' '''/ '' - ./ ' ( "12 ;Z A (-' ' '--. ///: :, , -, , - ,/, :....: 1/ 2/, , . ...,.. , -...-',2 . ,.../!'' f ..4'. : Z ... / . ., „ . . ''. 1 '' /' / .•- / /I / . ; '' ..7 -7 i / .. '.;/-,.. / - Z.:: x, ' - .-;`"/- - - - 2/" ,-. .. - /.. 'ii(: Zi.---..-.. '. (.- /./i././. ,..... E121114fl140111 011iplintal . . . . , /,,: ,(/'; ' ,, .... . 7 41.4 , ,,' / .:;', 7.-. /14%, Fuel I Or It...ttonn i /''' ,. / 2 t.),,.<1 ( 7:: / 6 -,' .,' .1 /C I( ? • ;' .. ' Received ..." — * 7 Weather ilf"rn4"".,"' ' ' vle•hoilv ''' mod i - i rr,,.. I... , CIti I WaVe: 1“.10111 , S10,06 1 i t AR3B-824 t r.t!nonds I feat 1 -- 03-37i Area of Review 11/30/2009 2 • • ID • TREE= McEvoy WFiLi-IEAC= FMC Gen 1 ACr A ^ - ®7 SAF iI NOTES: PLUG AT 11075' ' t,1ATof2= ... - �1XELSON 03 KB. E-E'V = 01' B. ELEV = KOP- 3200' Max An$le =_ 6800' Datum 110 = 10989' Germ TVO= 8800' SS Q "1 2166' H 7" CALICO BAL -0 SSSV NP, i0 = 5 937' 1 r13-3/8' CSG. 720, MN-80.10. 12 347 I--! 2699' 1 4 1 I 7" TI3G•FC, 261.1.-60. 0.0383 5p1 .10 = 6.276' ---1 10569' 10569' H 7•X5.112'X01 FOR OF 5.112' TBG -PC — 10569' I 105/1' 1---1 5.112' OTIS X NP, ID = 4 562' 1 Minimum 10 = 4.455 @ 10618' 10578' H 5 -112' BAKER 013•' SEAL ASSY 1 5 -1/2" XN NIPPLE ►, �� ►�� 10587' —1 9-5/8' x 5.117' BAKER 193.1 PKR, ID = 6.000' 1 1 10618' 5 -1;2' OTI3 XN NP NOGG, o = 4.45;' 1 5.112' TBG -IPC, 170, L.80, U 0232 bp( , D ° 4892" 10623' 111 10623' 5 TUBING TA L I 1 H _l PERFORATION SUTAAtARY 1 10618' 1 - 1 Euro 1 r LOGGEL) 10/ 17/91 I REs- LOG' BRCS on 10107/76 ANGLE AT TOP PE F: 42 @ 10765' N 1 Nate: Refer to Production CB f historical port data SITE SPF NTERVAL Cp+vSgz CAT€ ' 3-318' 4 10765.10802 0 05110/87 1 3.1)2' 4 10914 -10958 0 06127/97 3 -3)8' 4 10965 -11006 0 09109/85 1 3.318' 4 11010-11032 0 11121 /94 3.3)8' 4 11035-11055 0 11)21/94 3 -118' 4 11098.'11103 C 02)20)92 1 2418' 4 1 1114-11130 C 02/20)92 2 -7/8' 4 '1130-11139 6 05130115 1 2.718' 4 i 1154.11179 S 08130/85 TOPOF 4.112" TOG. 1PC1 11070' 111'.,11 `�� 11070' — 1 9-519'x4- 112' BAKER FB -1 ROI I (PBTO 1- -1 11076' 1 = 4Y1 11076' I — 4 -172" OTIS XN NIP '0 = 3.725' At 1 FI 111 VO W1PXN PLUG SET 2.20.92 Y4 1 4-112' RIG-1PC, 12.0 #, L-80, 0.0152 871,10 = 3 958" I 11078' • 1444444 V. 11077' 4.1/2" TUBNG TAIL A444.40444/ ∎ 4 4 4 4 • 4 4 4 4 4 4 4 4 + 4 4 < 11 4•14•4•41' •••••••■••4 4 4 4 4 4 1 4 4 4 4 4 4 4 4 • 4 1 4 1 4 1 4 1 4 •4 •4 4 4 • 414.1. •••••••••• **414 * 44444/1444 ■4 0.4.•••••• 4 14 4 444 4 4 4 4 4 t 4 4 4 4 t 4 4 4 4 •4 4 4 1 4 1 9 - 58° CSG. 471, MN u = 8.681 H 11669' 404 4 i 4 4 4 41 4 4 6 4 4 4 4 4 6 4 4 TO H 11695' DATE REV BY COMVI34TS GATE REV BY CONVENTS PRk 0l-KX SAY UNIT 10/20/76 OR*P4ALCOMPLE1ION WELL: 03.07 06/15/91 LAST WORKOVER PE2/41 'b. 76-053 12/19/00 StS•QAA COW DTI'S) TO CANVAS API No: 50-029-20220-00 ! 01/05/00 $IS-MO Fk1AL SC/Cl 1 )1oN RISE 497 FEL 1461 57 FNL 05)21/01 F -.WTP _COPRECTIC'G BP Exploration (Alaska) 03 -37i Area of Review 11/30/2009 3 • . • • 03 -07 Pre Rig Operation WILLI {EA D= RICGEN1 ACTUATOR= AXELSON KO E16V = 61.0' CO. ELEV „ Assurrod 27 1' KOP = 32C0' Max Angle . 48 @ 88C0' 7' CALICO 8AL -O SSSV _�_.._. � 2166' Datum td0 = t09E)9 I' S'8" FO Cementer I 2325' [ NP, ID. 5.937• Datum TVD- 3500 SS 19 5/8" FO Cementer Fr c j 13-318" CSG, 72A, 2699' I k MN-80, ID • 12 347" SAFETY NOTES R.UG AT 11076 7" TOG -PC, 260, L- 80.0 0383 apt . 0 10569' 6.276° l sko r 0 C1x 1nral cer'. 8.100' =--„,... , Minimum ID = 4.455 @ 10618' 5 -1/2" XN NIPPLE like rig cement F1&A I—i 10.500' I 7" X 5 1/2" XO; TOP OF — 10569' I \ 5-1/2' MG -VC I i I 10571' I--{ 5 -1/7" OTIS X NIP, v= 4.562' I E I 10578' I — I 5 -112" BAKER 08-1 SEAL ASSY I Z X I 1058T I — I 9.5/8" X 5.1/2" BAKER FB- : PKR. ID = 8 000' I I I I 10618' I — I 5 -1/2" OTIS XN NP NOGO. 0 = 4.455" I 1 5.1/2' TBG-IPC. 10623' 174,1 I I I i (Ii PERFORA1i0N SUMMARY I TOP OF 4 -1/2' TI3G-PC H 11070' ( REF LOG: BHCSor110J07 /76 A NGLE AT TOP PEW: 42 fp 10765' 9 -5/8" X 4.172' *7.31 Note: Refer to Producben 08 for historhat pert data 11070' BAKER FB-1 RtR I SIZE SPF ` NTERVAL Cpn/Sgz DATE ■Nur 1 3 -3/8' 4 10765-10802 0 05/10/87 — 4 -112' OTIS XN NP 4',4 fi iFe f 3-1/2' 4 10914 -10958 0 06/27/91 11076' ID a 3 725' 1 1 X 3 -3/8' 4 10965-11006 0 09/09/65 e : . *4 3 -3/8' 4 11010 -11032 0 11/21/8. W 2/20/92 Pu9 set X 1'�$*$*4 1 33x8' 4 14035 -1 0 11r2110+ 4 :41 . ...... $ 4:1...#1 4 ' 111t1�•1 -•1{ 3 -1/8' 4 11098 -11103 C 02/20/52 11"1'111111♦ 11 1 11•-111 111, 2.7/8 4 11114.11130 02720/92 1 ♦ 2 - 7/8' 4 11130.11139 S 08/30/85 95/8 CSG, 47a, LIN- 11 11669 11 111 1 2 - 7/8' 4 11154.11179 08730185 11 80,11= 8.681" 1 11 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 .Kiti!4!4!4 x!1.441 ITt) I 11695' I DATE REV BY COMMENTS DATE REV BY COM)/ENT'S PRU HOEBAY UNIT 10/20/76 ORIGINAL COMPLETION 01/26/04 dew Proposed pre rig work WELL 03-07 06/15/91 LAST WORKOVER PE}2MlTNo: 76-053 ' 12119/00 SIS -QAA CONVERTED TO CANVAS API N3. 50- 029.20220-00 01/05/00 SIS-MO FINAL ;r<' — T1 ON R15E4171.95 FEL 1461.57 FNL 05/21/01 I4WTP COF8TEE IONS BP Exploration (Alaska) 03 -37i Area of Review 11/30/2009 4 • • lTV 207- /37 Project: Prudhoe Bay Site: PB DS 03 Well: Plan 03 -37 _ Wellbore: Plan 03 -37 -750— Design: Plan #1 03 -37 • 1000- - 1250— - 1500 - -1750 — S -2000— / •2250— A�d ' o) ./ A -2500 — ,,,#. 03 - 37 Tnt Sag 6 6 , 03 -37 TSAD 1 ?j 0 ' 9 0 8 Q O 1 -2750— \O � 7 r X o i O Ili -3000— b • b -3250— '`'- •3500 — • 3750 — - I I I I I I I I I I I I I I I I I I I -6000 -5750 -5500 -5250 -5000 -4750 -4500 - 4250 -4000 -3750 -3500 -3250 -3000 -2750 -2500 -2250 -2000 -1750 -1500 -1250 West( -) /East( +) (500 ft/in) Alaska Department of Natura, sources Land Administration System. Page 1 of,/ Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28331 Printable Case File Summm See Township, Range, Section and Acreage? New Search Yes 0 No LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28331 ?.Iaw Search for Status Plat Updates As of 11/13/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: O10N Range: 015E Section: 15 Section Acres: 640 Search Plats Meridian: U Township: O10N Range: 015E Section: 16 Section Acres: 640 Meridian: U Township: O10N Range: 015E Section: 21 Section Acres: 640 Meridian: U Township: 010N Range: 015E Section: 22 Section Acres: 640 Legal Description 05 -28 -1965 ** *SALE NOTICE LEGAL DESCRIPTION * ** C14 -161 TION- RI5E -UM 15,16,21,22 2560.00 U- 3- 7 End of Case Summary Last updated on 11/13/2009. http://dnr.alaska.gov/projects/las/Case Summary.cfm?FileType=ADL&FileNumber=283... 11/13/2009 Alaska Department of Natural1sources Land Administration System Page 1 o . Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28328 8 Printable Case File Summary See Township, Range, Section and Acreage? New Search Yes 0 No LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28328 Search for Status Plat Updates As of 11/13/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: O10N Range: 015E Section: 03 Section Acres: 640 Search Plats Meridian: U Township: O10N Range: 015E Section: 04 Section Acres: 640 Meridian: U Township: 010N Range: 015E Section: 09 Section Acres: 640 Meridian: U Township: O10N Range: 015E Section: 10 Section Acres: 640 Legal Description 05 -28 -1965 ** *SALE NOTICE LEGAL DESCRIPTION * ** C14 -158 T10N- R15E -UM 3,4,9,102560.00 U- 3- 7 07 -06 -1987 * ** LISBURNE PARTICIPATING AREA LEGAL DESCRIPTION * ** T. 10N., R. 15E., U.M. SECTION 3: ALL 640 ACRES SECTION 4: ALL 640 ACRES http://dnr.alaska.gov/projects/las/Case Summary.cfm?FileType=ADL&FileNumber=283... 11/13/2009 • TRANSMITTAL LETTER CHECKLIST WELL NAME PTD# Development Service Exploratory Stratigraphic Test Non - Conventional Well • FIELD: l 0g 2 1 Y POOL: �,ed/.4r Z, O/G Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are 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(0, 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 logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject 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 All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 � ' _ � Well Name: PRUDHOE BAY 03 -37 Program SER Well bore seg ❑ PTD#: 2091390 Company BP EXPLORATION (ALASKA) INC Initial Class /Type SER / PEND GeoArea 890 Unit 11650 On /Off Shore On Annular Disposal Administration 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 2560 acres. 18 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Blanket Bond # 6194193. 111 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes ACS 11/13/2009 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes AIO 4C • 15 All wells within 1/4 mile area of review identified (For service well only) Yes 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 11 17 Nonconven. gas conforms to AS31.05.0304.1.A),(j.2.A -D) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA No aquifers 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No Cement planned to 750' below surface shoe. 22 CMT will cover all known productive horizons Yes cemented casing and liners. 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re-drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. 3 -07 within 250 ft at 10250 md. 27 If diverter required, does it meet regulations Yes Waiver requested for paddle removal approved for <1000' Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max. formation pressure= 3250 psi (7.2 ppg EMW) will drill with 8.4 ppg mud GLS 11/30/2009 29 BOPEs, do they meet regulation Yes 130 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 2377 psi Will test BOPs to 4000 psi 31 Choke manifold complies w /API RP -53 (May 84) Yes 1 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S on DS -3 . Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) Yes Only 3 -07 is within 1 /4mile. Well P & A'd and cemented across perforations. [ 35 Permit can be issued w/o hydrogen sulfide measures No Max level H2S on pad was 800ppm; well 03 -21 = 140ppm (11/25/08). Geology 36 Data presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones NA ACS 11/13/2009 38 Seabed condition survey (if off- shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering Pu r lic Commissioner: Date: Date ` l� ner Date r. C ommissione : Co /2 /_� . " z1 .....6 ? • • Well Histo ry File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history the. 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. 1 HALLI B U RTD' Sperry Drilling I END OF WELL REPORT 03 -37i Prudhoe Bay Field - EOA I 1 1 1 1 t 4111. ..... K . a .. MIA w o.." {aa. *. 4 { 1 Surface Data Logging Services I j09 - <3 9 0 HALLIBURTON S perry Drilling I TABLE OF CONTENTS ' 1. General Information ' 2. Daily Summary 3. Morning Reports 1 Digital Data including ' C- Ratio Gas Logs Engineering Logs Mud Logs ' ASCII Log Viewers End of Well report in PDF format 1 1 1 bp • I HALLIBURTON Sperr Drilling GENERAL WELL INFORMATION ' Company: BP Exploration Rig: Nabors 9ES Well: 03 -37i 1 Field: Prudhoe Bay - EOA Borough: North Slope Borough State: Alaska Country: United States API Number: 50- 029 - 23241 -00 1 Sperry Job Number: AK -AM- 7145033 Job Start Date: 26- Jan -2010 Total Depth: Surface section drilled to 3585' MD, 3418' TVD [01 Feb 2010] Intermediate section drilled to 9995' MD, 8660' ' TVD [11 Feb 2010] Production section drilled to 10740' MD, 9301' TVD [14 Feb 2010] ' Release Date: 15 Feb 2010 North Reference: True Declination: 22.479° 1 Dip Angle: 80.933° Total Field Strength: 57691 nT Date Of Magnetic Data: 14 Feb 2009 Wellhead Coordinates N: North 70° 13' 55.69" Wellhead Coordinates W: West 148° 16' 45.38" 1 Drill Floor Elevation 55.60' Ground Elevation: 27.10' 1 Permanent Datum: Ground Level SDL Engineers: Justin Carter, Colby Marks Company Geologist: Tania Cunningham ' Company Representatives: Bill Bixby / Roy Hunt SSDS Unit Number: 107 1 1 by 1 I HALLIBURTON I S perry Drilling DAILY SUMMARY 1 Begin 03 -37i 1 01/26/2010 — 01/31/2010 Sperry SDL on site — rigging up. 1 02/01/2010 Continued drilling from 3018' at 650 gpm, 218 spm, 2550 psi, and 60 rpm while backreaming I every 30' to the surface interval TD at 3585' MD/3418' TVD. Circulated at 650 gpm, 218 spm, 2365 psi and 100 rpm with sand and traces of gravel observed during the circulation. Backreamed from 3585' to 1968' at 550 gpm, 1680 psi, and 100 rpm. Started running 9 -5/8" casing at 2 minutes per joint while filling each joint as ran. I 02/02/2010 Continued running 9 -5/8" casing. As losses mounted while running, adjusted the running speed I to mitigate while still filling each joint and circulating every 10 joints. Took the string weight at 3,500 ft and staged circulation to 223 gpm at 75 spm and initiated casing rotation at 30 rpm. Worked the casing down to the landing ring and landed the casing at 3553' MD / 3388' MD. I During the landing, Phase 3 winter conditions were announced and the rig circulated through the casing while waiting on weather conditions to improve before starting cementing; circulated at 107 gpm at 36 spm with 223 psi pump pressure. Eventually lowered the pump rate over time I to 44 gpm at 15 spm with 180 psi pump pressure. While waiting on weather to improve, alternated pumping on and off for 15 minutes to keep annulus open. I 02/03/2010 Continued to wait on weather while staging the pumps on and off every 15 minutes. With the Phase 3 conditions dropped, circulated and conditioned the hole. Held pre -job safety meeting and batched up cement. Pumped 10 bbls of Mudpush and pressure tested to 3700 psi. 94 bbls I of Mudpush were pumped followed by 775 bbls of lead cement. 84 bbls of tail was pumped and 10 bbls water before chasing w/ 253 bbls of Drilplex mud and bumped the plug at calculated strokes. Sand observed during circulation and cement job but no Mudpush or cement seen at 1 surface. 02/04/2010 Checked the 9 -5/8" floats and tested OK. Trip in to TAM collar & circulated two annular volumes at 173 gpm (56spm) with 77 psi pump pressure and observed no Mudpush or cement at bottoms up. Ordered & waited for 80 deg fresh water & contam pill for top job while I circulating periodically until cement trucks were on location. Pumped 10.7 ppg cement at 2 bpm. Cement observed after 630 bbls pumped and an additional 20 bbls of cement was pumped followed by 10 bbls water. Closed TAM collar and circulated 3 annular volumes at 414 1 gpm (139spm) with 820 psi. Flushed surface stack, riser, and flow line before nippling down the surface equipment r by I 10 1 HALLIBURTON Sperry Drilling 02/05/2010 ' Nippled up and tested BOPE while performing work on the top drive. Picked up 25 stands of 4" drill pipe for 8.75" intermediate section and racked back in derrick. Picking up more 4" drill pipe at report time. ' 02/06/2010 Picked up additional 4" drill pipe and pressure tested the 9 -5/8" casing to 3500 psi— tested OK. Tripped in and tagged the Float Collar at 3465' and continued drilling cement to 3290' MD. t Displaced to new 8.8 ppg LSND mud and drilled cement plus 32' of new hole to 3605 MD' [Casing Shoe at 3550' MD]. Circulated 1 x bottoms up to condition the mud in the annulus and conducted a FIT to 13.1 ppg EMW. Drilled ahead to 4208' MD/3996' TVD with clay, sand, and 1 traces of coal observed. 02/07/2010 Drilled ahead from 4208' to 4954' MD before performing a wiper trip while repairing the mud pump #2 blower; hole swabbing was observed during the wiper trip. Circulated at 2.5gpm with 420 psi pump pressure up to 4200' MD before running back to bottom at 4954' MD with clay ' being observed at bottoms up. Continued directional drilling ahead to 6577' MD / 6219' TVD as of report time. Pumped two 40 bbl high viscous sweeps (PV:18 YP:67) at 4565' and 5500' MD with no increase of cuttings observed at surface for either sweep. Pumped another high viscous ' sweep at 6481' MD which resulted in a 10% increase in cuttings observed at surface. Clay, sand, and traces of coal were observed while drilling. Drilled gas was entirely methane averaging 50 -100 units during the drilled interval. 02/08/2010 Continued directional drilling ahead from 6577' MD / 6219' TVD to 8488' MD / 7626' TVD at 502 gpm (205spm) with 3080 psi pump pressure,15k WOB, and 120 rpm surface rotary where MWD lost detection with the BHA. Backreamed each stand at 60 rpm while reducing the pump rates to 450 gpm on the down stroke to mitigate packing off. Silt, clay, sand, shale splinters, and traces of coal were observed while drilling. Drilled formation gas averaged 150 -500 units being entirely dependent on ROP fluctuations with the exception of one large gas peak (entirely methane) was observed at 5072' MD / 4808' TVD. In addition, ethane was first observed at -7300' MD and has been slowly building since. Propane and butane were observed shortly ' thereafter and have remained in the sample since -7400' MD— pentane currently remains sporadic. ' 02/09/2010 Worked on MWD signal and finally regained detection. Continued drilling ahead from 8488' MD / 7626' TVD at 502 gpm (205spm) with 15 -18k WOB and 120 rpm surface rotary. Backreamed each stand at 60 rpm surface rotary while reducing the pump rates to 450 gpm on the down ' stroke. Pumped a 40 bbl 3ppb high vis sweep at 8488' and observed no increase in cuttings at surface. Lowered the pit volume to 100 bbls at 9,000' and circulated 290 bbls of 13.4 ppg LSND spike fluid over two circulations to obtain an average 10.5 ppg LSND before drilling into the HRZ ' formation (for wellbore stability). Drilling ahead at 9668' MD/8436' TVD at report time with silt, sand, shale splinters, and traces of coal throughout the drilled interval. Drilled formation gas bp HALLIBURTON I Sperry Drilling averaged 156 units across the interval and appears to be rising slightly from 9000' MD onward while the background gas levels during connection shave seen a slow decrease over time. Post 1 9000' MD, methane through pentane are now being picked up consistently. 02/10/2010 ' Continued drilling ahead from 9668' MD / 8436' TVD to the intermediate interval TD at 9920' MD / 8623' TVD with the same continued drilling parameters used throughout the section. Drilled gas continued to increase to 600 -750 units average and a 841 unit max —again methane through pentane care consistently being observed within the mud. Upon reaching TD, ' circulated and conditioned the hole while getting 2x bottoms up around while observing max trip gas of 963 units. Tripped out of the hole to surface and prepared to run 7" 29# L -80 VAM -Top casing. 1 02/11/2010 Rigged up casing running equipment and tripped in with 7" 29# L -80 VAM -Top casing while filling each joint and stopping to stage circulation every 10th joint. Circulated one annular volume at 3550 ft at 250 gpm (102 spm) with 552 psi pump pressure before continuing running ' the casing further down hole. While running the casing to bottom, circulated through the casing as needed at 210 gpm (86spm) with 950 psi pump pressure. Water maintained at 4 bph wile running pipe from 5800' with the casing depth run to 7077' MD as of report time. Low gas below ' 500 units observed while circulating. 02/12/2010 Continued to run 7" casing while filling each joint and staging circulation at every 10th joint; circulated as needed in tight spots at 210 gpm (86spm) with 950 psi pump pressure. Worked casing down to landing joint and landed at 9992' MD / 8678' TVD. Rigged up for cement job and pumped 25 bbls 10.7 ppg Mudpush before testing lines to 4500 psi. Dropped the bottom 1 plug, pumped 157bbIs 11.0 ppg Lead Cement followed by 3 bbls of 15.8 ppg Tail Cement. Dropped the top plug and chased first with 10 bbls of water and then 10.6 ppg LSND WBM at 5bpm. Initially lost partial returns and lowered the pump rate back to 3bpm; with full returns back, raised the pump rate back to 5bpm. Bumped plug at 6230 strokes. After cement cured, tested the casing to 4000 psi —OK. Change -out pipe rams and start picking up BHA at report time. 1 02/13/2010 Continue picking up 6" drilling assembly while injecting 100 bbls 10.6 ppg LSND & 65 bbls Dead ' Crude down the outer annulus for freeze protection. Held a safety stand -down meeting to discuss recent field incidents. Continued tripping with new BHA and washed and reamed from 9832' MD to the Float Collar at 9907' MD. Drilled cement to 9995' MD / 8680' TVD at 230 gpm with pump pressure 2380 psi & 60 rpm surface rotary. Displaced the 10.6 ppg LSND to 8.5 ppg ' FloPro SF at 9960' MD. Drilled ahead to 10015' MD at 250 gpm with pump pressure 1850 psi and surface rotary 60 rpm. Circulated one annular volume and performed a FIT test to 11.0 ppg EMW. Rotary drilled ahead from 10015' at 250 gpm (102spm) with pump pressure 1850psi, surface rotary 60rpm, and 15k WOB to 10119' MD / 8776' TVD as of report time. Drilled gas analysis indicated that after leaving the shoe, the heavy gas concentration was lower than the by ' HALLIBURTON I S perry Drilling 1 previous wellbore, showing the recycled gas content within the old mud system as it retained the heavier hydrocarbons over time. Drilled formation gas averaged 150 -300 units across the I interval, albeit the ROPs were rather low and sustained below 30fph for most of the interval and therefore suppressing the raw gas readings. I 02/14/2010 Continued drilling from 10015' MD to the production interval TD at 10740' MD / 9301' TVD with flow 230 gpm (96spm), pump pressure 1765 psi, & surface rotary 80 rpm. Initially backreamed from 10740' MD with full drilling rates to 9928' MD. Circulated a 40 bbl high viscous sweep (120 I vis) around and observed a 10% increase in cuttings at surface. Monitored the well for flow – static. Pumped a NaCL dry job and started tripping to surface. Racked back drill pipe, laid down heavyweight, downloaded MWD, and broke down the BHA. Rigged up and conducted 1 open hole logs with SLB at report time. Drilled gas significantly increased along with the increase in ROP at 10140' MD, jumping up to an average 2500 -5000 units for the reservoir section —after leaving the reservoir section, gas fell off to 250 -500 units background, although I the heavy hydrocarbon was proportionally higher because of the recycled heavy hydrocarbons within the mud system. Max drilled formation gas observed 7056 units at 10440' MD. 1 02/15/2010 Sperry officially released and rigged down unit. 1 1 1 1 1 1 1 1 I 1 i p 1 4 : 1 1 1 Customer: BP Report #: 1 Well: 03-37i Date: 2/7/2010 HALLIBURTON Area: GPB 04:00 Depth 4920' Location: North Slope Progress 24 hrs: 1334' Sperry Drilling Rig: Nabors 16E Rig Activity: Drilling Job No.: AK-AM-0007145033 Report For: Blair Nufeld Daily Charges $1,994.00 Total Charges: $21,844.00 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 100.0 257.0 376.0 4820' Flow In (gpm) 575 SPP (psi) 2353 Gas (units) 46 25 142 4565' Flow In (spm) 238 Gallons/stroke 2.5500 ' Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP lb/100ft m1/30min mg/I % 4208' 8.90 8.90 49 5.0 10 25 7.0 10.00 750 3.0 r 2 ';.., ' r ..:'•!:f-:** 1, f ' BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition ..i 3 PDC Hycalog 8.75 0.777 3553' ,...,, ,,,,..„...,,,, - *.„.,_ .. , --„• ,,..... ,, Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown 1 1 1 I 1 I 1 Gas (units) Chromatograph (ppm) Depth to *44 to to to ,,. 10 to to to to ,,,• to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; .'! POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip...; F-- - Formation...; E-- - Early... 24 hr Recap: Drilled from 3586' to 4815' with no significant gas peaks or hole problems. Will continue drilling ahead. All gas seen thus far consisted of methane only. . „ ! ..' Note: .. Logging 1 Engineer: Colby Marks/Justin Carter * 10000 units = 100% Gas In Air ....., ,.._ 3521•1111111MINEW ''ggilianiniiii.MiatiVoiZa. - - 1 ' ''' ' ' ---:* ' ' ,...., L 1 Customer: BP Report #: 2 Well: 03 -37i Date: 2/8/2010 HALLIBURTON Area: GPB 04:00 Depth 7390' Location: North Slope Progress 24 hrs: 2470' Sperry Drilling Rig: Nabors 16E Rig Activity: Drilling Job No.: AK -AM- 0007145033 Report For: B lair Nufeld Daily Charges $1,994.00 T otal Charges: $ 23,838.00 _.4., ,„.. ROP & Gas Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 290.0 102.9 615.0 5785' Flow In (gpm) 536 SPP (psi) 3069 Gas (units) 89 175 4303 5067' Flow In (spm) 221 Gallons /stroke 2.5500 • Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in I out (sec /qt) (ppb Eq) cP Ib /100ft m1/30min mg /I % 6577' 9.20 9.20 47 9.0 12 24 5.2 9.60 1,200 9.0 BHA Run # I Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 PDC Hycalog 8.75 0.777 3553' Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown 1 1 I 1 1 Gas (units) Chromatograph (ppm) Depth 3553' to 5100' 4303 60 428327 0 0 0 0 GP 5100' to 5800' 1776 325 253423 68 0 0 0 GP 5800' to 7350' 815 200 116939 0 0 0 0 GP to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T -- - Trip...; F -- - Formation...; E -- - Early... 24 hr Recap: Currently driling ahead. Max gas observed in the past 24 hours was 4303 units consisting only of methane. During the past 24 hours the gas has been composed mainly of methane only, with a few intervals here and there with a little ethane, sometimes accompanied by trace amounts of propane. No correction gas observed thus far. Once back on bottom after wiper trip to shoe, observed 1201 units of trip gas, again only methane. Average background gas has varied between 150 to 500 units, dependant upon ROP. Note: I Logging Engineer: Colby Marks /Justin Carter * 10000 units = 100% Gas In Air 1 Customer: BP Report #: 3 Well: 03 -37i Date: 2/9/2010 HALLIBURTON Area: GPB 04:00 Depth 8737' Location: North Slope Progress 24 hrs: 1347' Sperry Drilling Rig: Nabors 16E Rig Activity: Drilling Job No.: AK -AM- 0007145033 Report For: Blair Nufeld Daily Charges $1,994.00 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 190.0 173.0 637.0 8488' Flow In (gpm) 504 SPP (psi) 3401 Gas (units) 173 127 356 7514' Flow In (spm) 208 Gallons /stroke 2.5500 Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec /qt) (ppb Eq) cP Ib/100ft m1/30min mg /I % 6577' 9.20 9.20 47 9.0 12 24 5.2 9.60 1,200 9.0 ' : Av :, r , BHA Run # r Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 PDC Hycalog 8.75 0.777 3553' I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown 1 1 1 1 1 1 Gas (units) Chromatograph (ppm) Depth Max Avg 01 C2 C3 C4 C5 7400' to 8750' 356 120 13938 314 172 101 6 to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; } POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T -- - Trip...; F -- - Formation...; E -- - Early... :_, _ w . .�. 4 , , , , .r ti ;4A' ' ,A, 24 hr Recap: Currently driling ahead. Max gas observed in the past 24 hours was 356 units consisting of 01 - C4. Ethane began consistently showing up in the gas breakdown at —7300' MD. C3 and C4 came in around 7400' MD. C5 has remains sporadic. Connections have generally shown a decrease in gas. Average background gas has varied between 120 to 150 units. Note: 1 I Logging Engineer: Colby Marks /Justin Carter * 10000 units = 100% Gas In Air 1 .. - Customer: BP Report #: 4 Well: 03 -37i Date: 2/10/2010 HALLIBURTON Area: GPB 04:00 Depth 9920' Location: North Slope Progress 24 hrs: 1183' Sperry Drilling Rig: Nabors 16E Rig Activity: Drilling Job No.: AK -AM- 0007145033 Report For: Daily Charges $1,994.00 $ 1w , ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 75.2 111.7 306.0 8782' Flow In (gpm) 491 SPP (psi) 3483 Gas (units) 745 315 841 9492' Flow In (spm) _ 202 Gallons /stroke 2.5500 Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec /qt) (ppb Eq) cP Ib/100ft m1/30min mg /I % 9668' 10.50 10.50 46 15.0 17 28 4.2 9.60 1,400 12.0 �.' BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 PDC Hycalog 8.75 0.777 3553' � m L ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tu ,,,,.,, >; (current) Gas Breakdown 1 1 I 1 Gas (units) Chromatograph (ppm) Depth Max Avg 01 C2 C3 C4 C5 7400' to 8750' 356 120 13938 314 172 101 6 8750' to 9912' 841 318 37957 1529 1026 643 188 to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T -- - Trip...; F -- - Formation...; E -- - Early... 24 hr Recap: Currently driling ahead. Max gas observed in the past 24 hours was 841 units consisting of 01 - C5. C5 has joined the other gases consistently showing up in the breakdown at -9050' MD. Connections have generally shown a decrease in gas. Average background gas has been -300 units, however the gas has been increasing steadily since 9750' MD / 8486' TVD and is currently hovering around the 700 -750 units range. Note: Logging Engineer: Colby Marks /Justin Carter * 10000 units = 100% Gas In Air 1 1 Customer: BP Report #: 5 Well: 03 -37i Date: 2/11/2010 HALLIBURTON Area: GPB 04:00 Depth 9995' Location: North Slope Progress 24 hrs: 75' Sperry Drilling Rig: Nabors 16E Rig Activity: Out of Hole Job No.: AK -AM- 0007145033 Report For: Daily Charges $1,994.00 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) n/a 77.6 127.8 9960' Flow In (gpm) n/a SPP (psi) n/a Gas (units) n/a 462 953 9916' Flow In (spm) n/a Gallons /stroke n/a • Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in f1 m1/30min mg /I % 9668' 10.50 10.50 46 15.0 17 28 4.2 9.60 1,400 12.0 e, 3 BHA Run # I Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 PDC Hycalog 8.75 0.777 47.30 3553' 9995' 6442' 76.50 104 Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown I I I I I I I Gas (units) Chromatograph (ppm) Depth Max Avg 01 C2 C3 C4 C5 7400' to 8750' 356 120 13938 314 172 101 6 8750' to 9912' 841 318 37957 1529 1026 643 188 '' 9912' to 9995' 953 462 47541 2542 1995 1386 607 to to to to to to V Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; : ::. ; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T -- - Trip...; F -- - Formation...; E -- - Early... 24 hr Recap We have drilled to section TD at 9995' MD / 8660' TVD an d pulled out of the hole. Max gas observed in the past 24 hours was 953 units. Note: Logging Engineer: Colby Marks /Justin Carter * 10000 units = 100% Gas In Air III 1 Customer: BP Report #: 7 Well: 03 -37i Date: 2/13/2010 HALLIBURTON Area: GPB 04:00 Depth 9995' Location: North Slope Progress 24 hrs: Sperry Drilling Rig: Nabors 16E Rig Activity: Running Casing Job No.: AK -AM- 0007145033 Report For: Daily Charges $1,994.00 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pum • & Flow Data: R.O.P. ft/hr n/a n/a n/a n/a Flow In •.m n/a SPP •si n/a Gas (units) n/a n/a n/a n/a Flow In (spm) n/a Gallons /stroke n/a Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids De.th ft in out (sec /.t •.b E. cP Ib/100ft m1/30min m./I 9668' 10.60 10.60 46 17.5 13 18 4.0 9.30 1,000 12.0 BHA Run # I Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 PDC Hycalog 8.75 0.777 47.30 3553' 9995' 6442' 76.5E I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown 1 1 I 1 1 1 Gas (units) Chromatograph (ppm) Depth Max Avg 01 C2 C3 C4 C5 7400' to 8750' 356 120 13938 314 172 101 6 8750' to 9912' 841 318 37957 1529 1026 643 188 9912' to 9995' 953 462 47541 2542 1995 1386 607 to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T -- - Trip...; F -- - Formation...; E -- - Early... 24 hr Recap: Note: Logging Engineer: Colby Marks /Justin Carter * 10000 units = 100% Gas In Air 1 Customer: BP Report #: 7 Well: 03 -37i Date: 2/13/2010 HALLIBURTON Area: GPB 04:00 Depth 9995' Location: North Slope Progress 24 hrs: Sperry Drilling Rig: Nabors 16E Rig Activity: Running Casing Job No.: AK -AM- 0007145033 Report For: Daily Charges $1,994.00 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) n/a n/a n/a n/a Flow In (gpm) n/a SPP (psi) n/a Gas (units) n/a n/a n/a n/a Flow In (spm) n/a Gallons /stroke n/a Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids ( Depth ft in out (sec /qt) (ppb Eq) cP Ib /100ft m1/30min mg /I % 9668' 10.60 10.60 46 17.5 13 18 4.0 9.30 1 ,000 12.0 BHA Run # I Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 PDC Hycalog 8.75 0.777 47.30 3553' 9995' 6442' 16. 50 Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown 1 1 I I 1 I I Gas (units) Chromatograph (ppm) Depth Max Avg 01 C2 C3 C4 C5 7400' to 8750' 356 120 13938 314 172 101 6 8750' to 9912' 841 318 37957 1529 1026 643 188 9912' to 9995' 953 462 47541 2542 1995 1386 607 to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T -- - Trip...; F -- - Formation...; E -- - Early... 24 hr Recap: Note: Logging Engineer: Colby Marks /Justin Carter * 10000 units = 100% Gas In Air i 1 -,,,,-. ���-- ., -: ,,�� `��0 i l HALLIBURTON Customer: BP Report #: 8 Well: 03'37i Dmt�� 2/14/2010 Area: GPB O4�DOepth 1U422 Location: North Slope PrmQreoa24hre: 527 Sperry Drilling Rig: Nabors 16E Rig Activity: Drilling JobNm.: AK-AM-0007145033 Report For Daily Charges �1.0O4.00 ��' ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 07.0 74.4 204.9 10470' Flow |n(gpn) 228 SPP (psi) 1804 Gas (units) ., 1602 3684 10140' Flow |n(opm) 95 Gallons/stroke 2.5500 - � � . . Mud Data: Density (ppg) Viscosity API pH Chlorides MBT PV p r Solids Depth ft in out (sec/qt) (ppb Eq) cP |b/100f m1/30min mg/1 % 9660' 850 8.50 43 0.5 6 25 1.0 9.50 12.000 20 1 ' ' . BHA Run # | Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 XR 15T GPS 6 0.331 9995' ' %.,,,,,;. Lithology ( % ) : Sd Sst Silt Siltst Cht Clyst Sh Lst Coal CW Tuff (current) � Gas Breakdown �� I U U | | U | | U 1 1 1 1 1 . � ' Gas (units) Chromatograph (ppm) Depth Max Avg C1 C2 C3 C4 C5 7400' to 8750' 356 120 13938 314 172 101 6 8750' to 9912' 841 318 37957 1529 1026 643 188 9812' to 9995' 953 462 47541 2542 1895 1386 807 9995' to 10374' 3684 1511 57065 24708 23200 3494 148 :,i. t to to to to ' z Gas Type abreviations: BG - Background Gas GP - Ga Peak; CG - Co neutionGaaVVTG'V@per Trip Ga ; ` POG - Pumps Off Gas; PG Produced Gas; RG - Ream Gas; T-- - Trip...; F-- - Formation...; E-- - Early... ',,,' '1 ‘k?'..17 ' ���� , " "��� °v �� 1 ' =:S , | 24 hr Recap: We have drilled out cemen and completed the FIT. Resumed drilling from 9995 MD to 10439 MD. Gases C1-05 have been presen and consistant throughout the hole section. It's interesting how closely C2 and C3 track togethei often being within 1000ppm of each other. The level of C5 seems to have decreased from the previous hole section. | Note Logging Engineer Colby Marks/Justin Carter * 10000 units = 100% Gas In Air 1 Customer: BP Report #: 9 Well: 03-37i Date: 2/15/2010 Area: GPB 04:00 Depth 10739 ~~ Location: North Slope Progress 24 hrs: 317' Sperry Drilling Rig: Nabors 16E Rig Activity: POOH Job No.: AK-AM-0007145033 Report For: Daily Charges $1.804.00 ~_, � ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: `* R.O.P. (ft/hr) n/a 875 217.3 10504' Flow In (gpm) n/a SPP (psi) n/a Gas n /u 1231 8333 10440' Flow In (spm) n/a Gallons/stroke 25500 . �o ��, � 4�D; . ~ ���� �'' 4 ' Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP |b/100f m1/30min mg/I % 8.70 8.70 43 0.5 5 25 7.2 � 8.00 12 3.0 . . �� ` BHA Run # | Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition ^' 3 XR15TGPG 6 0.331 1610 9995 10739' 744' 96.30 ~ ' ~ " ^ Lithology CYO: Sd Sst Silt S�t Cht Clyst Sh Lst Coal G� Tuff ` U (current) Gas Breakdown I U U 1 1 U 1 1 U " . . ' � � , Gas (units) Chromatograph (ppm) Depth Max Avg C1 C2 C3 C4 C5 � 74OO' to 87 5O' 356 120 13938 314 172 101 6 ^ � 8750' to 8912' 841 318 37957 1529 1028 643 188 9912' to 9905' 953 462 47541 2542 1995 1386 607 9995' to 10374' 3684 1511 57865 24708 23200 3494 148 ' 10374' to 10739' 8333 1281 71988 10808 10050 2843 498 to to '� to to Gas Type abreviations: BG Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; " POG Pumps Off Gas; pG' Produced Gas; RQ' Ream Gas; T—'Thp—; F-- - Formation...; E-- - Early... . MD/9301'TVo Then POOH. Currently Iaying down BHA. , , / ' L . o , Note: , A Logging Co�yMo�oU��nCo�or * 10000 unda=100% Gas |n/�r
