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215-128
STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION 1f REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed NOV O 1 1015 Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ phaVlOe /P011�gmm ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ t ueeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number 215-126 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 11 6API Number: 50-029-22512-01-00 1 7 Property Designation (Lease Number): ADL 028325 8 028322 8. Well Name and Number: PBU 11-32A 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 13027 feet Plugs measured None feet true vertical 8742 feet Junk measured None feet Effective Depth: measured 12986 feet Packer measured 10188 feet true vertical 8742 feet Packer true vertical 8196 feet Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Conductor 77 20" 37-114 37-114 1490 470 Surface 3934 10-3/4" 36-3970 36-3807 4560 1730 Intermediate 10543 7-5/8" 34-10577 34-8530 8180/6890 5120 / 4790 Production Liner 2854 3-1/2" x 3-1/4" x 2-7/8" 10203 - 13027 8209-8742 Perforation Depth: Measured depth: 11203 - 12965 feet True vertical depth: 8759-8742 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 32-10260 32-8257 Packers and SSSV (type, measured and 4-1/2" Baker SABL-3 Packer 10188 8196 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Cement OA from Surface to 3979' Treatment descriptions including volumes used and final pressure: Pumped down OA: 10 bbls 60/40 spear, 48 bbls surfactant wash, 18 bbls 13.5 ppg mudpush II spacer, 20 bbls 15.8 ppg Class G cement, 78 bbls 15.8 ppg Class G with 15 -ppb aggregate (to empty tubs), 117 bbls neat 15.8 ppg Class G cement. Attempted hesitation squeeze twice w/minimal result. Final Pressures: OA = 42 psi, IA = 560 psi, TBG = 0 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 269 4805 4975 1712 215 Subsequent to operation: Shut In 560 0 14. Attachments (.,cored per20 nnc 25.070.25.071, a 25203) 15. Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WIND ❑ WAG ❑ 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: 319-283 Authorized Name: Smith, Travis T Contact Name: Smith, Travis T Authorized Title: Engin er Contact Email: travis.smithl@bp.com Authorized Signature: Date: / / Contac[ Phone: +1 9075645412 Form 10-404 Revised 04/2017fl�711I 1"`A& -X04g 9BDMSL NOV 0 51019 Submit Original Only Daily Report of Well Operations PBU 11-32A ACTI V IT V nATF c I uARA A My T/1/0=470/480/54 (LRS Unit 38 - OA Injectivity Test) DHD monitoring cellar and other wells in the vicinity. Vac truck on location. Pump 8 bbls crude down OA to pressure to 1000 psi. Pressure fell off. Established Final Injectivity of: 1 bpm @ 1700 psi. 2 bpm @ 248 psi. Pressure immediately fell off 3 bpm @ 540 psi 4 bpm @ 800 psi 5 bpm @ 1050 psi Valve positions=SV,WV,SSV closed MV open CV's OTG 575/480/18 9/14/2019 FWHP=575/480/18 SLB Fullbore Cementing crew. Job Objective: OA downsqueeze (cement OA from shoe to surface) MIRU/PT SLB cementers. SLB pumped down OA: 10 bbls 60/40 spear, 48 bbls surfactant wash, 18 bbls 13.5 ppg mudpush II spacer, 20 bbls 15.8 ppq Class G cement 78 bbls 15.8 ppq Class G with 15 -ppb aggregate (to empty tubs) 117 bbls neat 15.8 ppg Class G cement. Attempted hesitation squeeze twice w/minimal results. Grease crew serviced OA casing valve, tag hung on OA valve, operator notified. FWHP's=600/700/vac 10/11/2019 115.8 ppg Class G cement in OA from 3979' MD/ 3814' TVD to surface 1R/U T/1/0=750/600/0 POST CEMENT. R/D OA Valve. Inspect & clean out VR profile and valve body. 10/12/2019 OA valve. Torqued OA x CS to 297ft lbs. RDMO ***Job Cam lete*** FWHP = 750/600/0 WELLHEADMC REF LOG: GR/CCL ON 12/31/15 ACTURC Note: Refer to Production DB for hisbrical pert data OKB. 4.1' BF. ELA9' Opn/Sqz SHOT KOP=58' 2" Max A90'DatumNADatum'SS 11203 - 11549 O 01/01/16 DOME 2" 6 OACEMENTED SURFACE -3970' ■ -32A M�DOGLEM37.9- @ 1NOTES: WELL 1142'"`70CHROME TBG ' (1p/tuts) & WR'.. 191.5#, H-40, D = 19.124" 110-3/4" CSG, 45.5#, NT -80 BTC, D = 9.950" 1 CSG, 29.7#, NT -95 XO TO 13CR-80 NSCC 1-� 9980• Minimum ID = 2.3770• @1110061 33116" X 2-718" LNR XO I TOP OF 3-12" X 3-1/4" X 2-7/8' LNR (CMTD) I 4-1/2- TBG, 12.6#, 131CR-80 FOX, 10259' .0152 bpf, ID = 3.958' 3-12" LNR, 9.3#, 13CR-80 STL, 10557• .0087 bpf, D= 2.992- 7-5/8- CSG, 29.7#, 13CR-80 NSCC. D=6.875' 1 j 10573' 1 10573' PERFORATION S(1MMRY REF LOG: GR/CCL ON 12/31/15 ANGLEATTOP FHiF: 89° Q 11203' Note: Refer to Production DB for hisbrical pert data SIZE SFR= N(ERVAL Opn/Sqz SHOT SQZ 2" 6 11203 - 11549 O 01/01/16 DOME 2" 6 11712 - 11800 O 01/01/16 5502 2" 6 125(X1-12585 O 01/01/16 0 ! 11/14/16' 2" 6 12640 - 12965 O 01/01/16 TMPD 4-1/2" CA MCO TRCF-4A SSSV NP, D = 3.813" LOCKED OUT 12/23/05 HES GAS I IFT MAN IM S ST MID ND DEV TYPE VLV LATCH PORT' DATE 1 1 3884 3743 42 TMPD DOME BK 16 021 18/2 9 2 6401 5502 47 TMPD ONY BK 0 ! 11/14/16' 3 7222 6074 46 TMPD DOME BK 16 102/28/19 4 8201 6758 45 TMPD •OMY SK 0 01/12/06 5 9179 7442 46 TWO DONE BK 16 02/28/19 6 10079 8105 35 TMPD SO BK 26 -0228/19 cre.=1.v.0 �r e1CKING 1 10157' 1 14-12" HES EVO PLUG (07)27/19) f -5/8-X 4-1/2" BKR SABL-3 PKR W/ KBH-22 ANCHOR SEAL ASSY, ID = 3.955" FISH: (4) 4-12' WRP SLPS, (4) 4-12" WRP WS LP WRP SLP HOUSING PIECE (3/' 3.IU" 6KK Utmuy SLV, IU=: 3-12" HES X NP, D = 2.8113- 10248'4-1/2" OTIS X NP, D = 3.813" 10260•4-1/2" WLEG, o= 4.00" BOND CT LNR 10244' aMD TT LOGGED 11/15194 10557' MLLOUT WNDOW (11-32A) 10577'-10584- 1 0577'-10584' 3-1/4" LNR, 6.6#, 13 -CR TCI, .0079 bpf, D = 2.850' 1 11005• 1 13-3/16"X 2-7/8" XO, D = 2.377" PBTD 1298 .0058 bpf, ID = 2.441" DATE REVBY COMMENTS DATE REVBY COMMENTS 10/30194 N -18E ORIGINAL COMPLETION 03/04/19 RCB/JMD GLV C/O (0228/19) 01N1/18 NORDIC2 CTD SIDETRACK 11-32A 03/04/19 RCB/JMD FISH LEFT IN HOLE (03/01/19) 01/06M5 TBD/JMD GLV C/O 01104/16 06/03/19 JNUJMO ADDED BF ELEV B TAGGED FISH DEPTH 01/07/15 JMD DRLG HO CORRECTIONS 07/30/19 CJWJMD SET EVO PLUG (07Q7/191 01)20/16 JCVJMD FINAL ODE APPROVAL 10/14/19 MRD1JMU OA CEMENTED 10111/19 11/16/16 JTG/JMD GLVC/0(11M4/16) 12-7/8" RA PUP JOINT I 12822' H z-718" RA PRUDHOE BAYUNIT WELL: 11-32A PERMIT No:'2151280 API No: 5002&22512-01 BP Expbrabm (Alaska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Travis Smith Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 11-32A Permit to Drill Number: 215-128 Sundry Number: 319-283 Dear Mr. Smith: Alaska Oil and Gas Conservation Commission 333 Wesf Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogccalaska.gov 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, .�pp oC/ essi7 e,L Chmielowski Commissioner DATED this 12 day of June, 2019. RBDMSt±j JUN 13 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 mom` E€VD Opti 6 0q1 7 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 • Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program „0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other OA Cement Squeeze 0 . 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number. 215-128 ' 3. Address: P.O. Box 196612 Anchorage, AK 9951 9-8612 Stratigrephic ❑ Service ❑ 6. Apt Number: 50-029-22512-01-00 7, If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 11.32A 9. Property Designation (Lease Number): 10. Field/Pools: • ADL 028325 8 028322 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (tt): Total Depth TVD(ft) : Effective Depth MD: EBective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13027 • 8742 12986 8742 None 10173 Casing Length Size MD TVD Buret Collapse Structural Conductor 78 20' 37-114 36-114 1490 - 470 Surface 3932 10-3/4" 36-3970 36-3807 4560 1730 Intermediate 10543 7-5/8" 34-10577 34-8530 8180/6890 5120 / 4790 Production Liner 2854 /3-1/2" x 3-1/4" x 2-7/8" 10203 - 13027 8209-8742 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 1 11203 - 12965 1 - 8742 4-1/2" 12.6# 13Cr80 32-10260 Packers and SSSV Type: 4-1/2" Baker SABL-3 Packer Packets and SSSV MD (ft) and TVD (ft): 10188 / 8196 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 ❑ Exploratory ❑ Stratigraphic ❑ Development 0 • Service ❑ 14. Estimated Date for Commencing Operations: June 16, 2019 15. Well Status after proposed work: Oil 0 • WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ 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: Smith, Travis T be deviated from without prior written approval. Contact Email: tmAs.smithl@bp.com Authorized Name: Smith, Travis T Contact Phone: +1 907 564-5412 Authorized Title: Engi r Authorized Signature: Date: / COMMISSION USE ONLY Conditions of approval: Notify mission so that a representative may witness Sundry Number. n I Plug Integrity ❑ BOP Test ❑ Mechanical Integnty Test ❑ Location Clearance C]L�/, Other: Past Initial Injection MIT Req'd? Yes ❑ No ❑ / ff�� Spacing Exception Required? Yes ❑ No ©/ Subsequent Form Required:APPROVED • THE COMMISSION Approved by: COMMISSIONER COMMISSION Date: U ORIGINAL 'qBDMS_W`/JUN 13 7019 14 6T 6 N�/ Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate by 0 11-32A OA Cement Squeeze Well Interventions Engineer: Travis Smith (907) 564-5412 Pad Engineer: Travis Alatalo (907) 564-5351 History 11-32A is a gas -lifted producer that was made Not Operable and shut-in due to a surface casing leak in April 2019. �QSs I ea C_ IrV7 7 -r- --,cw rsa 00/��&_�' Current Status /0Abt0cal/ 40/-r,-..r55/Y1/6 -J 0lvE ! J The well is currently classified as Not Operable by BP due to a surface casing leak to gas. - Objective In order to reduce possible risks associated with surface casing leaks to the conductor, the OA will be cemented to surface with a downsqueeze cement job. Procedure Overview Special Projects 1. Steam clean the Conductor x Surface Casing Annulus to top of good cement. 2. Circulate cement into the conductor from the top of existing cement until clean cement returns are observed. Fullbore 3. WOC from conductor job at least 3 days. Establish injectivity rate and pressure with diesel or crude down the OA and into formation. Perform a step -rate injection test and record pump pressure and rate at several different pump rates. Max OA pressure 2500 psi. a. Make certain to monitor the cellar and conductor for returns while pumping down the OA. b. Have a vac truck on location and prepared to pump out of the cellar in case of returns to surface. Special Projects/ Fullbore 4. RU Cementers to the OA. RU in such a way that the OA can be closed in and wash-up water diverted upstream of the OA. Mix cement on the fly. Pump the following schedule at maximum rate below 2500 psi treating pressure. Prior to pumping, bump IA pressure to 1,000 psi backpressure to minimize risk of collapse for the 7-5/8" casing. 1. 10 bbls of 60/40 or neat McOH 2. 50 bbls hot surfactant wash (180°F freshwater + 2 gal/mgal F103 + 2 gal/mgal U067) 3. 10 bbls of 13.5 ppg MUDPUSH II Spacer 4. 20 bbls of neat 15.8 ppg Class G cement 5. 70 bbls of 15.8 ppg Class G with 15 -ppb aggregate 6. 120 bbls of neat 15.8 ppg Class G cement 5. Pump no displacement behind cement. Slow rate to approximately 1 bpm when aggregate reaches the casing shoe (-200 bbls of cement away / 10 bbls cement remaining to pump). 11-32A OA Down -Squeeze: 5/30/2019 TTS a. With 3-5 bbls of cement left to pump: Swap to take returns from upstream of the OA while still on cement (S/D pumping as needed). Be sure to swap away from the OA and direct returns to surface before the last of the cement is pumped downhole to ensure only cement goes down the OA. b. SI the OA and flush lines only to surface, without pumping down the OA. Note that the OA may be on a vacuum and may suck any wash water that is pumped across the OA down into the OA if allowed to do so. Note: Good success on OA down -squeezes has been realized by the hesitation squeeze method; i.e. shutting down pump entirely as the last —10 bbls of cement are pumped, watching to see if pressure is maintained or drops right off then pumping a couple more barrels until catching fluid and repeating this to give the aggregate every opportunity to bridge off either in the OA or at the shoe. See WSRs from X- 34, Y-39, and L1-13 for reference. 6. After washing up surface lines, hold an open bleed on OA for 1 hour, sniff for LEL's, then remove OA gate valve and manually clean any residual cement from the valve and VR profile. (See MOC #10083 for specific deviation details allowing for this operation). Cement Calculations — Fullbore OA Downs ueeze 10-3/4" x 7-5/8" volume from 3970' MD to surface 0.03975 b 160 bbls Total Cement to Pum 50 bbl excess 210 bbls Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to beequal to lab +/- 0.1 ppg Slurry Temperature 800 to 110° F Fluid Loss 40-200cc 20-100 cc / 30 min Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 4 hours Cement thickening time: Mix on the fly Activit Time hours Shearing time, quality control, PJSM 0 Cement displacement 2 Cement contamination 0 Safety 2 Minimum required thickening time: 4 Operations 7. Leave well shut-in. DHD 8. Monitor for fluid to surface 11-32A OA Down -Squeeze: 5/30/2019 TTS V*E LHEAD= FMC ACTUATOR= BAKERC OKB. E.EV = 64.1' BE. LLEV = 30.49' I(W= 2658' Max Angle = 96' @ 12190' Datum MD= NA Datum WD= 8800'SS )1.5#, FF40, D =19.124' NT -95 XO TO 13CR-80 NSCC Minimum ID = 2.377" @11005' 33116" X 2-718" LNR XO 4-12' TBG, 12.6#. 131CR-90 PDX, 10259' .0152 hpf, D = 3.958' 3-12' LNR 9.3#,13GR-90 STL, .0087 hpf, D= 2.992' 1 7-5/8' CSG. 29.7#. 13CR 80 NSCC. D=6.875' I PEiFORATIDN SUMMARY REF LOG: GR/CCL ON 12/31/15 ANGLEAT TOP FBiF: 89" @ 1120Y Note: R@fer to noduction DB for historical pert data SIZE SPF INTERVAL OpiVSclz SHOT SOZ 2' 6 11203-11549 O 01/01/16 BK 2' 6 11712-11800 O 01/01/16 2- 6 12500-12585 O 01/01/16 3 2" 6 12640-12965 O 01/01/16 BK 11-32A MAXDOGLEG: 378 NOTES: W @AN142 CHROME TBG & LNR**' 2091' 14-12" CAL400 TRCF-4A SSSV NP, D = LOCKED OUT 1223!05 HES GAS LIFT MANDRELS ST MD TVD I DEV1 TYPE VLV LATCH PORT DATE 1 3884 37431 42 1 TMPD DOME BK 16 022&19 2 6401 DMY BK 0 11/14/16 3 7222 DOME BK 16 0228119 4 8201 17"246 LTIMPD 'OMY BK 0 01/12106 5 9179 DOME BK 16 0228119 6 10079 SO BK 26 0228119 SIA64=131101Yrw5k 1w rw{iw11Rf 1018T 101.70194 N.18E ORIGINAL COMPLETION 7-SWX4-12"BKRSABL-3PKR 01/01116 C CTOSIDEMACK(11J2A) W KBFI-22 ANCHOR SEAL ASSY, D = 1955" 10173' SLM FISH: (4) 4-12' VVRP SLIPS, (4) 4-12' VMRP SLY 01107/15 .MD DRUG HO CORRBaTDNS SPRINGS, (1) 4-12' VVRPSLP HOUSING PETE 1—0� 3.70" BKR DR3'LOY SLV. D = 3.00' D=2.850' 10248' 4-'r--6SXNP,D=3.813' BEHIND 10260'j4-12'VVLEG,D=4.00' CT LNR 10214' HaAuTT LOGG®11/15/94 MILLOUTWNDOW(71�2A) 10577'-10584' 11269' 2-7/8• Ra. PUPJONr 11005' J ® I -CR .0058 hpf. D = DATE REV BY COMMENTS DATE REV BY COMMENTS 101.70194 N.18E ORIGINAL COMPLETION 03/04/19 RCBIMD GLV C/O (0226/19) 01/01116 C CTOSIDEMACK(11J2A) 03/04/19 RCB/J4D FISH LEFT IN HOLE (03/01/19) 01/06/15 TBD/JM GLV C/O (01104/16) 06/03/19 JNL/JM) ADDED BE B -B/ & TAGGED FISH 013TH 01107/15 .MD DRUG HO CORRBaTDNS 0120/16 JG/JMD FINAL ODEAPPROVAL 11/16/16 JTGCw1D GLV =(11114/16) PRUDFOE BAY UNIT WLL: 11-32A PERMIT No: 1151280 AR No: 50-029-22512-01 E, T11 N, R1 5E, 48' FNL & 125' FEL BP Exploration (Alaska) RA Proposed Schematic Tom= C16✓ . . A AA 1_"arryNnTFq-wFii AN[tl F> 70• ® 10940'... DATE REV BY COkbBJTS DATE REV BY COWARM 10130184 1418E ORXMLCOMPLEnON 03/04/79 RCWJAD GLV 00(02/2&19) 01101116 CTDSIDETRACK(11-32A) 03iOM19 Rmic FisHLEFrNHOLE(03/01/19) 01106/15 TBDfJVD GLV C20 (01/04/16) 01/07/15 JMD DRLGHDCORRFCTIONS 01M16 JG/JW F84ALODEAPPROVAL 1111&16 JT AU GLV O'O (11/14/16) 11-32A OA Down -Squeeze: 5/30/2019 TTS PRUDHOE BAY U7T WELL 11-32A R NIT' No: 2151280 AR 1b: 50-029-22512-01 t. T11N. R15E 48' FNL & 125' FE BP Exploration (Alaska) CO - v W as W r u N.- .-- • 0 0NZ u N CD o w X � Q � h JCA m �- �/1 +� 1110.12 HIN O ��� O 0� t. oOn F- a O ra NN a v, a c O o •0 C o C F- p Y > o < Q J w t0 (O R7 O O E m Q vJi Q o " +' F. O (c (a N C of C ro w V7 E. N Q ,- N N > _a) Z O E Q u -O O T F- C O N ro C W J J ra 41u W W_ pOp co 0 O --+ F- LL LL .N N N CO d ICo a- J J C_ 0 00 f6 0 0 g Z Z O M + M a p u LL LL N i v v ��yy 4 Y 0 > N 0 L� Y 0 E al a O 42 C� NC O m NU N (°} O > > C iO a. F 1-4:. a). g C (O L 00 .Tco a W V) W W w co U ' W Z 1M1 > l a.) 44C., , c. �� o t0 P4Oi.-rc Zai �' � HE2 W ..)• 0 e , ,,01/2...,111, Lu ba 00 4 a) l- d Z £ Z O U c _ , III , u L w 0 F- Z V1 LL CL O +-, 0 a CI yy Cr. x i•7"-)4° C' uj .� Q N N u ,c,..?„ O O f0 0 O " O O O O '!6 a', 'R o N Nel Lu V p >-" Y Y C m p o u cD o ovi I u� o m EI n N N of O EN N N , u N c d O 0 0 o 0 0 dC o L) O LI E L m E VEL. 5 a W 8 > w CC C .0 CID 3 CL pip r� Z r> -_ co CU I- 2 — y Lti Q 0 N -J d co N w 0 4-, vt — ( ZC .3L) Regg, James B (DOA) From: AK, OPS FS2 Field OTL <AKOPSFS2FieldOTL@bp.com> Sent: Wednesday, February 24, 2016 9:45 AM I` t ej To: Grimaldi, Louis R (DOA); AK, OPS FF Well Ops Comp Rep; AK, OPS FS2 DS Ops Lead;AK, OPS FS2 OSM Cc: Cocklan-vendl, Mary E; Regg, James B (DOA) Subject: RE: 11-32 Flowline and IA Line AOGCC Deficiency Report Attachments: 11-32 deficiency report.pdf; 11-32 VSM repair WO.PDF Hello, Please see attached signed copy of the 11-32 VSM deficiency report and a work order for Narcan to plan, construct and execute the installation of the 11-32 VSM repairs post RWO. Thank you, Jenna Witt, PE SCANNED SEP. 2 12016 Alternate:James Barndt FS2 Field OTL BPXA (o) 907.659.5493 (c) 406.231.2814 Hx702 From: Grimaldi, Louis R (DOA) [mailto:lou.grimaldi@alaska.gov] Sent: Wednesday, February 24, 2016 5:48 AM To: AK, OPS FF Well Ops Comp Rep; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Field OTL; AK, OPS FS2 OSM Cc: Cocklan-vendl, Mary E; Regg, James B (DOA) Subject: RE: 11-32 Flowline and IA Line AOGCC Deficiency Report Have not received signed copy. That copy only confirms your receipt of the deficiency report. Please sign, scan and return to me. Copy Jim Regg also. Thank you, Lou Louis R. Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission 907-776-5402 (Home) 907-252-3409 (Cell) Lou.Grimaldi(c�Alaska.gov 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 Lou Grimaldi at 907-252-3409 or Lou.Grimaldi@Alaska.gov. From: AK, OPS FF Well Ops Comp Rep [mailto:AKOPSFFWellOosCompRep(&bb.com] Sent: Tuesday, February 23, 2016 3:11 PM To: AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Field OTL; AK, OPS FS2 OSM Cc: AK, OPS FF Well Ops Comp Rep; Cocklan-vendl, Mary E; Grimaldi, Louis R (DOA) 1 State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: PBU Drillsite 11,Well#32A Date: 02/23/16 - Operator: BP Exploration PTD: 215-128 Operator Rep: Beau Obrigewitch (Hulme/Pokryfki) Position: Field compliance Op. Phone: 907-659-5332 Inspector: Lou Grimaldi Op. Email: Type Inspection: MIT Follow Up Req: yes Correct by(date): send estimate Detailed Description of Deficiencies Date Corrected Flowline/AL lines supports in reserve pit"jacking"out of ground and leaning. Develop remediation plan and submit to Commission. kCZ—) Signatures: g1/41"rwi;✓} ja - Operator Rep Lou Grimaldi AOGCC Inspector *After signing,a copy of this form is to be left with the operator. Follow-up instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the "Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification Failure to provide the required documentation of corrective actions constitutes a violation of 20 MC 25.300 and is subject to enforcement action under 20 MC 25.535 ` • • 1 1 1 I rr 4•I N v 0 C a C' CJ c v c f'•-I 4 o CO b0 ca g a N Q a. g 0 al b 0 N ,, fT CI c o ,b -°&'. w a d 2 I ro � 'r u _> co vi 0 o co c I X' 0 a) m Z W a. O O 2 ft. '.C« uJ p z r; el U2 ° ce tp `o 'till D. ° z 8 O o i oof uUi o 1-I ° 6 g ! ' 0) § ° 'e" -,c2- Ai , m h J U I , it,,...-4 Ns X M Pc: a is r o d N VI C � #+ t. 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I 1 I t; ,..- P/•6 2rs-izto Grimaldi, Louis R (DOA) To: AK, OPS FF Well Ops Comp Rep;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Field OTL;AK, OPS FS2 OSM Cc: Cocklan-vendl, Mary E Subject: RE: 11-32 Flowline and IA Line AOGCC Deficiency Report Have not received signed copy.That copy only confirms your receipt of the deficiency report. Please sign,scan and return to me. Copy Jim Regg also. Thank you, Lou Louis R. Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission 907-776-5402 (Home) 907-252-3409(Cell) Lou.Grimaldi@Alaska.bov 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 Lou Grimaldi at 907-252-3409 or Lou.Grimaldi@Alaska.gov. From: AK, OPS FF Well Ops Comp Rep [mailto:AKOPSFFWeIIOpsCompRep©bp.com] Sent: Tuesday, February 23, 2016 3:11 PM To: AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Field OTL; AK, OPS FS2 OSM Cc: AK, OPS FF Well Ops Comp Rep; Cocklan-vendl, Mary E; Grimaldi, Louis R(DOA) Subject: FW: 11-32 Flowline and IA Line AOGCC Deficiency Report Importance: High FS2 Team, Be advised that I had the attached deficiency report on flowlines in the reserve pit `jacking"out of the ground and leaning. As noted in the bottom of the report, they are requesting a remediation plan be developed and submitted to the AOGCC Commission within 7 days of this receipt. Please sign and scan a copy of the deficiency report to Lou Grimaldi (included in this email) today. Thank you, Lee Hulme Well Ops Compliance Advisor BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony—7187 (Alternate: Vince Pokryfki) 1 • From: Obrigewitch, Beau Sent: Tuesday, February 23, 2016 1:14 PM To: AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator Cc: Grimaldi, Louis R(DOA) Subject: 11-32 Flowline and IA Line AOGCC Deficiency Report Lee, Here is the Deficiency Report for the flowline and IA line on well 11-32 from Lou Grimaldi. If you have any questions, please let me know. I go home tonight, 2/23/1016. Beau Beau Obrigewitch Well Integrity Engineer BP Exploration (Alaska) Inc. PBOC—A210 Office: (907) 659-5766 Cell: (907)952-6271 Harmony—2377 W From: Grimaldi, Louis R (DOA) [mailto:Iou.grimaldi@alaska.aov] Sent: Tuesday, February 23, 2016 10:58 AM To: Obrigewitch, Beau Subject: Flowlines deficiency Please sign, scan and send me a copy. 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T T ill z co CO m N o I CO m o 0 Q O.c O. ° ili Q ° E o E 0 co z a) • N Tr t0 co > m T ~ a `) N d d CY 1 coD w M l6 U Z. £ o c a Link, Liz M (DOA) From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent: Thursday, February 25, 2016 2:13 PM To: AOGCC Reporting (DOA sponsored) Subject: PBU 11-32A/ PTD#215-128 Hello, Please reference the following well: Well Name: PBU 11-32A Permit* 215-128 API #: 50-029-22512-01-00 Date of Test: 2/12/16 Type of Test: IPT (Initial Production Test) Choke Size: 75 Choke Unit: 64ths Production Method: Gas Lift Duration (Hours Tested): 14 Top Reference (Top Perf MD): 11203' Bottom Reference (Bottom Perf MD): 12965' Tubing Flowing (Pressure): 188 Casing Pressure: 1400 Total Test(Rate f/0, G, W): 107/26/2498 24-Hour Rate (0, G, W): 184/44/4282 Gravity (Oil, API): N/A GOR (Gas-Oil Ratio): 238 This well began Production on: February 10, 2016 Method of Operations on this date: Gas Lift 1 RBDMS u- FE.B 2 6 2016 STATE OF ALASKA glitLASKA OIL AND GAS CONSERVATION COMMI WEL MPLETION OR RECOMPLETION REPAND LOG 1 a. Well Status: Oil 2• Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 0 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development p Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: One . Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 1/1/2016- . 215-128• 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 12/24/2015 50-029-22512-01-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 12T8t2err5-yam l' 12•1IAt%C PBU 11-32A • Surface: 48'FNL,125'FEL,Sec.33,T11N,R15E,UM 9 KB Ref Elevations • 17. Field/Pool(s): 64.1 i Top of Productive Interval: 52 FSL,276'FEL,Sec.21,T11N,R15E,UM GL 29.3 ° BF 30.49 PRUDHOE BAY,PRUDHOE OIL . Total Depth: 881'FNL,1921'FEL,Sec.28,T11N,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: • 12986'/8742' . ADL 028325&028322 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 707429° y- 5951673 " Zone - ASP 4 . 13027'/8742' - • 70-054 TPI: x- 707119 y- 5957046 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 705502 y- 5956069 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes p (attached) No 0 13. Water Deoth.if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) . 10577'/8530' • 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary MWD/GR/RES,GR/CCL/RPM 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT FT. CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM P0" 91.5# H-40 37' 114' 37' 114' 30" 260 sx Arctic Set(Approx.) 10-3/4" 45.5# NT-80 36' 3970' 36' 3807' 13-1/2" 1310 sx CS III,375 sx Class'G' 7-5/8" 29.7# NT-95/13Cr80 34' 10577' 34' 8530' 9-7/8" 650 sx Class'G' 3-1/2"x3-1/4" 9.3#/6.6# 13Cr80/13Cr85 10203' 13027' 8209' 8742' 4-1/4" 204 sx Class'G' x2-7/8" 6.5# /13Cr80 24. Open to production or injection? Yes p No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top anciQpl<p,Ln;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): ((�;UUMPLETION 4-1/2"12.6#13Cr80 10260' 10188'/8196' D�TE 2"Gun Diameter,6 spf lit l ZAAL) 11203'-11549' 8759'-8768' VERIFIED 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 11712'-11800' 8772'-8771' 1.'- 12500'-12585' 8750'-8751' Was hydraulic fracturing used during completion? Yes 0 No 2 - 12640'-12965' 8751'-8742' RECEIVED Per 20 AAC 25.283(i)(2)attach electronic and printed information JAN 2 6 2016 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 2500' Freeze Protect w/40 Bbls Diesel AOGCC 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ..+ Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate ''"10' Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only t YTL z/i R l k 'RBDMS �� JAN 2 7 2016 ,,, . ? oJ� 28. CORE DATA Conventional Core(s) Yes ❑ No El -• Sidewall Cores Yes ❑ No D - 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 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes ❑ No 0 Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 10882' 8721' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. 21 TS-Zone 2A 10704' 8624' Zone 1B 10799' 8679' TDF-ZONE 1 A 10882' 8721' Formation at total depth: Zone 1A 10882' - 8721' 31. List of Attachments: Summary of Daily Drilling Reports,Survey,Cement Report,Well Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Gorrell,John Email: John.Gorrell@bp.com Printed Name: Joe Lastuf Title: Drilling Technologist Signature: 1 + Phone: +1 907 564 4091 Date: i/2. J)-a 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. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a. 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 lb.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations 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 15.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 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records 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. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only TREE= PIN 4VELLtEAD= FMC ` -32A M��3 9(11142' 7 CH@ROMETBG ACTUATOR= BAKER C 8 LNR"' OKB.ELEV= 64.1' I BF.ELEV= KOP= 2658' Max Angle= 96"@ 12190' 20"CONDUCTOR, 112' Datum MD= NA 91.5#,H-40, I f::10 . [I 2091' —4-1/2"CAMCO TRCF 4A SSSV NF,D=3.813" Datum TVD= 8800'SS D=19.124" LOCK®OUT 12/23/05 HES GAS LFT MANDRELS 10-3/4"CSG,45.5#,NT-80 BTC,ID=9.950" —^3970' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3884 3743 42 TMPD DOME BK 16 01/04/16 2 6401 5502 47 TMPD SO BK 20 01/04/16 3 7222 6074 46 TMPD DMY BK-2 0 11/06/96 I 4 8201 6758 45 TMPD "DMY BK 0 01/12/06 7-5/8"CSG,29.7#,NT-95 XO TO 13CR-80 NSCC —j 9980' x ` y,� 5 9179 7442 46 TMPD DMY BK-2 0 04/07/96 6 10079 8105 35 TMD DMY BK-2 0 11/29/95 STA#4=DMY HAS MOWED PACKING Minimum ID = 2.377" @ 11005' 3-3/16" X 2-7/8" LNR XO 10187' —7-5/8"X 4-1/2"BKR SABL-3 PKR W/KBH-22 ANCHOR SEAL ASSY,D=3.955" TOP OF 3-1/2"X 3-114'X 2-718"LNR(CMTD) — 10203' 10203' --I3.70"BKR DEPLOY SLV,D=3.00" 01 S ogI. I 10224' 1-13-112"HES X NIP-,'D=2.813' I 9 10248' —14-112"OTIS X NP,D=3.813" i 4-1/2"TBG,12.6#,131CR-80 FOX, — 10259' ," 10260' --14-1/2"WLEG,ID=4.00" CT LNRINR � , ; 0152 bpf,13=3.958" #X. 10244• --I ELMD TT LOGGED 11/15/94 r#• y ► * . } + , ' 6 3-1/2"LNR,9.3#,13CR-80 STL, H 10557' *= +- # 10557' _-13-1/2"X 3-3116"XO,ID=2.786" .0087 bpf,D=2.992" 7-5/8'BKR WHIPSTOCK(08/25/15) H 10573' + k +' .,,,. ..,4" FALLOUT WINDOW(11-32A) 10577'-10584' r • 7-5/8"CSG,29.7#,13CR-80 NSCC,D=6.875" --I ^10573' T.......+ -.T 11005' —I3-3/16"X 2-7/8"XO,ID=2,377" PERFORATION SUMMARY REF LOG: GR/CCL ON 12/31/15 .. -4"1",.. 11259' H2-7/8"RA PUP JOINT ANGLE AT TOP PERF: 89"@ 11203' Note:Refer to Production DB for historical pert data �, �`a►, tt.•••••t'ti4 SE SPF INTERVAL Opn/Sqz SHOT SQZ 1�1�1l1..011 . 12822' 2-7/8"RA 2" 6 11203-11549 0 01/01/16 �1:1:•;t:1:�.�:�:��1 ►'�A PIP JOINT 2" 6 11712 11800 0 01/01/16 3-1/4"LNR,6.6#,13-CR TCI 11005' - 2" 6 12500-12585 0 01/01/16 2" 6 12640-12965 0 01/01/16 .0079 bpf,D=2.850" PBTD —I 12986' % 2-7/8"LNR,6.5#,13-CR,.0058 bpf,D=2.441" —I 13027' DATE REV BY COMUENTS DATE REV BY COMMENTS FRUDHOE BAY (NTT 10/30/94 N-18E ORIGINAL COMPLETION WELL: 11-32A 01/01/16 NORDIC2 CTD SIDETRACK(11-32A) PERMT No:'2151280 01/06/15 TBD/JM?GLV C/O(01/04/16) API No: 50-029-22512-01 01/07/15 JMJ DRLG HO CORRECTIONS SEC 33,T11N,R15E,48'FNL&125'FEL 01/20/16 JG/JM) FINAL ODE APPROVAL BP Exploration(Alaska) • • North America-ALASKA-BP Page 1 of 13 Operation Summary Report Common Well Name:11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 End Date:12/29/2015 X3-0173J-C:(3,376,474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00 @64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/20/2015 18:00 - 18:30 0.50 MOB P PRE CHANGE OUT MCC BREAKER IN SCR ROOM PER AGREEMENT WITH NORDIC TO CONDUCT THIS OPERATION AT WELL COMPLETION. 18:30 - 19:30 1.00 MOB P PRE PJSM FOR MOVING RIG OFF OF DS 11-10. DISCUSSION AND VERIFICATIONS TAKING PLACE FOR MOVE: -VERIFY ALL TREE VALVES(MV,SSV,SV) ARE CLOSED FOR MOVE OFF WELL. -PHYSICAL BARRIERS,12"X 12"STOPS,WILL BE IN PLACE TO PREVENT THE RIG FROM ROLLING BACK TOWARDS TREE/ VELLHEAD. -ESD WILL BE FUNCTION TESTED BEFORE MOVING THE RIG OFF THE WELL AND MANNED BY THE TOOLPUSHER OR NORDIC FIELD SUPERINTENDENT. -RADIO COMMUNICATION AND HAND SIGNALS WILL BE DISCUSSED IN THE PJSM AND VERIFIED FOR ALL INDIVIDUALS INVOLVED IN THE MOVE PRIOR TO MOVING THE RIG(SPOTTERS,ETC). -THE AGREED"COMMAND"TO STOP THE RIG MOVE WILL BE DISCUSSED AND UNDERSTOOD BY ALL. 19:30 - 20:30 1.00 MOB P PRE BACK OFF WELL AND MOVE RIG FROM 11-10AI TO 11-32A. 20:30 - 21:30 1.00 MOB P PRE PJSM FOR MOVING RIG ONTO DS 11-32A. DISCUSSION AND VERIFICATIONS TAKING PLACE FOR MOVING ONTO WELL: -VERIFY ALL TREE VALVES(MV,SSV,SV) ARE CLOSED FOR MOVE ON WELL. -PHYSICAL BARRIERS,12"X 12"STOPS,WILL BE IN PLACE TO PREVENT THE RIG FROM ROLLING BACK TOWARDS TREE/WELLHEAD. -ESD WILL BE FUNCTION TESTED BEFORE MOVING THE RIG OVER THE WELL AND MANNED BY THE TOOLPUSHER OR NORDIC FIELD SUPERINTENDENT. -RADIO COMMUNICATION AND HAND SIGNALS WILL BE DISCUSSED IN THE PJSM AND VERIFIED FOR ALL INDIVIDUALS INVOLVED IN THE MOVE PRIOR TO MOVING THE RIG(SPOTTERS,ETC). -THE AGREED"COMMAND"TO STOP THE RIG MOVE WILL BE DISCUSSED AND UNDERSTOOD BY ALL. -BP SUPERINTENDENT DAVE NEWLON ON LOCATION FOR PJSM AND MOVING OVER I THE WELL DUE TO 290 PSI ON OA THAT CANNOT BE BLED OFF. 21:30 - 22:00 0.50 MOB P PRE MOVE RIG OVER WELLAND JACK DOWN RIG. RIG ACCEPTED AT 22:00. SECURE AND HEAT CELLAR PLACE BOARDS ACROSS CELLAR Printed 1/11/2016 8:57.55AM • North America-ALASKA-BP • Page 2 of 13 Operation Summary Report Common Well Name:11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 End Date: 12/29/2015 X3-0173J-C:(3,376,474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00 @64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 00:00 2.00 MOB P PRE CYCLE TREE VALVES,STROKE SSV WITH SLB HYDRAULIC PANEL PAD OPERATOR ON LOCATION TO REMOVE LOCK ON WING VALVE OPEN SWAB,SSV,AND MASTER VALVE. ZERO PSI ON TUBING. CLOSE SWAB AND MASTER VALVE FOR LEAK TIGHT TEST. LEAK TIGHT TEST IS GOOD. REMOVE TREE CAP. 12/21/2015 00:00 - 06:00 6.00 MOB P PRE HOLD PJSM FOR REMOVING TREE CAP AND NIPPLING UP BOPE TREE VALVES CYCLED,VISUAL LEAK TIGHT TEST PER WELL PROGRAM GOOD-REMOVE TREE CAP,NO PRESSURE OBSERVED NIPPLE UP BOPE INSTALL LUBRICATOR OFFLOAD FRESH WATER TO THE RIG FOR BOP TESTING TAKE STACK MEASUREMETS GREASE/SERVICE HCRS -HOLD H2S RIG EVACUATION DRILL WITH AAR WITH NIGHT CREW CONDUCT PRE-SPUD WITH DAY CREW AFTER MORNING PRE-TOUR MEETING 06:00 - 10:00 4.00 BOPSUR P PRE SLIGHT TRICKLE LEAK ON DOOR SEAL. CONDUCT INSPECTION ON DOOR SEALS TO CONFIRM CORRECT INSTALLATION,FIND PINCH ON ONE SEAL,REST ARE FINE. REPLACE THE ONE SEAL,RE-TIGHTEN ALL DOORS. (NOTE:EQUIPMENT MANUFACTURER SENT A NEW TYPE OF DOOR SEAL FOR THEIR BOP DOORS-THESE SEALS HAVE BEEN USED WITH CDR RIG ON CONOCO SIDE WITH SOME HISTORICAL ISSUES WITH DIFFICULTY IN GETTING SEAL. THIS IS BEING LOOKED INTO BY NORDIC MANAGEMENT). -GREASE CREW VERIFIED STROKE ON SSV, ADJUSTMENT ON FUSIBLE CAP -TEST ALL AUDIBLE AND VISUAL ALARMS FOR BOP TEST -DISCUSS PRESSURE CROSSCHECKS AND CONTROL DURING BOP TEST 10:00 - 10:15 0.25 BOPSUR P PRE PUMP WATER THROUGH MGS,FLOW PATH THROUGH MGS IS VERIFIED CLEAR. Printed 1/11/2016 8:57:55AM North America-ALASKA-BP Page 3 of 13 t Operation Summary Report d F/- .� Common Well Name:11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 End Date:12/29/2015 X3-0173J-C:(3,376,474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UVI:500292251200 Active datum:49:32 10/14/1994 00:00 @64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 10:15 - 19:00 8.75 BOPSUR P PRE FILL STACK AND ALL LINES,CONDUCT BODY TEST,TEST GOOD. I-TEST BOP COMPONENTS WITH 2-3/8"AND 3-12"TEST JOINTS PER BP,NORDIC,AND AOGCC STANDARDS TO 250 LOW/3500 HIGH. FUNCTION COMPONENTS FROM DRILLER'S CONSOLE. CONDUCT DRAWDOWN TEST. FUNCTION ALL COMPONENTS FROM CTS REMOTE CONSOLE. AOGCC NOTIFIED OF BOP TEST ON SUNDAY DECEMBER 20,2015 AT 18:17 AOGCC INSPECTOR GUY COOK WAIVED WITNESS BY EMAIL ON SUNDAY DECEMBER 20,2015 AT 20:11 -HOLD PRE SPUD MEETING WITH ELLINGTON NIGHT CREW AFTER PTM 19:00 - 22:00 3.00 BOPSUR P PRE HOLD PJSM,DISPLACE DIESEL FROM COIL WITH FRESH WATER FOR PRESSURE TEST -TEST FROM KILL LINE TO INNER REEL IRON, INNER REEL VALVE,AND PACKOFFS;TEST FROM PUMP THROUGH RIG IRON TO INNER REEL VALVE I TORQUE ALL TREE BOLTS WITH INJECTOR WEIGHT ON TREE 22:00 - 22:30 0.50 BOPSUR P PRE HOLD PJSM AND PULL BOP TEST PLUG-NO PROBLEMS 22:30 - 00:00 1.50 BOPSUR P PRE PJSM TO PULL TWC AND BRING DSM LUBRICATOR TO RIG FLOOR. VERIFY TREE MEASUREMENTS TO ENSURE PROPER ROD AND STROKE LENGTH. RIG UP LUBRICATOR. 12/22/2015 00:00 - 02:30 2.50 BOPSUR P PRE PULL TWC CONTINUE RIGGING UP DSM LUBRICATOR I PT 250 PSI LOW/3500 PSI HIGH FOR 5 CHARTED MINUTES EACH-GOOD TEST PER CRITERIA FOR TEMPORARY PIPEWORK OPEN MASTER AND SWAB VALVES STROKE ROD IN AND ENGAGE TWC. TUBING PRESSURE=60 PSI OPEN WELL TO TIGER TANK,PRESSURE BLEEDS OFF IMMEDIATLY. SHUT IN FOR 10 MINS AND OPEN BACK UP TO CHECK FOR REPRESSURIZATION-NONE. PULL TWC TO SURFACE. CLOSE MASTER AND SWAB RIG DOWN DSM LUBRICATOR AND REMOVE FROM RIG -HOLD H2S/RIG EVACUATION DRILL WITH ELLINGTON'S CREW,NIGHTS Printed 1/11/2016 8:57:55AM • North America-ALASKA-BP • Page 4 of 13 Operation Summary Report Common Well Name 11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 End Date 12/29/2015 X3-0173J-C:(3,376,474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM, Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00 @64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 05:30 3.00 RIGU P PRE HOLD PJSM,CUT COIL STAB ON INJECTOR AND PT 7-1/16"OTIS CONNECTION. BLOW BACK COIL WITH RIG AIR BLOW DOWN STACK CUT 100'OF COIL DRESS END OF COIL FOR EXTERNAL CONECTOR !MU EXTERNAL SLIP TYPE CTC PULL TEST TO 42K BOOT ELINE PT CTC 250 PSI LOW/3500 PSI 05:30 - 07:15 1.75 STWHIP P WEXIT MU 3.80"WINDOW MILLING BHA ON BAKER OIL TOOLS STRAIGHT MOTOR AND DUMB IRON WORK STRING. STAB ON,PT QTS WHILE PREPARING TO RIM. 07:15 - 12:15 5.00 STWHIP P WEXIT RIH WITH BHA CIRCULATING 8.3 PPG KCL ON TRIP IN AT MIN RATE. NO ISSUES RUNNING DOWN. GET TO BOTTOM,SLOW RUNNING RATE. DRY TAG WHIPSTOCK AT 10,598' UNCORRECTED DEPTH. -PICK UP,BRING PUMPS ON AND DISPLACE WELL WITH WARM KCLAT 2.78 BPM,2100 PSI. IAAND OA PRESSURES BOTH ROSE AS WARM FLUID WAS CIRCULATED. BLEED IA FROM 925 PSI TO 25 PSI,BLEED OA FROM 660 PSI TO 0 PSI. -CHASE KCL WITH 9.45 PPG MUD SYSTEM AT !2.75 BPM,2520 PSI. RECORD SLOW PUMP RATES WHEN MUD IS ALL THE WAY AROUND. 12:15 - 18:00 5.75 STWHIP P WEXIT MOVE DOWN,BRING RATE UP. FREE SPIN OF 2860 PSI AT 2.70 BPM. POSSIBLE MOTORWORKAT 10,593'UNCORRECTED DEPTH. PICK UP TO AVOID STALL,MOVE BACK DOWN SLOWLY. ENGAGE WHIPSTOCK,BEGIN MILLING FROM 10,593'AT 2.73 BPM,2915 PSI,UTILIZING SURFACE WEIGHT ON BIT INDICATOR AND TIME-MILLING. -CONSISTENT MOTOR WORK BUT PRETTY LOW DIFFERENTIAL PRESSURE AT 100-140 PSI. WOB VARIED FROM 1.3-6.4K ON SURFACE WEIGHT INDICATOR. SLACK OFF WEIGHT 23-24K. -MW IN 9.48 PPG,MW OUT 9.40 PPG 18:00 - 00:00 6.00 STWHIP P WEXIT CONTINUE MILLING PER DIRECTION FROM OCN AND BOT REP. DIFFERENTIAL MOTORWORK HAS BEEN PICKING UP SINCE 10,597'. SLACK OFF WEIGHT STAYING IN THE RANGE OF 22-23K. -CIRCULATING PRESSURE AT 2.73 BPM AT 3140 PSI,PREVIOUS FREE SPIN WAS AT 2860 PSI. WOB -SEE BOT REPORT FOR FULL MILLING OPERATIONAL PARAMETERS -DRILL TO 10600. MILL SHOULD BE EXITED. HAVE 300-400#MOTORWORK/FULL 7K WOB. NOT DRILLING AHEAD. -PICK UP TO VERIFY PARAMETERS. 2850#AT 2.73 BPM. Printed 1/11/2016 8:57.55AM North America-ALASKA-BP S Page 5 of 13 Operation Summary Report Common Well Name:11-32 AFE No Event Type.RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 End Date:12/29/2015 1X3-0173J-C:(3,376,474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA i UWI:500292251200 Active datum:49:32 10/14/1994 00:00 a©64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/23/2015 00:00 - 02:30 2.50 STWHIP P WEXIT 2850#FREE SPIN AT 2.74 -MAKING NO HEAD WAY. PUMP SAMPLE UP. 30%CHERT PEBBLES -PUMP 15 BBL LO VIS PILL TO STIR UP. sTILL NO CHANGE. 02:30 - 03:30 1.00 STWHIP P WEXIT 1 CALL ODE. DISCUSS OPTIONS I PULL UP INTO TAILPIPE TO VERIFY WE CAN COME INTO TAIL. NO OVERPULLS, CIRC PRESSURE RAPIDLY CLIMBING LIKE WE ARE DRAGGING SOMETHING. RIH TO BOTTOM FOR FLOW ICHECK HAD TWICE WERE CIRC PRESSURE JUMPED IN THE MIDDLE OF NO WERE. 03:30 - 04:06 0.60 STWHIP P WEXIT RIH TO ABOVE WHIPSTOCK 04:06 - 04:30 0.40 STWHIP P WEXIT START DYNAMIC FLOW CHECK. OUT RATE READING 0.06 HIGH. SHUT DOWN FOR PUMPS OFF FLOW CHECK AFTER INITIAL BLEED DOWN. FLOW TO POSSUM BELLY. I SHUT IN WELL PER STANDING ORDERS/ OPEN WELL UP TO A CLOSED CHOKE MONITOR WELL. CREEP OUT OF HOLE AND PUMP PIPE DISPLACEMENT.WHILE PRESSURE STABILIZE 04:30 - 06:00 1.50 STWHIP P WEXIT DISCUSS ANOMALY WITH WELL SUPERINTENDENT/WTL. DECISION IS TO MONITOR WELLBORE WHILE CONDUCTING CREW CHANGE. WELL IS NOT ON LOSSES, HOLE FULL WITH 9.45 PPG MUD SYSTEM. 06.00 - 14:00 8.00 STWHIP N DPRB WEXIT CONDUCT CREW CHANGEOUT,WSLS AND FIELD SUPERINTENDENT DISCUSS ALTERNATIVES. UTILIZE INFORMATION FROM WELLS GROUP DATABASE,SOR AND GEO TEAM TO DETERMINE THAT THIS IS ANTICIPATED GAS POCKET OUTSIDE OF WELLBORE. DEVELOPED PLAN FOR CIRCULATION. LINED UP THROUGH CHOKE AND CONDUCTED CIRCULATION TO CLEAN UP MUD. ONE-FOR-ONE RETURNS AND EQUALIZED MUD WEIGHT AFTER 170 BBLS. MONITOR FOR 30 MINUTES,NO PRESSURE AND NO FLOW AT FLOW CHECK. DISCUSS WITH TOWN,CONDUCT ONE MORE BOTTOMS UP THROUGH MGS,AGAIN NO PRESSURE ON CASING OR TUBING. NOTIFIED TOWN,RECEIVED PERMISSION TO OPEN UP TO WELLAND CONDUCT FLOW CHECK FLOW CHECK ALL GOOD. 14:00 - 16:30 2.50 STWHIP N DPRB WEXIT POH CIRCULATING THROUGH MGS. NO ISSUES ON TRIP UP,MUD PROPERTIES AND FLOW RATES GOOD. FLOW CHECK AT j SURFACE,ALL GOOD. -MW IN 9.45 PPG,MW OUT 9.41 PPG,NO LOSSES TO WELL -IA 0 PSI,OA INITIAL AT 338 PSI,FINAL 298 PSI Printed 1/11/2016 8:57:55AM • North America-ALASKA-BP • Page 6 of 13 Operation Summary Report Common Well Name:11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 End Date:12/29/2015 X3-0173J-C:(3,376,474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00©64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 17:45 1.25 STWHIP N DPRB WEXIT MONITOR WELL PARAMETERS. DISCUSSION WITH ODE AND TOWN GEO REP,DECIDE TO USE SMART TOOLS ON NEXT RUN IN ORDER TO MONITOR REALTIME PRESSURES ON BOTTOM. -LD BHA,WINDOW MILL GAUGE AT 3.52" NO-GO,STRING REAMER GAUGE AT 3.75" NO-GO. WINDOW MILL CENTER IN GOOD SHAPE. -TEST HCR PER AOGCC.REQUIREMENTS SINCE IT WAS CLOSED IN FOR THE CIRCULATION OPERATION. GOOD TEST. 17:45 - 23:15 5.50 STWHIP P WEXIT PREP TOOLS FOR NEXT OPERATION. CLEAR AND CLEAN RIG FLOOR. PREPARE FOR PUMPING SLACK BACK. -STAB ON WITH INJECTOR,PUMP SLACK BACK. CUT 280'COIL. -PJSM, OPEN HOT WORK PERMIT.DRESS COIL FOR CONNECTOR. -ATTEMPT TO UTILIZE SLB COIL CONNECTOR INTERNAL. DECIDE TO GO EXTERNAL DIMPLE INSTALL EXTERNAL DIMPLE. PULL TEST TO 35K. PRESSURE TEST COIL CONNECTOR TO 300# LOW/4000# GOOD TEST -INSTALL NOZZLE/STAB INJECTOR. PUMP SLACK FORWARD -MEG E-LINE 1670 MEGAOHMS,CONTINUITY TEST 54 OHMS -MAKE UP BHI UPPER QUICK CONNECT. PRESSURE TEST 300 LOW/4000#HIGH -STAB INJECTOR/FLUID PACK. 23:15 - 23:40 0.42 STWHIP P WEXIT -PRESSURE TEST PACKOFF/FLOATS TO LOW/HIGH 3500#PASSED 23:40 - 00:00 0.33 STWHIP P WEXIT DISPLACE COIL OVER TO MUD 12/24/2015 00:00 - 01:00 1.00 STWHIP P WEXIT OPEN WELL TO CLOSED CHOKE. WELL STATIC. MAKE UP BHA 01:00 - 03:40 2.67 STWHIP P WEXIT INJECTOR ON WELL RIH WITH BHA#2 ISSUES WITH BHI COMPUTER SOFTWARE RUN TO JUST ABOVE WHIPSTOCK 03:40 - 04:45 1.08 STWHIP P WEXIT CIRCULATE A BOTTOMS UP 04:45 - 05:15 0.50 STWHIP P WEXIT PERFORM 30 MIN FLOW CHECK OFF BOTTOM. WELL STATIC 05:15 - 05:20 0.08 STWHIP P WEXIT BHI FIXED PULL UP TO 10400'FOR TIE IN 05:20 - 06:00 0.67 STWHIP P WEXIT PERFORM TIE IN LOG AT 150'/HR 06:00 - 07:00 1.00 STWHIP P WEXIT COMPLETE LOGGING FOR PRIMARY DEPTH CONTROL WITH-17'CORRECTION. RECORD SLOW PUMP RATES. DRY TAG WHIPSTOCK AT 10,582'CORRECTED DEPTH. PICK UP,ON WITH PUMPS. Printed 1/11/2016 8:57:55AM 41111 North America-ALASKA-BP • Page 7 of 13 Operation Summary Report Common Well Name:11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 End Date:12/29/2015 X3-0173J-C:(3,376,474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00©64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:00 - 11:00 4.00 STWHIP P WEXIT BEGIN MILLING OPERATIONS FROM 10,582' BY SLOWLY MOVING DOWN TO ENGAGE WHIPSTOCK. USE CAUTION DUE TO UNDER-GAUGE OF LAST MILL ASSEMBLY (3.52"WINDOW MILL AND 3.75"STRING REAMER). FREE SPIN OF 2760 PSI AT 2.70 BPM. MILL AHEAD AT 2.70-2.85 BPM,2915-3040 PSI,.15-.45K WOB -FIRST SAMPLE UP CONSISTS OF SANDSTONE AND CHERT -MW IN 9.45 PPG,MW OUT 9.40 PPG,ECD OF 10.50 PPG -ADDING METAL FRICTION REDUCER TO SYSTEM DUE TO INDICATIONS OF STICK-SLIP DURING MILLING. 11:00 - 12:15 1.25 STWHIP P WEXIT CALCULATED STRING REAMER IS OUT OF WINDOW,MILLING RATHOLE. MILL AT 2.85 BPM,3040-3090 PSI. -MW IN 9.43 PPG,MW OUT 9.38 PPG,ECD OF 10.55 PPG,NO LOSSES TO FORMATION. -MILL NEW FORMATION TO 10,600' -IA CLIMBED TO 160 PSI,OA CLIMBED TO 640 PSI 12:15 - 13:30 1.25 STWHIP P WEXIT CONDUCT REAM PASSES PER WELL PLAN AND BOT REP. PICK UP OFF BOTTOM CLEAN. FIRST PASS UP THROUGH WINDOW VERY CLEAN. -REAM AT 2.85 BPM,3050-3080 PSI -PASSES DOWN CLEAN AT 27-29K SLACK OFF WEIGHT. CONDUCT DRY DRIFT AFTER i THIRD REAM PASSES. -IAAT 160 PSI,OAAT 415 PSI WITH PUMPS DOWN. HAD ONE-FOR-ONE RETURNS DURING MILLING OPERATIONS. BOTTOMS UP SAMPLE IS 85%SANDSTONE,15% CHERT. 13:30 - 14:30 1.00 STWHIP P WEXIT OPEN EDC OFF BOTTOM,PICK UP TO LOG CCL WHILE CIRCULATING DOWN HI-VIS PILL. LOG CCL FROM 10,100-10,400'FOR LINER TOP SETTING LATER IN WELL. RUN DOWN TO TIME BOTTOM WITH HI-VIS PILL COMING OUT OF BHA. -CONDUCT FLOW CHECK AT BOTTOM,NO FLOW 14:30 - 17:00 2.50 STWHIP P WEXIT 1 POH CHASING HI-VIS PILL OUT OF HOLE AT 3.50 BPM,3000 PSI. -MW IN 9.42 PPG,MW OUT 9.37 PPG,IA 200 PSI,OA 450 PSI,NO LOSSES PJSM ON HANDLING BHA. DISCUSSION FOCUSED ON PARTICULARLY LONG BHAAND MEASURES TAKEN IN A WELL CONTROL EVENT. CONDUCT FLOW CHECK AT SURFACE,ALL GOOD. -POP OFF WITH INJECTOR Printed 1/11/2016 8:57:55AM North America-ALASKA-BP Page 8 of 13 Operation Summary Report Common Well Name:11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 End Date: 12/29/2015 X3-0173J-C:(3,376,474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA i UWI:500292251200 Active datum:49:32 10/14/1994 00:00(4164.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 18:30 1.50 DRILL P PROD1 BREAK OFF AND LAY DOWN BHA. VNNDOW MILL GAUGE AT 3.79"NO-GO,STRING REAMER AT 3.79"NO-GO. WINDOW MILL (BEAR CLAW)HAD ONE CHUNK MISSING FROM JUNK SLOT AND PRETTY WORN DOWN AROUND GAUGE AREA OF FACE. -ARRANGE AND SWAP OUT COMPONENTS OF BHA FOR NEXT RUN -CLEAR AND CLEAN RIG FLOOR,MOBILIZE BOT TOOLS OFF OF RIG 18:30 - 20:50 2.33 DRILL P PROD1 STAB INJECTOR RIH LOG TIE IN APPLY A -19.5'CORRECTION CLOSE EDC. _ 20:50 - 22:20 1.50 DRILL P PROD1 TAG BOTTOM AT 10601' DRILL AHEAD TO GET SOME ROOM 22:20 - 22:30 0.17 DRILL P PROD1 PERFORM SCR'$/ UPDATE KILL SHEET 22:30 - 23:00 0.50 DRILL P PROD1 DRILLED AHEAD-TO 10633' HAVING TECHNICAL DIFFICULTIES WITH BHI DIRECTIONAL SOFTWARE PULL UP INTO CASED HOLE/OPEN EDC _ 23:00 - 00:00 1.00 DRILL N SFAL 10,633.00 PROD1 WAITING ON TECH SUPPORT TO GET -DIRECTIONAL SURVEY 12/25/2015 00:00 - 02:00 2.00 DRILL N SFAL 10,633.00 PROD1 BHI SOFTWARE ISSUE. RESTARTED MULTIPLE TIMES. DIRECTIONAL SURVEY FINALLY WORKING. BHI SENDING SCREEN SHOTS TO TECH SUPPORT TO GET TO THE BOTTOM OF THE PROBLEM 02:00 - 04:00 2.00 DRILL P PROD1 DRILL BUILD SECTION 10633-10670 FREE SPIN=3307 PSI AT 2.92 BPM RATE IN=3.00 BPM RATE OUT=3.00 BPM MW IN=9.44 PPG MW OUT=9.37 PPG ECD =10.60PPG ROP=18 FPH WOB=0.6-1.0K CIRC PSI= 3409 PSI IAP=123 PSI OAP=330 PSI PVT=457 BBLS 04:00 - 06:00 2.00 DRILL P PROD1 DRILL BUILD SECTION 10670-10680' FREE SPIN=3307 PSI AT 2.92 BPM RATE IN=3.00 BPM RATE OUT=3.00 BPM MW IN=9.44 PPG MW OUT=9.36 PPG ECD =10.60 PPG ROP=10 FPH WOB=0.6-1.4K CIRC PSI= 3409 PSI IAP=315 PSI OAP=490 PSI PVT=457 BBLS 06:00 - 11:30 5.50 DRILL P PROD1 DRILL AHEAD IN BUILD SECTION FROM 10,680'. FREE SPIN OF 3230 PSI AT 2.97 BPM. -2.93-2.97 BPM,3325-3650 PSI,2.5-4.5K WOB, ECD INCREASED FROM 10.58-10.65 -VARIED ROP DUE TO SHALE AND CHERT STRINGERS -PUMP HI-VIS SWEEP IN ATTEMPT TO CLEAN UP METAL RETURNS. SWEEP INCREASED CUTTINGS ACROSS SHAKER BY-25%;NO MORE OBSERVATIONS OF METAL SHAVINGS. -MW IN 9.44 PPG,MW OUT 9.38 PPG,NO LOSSES -IA 475 PSI,OA 565 PSI,NO BLEEDS Printed 1/11/2016 8:57:55AM • North America-ALASKA-BP • Page 9 of 13 Operation Summary Report Common Well Name:11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 ' End Date:12/29/2015 X3-0173J-C:(3,376,474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00©64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 13:30 2.00 DRILL P PROD1 WIPER UP TO WINDOW. PICKUP CLEAN AND NO ISSUES ON TRIP AND PULLING INTO WINDOW. OPEN EDC,JET UP THROUGH 7-5/8"CASING. LOG TIE-IN TO FORMATION AND RA TAG WITHA+2'CORRECTION. CONTINUE WITH RIH BACK TO BOTTOM OF 10,850% 13:30 - 18:00 4.50 DRILL P PROD1 DRILL AHEAD FROM 10,850'. FREE SPIN OF 3150 PSI AT 2.93 BPM. 2.91-2.97 BPM,3230-3600 PSI,1.7-3.65K WOB,10.65 PPG ECD -MW IN 9.44 PPG,MW OUT 9.40 PPG,NO LOSSES -IA AT 650 PSI,OA AT 630 PSI VARIED ROP,SAMPLES REVEALING SOME CHERT AND ALSO SILTSTONE MIXED INTO j THE PREDOMINANT SANDSTONE PUMPED HI-VIS SWEEP TO SEE IF IT WOULD HELP WITH ROP,NOTHING _ SIGNIFICANT WITH RETURN 18:00 - 23:30 5.50 DRILL P PROD1 DRILL BUILD SECTION 11000'TO 11170' FREE SPIN=3307 PSI AT 2.92 BPM RATE IN=3.00 BPM RATE OUT=3.00 BPM MW IN=9.44 PPG MW OUT=9.37 PPG ECD =10.70 PPG ROP=VARIED FPH WOB=0.6-1.0K CIRC PSI=3409 PSI IAP=717 PSI OAP=603 PSI PVT=454 BBLS LACKING FINAL SURVEY DUE TO MAGNETIC STORM DISCUSSED WITH DD, WILL LAND FINAL 30' OF BUILD WITH LATERAL BHA. STORM SHOULD BE OVER 23:30 - 00:00 0.50 DRILL P PROD1 STAGE 10 BBLS LO VIS /10 BBLS HI VIS AT 1 BIT PERFORM 10 MIN DYNAMIC FLOW CHECK. 0.53 BPM IN /0.47 BPM OUT MOVING 10'/MIN.WELL STATIC POOH 12/26/2015 00:00 - 02:30 2.50 DRILL P PROD1 PULL TO WINDOW OPEN EDC. COME ONLINE AT 3.5 BPM/ JET ACROSS 7-5/8"AT 80% WHEN PILLS ARRIVED AT SURFACE, INCREASE IN CUTTING BY-15-20% 9.40 PPG IN/9.41 PPG OUT PULL TO 200', PERFORM 10 MIN FLOWCHECK. WELL STATIC LOST 3 BBLS ON WAY OUT INJECTOR OFF WELL 02:30 02:30 - 03:24 0.90 DRILL P PROD1 LAY DOWN BUILD BHA -BIT GRADED 2-1 -MAKE UP LATERAL BHA. STAB INJECTOR 03:24 - 03:55 0.52 DRILL P PROD1 PT QTS 300 LOW/3500 HIGH OPEN EDC Printed 1/11/2016 8:57:55AM • North America-ALASKA-BP • Page 10 of 13 Operation Summary Report Common Well Name:11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 ' End Date:12/29/2015 X3-0173J-C:(3,376,474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00 Q64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) . (usft) 03:55 - 05:30 1.58 DRILL P PROD1 RIH WITH BHA#4 0.59 BPM IN/1.22 BPM OUT 9.39 PPG IN /9.42 PPG OUT IA/OA=333/363 NO BLEEDS 05:30 - 05:50 0.33 DRILL P PROD1 LOG TIE IN. APPLY-20'CORRECTION 05:50 06:30 0.67 DRILL P PROD1 CLOSE EDC. PERFORM SPR'S RIH TO BOTTOM 06:30 - 14:15 7.75 DRILL P PROD1 TAG AT 11170' FREE SPIN=3200 PSI AT 2.5 BPM RATE IN=2.5-2.81 BPM RATE OUT=2.5-2.84 BPM INITIAL MW IN=9.45 PPG,CLIMBED TO 9.55 PPG MW OUT=9.46 PPG INITIAL ECD= 10.70 PPG WOB=2.3-3.15K CIRC PSI=3450-4000 PSI INITIAL IAP=448 PSI,ROSE TO 775 PSI INITIAL OAP=322 PSI,ROSE TO 530 PSI -NO LOSSES TO FORMATION,CUTTINGS WET OVER SHAKER -SLACK OFF WEIGHT WHILE DRILLING AVERAGED 18-20K. PICK UP WEIGHT DURING WIPERS 49-52K. CONDUCT SEVERAL PICKUPS AND TWO BHA WIPERS DURING DRILLING. PUMP ONE LO-VIS AND HI-VIS PILL COMBO,INCREASE IN FLUID VOLUME BUT NO CUTTINGS DIFFERENCE. LAST TWO PICKUPS SEMI-STICKY,ECD HAS BUILT UP TO 10.87 PPG. _.....-._------- 14:15 - 15:45 1.50 DRILL P PROD1 CONDUCT LONG WIPER FROM 11,628'TO WINDOW IN ATTEMPT TO CLEAN UP WELLBORE. PUMP HI-VIS PILL DOWN AND THEN CHASE UP DURING WIPER. CIRCULATE AT 2.77 BPM,3215 PSI,PUW 51-52K. -LOG TIE-IN TO RA TAG WITH-1.5' CORRECTION -MOVE BACK DOWN TO BOTTOM AT 2.90 BPM,3425 PSI,22-24K SLACK OFF WEIGHT 15:45 - 19:00 3.25 DRILL P PROD1 BACK TO BOTTOM, FREE SPIN OF 3340 PSI AT 2.92 BPM. -BLEED IA DOWN FROM 705 PSI TO 0 PSI, DROPPED OA PRESSURE FROM 530 PSI TO 475 PSI. -2.90-2.92 BPM,3640-4000 PSI,4.8-5.0K WOB, ECD AT 10.87 PPG -MW IN 9.55 PPG,MW OUT 9.46 PPG,SOME LOSSES WITH CONSISTENT CUTTINGS OVER SHAKER BUT NONE TO FORMATION 19:00 - 00:00 5.00 DRILL P PROD1 DRILLING AHEAD. GAMMA SIGNATURE SHOWING TOP OF BSAD. TURN UP TO DRILL OUT. PERFORM WIPERS AS NEEDED. VERY SLOW ROP. ECD FLUCTUATING 10.8 TO 11.07 9.53 PPG IN /9.48 PPG OUT SOME LOSSES WITH CONSISTENT CUTTINGS OVER SHAKER. 12/27/2015 00:00 - 01:50 1.83 DRILL P PROD1 MAKING NO HEADWAY. WEIGHT TRANSFER BECOMING ISSUE. ECD GOING UP PUMP 10 BBLS LOVIS/10BBLS HIVIS Printed 1/11/2016 8:57:55AM • North America-ALASKA-BP S Page 11 of 13 Operation Summary Report Common Well Name:11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 End Date:12/29/2015 X3-0173J-C:(3,376;474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00 l 64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:50 - 04:15 2.42 DRILL P PROD1 WIPER TO WINDOW -OPEN EDC. PUMP AT 3.8 BPM WHILE SWEEPING 7-5/8"UP TO 10000' -NO REAL NOTICIBLE INCREASE IN CUTTINGS -PUMP BOTTOMS UP WHILE PERFORM TIE IN. APPLY+4.5 CORRECTION 04:15 - 05:00 0.75 DRILL P PROD1 RtH TO START DRILLING 05:00 - 06:00 1.00 DRILL P PROD1 TAG AT 11931' FREE SPIN=3527 PSI AT 2.93 BPM RATE IN=2.93 BPM RATE OUT=2.93 BPM INITIAL MW IN=9.52 PPG MW OUT=9.47 PPG INITIAL ECD=10.89 PPG WOB=2.3-3.15K CIRC PSI=3450-4000 PSI INITIAL IAP=249 INITIAL OAP=594 PSI 06:00 - 14:30 8.50 DRILL P PROD1 DRILL AHEAD SLOWLY IN TOUGH FORMATION. ENCOUNTERING STICK SLIP, CONDUCT FREQUENT PICKUPS AND SHORT WIPERS THAT HELPED FOR SHORT DURATION(10'). -FREE SPIN AT 2.91 BPM OF 3440 PSI. CIRC PRESSURES VARIED FROM 3805-4000 PSI WHILE DRILLING. -MW IN 9.55 PPG,MW OUT 9.49 PPG,ECD ROSE FROM 10.95 PPG TO 11.1 PPG,-1 BPH LOSSES TO FORMATION -HARD TO TRANSFER WEIGHT AND INITIATE DRILLING,PREPARE TO DISPLACE TO NEW 9.5 PPG POWERPRO MUD SYSTEM 14:30 - 15:30 1.00 DRILL P PROD1 WIPER FROM BOTTOM TO WINDOW TO CLEAN UP HOLE WHILE DISPLACING TO NEW MUD SYSTEM. CIRC PRESSURES AND ECD DROPPED AS NEW POWERPRO MUD SYSTEM COMING AROUND. MW IN 9.53 PPG, MW OUT 9.50 PPG -INITIAL PICK UP CLEAN,PICK UP WEIGHT COMING UP HOLE-54K. PICK UP THROUGH SHALE ZONE AT 11,750-11,630'WITH ONE OVERPULL OF 2-3K,OTHERWISE CLEAN. -PULL INTO WINDOW WITH NO ISSUES. OPEN EDC AND JET 7-5/8"CASING TO MOVE CUTTINGS. 15:30 - 16:30 1.00 DRILL P PROD1 PREPARE TO LOG. BOTTOMS UP HAS INCREASE OF-10%MORE CUTTINGS RETURNS. LOG TO FORMATION MARKER WITH+6'CORRECTION. -IA PRESSURE DROPPED FROM 335 PSI TO 0 PSI,OA PRESSURE DROPPED FROM 600 PSI TO 240 PSI WITH CLEAN MUD ALL THE WAY AROUND 16:30 - 19:00 2.50 DRILL P PROD1 CLOSE EDC,RIH. FLOW RATE OF 2.1 BPM, 2390 PSI,SLACK OFF WEIGHT WHILE MOVING DOWN 27-30K. ONE MINOR AREA OF MOTORWORKAT 11,700'ON TRIP BACK DOWN. Printed 1/11/2016 8:57:55AM • North America-ALASKA-BP • Page 12 of 13 Operation Summary Report Common Well Name:11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 End Date:12/29/2015 X3-0173J-C:(3,376,474.00) Project Prudhoe Bay I Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM !Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00 @64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 20:45 1.75 DRILL P PROD1 DRILL AHEAD FROM 12281'TO 12416' FREE SPIN=3230 PSI AT 2.88 BPM RATE IN=2.89 BPM RATE OUT=2.87 BPM MW IN=9.53 PPG MW OUT=9.48 PPG ECD =11.16 PPG •WOB=2.0-2.5K CIRC PSI=3650 PSI IAP=0 OAP=277 PSI -DRILLED AHEAD, STARTED HAVING SLIDE ISSUES AFTER 135'. PERFORM WIPER TO WINDOW OPEN EDC. JET 7-5/8"UP INTO TUBING TAIL. 20:45 - 21:15 0.50 DRILL P PROD1 FINISH WIPER TO 10,000' 4.22 BPM IN /4.46 BPM OUT ECD AT 11.47 PPG I RIH SPEED 40'/MIN TO INCREASE AVS TO 459'/MIN IN TUBING TIE INTO FORMATION +2.5 PUMP A BOTTOMS UP, SLIGHT INCREASE IN CUTTINGS 21:15 - 22:13 0.97 DRILL P PROD1 CLOSE EDC AND HEAD BACK TO BOTTOM SAW SLIGHT MOTORWORK/SET DOWN AT 11683' 22:13 - 23:30 1.28 DRILL P PROD1 TAG AT 12416' LOST 3 BBLS TO FORMATION DURING WIPER DRILL AHEAD WITH VARYING ROP AVERAGE OF 40'MIN. I COME TO A STAND STILL. WEIGHT TRANSFER BECOMING ISSUE PUMP 10 BBLS LOVIS/10 BBLS HIVIS, WHILE WIPER UP TO 12,000' 23:30 - 00:00 0.50 DRILL P PROD1 WIPER UP TO 12,000 12/28/2015 00:00 - 02:13 2.22 DRILL P PROD1 RIH TO 12502'WHEN LO VIS OUT BIT. DRILLED AHEAD WITH MULTIPLE SHORT WIPERS 2.98 BPM IN /2.98 BPM OUT AVERAGING 500-600#MOTOR WORK DRILL 10' ATA SHOT THEN WON'T SLIDE PUMPED ANOTHER TANDEM LO/HI VIS SWEEP NO HELP. PULL OUT FOR AGITATOR 02:13 - 02:23 0.17 DRILL P PROD1 PERFORM 10 MIN DYNAMIC FLOW CHECK 0.54 BPM IN /0.48 BPM OUT 9.49 PPG IN /9.48 PPG OUT POOH AT 5'/MIN LOSSES OF 1.8 BPH TO FORMATION. 02:23 - 05:50 3.45 DRILL P PROD1 WIPER UP TO WINDOW. OPEN EDC, JET 7-5/8" POOH 3.55 BPM IN/3.18 BPM OUT 9.53 PPG IN/9.50 PPG OUT PULL TO SURFACE/RIH 200'TO CLEAR BHA. LOST 8 BBLS THIS TRIP 05:50 - 06:15 0.42 DRILL P PROD1 PERFORM 10 MIN FLOW CHECK GOOD FLOW CHECK. COME ONLINE FOR HOLE FILL CALCULATED LOSSES 1.2 BPH. -POP OFF WITH INJECTOR _ 06:15 - 07:30 1.25 DRILL P PROD1 STAND INJECTOR BACK LD BHA,BIT GRADE 1-1-NO. MODIFY BHA TO INCLUDE NEW GAMMA SUB AND AGITATOR. MU NEW BHA. STAB ON WITH INJECTOR. Printed 1/11/2016 8:57:55AM • North America ALASKA-BP • Page 13 of 13 Operation Summary Report Common Well Name: 11-32 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/20/2015 End Date:12/29/2015 X3-0173J-C:(3,376,474.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00(d264.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 12:00 4.50 DRILL P PROD1 RIH WITH BHA WHILE PRESSURE TESTING QTS. LOG TIE-IN TO FORMATION WITH-20' CORRECTION. CONTINUE TO RIH,CLOSE EDC AT WINDOW. RUN INTO OPEN HOLE WITH NO ISSUES. SLACK OFF WEIGHT WHILE RUNNING DOWN GOOD AT 23-25K. SLIGHT BOBBLE AT 11,684'BUT NO ISSUE 'MOVING PAST. CONTINUE DOWN,CONFIRM SURVEY WITH JORPS. RUN TO BOTTOM. 12:00 - 18:00 6.00 DRILL P PROD1 ON BOTTOM,FREE SPIN OF 3600 PSI AT 2.58 BPM. -DRILL AHEAD WITH ERRATIC ROP,LOT'S OF PICK UPS TO KEEP WEIGHT TRANSFER -2.52-2.67 BPM,3685-4150 PSI,AGITATOR SEEMS TO BE WORKING WELL -1.9-3.5K WOB,ECD OF 11.1 PPG -MW IN 9.58 PPG,MW OUT 9.55 PPG,TOTAL OF 5 BBLS LOST DURING DRILLING -IAAT 235 PSI,OA AT 430 PSI,NO BLEEDS DURING TOUR -CONDUCT H2S RIG EVAC DRILL WITH DAY TOUR CREW 18:00 - 22:25 4.42 DRILL P PROD1 DISCUSSED WITH TOWN. DRILL AHEAD FROM 12995-13015'UNCORRECTED CALLED TD. WIPER FROM TD TO WINDOW OPENED EDC. JET 7-5/8"UP INTO TUBING TAIL 22:25 - 23:30 1.08 DRILL P PROD1 ;FINISHED JETTING UP TO 9995' RIH AND TIE IN TO FORMATION WITH+10.5' CORRECTION CONTINUE PUMPING AT 3.6 BPM WHILE PERFORMING TIE IN. PUH TO LOG CCL WHILE PUMPING BOTTOMS UP. 23:30 - 00:00 0.50 DRILL P PROD1 LOGGED CCL 12/29/2015 00:00 - 00:30 0.50 DRILL P PROD1 CONTINUE IN HOLE WITH CCL. LOG ACROSS RA. RIH 00:30 - 01:47 1.28 DRILL P PROD1 RIH TO CORRECTED TD AT 13027. SLIGHT SET DOWN AT 12006' PICK UP. DROP TO MIN RATE AND GO BY 01:47 - 01:57 0.17 DRILL P PROD1 PERFORM 10 MIN DYNAMIC FLOW CHECK 1.0 BPH LOSS RATE 01:57 - 03:30 1.55 DRILL P PROD1 LAY IN LINER RUNNING PILL OPEN EDC AT WINDOW. 03:30 - 06:30 3.00 DRILL P PROD1 PAUSE AT 9985'. FLAG PIPE YELLOW(EOP OF 9900'). PICK UP,PAINT WINDOW FLAG. -CONDUCT H2S RIG EVACUATION DRILL WITH NIGHT TOUR CREW,FOLLOW WITH AAR. -POH WITH BHA TO SURFACE. FLOW CHECK,ALL GOOD. FUNCTION TEST AGITATOR AT SURFACE;INDICATIONS IT IS WORKING AT 2.4 BPM,3150 PSI -PULL BHA INTO BOP,POP OFF 06:30 - 07:00 0.50 DRILL P PROD1 LD BHA. SEE CON REPORT FOR CONTINUED OPERATIONS. Printed 1/11/2016 8:57:55AM • • North America-ALASKA-BP Page 1 of 6 Operation Summary Report ', Common Well Name:11-32 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/29/2015 End Date:1/1/2016 X3-0173J-C:(2,390,554.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00 @64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/29/2015 07:00 - 10:00 3.00 CASING P RUNPRD CUT OFF COIL CONNECTOR,CIRCULATE TO PUMP SLACK FORWARD. PUMP OUT 204'OF E-LINE. -PREP END OF COIL,INSTALL BOT CONNECTOR,PULL TEST AND PT IS GOOD. 1-CIRCULATE 3/4"DRIFT BALL AROUND I-FUNCTION TEST CROWN SAVER 10.00 - 15:30 5.50 CASING P RUNPRD PJSM FOR RUNNING LINER. DISCUSS HANDLING,WELL CONTROL CONTINGENCIES (CHANGE TO STANDING ORDERS). -RE-COUNT PIPE TO VERIFY RUNNING ORDER AND PIPE OUT OF ORDER 1-MU 2-7/8"X3-1/4"X3-112"LINER ASSEMBLY PER WELL PLAN AND LINER SUMMARY 15:30 - 17:00 1.50 CASING P RUNPRD M/U LINER RUNNING TOOLS AND 6 JTS OF 2-3/8"PH-6. 17:00 - 19:00 2.00 CASING P RUNPRD ZERO COUNTERS,TEST QTS,RIH. PUMP 0.36 BPM/1440 PSI. 19:00 - 20:10 1.17 CASING P RUNPRD STOP AT FIRST FLAG,CORRECT-31 FT TO 10,424 FT. CONTINUE RIH. START STACKING WT AND WORKING LINER AFTER 12,280 FT. CYCLE PIPE UP AND DOWN,UP WT IS 70K DOWN TO-7K. GET ABOUT 10-20 FT EACH TIME. MAINTAIN 0.2-0.3 BPM WHILE WORKING PIPE. 20:10 - 20:10 0.00 CASING P RUNPRD GET MINERAL OIL SPOTTED,START BUILDING KCL SPACER. 20:10 - 00:00 3.83 CASING P RUNPRD SEND 10 BBL KCL SPACER/20 BBLS MINERAL OIL/10 BBLS KCL 0.32 BPM IN /0.32 BPM OUT 12/30/2015 00:00 - 00:40 0.67 CASING P RUNPRD KCL COMING OUT SHOE. CAN'T PUMP BELOW 1500#, CALL AND DISCUSS WITH BOT/ODE ABOUT RAISING TRIPS TO 1800# WHILE PUSHING MINERAL OIL AROUND RATE WENT FROM.97 BPM IN /AND.96 BPM OUT 1696# 00:40 - 01:10 0.50 CASING P RUNPRD MINERAL OIL TURN CORNER. SPOT 5 BBLS OUT. DROP TO MINIMUM RATE. KEEP WORKING PIPE. SLOWLY MOVING LINER DOWN HOLE. PICKUPS BETWEEN 72K-85K 01:10 - 01:30 0.33 CASING P RUNPRD WENT BY SECOND FLAG. -2'CORRECTION. TAG BOTTOM OVER AND OVER SAME SPOT AT 13014' PICK UPS CLEAN COMING OFF BOTTOM CALLED AND DISCUSSED WITH ODE, WITH AS MUCH AS WE WORKED PIPE. CALLED LINER AT TD 01.30 - 03.15 1.75 CASING P RUNPRD FINISH CIRCULATING MINERAL OIL AND SPACERS OUT PREP PITS FOR RELEASING FROM LINER Printed 1/11/2016 9.11:09AM • North America-ALASKA-BP • Page 2 of 6 Operation Summary Report Common Well Name.11-32 AFE No Event Type:COM-ONSHORE(CON) ' Start Date: 12/29/2015 End Date:1/1/2016 X3-0173J-C:(2,390,554.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00 @64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:15 - 03:30 0.25 CASING P RUNPRD PU WEIGHT 12994'©64K. REPEAT THREE TIMES 13013'TD WITH 10K DOWN. PJSM WSL/BOT/SLB VERIFIED 5/8"BALL LOAD 5/8"STEEL BALL 03:30 - 04:00 0.50 CASING P RUNPRD LAUNCH 5//8 BALL 9;50 PPG IN/9.5 PPG OUT BALL LANDED AT 51.1 BBLS SHEARED OUT AT 4400#. PICK UP TO BREAKOVER 52K AT 13003'TO VERIFY WE ARE RELEASED 04:00 - 06:00 2.00 CASING P RUNPRD CIRCULATE KCL AROUND. 1.5 BPM 850 PSI 8.36 PPG IN/8.36 PPG OUT.-3 BPH LOSSES IA/OA=16#/587# 06:00 - 08:30 2.50 CASING P RUNPRD CREW CHANGE AND RIG CHECKS. GET EXHAUST PILL LOADED ONTO RIG. CEMENT CREW CHANGES OUT AND GETS RIGGED UP. 08:30 - 10:00 1.50 CASING P RUNPRD PJSM WITH SLB CEMENT CREW AND NORDIC RIG CREW FOR MIXING AND PUMPING CEMENT. WSL CONDUCT PRESSURE XCHECK CARD AND VERIFY ELECTRONIC TRIP FUNCTION WITH SLB SUPERVISOR. LOW PRESSURE TEST FAILS INITIALLY, GREASE REEL ISOLATION VALVE ON RIG AND RE-TEST. Printed 1/11/2016 9:11:09AM 1111 North America-ALASKA-BP • Page 3 of 6 Operation Summary Report Common Well Name:11-32 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/29/2015 End Date:1/1/2016 'X3-0173J-C:(2,390,554.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00 @64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 12:20 2.33 CEMT P RUNPRD LO PRESSURE RE-TEST IS GOOD. PT TO HIGH PRESSURE IS GOOD. CEMENT IS WET AT 10:33. VERIFY WEIGHT AND START CEMENT DOWN CT. ZERO IN MM WHEN CEMENT IS UP TO WEIGHT. SLB PUMP UNIT PUTS 42.4 BBLS CEMENT IN REEL,THEN SHUT DOWN AND CLEAN UP THE LINES. RIG DISPLACES CEMENT AT 2.1 BPM UNTIL IT REACHES SHOE,ZERO OUT MM AT THIS POINT. STOP WITH 2 BBLS CEMENT LEFT ABOVE SELRT. SET PUMP TRIPS TO 1800 PSI,PICK UP+13 FT AND SET BACK DOWN,NOW 10 FT HIGHER. ROLL PUMP AND SEAT PEE-WEE DART WITH 1500 PSI. CLOSE BAKER CHOKE AND SET DOWN-10K, ZERO IN MM AND LAUNCH PLUG(TOOK 0.6 BBLS TO LAUNCH) PUSH PLUG AT 2.4-2.74 BPM UP TO 3700 PSI. -SHUT DOWN AT 18.7 BBLS(0.6 BBLS OVER) -DID NOT SEE PRESSURE SPIKE,HOWEVER PRESSURE HELD AT 2600 PSI AFTER SHUTTING DOWN. PLUG MAY HAVE BUMPED. BLEED OFF CT PRESSURE,CHECK FLOATS, GOOD. PRESSURE UP TO 700 PSI,PICK UP TO BREAKOVER+2 FT. PUMP 5 BBLS HERE AT 1 BPM. TOTAL CEMENT PUMPED 42.4 BBLS. TOTAL BEHIND PIPE 38.4 BBLS. 12:20 - 14:15 1.92 CEMT P RUNPRD POOH MAKE OUT RATE 0.3 BPM. 14:15 - 15:00 0.75 CEMT P RUNPRD 10 MIN PUMPS OFF FLOWCHECK SHOWS NO FLOW. UD 6 JTS OF PH6 AND LINER RUNNING TOOLS. RECOVER 5/8"BALL,TOOLS HAVE FUNCTIONED NORMALLY. OFFLOAD BTT EQUIPMENT. 15:00 - 16:30 1.50 CEMT P RUNPRD CUT OFF CT CONNECTOR. INSTALL SLIM CONNECTOR. PULL TEST TO 35K IS GOOD,PT 250/3800 PSI IS GOOD. 16:30 - 17:00 0.50 CLEAN P OTHCMP i PREP RIG FLOOR FOR RUNNING CSH. 17:00 - 22:20 5.33 CLEAN P OTHCMP M/U BHA#7,LOGGING/CLEANOUT BHA. 22:20 - 23:53 1.55 CLEAN P OTHCMP STAB INJECTOR PT QTS. RUN IN HOLE WITH LOGGING BHA 23:53 - 00:00 0.12 CLEAN P OTHCMP START LOGGING FROM 9950' AT 30'/MIN DOWN 12/31/2015 00:00 - 01:43 1.72 CLEAN P OTHCMP SAT DOWN AT LINER TOP. PICKUP AND LOG BACK DOWN. NO ISSUE LOG DOWN TO A UNCORRECTED PBTD OF 13000.06(IMMEDIATE MOTOR WORK) Printed 1/11/2016 9:11:09AM • North America-ALASKA-BP • Page 4 of 6 Operation Summary Report Common Well Name:11-32 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/29/2015 End Date:1/1/2016 X3-0173J-C:(2,390,554.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00 t64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:43 - 04:23 2.67 CLEAN P OTHCMP 1%KCL WITH SAFELUBE AT BIT START LOGGING UP AT 20'/MIN PERFORM DYNAMIC FLOW CHECK 1:1 PAINT WHITE FLAG AT 12839.96'BIT DEPTH I(10509.65'EOP) PAINT YELLOW FLAG AT 10053.21' BIT DEPTH (7722.90'EOP) GETTING A LOT OF GREEN CEMENT THROUGH MM. FINALLY CLEAN KCL BACK. BRING IN. 04:23 - 06:00 1.62 CLEAN P OTHCMP POOH TO MARKER PUP. CONDUCT PJSM WITH RIG CREWAND LOGGING HAND FOR PULLING TOOLS OUT. 06:00 - 10:00 4.00 CLEAN P OTHCMP SHIFT CHANGE AND RIG CHECKS. 15 MIN PUMPS OFF FLOW CHECK SHOWS NO FLOW. PJSM WITH DAY SHIFT FOR REMOVING INJECTOR FROM WELL. UD 2 JTS 2-1/16"CSH AND 60 JTS OF 1-1/4" CSH. *** CONDUCT KICK WHILE TRIPPING DRILL WITH ELLINGTON CREW. CREW LOADS SAFETY JOINT ONTO V-DOOR,PICKS IT UP AND TORQUES IT,RUNS IT INTO THE WELL. DRILLER CORRECTLY IDENTIFIES SHUT IN SEQUENCE AS PER STANDING ORDERS. WELL SECURED IN 2 MIN. AAR WITH CREW. UD LOGGING TOOLS AND OFFLOAD FOR DATA DOWNLOAD. 10:00 - 10:30 0.50 CLEAN P OTHCMP DOWNLOAD DATA. RPM TOOL QUIT WORKING AT 10,700 FT ON THE WAY IN,GR AND CCL DATA IS GOOD ALL THE WAY DOWN AND UP. DISCUSS WITH ODE,DECISION IS MADE NOT TO RE-RUN THE LOGS. 10:30 - 11:35 1.08 DHB P OTHCMP CONDUCT PJSM FOR LINER LAP TEST. DISCUSS EXCLUSION ZONES AND VALVE LINEUPS. TEST LINER LAP. LOW PRESSURE PASS. HIGH PRESSURE AS FOLLOWS(TOOK 2.2 BBLS TO PRESSURE UP): 0 MIN=2869 PSI 15 MIN=2816 PSI 30 MIN=2791 PSI TEST ISA PASS AS PER CRITERIA IN WELL PLAN SECTION 2.3.4 TEST PRESSURE ON ANALOG CIRCLE CHART IS LOWER,ALSO SHOWS PASS. 11:35 - 12:00 0.42 PERFOB P OTHCMP PREP RIG FLOOR TO RUN PERF GUNS. 12:00 - 14:30 2.50 PERFOB P OTHCMP WAIT ON SLB PERFORATORS,GR/CCL DATA WAS NEEDED TO FINALIZE THE PERF MEMO. 14:30 - 17:00 2.50 PERFOB P OTHCMP PERFORATING CREWARRIVES. LOAD PERF GUNS ONTO RIG. SORT AND PREP GUNS. 17:00 - 21:47 4.78 PERFOB P OTHCMP PJSM WITH NORDIC AND SLB TCP CREWS. M/U PERF GUNS AS PER PERF MEMO. Printed 1/11/2016 9:11:09AM • North America-ALASKA-BP Page 5 of 6 Operation Summary Report ,, .,, Common Well Name. 11-32 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/29/2015 End Date: 1/1/2016 X3-0173J-C:(2,390,554.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00 @64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:47 - 00:00 2.22 PERFOB P OTHCMP INJECTOR ON WELL PT QTS SUB RIH AT MINIMUM RATE. 1/1/2016 00:00 00:52 0.87 PERFOB P OTHCMP STOP AT FLAG(WHITE) 12686.8'CTDS. CORRECT DEPTH TO 12667.20'(10502.69'CORRECTED EOP+ 2164.51') -19.6'CORRECTION. SAME AS OUR DRILLING CORRECTIONS RIH TO TAG PBTD ON DEPTH. PICK UP TO BREAKOVER. RESET DEPTH TO 12986.07' 00:52 - 01:07 0.25 PERFOB P OTHCMP SLOWLY CREEP UP TO JUST BELOW FIRING DEPTH WHILE PERFORMING FIRING COMMANDS PER TCP REP FIRE GUNS ON DEPTH. GOOD SHOT !DETECTION 11,203'-11,549' 11,712'-11,800' 12,500'-12,585' 12,640'-12,965' 01:07 - 02:30 1.38 PERFOB P OTHCMP SHUT CHOKE IN WHILE WE TRY TO GET RETURNS WELL INITIALLY TOOK 2 BBLS TO FILL GUNS MAINTAIN 200 PSI ON WELL WHILE PULLING GUNS OUT OF LINER 02:30 - 02:45 0.25 PERFOB P OTHCMP AT LINER TOP. OPEN CHOKE PERFORM 10 MIN FLOW CHECK. FLOW CHECK STATIC. 9 BBLS LOST ON TRIP SHEET TO THIS POINT 02:45 - 04:35 1.83 PERFOB P OTHCMP CONTINUE OUT OF HOLE. 1.40BPM IN /0.88 BPM OUT 8.34 PPG IN /8.34 PPG OUT TRIP SHEET LOST 17 BBLS 04:35 - 04:45 0.17 PERFOB P OTHCMP PERFORM 10 MIN FLOW CHECK 04:45 - 11:00 6.25 PERFOB P OTHCMP TAG UP. FLUSH HYDRIL WITH FRESHWATER PJSM WITH TCP. START PULLING OUT OF HOLE WITH PERF GUNS. FILL WELL EVERY 20 PERF GUNS PULLED. WHILE PULLING PERF GUNS GET LRS RIGGED UP AND PT THE LINES. WSL PERFORM PRESSURE XCHECK VERIFICATION WITH LRS SUPERVISOR. FINISH L/D FINAL PERF GUN,ALL SHOTS FIRED. 11:00 - 12:20 1.33 PERFOB P OTHCMP CLEAN AND CLEAR RIG FLOOR. OFFLOAD PERF GUNS AND RUNNING EQUIPMENT. FILL WELL. LOST ABOUT 10 BBLS WHILE PULLING PERF GUNS. 12:20 - 14:30 2.17 WHSUR P POST PJSM WITH LRS AND NORDIC CREW FOR PUMPING FREEZE PROTECT. FREEZE PROTECT TUBING FROM 2500 FT WITH 40 BBLS DIESEL. TAG STRIPPER WITH DIESEL AT SURFACE, CLOSE SWAB AND MASTER VALVES. 14:30 - 16:00 1.50 WHSUR P POST PJSM WITH N2 CREW. REVIEW PRESSURE XCHECK VERIFICATION. WSL VERIFY ELECTRONIC TRIPS WORKING. COOL DOWN AND PT LINES,GOOD. Printed 1/11/2016 9.11:09AM North America-ALASKA-BP • Page 6 of 6 Operation Summary Report Common Well Name:11-32 AFE No Event Type:COM-ONSHORE(CON) Start Date:12/29/2015 End Date:1/1/2016 1X3-0173J-C:(2,390,554.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1994 12:00:00AM Rig Release:1/1/2016 Rig Contractor:NORDIC CALISTA UWI:500292251200 Active datum:49:32 10/14/1994 00:00©64.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 17:00 1.00 WHSUR P POST PURGE REEL WITH N2. ALLOW IT TO BLEED OFF. 17:00 - 18:00 1.00 WHSUR P POST GREASE TREE VALVES,PREP FOR LEAK TIGHT TEST. REMOVE INJECTOR. 18:00 - 00:00 6.00 WHSUR P POST CREW CHANGE. WALK RIG. PERFORM LEAK TIGHT TEST. 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BP Z,ot1 by Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 11-32 Project: Prudhoe Bay ND Reference: 49:32 10/14/1994 00:00 @ 64.10usft(generic drilling rig) Reference Site: PB DS 11 MD Reference: 49:32 10/14/1994 00:00 @ 64.10usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 11-32 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 11-32A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 11-32A Offset TVD Reference: Offset Datum Reference 11-32A Filter type: NO GLOBAL FILTER:Using user defined selection&filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 500.00usft Error Surface: Elliptical Conic !Survey Program Date 1/25/2016 From To , (usft) (usft) Survey(Wellbore) Tool Name Description 185.70 10,524.63 1 :MWD-Standard(11-32) MWD MWD-Standard 10,573.00 12,978.24 CTK MWD 4-1/2"(11-32A) MWD MWD-Standard AOGCC OFFSET REPORT 1/25/2016 2:41:33PM Page 2 of 5 COMPASS 5000.1 Build 61 • • BP 0 bp Anticollisiion Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 11-32 Project: Prudhoe Bay TVD Reference: 49:32 10/14/1994 00:00 @ 64.10usft(generic drilling rig) Reference Site: PB DS 11 MD Reference: 49:32 10/14/1994 00:00 @ 64.10usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 11-32 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 11-32A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 11-32A Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Lis DS 03 L3-31-L3-31-L3-31 12,150.00 10,799.99 254.25 161.83 103.56 Pass-Major Risk PB DS 11 11-05-11-05-11-05 1,448.10 1,450.00 446.15 22.17 423.97 Pass-Major Risk 11-05-11-05A-11-05A 1,454.72 1,450.00 446.24 22.26 423.98 Pass-Major Risk 11-06-11-06-11-06 1,102.94 1,100.00 319.15 19.12 300.05 Pass-Major Risk 11-06-11-06A-11-06A 1,102.94 1,100.00 319.15 19.12 300.05 Pass-Major Risk 11-07-11-07-11-07 1,102.21 1,100.00 202.11 19.58 182.53 Pass-Major Risk 11-07-11-07PB1-11-07PB1 1,102.21 1,100.00 202.11 19.58 182.53 Pass-Major Risk 11-08-11-08-11-08 5,876.33 5,450.00 239.34 259.07 4.23 Pass-Major Risk 11-09-11-09-11-09 Out of range 11-09-11-09A-11-09A Out of range 11-10-11-10-11-10 5,040.13 4,475.00 482.76 113.30 375.63 Pass-Major Risk 11-10-11-10A-11-10A 5,040.13 4,475.00 482.76 113.46 375.47 Pass-Major Risk 11-11-11-11-11-11 Out of range 11-12-11-12-11-12 906.48 900.00 84.56 13.96 70.60 Pass-Major Risk 11-13-11-13-11-13 3,838.95 3,725.00 269.24 80.96 188.14 Pass-Major Risk 11-13-11-13A-11-13A 3,838.95 3,725.00 269.24 80.96 188.14 Pass-Major Risk 11-14-11-14-11-14 Out of range 11-15-11-15-11-15 505.60 500.00 31.20 8.37 22.84 Pass-Major Risk 11-23-11-23-11-23 Out of range 11-23-11-23A-11-23A Out of range 11-23-11-23B-11-23B WP03 Out of range 11-24-11-24-11-24 3,352.31 3,300.00 118.52 56.90 61.72 Pass-Major Risk 11-24-11-24A-11-24A 3,352.31 3,300.00 118.52 56.90 61.72 Pass-Major Risk 11-25-11-25-11-25 Out of range 11-25A-11-25A-11-25A Out of range 11 26 11 26 11 26 1,589.69 1,575.00 398.18 22.26 376.11 Pass-Major Risk 11-27-11-27-11-27 Out of range 11-28-11-28-11-28 Out of range 11-28-11-28A-11-28A Out of range 11-28-11-28B-11-28B Out of range 11-29-11-29-11-29 2,370.15 2,400.00 238.03 49.38 189.24 Pass-Major Risk 11-30-11-30-11-30 Out of range 11-30-11-30A-11-30A Out of range 11-31-11-31-11-31 675.95 675.00 24.23 9.91 14.32 Pass-Major Risk 11-31-11-31A-11-31A 675.95 675.00 24.23 9.91 14.32 Pass-Major Risk 11-32-11-32-11-32 10,599.99 10,600.00 0.54 6.73 -3.97 FAIL-Major Risk 11-33-11-33-11-33 Out of range 11-34-11-34-11-34 1,531.10 1,550.00 349.25 26.09 323.27 Pass-Major Risk 11-35-11-35-11-35 3,926.74 3,775.00 116.85 63.41 53.51 Pass-Major Risk 11-36-11-36-11-36 496.01 500.00 482.18 7.38 474.81 Pass-Major Risk 11-38-11-38-11-38 1,149.54 1,150.00 120.98 17.10 103.91 Pass-Major Risk 11-38-11-38A-11-38A 1,149.54 1,150.00 120.98 17.10 103.91 Pass-Major Risk 11-39-11-39-11-39 1,503.50 1,550.00 247.71 23.18 225.13 Pass-Major Risk 11-39-11-39-Plan#12 11-39 1,503.50 1,550.00 247.71 23.18 225.13 Pass-Major Risk 11-39-11-39PB1-11-39PB1 1,503.50 1,550.00 247.71 23.18 225.13 Pass-Major Risk 11-39-11-39PB1-Plan#6 11-39PB1 1,552.51 1,600.00 237.56 24.62 213.46 Pass-Major Risk 11-40-11-40-11-40 Out of range 11-40-11-40PB1-11-40 wp07 Out of range 11-4Plan 1 - 1-11 sbsO G C C OFFSET REPORT Out of range Plan Lisburne Plan- Lisburne-Lis n W 0 Out of range 1/25/2016 2:41:33PM Page 3 of 5 COMPASS 5000.1 Build 61 • i .µ+. BP bp p Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 11-32 Project: Prudhoe Bay TVD Reference: 49:32 10/14/1994 00:00 @ 64.10usft(generic drilling rig) Reference Site: PB DS 11 MD Reference: 49:32 10/14/1994 00:00 @ 64.10usft(generic drilling rig) Site Error: 0.00usft North Reference: True Reference Well: 11-32 Survey Calculation Method: Minimum Curvature Well Error: 0.O0usft Output errors are at 1.00 sigma Reference Wellbore 11-32A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 11-32A Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) UAT TEST SITE ONLY TEST WELL X_COMPASS-TEST WELL X-Com 34.80 34.80 0.00 1.01 -1.01 FAIL-Major Risk TEST WELL X_COMPASS-TEST WELL X-TES 10,350.00 10,350.00 0.00 433.71 -408.17 FAIL-Major Risk TEST WELL X_OW-TEST WELL X-TEST WEL 10,350.00 10,350.00 0.00 433.71 -408.17 FAIL-Major Risk AOGCC OFFSET REPORT 1/25/2016 2:41:33PM Page 4 of 5 COMPASS 5000.1 Build 61 • • .•M. B P i by Anticollision Report Mh Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 11-32 Project: Prudhoe Bay TVD Reference: 49:32 10/14/1994 00:00 @ 64.10usft(generic drilling rig) Reference Site: PB DS 11 MD Reference: 49:32 10/14/1994 00:00 @ 64.10usft(generic drilling rig) Site Error: 0.O0usft North Reference: True Reference Well: 11-32 Survey Calculation Method: Minimum Curvature Well Error: 0.O0usft Output errors are at 1.00 sigma Reference Wellbore 11-32A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 11-32A Offset TVD Reference: Offset Datum Reference Depths are relative to 49:32 10/14/1994 00:00 @ Coordinates are relative to: 11-32 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:1.58° Ladder Plot 600 - --- I I I I J J J J I450742 yi. to ,1 .0 O'r*1,....%',. 1:.. 77! i-i. II cn 300— •--- -�. LI Z .46 ' , mi. ofi,„ h, a, o o ,..A,,A // 04' it h m aci 1 nor a7i 150— - i 47:,?,,;., U , „ ��4;11 /J e\/k \��11 i'i'i=�w_=' i____ J J J �` _ .../'I I I 0 2000 4000 6000 8000 10000 12000 $ 11-15,11-15,111 easured Depth(2000usfUin) -e- 11-33,11-33,11-33 V1 - E- 11-23,11-23,11-23V0 $ 11-34,11-34,11-34V1 -4- 11-L3,11-23A,11-1:3A Vl $ 11-35,11-35,11-35 Vl -0- 11-23,11-236,11-236WP03V0 -E' 11-36,11-36,11-36 V1 -0- 11-24,11-24,11-24 V1 -kr- 11-38,11-38,11-38 V6 -2S- 11-24,11-24A,11-24AV1 -4-- 11-38,11-38A,11-38AV2 -)E- 11-25,11-25,11-25 V1 -8- 11-39,11-39,11-39V0 /1 -b- 11-25A,11-25A,11-25A V4 -0- 11-39,11-39,Plan#1211-39V0 -34- 11-26,11-26,11-26 V1 -X- 11-39,11-39PB1,11-39PB1V0 9- 11-27,11-27,11-27 V1 $ 11-39,11-39PB1,Plan#6 11-39PB1\ -e- 11-28,11-28,11-28 V1 $ 11-40,11-40,11-40V0 - 11-28,11-28A,11-28A V10 -e- 11-40,11-40PB1,11-40wp07V0 -4- 11-28,11-2813,11-28B VO -9- 11-40.11-4OPB1,11-40PB1V0 AOGCC OFFSET REPORT 1/25/2016 2:41:33PM Page 5 of 5 COMPASS 5000.1 Build 61 • • N O a) O ca W d JO c N d' = c LU w O N a W w (a 2 v n = O O a co N N '5)) uj Z W U) O r w V- a) O O w U o. 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COUNTY North Slope Borough LOG TYPE GR-RES --- BHI DISTRICT Alaska --- LOG DATE December 29,2015 AUTHORIZED BY Patrick Rider EMAIL Patrick.Ridera(�.bakerhuclhes.com TODAYS DATE January 13,2016 Revision STATUS Final Replacement: No Details: Requested by: --- COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #Ob I'KIN I S #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope 1 0 1 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 1 1 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 Exxon Mobil,Alaska I I 1 1 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC ( 1 1 I 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 *Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 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N LU 0 ‘.0 LO 0 LU 0 0) 1 .--1 < , CCL C) >, . . : cu CO ! , E 1., ;I v 000664 0 N 0 CO 0 N N V) < 0 01 0 , 4. c6 ..-: O. 6 6 6 CV N. 0 CV C0 til 0 (0 0 0Lc) Lc, co (0 CO COCO (0 t..... - - - - - - - I 0 2 o_ ,..) a c., ,) ., 6 I < . , . CO 0 C <5 4'''' Q. ,y, ',5 = 1 - .o = 1 .0) E — it; = o 2 := CD : . . , , , co <- o . 04 0 : '45 .',. • , • • • • OF T „frt.- 1//7, � � THE STATE• • Alaska Oil and Gas of Conservation Commission Witt 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 S Main: 907.279.1433 of ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John McMullen Engineering Team Leader BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 11-32A BP Exploration(Alaska), Inc. Permit No: 215-128 Surface Location: 48' FNL, 125' FEL, SEC. 33, T11N, R15E, UM Bottomhole Location: 4391' FSL, 1833' FEL, SEC. 28, T11N, R15E, UM Dear Ms. McMullen : Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC 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 AOGCC 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, oz Cathy P. oerster Chair DATED thisday of August, 2015. RECEIVED STATE OF ALASKA .LASKA OIL AND GAS CONSERVATION COMMIS JUL 2 2 2015 PERMIT TO DRILL 20 AAC 25.005 (^) 1 a. Type of Work: 1 b. Proposed Well Class: Development-Oil RI• Service-Winj III Single Zone• 0 1 Ap ifPin icrroposed for: Drill 0 Lateral 0 Stratigraphic Test 0 Development-Gas 0 Service-Supply 0 Multiple Zone 0 Colabed Gas 0 Gas Hydrates 0 Redrill •0 Reentry ❑ Exploratory 0 Service-WAG 0 Service-Disp 0 Geothermal 0 Shale Gas ❑ 2. Operator Name: 5. Bond • Blanket IZI Single Well 0 11. Well Name and Number: BP Exploration(Alaska),Inc Bond No. 6194193 - PBU 11-32A 3 Address: 6. Proposed Depth: 12. Field/Pool(s): P.O.Box 196612 Anchorage,AK 99519-6612 MD: 13000' • TVD: 8706'ss • PRUDHOE BAY,PRUDHOE OIL 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): ADL 028322 //4•c L C r.'.0 j z Surface: 48'FNL,125 FEL,Sec.33,T11 N,R15E,UM • 8. Land Use Permit: 4,2:7. 13, Approximate spud date: /�Top of Productive Horizon: 5052'FSL,200'FEL,Sec.28,T11,R15E,UM December 1,2015 Total Depth: 4391'FSL,1833'FEL,Sec.28,T11N,R15E,UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 34490' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL: 64.1' feet- 15. Distance to Nearest Well Open to Same Pool: Surface:x- 707429' y- 5951673' Zone - ASP 4 GL Elevation above MSL: 29.3' feet' 525' 16. Deviated wells: Kickoff Depth: 10580' • feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: 3326 . Surface: 2455 18. Casing Program: Specifications Top-Setting Depth-Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 4-1/4" 3-1/2"x3-1/4'9.3#/6.6# 13Cr80 STL/TC-II 2780' 10220' 8159'ss 13000' 8706'ss 194 sx Class'G' x 2-7/8" /6.4# /STL 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth D(ft): Junk(measured): 11003' 8901' I 10783'(TOC) I 10903' I N 8813' 110903'(2),Unknown(1) Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 20" 260 sx Arctic Set(Approx.) 34'-114' 34'-114' Surface 3936' 10-3/4" 1310 sx CS III,375 sx Class'G' 34'-3970' 34'-3807' Intermediate Production 10956' 7-5/8" 650 sx Class'G' 32'-10988' 32'-8888' Liner Perforation Depth MD(ft): 10658'-10766' I Perforation Depth ND(ft): 8600'-8694' 20.Attachments Property Plat ❑ BOP Sketch RI Drilling Program 0 Time v.Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program RI 20 AAC 25.050 requirements RI 21.Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and correct. Contact Raese.J.Kyle Email john.raese@bp.com Printed Name J/ r v. IlenTitle Engineering Team Leader Sign, i ‘•-, Phone +1 9075644711 Date 7/22. /5' Commission Use Only P•n to Drill ,_,....— API Number: Permit Approval Number: ,e,'. f �Z 50-029-22512-01-00 Date: V I I r See cover letter for other �,J requirements: Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,� gas hydrates,or gas contained in shales: RI' Other: 0o ft---5-/tb SU O p$ / [ 1, Samples� reeqq'd:l' Yes ❑l No RI Mud log req'd: Yes CI No L i ,yt,-- (/Lac V pret/ava 7L['/ tts/ `6' H- measures Yes ® No ❑ Directional svy req'd: Yes 13No ❑ Spacing exception req'd: Yes 0 No 11" Inclination-only svy req'd: Yes 0 No Pi APPROVED BY Approved by: / ; n •u ISSIONER THE COMMISSION Date: �^/s V 8 ORG1 AL ' 7A..- Form S .� T4 , Form 10-401 Revised 10/2012 This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit Form and Attachments in Duplicate • • To: Alaska Oil & Gas Conservation Commission From: Kyle Raese CTD Engineer bp Date: July 16, 2015 Re: 11-32A Permit to Drill Request Approval is requested for a permit to drill a CTD sidetrack lateral from well 11-32 by the Nordic 2 Coiled Tubing Drilling rig on or around December 1, 2015. The 11-32A sidetrack will perform a single-string exit through the existing 7-5/8" casing. Kick-off will occur in Zone 2C and target Zone 1A reserves. The proposed sidetrack is a 2,420' horizontal Ivishak Zone 1A producer which will access targets north of DS 11. The lateral will be . completed with a 3-1/2" x 3-1/4" x 2-7/8" 13-Chrome liner which will be cemented and perforated. Rig Work(scheduled to begin December 1,2015) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,455 psi). 2. Pull TWC and kill well (if necessary). 3. Mill 3.80"window and 10' of rathole. 4. Drill build: 4.25" OH, -620' (30 deg DLS planned). 5. Drill lateral: 4.25" OH, -1780' (12 deg DLS planned). 6. Run 3-1/2" x 3-1/4" x 2-7/8" 13Cr-80 liner leaving TOL at-10,220' MD. 7. Pump primary cement job: 40 bbls, 15.8 ppg Class G, TOC at-10,220' MD.* 8. Liner cleanout and RPM/GR/CCL log. 9. Perform liner lap test. 10. Perforate-500' liner based on log interpretation. 11. Freeze protect well to 2,500' TVDss. 12. Set TWC; RDMO. Post-Rig Work 1. V Pull TWC. 2. S Set LTP*(if needed) and GLVs. 3. T Test separator. *Approved alternate plug placement per 20 AAC 25.112(i) Mud Program: • S • Well kill: 8.4 ppg 1% KCI brine (480 psi over-balance) • • Milling/drilling: 9.5 ppg PowerPro mud (979 psi over-balance) Disposal: • All Class I & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or • Pad 3 at DS 6. • Fluids >1% hydrocarbons or flammables must go to Pad 3. • Fluids >15% solids by volume must go to GNI. • Fluids with solids that will not pass through 1/4" screen must go to GNI. • Fluids with PH >11 must go to GNI. Hole Size: • 4.25" from 10,600' MD to 13,000' MD - Liner Program: • 3-1/2", 9.3 lb/ft, 13Cr-80 STL liner(10,220' — 10,560' MD) • 3-1/4", 6.6 lb/ft, 13Cr-80 TC-II liner with cementralizers (10,560'— 11,000' MD) • 2-7/8", 6.4 lb/ft, 13Cr-80 STL liner with cementralizers (11,000' MD— 13,000' MD) • A minimum of 40 bbls of 15.8 ppg Class G cement will be used for liner cementing (TOC 10,220' MD). • The primary barrier for this operation is a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional: • See attached directional plan. Maximum planned hole angle is 91°. Inclination at kick off point is 30°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property—34,490'. • • Distance to nearest well within pool—525'.- Logging: • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. • Cased hole GR/CCL/RPM logs will be run. - Perforating: • 2" PowerJet, 6 spf, 60 deg phasing, 1-1/4" CSH work string &2-3/8" PH6. • The primary barrier for this operation is a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti-Collision Failures: • 11-32 Center to center: 0' — Parent wellbore at KOP Hazards: ✓ • DS-11 is a H2S pad. • 11-32 had 200 ppm H2S on 5/20/2013. • The lost circulation risk for 11-32A is considered to be medium with no planned fault crossings. Reservoir Pressure: • The reservoir pressure on 11-32A is expected to be 3,326 psi at 8,715' TVDss (7.34 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,455 psi. • An EMW of 8.4 ppg for this well will provide 480 psi over-balance to the reservoir. Kyle Raese CC: Well File CTD Engineer Joseph Lastufka TREE= FMC ' = aW • 11 -3 2 SA�n E * ACTUATOR= BKR C 2 X 3"ARM SPRINGS LOST 8/30/05*** OKB.ELEV= 64.1' 1 BF.ELEV= KOP= 2658' Max Angle= 47`@ 5808' 20"CONDUCTOR, 112' Datum ND= 10961' 91.5#,1440, 2091' —4-1/2"CAMCO TRCF-4A SSSV NP,D=3.813" Datum TVD= 8800'SS D=19.124" LOCKS)OUT 12123105 GAS LFT MANDRELS 10-3/4"CSG,45.5#,NT-80 BTC,ID=9.950" H 3970' I ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3884 3743 42 HES-TMPD DMY BK 0 03/26/15 2 6401 5502 47 l-ES-TMPD DMI( BK 0 03126/15 3 7222 6074 46 IIs-TMPD DM' BK-2 0 11/06/96 4 8201 6758 45 HES-TMPD *DMY BK 0 01/12/06 5 9179 7442 46 HES-TM() DMY BK-2 0 04/07/96 7-5/8"CSG,29.7#,NT-95 XO TO 13CR-80 NSCC —{ 9980' x 6 10079 8105 35 HES-TMPD DMY BK-2 0 11/29/95 STA#4=DMY HAS EXTBVDED PACKING Minimum ID = 3.813" @ 2091' 4-1/2" CAMCO SSSV NIPPLE i 10187' —7-5/8"X 4-1/2"BKR SABL-3 PKR W/KBI+22 ANCHOR SEAL ASSY,D=3.955" 10248' H4-112"OTIS X NP,D=3.813" 4-1/2"TBG,12.6#,131CR-80 FOX, H 10259' 10260' —14-1/2"WLEG,ID=4.00" .0152 bpf,ID=3.958" 10244' H BMD TT LOGGED 11/15/94 PERFORATION SUMMARY Ilk , ? H FISH-2 KOT 1/2-X 3'ARM SPRINGS(08/30/05) REF LOG: WA/BHCIGR ON 10125/94 ANGLE AT TOP FERF: 30'@ 10711' Note:Refer to Production DB for historical perf data SIZE SW INTERVAL Opn/Sgz SHOT SQZ 3-3/8" 6 10658-10664 0 05/31/14 3-3/8" 6 10658-10664 S 08/02/05 07/07/08 3-3/8" 6 10682-10688 S 08/02/05 07/07/08 2-7/8' 4 10710-10715 S 03/01/01 07/07/08 3-3/8" 6 10711 -10726 0 12/20/08 3-3/8" 6 10732-10739 0 07/15/08 ' 3-3/8" 6 10756-10766 0 12/20/08 3-3/8" 6 10759-10765 S 07/30/95 07/07/08 1111111111 10783' H EST.TOC(07/07/08) 3-3/8" 6 10816-10836 S 07/07/95 07/07/08 1/1111/111111/11/11.1 2-1/2' 4 10824-10844 S 07/07/95 07/07/08 1111/111111111/11111/ 111111111111111111114 11111111111/1/11111. /1•..IVit!'111`1•1//11 ��1. N ♦. •• 10903' --FISH-ELEMENT-6.0"& At'.t 1./.•:1•A PBTD --I 10903' Y1v1Y,v.v.v.v.v.v.Y,V STFFENER RING-1.0"(03/19/07) 111111111111111111111 1111111111111111111111 7-518"CSG,29.7#,13CR --180 NSCO,D=6.875" � 11003' '1.1.1.1.1.1.1.1.1.. DATE REV BY COMMENTS DATE REV BY C MENTS PRUDHOE BAY UdT 10/30/94 N-18E ORIGINAL COMPLETION 06/03/14 GTW/JMC REEF(05/31/14) WELL: '11-32 10/11/01 RN/KAK CORRECTIONS 06/19/14 PJC 1 FCORRECTION PERMIT Nb:'1941310 07/18/08 JA/JMD GLV GO(07/14/08) 04/02/15 JIW#JMD GLV C/O(03/26/15) API Nb: 50-029-22512-00 07/22/08 SRB/SV CMF SQZ(07/07/08) 04/17/15 PJC LNR/TBG-FRE RIG UPDA I ES SED 33,T11 N,R15E 48'FNL 8 125'FEL 07/22/08 RRK/SV ADPERF(07/15/08) 04/20/15 PJC ADD 7-5/8"CHROME CSG XO 01/13/09 RRD/SV ADPERF(12/20/08) BP Exploration(Alaska) sAl ACTLtATOR= BAKERC PROPO'S�L NOTEs:wELL ANGLE>7o•1/ O•_ TREE= FMC WWELLFEAD= CM/ 11 _32A M - •"`4-112"CHROME OKB.aEV= 64.1' I I TBG CSG*** BF BEV= KOP= 2658' Max Angle= @ 20"CONDUCTOR NEM Datum MD= 91.5#,H-40, 2091' 14-1/2"CAMCO TRCF-4A SSSV NP,D=3.813" - LOCK®OUT 12123/05 Datum TVD= 8800'SS D=19.124" I-ES GAS LFT MANDRELS 10-3/4"CSG,45.5#,NT-80 BTC,D=9.950" H 3970' ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3884 3743 42 TMD DMY BK 0 03/26/15 2 6401 5502 47 TMPD DM' BK 0 03/26/15 3 7922 6074 46 TMPD DM' BK-2 0 11/06/96 4 8201 6758 45 INFO "DMY BK 0 01/12/06 7-518"CSG,29.7#,NT-95 XO TO 13CR-80 NSCC H 8980• >c 5 9179 7442 46 TWO DMY BK-2 0 04/07/96 6 10079 8105 35 TMPD DMY BK-2 0 11/29/95 STA#4=DMY HAS EXTENDED PACKING Minimum ID = 2.377" a@'a 3-3/16" X 2-7/8" LNR XO 10187' -J7-518"X 4-1/2"BKR SABL-3 PKR W/KBH-22 ANCHOR SEAL ASSY,D=3.955" -10220 J-J3.70"BKR DEPLOY SLV,D=3.00" TOP OF 3-1/2"X 3-1/4"X 2-7/8"LNR(CMTD) -( -10220 !. ^10240-{3 1/2"HES X NP,D=2.813" s. N ► 10248' {4-1/2"OTIS X NP,D=3.813" 4,4 4-1/2"TBG,12.6#,131CR-80 FOX, -I 10259' ar , ,elii - 10260' H4-112"WLEG,D=4.00"% CT LNR .0152 bpf,D=3.958" `A 10244' -JEIMOTT LOGG®11/15/94 ♦1 14,16 6N% 3-1/2"LNR #,13CR_STL, — -10560 '�►t"+ -10560 H3-1/2"X 3-3/16"X0,D=2.786" .0087 bpf,11-2=2.992" J It S 7-5/8"X 4-1/2"DELTA WI TOCK(XX/XX/15) -I -10580 IN � : w/RA TAGS @ ,f„,r0 r +' MLLOUT WINDOW(11-32A) -10580'- ' 7-5/8"CSG,29.7#,13CR-80 NSCC,0=6.875" -{ 10560 r ESTMA i U)TOP OF CEMENT(XX/XXX/15) -[-10620 .E ,�••*N41, +►� -11000 --13-3/16"X 2-7/8"XO,D=2.377" 7-5/8"POSISET PLUG(XX/XX/15) -I -10630 �- `�{�*� rte` +4k1 r � '.►+ -12-7/8"RA PUP JOINT NSUMMNRY � � �+ REF LOG: _ ON XX/XX/15 •••••••vr•4 �!••*`o*'�-._ r ANGLE AT TOP PERF: "@ `1.1... 4A.•.4 Nt+�i `1P.� 1RPJQNT 2-7/8"RA Nbte:Refer to Production DB for historical pert data :01S.G�:�.4..:4.. + � SIZE SPF NTSNAL Opn/Sqz SHOT SOZ •+i.• *i 3-1/4"LNR,6.6#,13CR-_TCII, -11000 .0079 bpf,0=2.850" �`#'►#� ''*N, 4E •�.'l PBTD - `d'*,!•�„ a 2-7/8"LNIR, #,13CR-85 Sit,.0058 bpf,D=2.441" - -13000 • DATE REV BY COMuEJTS DATE REV BY COW/NTS PRUDHOE BAY I.NT 10/30/94 N-18E ORIGINAL COMPLETION WaL: 11-32A XX/XX/15 CTD SIDETRACK(11-32A) PERMIT Pb: 04/19/15 KJR/PJC BUILD PROPOSAL AR Pb: 50-029-22512-01 04/20/15 KJRI PJC REV 1-CTD PROPOSAL SEC 33,T11N,R15E,48"FNL&125'Fa BP Exploration(Alaska) 111. 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I I I I I ri$11 01 POI*IP*40 CI ����� *** pOp ,/�,•���►� ��OP►� N 3 • • bp North America - ALASKA - BP Prudhoe Bay PB DS 11 11-32 500292251200 11-32A 11-32A WP04 Travelling Cylinder Report 20 July, 2015 rat 11 BAKER HUGHES III i BP vsku 04 fp Travelling Cylinder Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 11-32 Project Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 11 MD Reference: 49:32 10/14/1994 00:00 @ 64.10usft (generic drilling rig) Site Error: 0.00 usft North Reference: True Reference Well: 11-32 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 11-32A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 11-32A WP04 Offset TVD Reference: Offset Datum Reference 11-32A WP04 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 10,429.13 to 13,000.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,496.52 usft Error Surface: Elliptical Conic Survey Tool Program Date 7/16/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 185.70 10,429.13 1 :MWD-Standard(11-32) MWD MWD-Standard 10,429.13 13,000.00 11-32A WP04(11-32A) MWD MWD-Standard Casing Points Measured Vertical , Casing Hole f Depth Depthe,Ai` t� Diameter Diameter e ..: (usft) (usft) ,,:_, /,., Name ,(in) (fn) 1f 3,970.00 3,743.37 10 3/4" 10.750 13.500 13,000.00 8,706.07 2-7/8" 2.875 4.250 Summary �� : Reference Offset Centre to No-Go Allowable? ,, s, ,r, „ Measured Measured Centre Distance Deviation Warning Site Name .Depth y Depth Distance (usft) from Plan. e, Offset Well-Wellbore Design; ' usft) (usft), (usft). , ,,,,,,,,p„.,-..14(usft f,,, Lis DS 03 L3-31-L3-31-L3-31 12,15111. I 1 .2 1 290.46 167.70 135.44 Pass-Major Risk PB DS 11 11-06-11-06-11-06 Out of range 11-06-11-06A-11-06A Out of range 11-07-11-07-11-07 Out of range 11-07-11-07PB1-11-07PB1 Out of range 11-08-11-08-11-08 Out of range 11-09-11-09-11-09 Out of range 11-09-11-09A-11-09A Out of range 11-10-11-10-11-10 Out of range 11-10-11-10A-11-10A WP5 11,120.00 13,000.00 586.50 278.99 309.85 Pass-Major Risk 11-11-11-11-11-11 12,775.00 9,758.00 558.70 158.20 417.61 Pass-Major Risk 11-12-11-12-11-12 Out of range 11-13-11-13-11-13 Out of range 11-13-11-13A-11-13A Out of range 11-14-11-14-11-14 Out of range 11-15-11-15-11-15 Out of range 11-23-11-23-11-23 Out of range 11-23-11-23A-11-23A Out of range 11-24-11-24-11-24 Out of range 11-24-11-24A-11-24A Out of range 11-25-11-25-11-25 Out of range 11-25A-11-25A-11-25A Out of range 11-26-11-26-11-26 Out of range 11-27-11-27-11-27 Out of range 11-28-11-28-11-28 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 7/20/2015 10:16:21AM Page 2 COMPASS 5000.1 Build 61 • BPID by Travelling Cylinder Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 11-32 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 11 MD Reference: 49:32 10/14/1994 00:00 @ 64.10usft (generic drilling rig) Site Error: 0.00 usft North Reference: True Reference Well: 11-32 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 11-32A Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: 11-32A WP04 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) PB DS 11 11-28-11-28A-11-28A Out of range 11-28-11-28B-11-28B Out of range 11-29-11-29-11-29 Out of range 11-30-11-30-11-30 Out of range 11-30-11-30A-11-30A Out of range 11-31-11-31-11-31 Out of range 11-31-11-31A-11-31A Out of range 11-32-11-32-11-32 10,525.00 10,525.00 0.00 2.97 -2.95 FAIL-NOERRORS 11-33-11-33-11-33 Out of range 11-34-11-34-11-34 Out of range 11-35-11-35-11-35 Out of range 11-38-11-38-11-38 Out of range 11-38-11-38A-11-38A Out of range 11-39-11-39-11-39 Out of range 11-39-11-39-Plan#12 11-39 Out of range 11-39-11-39PB1-11-39PB1 Out of range 11-39-11-39PB1-Plan#6 11-39PB1 Out of range Plan 11-40 SL1-Plan 11-40-11-40 wp05 SL1 Out of range Plan Lisburne-Plan Lisburne-Lisburne Wp 1.0 Out of range Offset Design Lis DS 03- L3-31-L3-31-L3-31 Offset Site Error 0.00 usft Survey Program: 42-GCT-MS Rule Assigned:Major Risk Offset Well Error 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Foolface a Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +WS +El-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) 11 (usft) (ustt) (in) (usft) (usft) (usft) 11,843.23 8,715.06 9,950.00 7,946.06 62.52 36.11 -108.51 A,81,69' ,4 'x7415.52 6.937 80072 225.99 663.06 Pass-Major Risk 11,869.85 8,71479 9,975.00 7,963.12 62.38 36.24 -105.76 4,856.53 -746.83 6.937 781.17 214.35 645.10 Pass-Major Risk 11,89424 8,714.54 10,000.00 7,980.25 6226 36.38 -103.29 4,839.46 -753.15 6.937 76141 203.69 626.63 Pass-Major Risk 11,916.56 8,714.32 10,025.00 7,997.46 62.17 36.51 -101.14 4,82247 -759.48 6.937 741.49 194.09 607.72 Pass-Major Risk 11,937.02 8,714.11 10,050.00 8,014.73 62.09 36.64 -99.28 4,805.53 -765.82 6.937 72147 185.58 588.44 Pass-Major Risk 11,955.71 8,713.93 10,075.00 8,03208 62.04 36.78 -97.71 4,788.68 -772.13 6.937 701.34 178.21 568.83 Pass-Major Risk 11,972.77 8,713.76 10,100.00 8,049.54 62.00 36.91 -96.41 4,771.92 -77840 6.937 681.14 171.97 548.95 Pass-Major Risk 11,988.29 8,713.61 10,125.00 8,067.13 61.97 37.04 -95.36 4,75526 -784.57 6.937 660.87 166.86 528.83 Pass-Major Risk 12,002.43 8,713.47 10,150-00 8,084.84 61.95 37.16 -94.55 4,738.70 -790.64 6.937 640.59 162.78 508.54 Pass-Major Risk 12,015.32 8,713.35 10,175.00 8,102.65 61.93 3729 -93-98 4,722.19 -796.59 6.937 620.34 159.65 488.17 Pass-Major Risk 12,027.12 8,713.23 10,200.00 8,120.55 61.92 37.42 -93.63 4,705.75 -802.46 6.937 600.17 157.32 467.78 Pass-Major Risk 12,037.95 8,713.13 10,225.00 8,138.53 61.92 37.55 -93.48 4,689.38 -80826 6.937 580.12 15569 447.43 Pass-Major Risk 12,047.91 8,713.04 10,250.00 8,156.66 61.92 3767 -93.52 4,673.16 -814.00 6.937 560.17 15461 427.12 Pass-Major Risk 12,057.07 8,712.96 10,275.00 8,174.98 61.93 37.80 -93.75 4,657.12 -819.67 6.937 540.33 15369 406.87 Pass-Major Risk 12,065.49 8,712.88 10,300.00 8,193.55 61.93 37.93 -94.16 4,641.33 -825.26 6.937 520.56 153.73 386.67 Pass-Major Risk 12,073.25 8,712.81 10,325.00 8,212.33 61.94 38.05 -94.75 4,625.78 -830.77 6.937 500.93 153.73 366.60 Pass-Major Risk 12,080.46 8,712.74 10,350.00 8,231.31 6195 38.18 -95.52 4,610.46 -836.23 6.937 481.49 153.93 346.73 Pass-Major Risk 12,08722 8,712.68 10,375.00 8,250.39 61.96 38.30 -9648 4,595.25 -841.68 6.937 462.38 154.30 327.19 Pass-Major Risk 12,093.59 8,712.63 10,400.00 8,269.54 6197 38.43 -97.63 4,580.13 -847.14 6.937 443.69 154.80 308.08 Pass-Major Risk 12,100.00 8,712.57 10,425.00 8,288.68 6198 38.56 -98.96 4,565.03 -85265 6.937 425.55 155.42 289.55 Pass-Major Risk 12,105.39 8,712.52 10,450.00 8,307.85 61.99 38.70 -100.60 4,54996 -858.18 6.937 408.01 156.08 27168 Pass-Major Risk 12,110.84 8,712.48 10,475.00 8,327.05 62.00 38.83 -102.43 4,534.94 -863.74 6.937 391.17 156.80 254.55 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 7/20/2015 10:16:21AM Page 3 COMPASS 5000.1 Build 61 a s ---� I! €si•g Ii � 2 � = 4 1 r 1-.f:4.; a I g a 1 i $ $ $ Cl71 a, MINI 2 t z. a.i ea m C �' "`� ° llui!II zE dr4) o co Efibtlitr! —44 a 4 a ' dam 4111=11 r. 3 / k ,f 8 .� d d F F 8 8{ s s Mil 4Ditle � lit fcLL o a� ?3p;`a,� € M m I I I I I D _ i `I o 2c. o E I X1,1:8 s2 g,Po 4 I 8 ga a ;Iliaa 8 „QS mm3 € ,c_,; s s 71 QuCr g maFi!$=i ti • FE $! Q D I iD 5 gilt;;;Drop 1 §a Vis. at „s= �, „s. — W ry __ s� a' 2. • 4 ..... o•: /1114- . , 0 N 4 PA . IA O' ddd J r / H♦ \ g . ' I\ rye` -4 _ .� 7o •''. 4\ 0' m < Z -ter • • Davies, Stephen F (DOA) From: Stair, Kelley <Kelley.Stair@BP.com> Sent: Monday,July 27, 2015 4:22 PM To: Davies, Stephen F (DOA) Cc: Raese,J. Kyle Subject: RE: PBU 11-32A (PTD#215-128) - Location Question Attachments: 11-32A_BaseMap_Lease.pdf Steve, A very small portion of the well (just after KO)will drill in the northern Section 21 (ADL 28322), but most of it will be in Section 28 ADL 28325. I have attached a map for reference. Many thanks, Kelley Stair Kelley Stair NWD Geologist- Prudhoe 907-564-4108 From: Raese, J. Kyle Sent: Monday, July 27, 2015 1:13 PM To: Stair, Kelley Subject: FW: PBU 11-32A (PTD #215-128) Location Question Kelley, Would you be able to help with Steve's question below? From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, July 27, 2015 12:16 PM To: Raese, J. Kyle Subject: PBU 11-32A (PTD #215-128) - Location Question John, I'm working through the permit to drill application for PBU 11-32A, and I have a quick question. According to BP's base maps, does any portion of the planned PBU 11-32A wellbore lap into governmental Section 21,which lies within State Lease ADL 28322? Or will the well lie entirely within governmental Section 28,which lies within State Lease ADL 28325? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 1 • CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Sent from my desktop PC 2 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: (9151‘ , /7 3i/4 PTD: . /S--- /2 ? Development Service Exploratory Stratigraphic Test _Non-Conventional FIELD: FC` C� POOL: Lr Gni G" °.��-. ,/ F ( Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 2/2015 • • L TO 0) Q N N O 0 O a TD- c Q o' a, a> ca 1 y a. ai O -0 >. a)' , co CO , a � ca 2 . O c c. rn N U' a o -- c, a n m v' o to J' 0 Oco 0E 3 4-. N o' •�� T Q. o. @ 3. v. 0 or CY o, I 0 FCO ami o y' 3' o a . E O. O O Q O2 7 r' _ a) w' , 0 3' a M' y. CO. o 0 d 0 O D a) .. '3, D .0 a, �, a c. m. w. m to cA a c. a N Or, c, } N, N, O, 5' oa o> aZi, cn' C' fl' p' 0) �� of p? Q 0 'o. m. 3, U, a) c, c � �, ' o. `�' 2) C c m. U) O C dO OW0 n ._ O � oc N 3 CD, N O _mUoO' ' N' o 8 5' > ' vI ca 45 TD z 2. .,-- 0 � y _ € � od' p ;12i 0, • Z ' o 0) c' O a o' 0 T >, O'. Orn �� 'c� 0 CO u) N 0. 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