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215-018
Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 12/30/2021 To: Department of Natural Resources Resource Evaluation 550 W 7th Ave, Suite 1100 Anchorage, AK 99501 DATA TRANSMITTAL PBU L3-03 (PTD 215-018) RBT 12/17/2021 Please include current contact information if different from above. Received By: 01/03/2022 37' (6HW By Abby Bell at 9:43 am, Jan 03, 2022 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend ❑ Perforate ® Other Stimulate RI Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 215-018 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number 50-029-23535-00-00 7. Property Designation(Lease Number): ADL 0034631 8. Well Name and Number. PBU L3-03 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 12875 feet Plugs measured 12185/12420 feet true vertical 8779 feet Junk measured 10131 feet SEP 1 9 2017 Effective Depth: measured 12185 feet Packer measured 9532 feet true vertical 8859 feet Packer true vertical 8563.8 feet A Casing: Length: Size: MD: TVD: Burst: Collapse:�! Structural Conductor 80 20"91.5#H-40 50-130 50-130 1490 470 Surface 4095 13-3/8"68#L-80 48-4143 48-3832 5020 2260 Intermediate 9207 9-5/8"47#L-80 45-9252 45-8325 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet (� True vertical depth: See Attachment feet SCANNED ! O V 0 v 1l N Tubing(size,grade,measured and true vertical depth) 4-1/2"13.5#13Cr85 42-9656 42-8669 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10331'-10591',10850'-11078'. Treatment descriptions including volumes used and final pressure: 124 Bbls Slick 1%KCL w/SafeLube,178 Bbls Diesel,87 Bbls 3%Slick KCL,272 3%KCL w/F103,30 Bbls 3%KCL w/F103&U67,135 bbls ETCH Acid,41 Bbls VDA Diverting Acid,7150 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 231 10282 45 0 5 604 Subsequent to operation: 836 16335 329 312 735 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory ❑ Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil IRI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Sauve,Mark A Contact Name Sauve,Mark A Authorized Title: GPMA/Lisbume L d PE Contact Email: Mark.Sauve©bp.com Authorized Signature Date: / (1,/(1._ Contact Phone: +1 907 564 4660 Form 10-404 Revised 04/2017 Uri- /6 76' 1 /7— /fo6// RBDMS S„>y, SEP 2 5 2017 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue RECEIVED Anchorage, AK 99501-3572 SEP 1 9 2017 AOGCC RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary September 13, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Addition of Perforations and Acid Stimulation for Well L3-03, PTD # 215-018. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 w O000OMO CO 0 CO W e- Lo NN- tLO Cn NCO CO CO 0 vla 0) N C=1000010� N N 0 co N 0 0 Ca r O CO N- 0) O O N Lc) O) O r C) co N O 0) CO Cfl co co co CO N- N- CO CY) co CO CO CO CO H 0) co O O CO it) CO CO 0) N LO r CO NI- O O O it 0N 00 0) LT CO [f co O) L 0) 0 241: • M fr °) O co in O) N O M v2cN � • J • m H O. O O C) l _J c9C3M M CO cr N N cI'so Co N LO Cl) 0) w 00 N r O) ✓ - - - - N L9 P- N N N r r v- 4 4 M 4 C)0 0)O O ) N- N.J CO v• 0))-J )) M 0 00) W C C� W 0 .y U U O0u_ CeW WaoZ Z W W W W QDF- ZZZD U f/) Z ▪ J J f- • • • 0) N CO m C17 Tr N- M CS) N C3) CA r C3) 0 O Tr N- CO 0 CO CO M CO M N O) Tr co N- co co CD M r Cn M p N- CO r N- r C) 00 et lD O N N 1� 00 r M N O N r- r- CO V O 00 a ti CD CD CD CO CQ CD 00 CA CO UD M r N- O M 00 CD CD TY' r OD CI 000 OD 00 00 CD VO CD p CD CD CD O CD CD OD 0 CO OD 000 CO0CO Oop 00 000 a O I- r Is Tr N- r CD N F CA r r CD p Tr CO CO M CD CD CO O CD t C D O M CC Tr ) CO 00 Tr CO CO CD Tr of MTr CD r CD V UP O 0. T- T- O N 0 N- co co M M C D ' N 0 0 N- CCS I- N T O N 0 47 CO r CO CO r CD CO CD O C D N- Ul M M r N- ON CD CD CO M r W CD 0 0cD OD 03 CO 00 00 A C00 COCD CD COCD CA D C D O CD CD cn CD CD CD CD CD CT C) C D O C D C D CO co OD CD CD 03 CD CO 0 2 W h a! O 0 w w g g 0 o m O O w Y Y r Cn CD r r CD r 0 CO CA r C D I,- CD C D N r C D N CC) C D N CA - N J 0 0 w w w +� a O O O O N co N N Tr T CD O00 CD C) O Tr Tr N- CA CD '- M UD N- Q Q < w a tl m Z • C) O O O O O O O O O O O O N N N N ZZ Z -I J J D J Q Q Q 2 0 0 a w22 = 2 0 0 0 W d d 0 I- 0 OZ w w w a I- I- Q O M 2 2 2 O cn cn <n cn QM a Jl°- t CD r M CD r r CO CD N O Tr N- O CD N N CD N CC) O M O d. r N r M Tr co CC) 0 co CC) co CD N O T- Cf) N- CD CO CO V- %# O MM M p p O O r N N CO Tr Tr CO CO CD CD r Tr Tr N- CA cn r M CD W 0 p p 0 0 0 0 0 0 0 0 0 0 0 0 N N N tea ; L ro O J = H O a d 2 O cn cn <n cn cn 0 Cl. 0 C) °• 00L- OOLLOOCL000LLOOCLO0U- Ocncncn 11F- F- dF- F- aF- F- 0_ F- h F- aF- F- n- F- F- n F- aaa acncn ¢ cnoocLoo nacncncn < U) U) ¢ cnU) QCI) mmm 0 t a w J aW E- 0 J .17 C Cf) N- N- N- N- N- N- N- N- N- CC) N- ti N- N- N- N- N- N- N- CO CO CO • o o O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 W J Z w O N N N N N N N N (V N N N N N N N N N CV N N N CV Z d d Q w w 5 M Ns Ns ti N- N- N N- N- N- UP N- Is N- ti N N- CO CD CD N N N 00 Ce L1.1 d U L V W W l LU UJ a I- CD CD CD co co CD OD CO CD N- 00 CD CD CD CD CD CD CD CD Tt Tr Tr Q 0 0 0 J J 0 0 re CL O m o m Fe J J ('J ('J W Q Q m m CL LL N N 0. LY N E CCC Z M01M M 01M M M Cr) M M M M M 01M M 01M M M 01 0199999999999999999999999 waco0 lL 0 t M co M M M co M M co co co M M co co M co Ch Ch M M Ch M m 0_ 0_ 4_ U J G) d w W d -J J J J J J J J J J J J J -J J J J J J J J J J < < CO m CL CLL CD CO 0_ re • • Packers and SSV's Attachment PBU L3-03 SW Name Type MD TVD Depscription L3-03 PACKER 9090.77 8188.52 7" Baker HRD-E ZXPN LTP L3-03 TBG PACKER 9532.41 8563.8 4-1/2" HES TNT Perm Packer L3-03 PACKER 9648.98 8663.15 7" Baker HRD-E ZXP LTP L3-03 PACKER 9905.49 8879.34 4-1/2" HES Water Swell Packer L3-03 PACKER 10071.06 8992.77 4-1/2" HES Water Swell Packer L3-03 PACKER 10289.74 9081.43 4-1/2" HES Water Swell Packer L3-03 PACKER 10590.69 9084.43 4-1/2" HES Water Swell Packer L3-03 PACKER 10808.92 9057.17 4-1/2" HES Water Swell Packer L3-03 PACKER 11078.33 9017.51 4-1/2" HES Water Swell Packer L3-03 PACKER 11710.54 8931.82 4-1/2" HES Water Swell Packer L3-03 PACKER 12124.82 8866.75 4-1/2" HES Water Swell Packer L3-03 PACKER 12319.4 8844.12 4-1/2" HES Water Swell Packer L3-03 PACKER 12572.42 8816.89 4-1/2" HES Water Swell Packer L3-03 PACKER 12798.86 8788.84 3-1/2" HES Swell Packer TREE= CM/4-1/16" WELLHEAD= FMC 0 L 3-03 SA NOTES: WELL ANGLE>70' 7, 10236'***MAX dLI AA- TOF2;--- BAKBR C DOGL : 12.6" 7' 10267°".CHROME TBG&LNR- OKB.EI_EV= 69.55 J 1 BF.ELEV---, 48.15' 10P= -"-861' 20"COND, - -128' --Ma--> Angle= 11:06-4 1163-3' 1• 1' 2247' -14-1/2"HES X MP,ID=3.813" Datum NU; 1003i 91.5#'A-53' Datum ND= 8900 SS o=lg.124- al. GAS LFT MAM:RELS 13-3/8"CSG,68#,L-80 BTC,I3=12.415" H 4143' V4Il ST MD ND DB/ TYPE VLV LATCH PORT DATE 4 4343 4010 27 1443 DOLE RK 16 08/07/15 3 6830 6211 28 1114.16 SO 9< 08/07/1 TOP OF CEMENT(03/29/15) -I -4200' N 8 F 20 5 6, I' 2 8156 7376 2MkG DP& RK 0 06/08/15 Ii- :0,i g 1 8972 8088 31 MAC DI& RK 0 01/30/16 , . TOP 7"OF LNR -' " 9091 1 40' 16,1 .,.+1 cl_jel 9091' H 9-5/8"x 7"BKR HRD-E ZXFN LTP.ID=7.34" k,'`..4.Pit: 1,--e• 9196' ___10-5/8-X 7"BKR FOC HGR.ID=6.18" 9-5/8"CSG,47#,L-80 TCINAM TOFYBTC, H 9252' ,.Nli Ilk 4-•••• de lb ID=8,681" 416 1" 9466' H4-1/2"I-Es X MR.ID=3.813" Minimum ID =3.71" @ 985T r. ; I I t 4-1/2" FRAC PORT SLEEVES r, N e P. i IS 40 9497' -14-1/2"NDPG-C SAPPHIRE GAUGE,D=3.879' FERFORATION SUA464ARY REF LOG: I ,.r1 13 k• - 9532' _I r X 4-1/2"HES TNT PKR,ID=3.856" ANGLE AT TOP PERF: 500©10018' /60.,1..... 1.'ill ge 9569' H4-1/2"HES X NP,ID3.813" = Nate:Refer to Roduction DB for historical pert data P I I ) i . SIZE SPF NTERVAL Opn/Sqz SHOT SQZ ,.• h, 2-1/2' 6 10018-10321 0 08/16/17li e. ki. 9639' 2-1/2" 6 10238-10241 0 08/17/17 :4 I I • e, k 2-1/2" 6 10456-10459 0 08/17/17 ,-'4 41 2-1/2" 6 10984-10987 0 08/17/17 'ili , ‘ 9649' HT X 5'BKR I-RD-E ZXPN LIP,D=4.32' 2-1/2" 6 11409- 11412 0 08/17/17 e, t!..,:ete ' 2-1/2" 6 11979- 11982 0 08/17/17 9656 -14-1/2"VVLEG,ID=3,958"itf. 411, bp,* 4-1/2"TBG 12.6#,13CR-85 VAM TOP, 9656' c, H ELMO Tr NOT LOGGED .0152 bpf,ID-3.958" 9673* H7'X 5"BKR FW(-LCCK HGR,0=4.33" .-_. ..._. 9683' -I 5' 4-1/2*XO,ID=3.910" 7"LNR,26#,L-80 VAM TOP HC/BTC-M H 9820' .0383 bpf.D=6.276 Num= 41/2" FRAC PORT SLEEVES 1:31 .. FES SWELL PACKERS RSI-t EVOITREV E -1013V s CEPTH SEAT SZ. ACTUAL SIZE 0/C DATE I-E"is 7. NO NO CEPTII IDi...... •,-..:. 10 9857 3.71" 5.625" 0 08/04/15 RUG a 11 9905 3.920' IN In 1111 9 10023 331' 5.625' 0 08/04/15 10 10071 3.920" .. Pnl III Mll8 10242 3.71' 5.625' 0 08/04/15 e 9 10290 3.920" 7 10460 3.71" 5.625" 0 08/04/15 .:. .:. 8 10591 3.920' sum. 6 10719 3.71" 5.625" 0 08/04/15 7 10809 3.920" ,•:.. ..:. 5 10989 3.71" 5.625" 0 08/04/15 6 11078 3.920" 4 11414 3.71" 5.625' 0 08/04/15 5 11711 3.920' 4-1/2"VVFD CMT - 12185' •-:' ,•:' 3 11984 3.71" 5.625' 0 08/04/15 4 12125 3.920" RET(04/24/16) CTMD : 2 12221 3.71" 5.625° C 04/24/16 3 12319 3.920" 4-1/2"WFD CEP 12420 1 12447 3.71" 5.625" C 04/24/16 ' 2 12572 3.9207 PA 12878 WA 5.590" C 06/05/15 '1 12799 2.892' (02/10/16) m m• "1 =3-1/2"SWELL FKR . , PBTD --I 12777' " ---- " 12561' -14-112"BKR SI-FT TOOL VERF1CA1ION SUB,D=3.89' 4-1/2"LNR,13.5#,13CR-80 HYD 521, H 12791' IN E.• 12777' 4-1/2"SLB CRC VALVE,D=1.15 - - .0152 bpf,ID=3.958" 12791' -14-1/2"X 3-1/2"X0,ID=2.992" 3-1/2"LNR,9.2#,L-80 BTNAM TOP, ---1 12858' I•II Inn .0087 bpf,ID=2.992" eg... DATE REV BY COMENTS DATE REV BY COMIENTS LISBURNE UNIT 06/08/15 PKR 272 INITIAL COMPLETION 04/27/18 JD/.9.13 SET WFD CMT RETAIIER(04/24/16) • WELL L3-03 11/19/15 MS/A134 UPDATED MN I) 09/13/17 MSS/JWIDFERF FRAC SLEEVES(08/16-17/17) PERAT hb:u2150180 12/01/15 MS/J14.13 ADDED FISH AR No: 50-029-23535-00 02/12/16 JTC/JIAD FULLED DREANCATC1-ER(12/23/15) SEC.22,T11N,R15E,346'FT/&5E2'FWL 02/12/16 GlVVIJAK GLV 00(01/30/16) 02/12/16 JTC/JA43 SET VVFD GBP(02/10/16) _ BP Exploration(Alaska) • I i+l'iFV • croft';'. CT11414 2-0-CT Job Objent ye:Ac4d Stimoul€WFT Surge Frac Pecker up to 10467'flower element depth!to straddle across Frac Port e7.Pump 30c KCL down coil to set packer.initial Infectivity 3 21pm @-7000psi into Frac Port 57.Pump Acid treatment per pump schedule.Pump at max treating pressure of-7000p i core-pressure.Final Injectik ty into Frac Port 47 3bpm<`a1-7146psi.Displace Coil with D esel Pull up to equalize packer&let elements relax.Had difficulty egaalco ng across the lower packer.Run in&out of hole to get pressures to equalize across the lower packer.Poohf"In Progreso"'.ACID TREATMENT.RIG DOWN.Diesel 33.2 6bte3W Slick KCL:17 bbls3Oc KCL+P103:108 bbts3%FCC F103+567:8+ 7=715 bblsETCH Acid.20+20.6.34.6=75.2 6615 15%VGA Diverting Acid.I0+10.8.20.8 bbl's CTU414 2.0 CT job Objective:Acid StimPull WFT Surge Frac Packer up to 10467 tower element depth}to straddle across Frac Port 47.Pump 33'i KCL down spit to set packer tai Infectivity 3.2bpm @-7000pei into Frac Port 47.Pump Acid treatment per pump schedule.Pump at max treating pressure of-7000psi circ-pressure.Fina!Injectivity into Frac Port 47 3bp'cCfle-T1O0psi.Displace Coil with D;eset.Putt up to equalise packer&let elements relax.Had difficulty equal-zing across the lower packer.Run-n&o t of hole to get pressures to equa se across the lower packer.Pooh.Lay down toots Both elements came back intact RDMOL.'^Jeb complete'".ACID TREATMENT:RIG DOWN.Diesel 33 2 b'le3'x Slick KCL.17 bbts398 KCL.F103:108 bbls3%KCL-F1,33.1167.S*7=75 bblsETCH Acid;20+20.6+34 6=75.2 66151596:VOA Diverting Acid.10+10.8.20.8 blots t=I ,-;!7 • ass A Eti LRS Test Unit i.Inlet Well13-03,Outlet Well 13-05.Acid P oucoack with Coil Current Barriers Inlet 3'Block and ICK valve Outset SSU Continue from WSR 0117/17 Assist CTU SB for CTU-CTU Pumping ACID,Begin 58 for Sticklrc 58 for DSO.Continue on WSR 08/19/17_FLOWBACK,STANDBY *t '20,.7 • 6,761711llii CTU414 2 00 Coil"'Como rue from/5R 81,6717"'Job Objective.Acid SGmPerforated interval 42,11459 11412 and interval 83,10984.-10987 wi HES 2.5 P 1 ccium Guns.6 SPF.60'phasing using time delay fuse between gulls.. PERFORATING-Slic.k i?§KCL cc SafeLuba-41 550750 Metbanoi- LRS Tose Unit 1 ln;at Welt L3-83-Cutlet Well L3-05.Acid Plowback with Coil.Current Barriers:Inlet pip ng.Vessel.Outlet 55V.Continua from WSR 8717117.Assist CTU-SE for CTU,CTU Pumping ACID Continue on WSR 08118717.FLOWBACK, STANDBY C1114I42.00dtJob 06; t e.Acid Sri Pe to ed interval 02:11409-11412 and interrat.3 10984-16987'wl HES 25 Mitieniurn Gums.6SPF.6 phasing tieingt' e dely fuse between guns.MU&RIB,with 4E525 22 perf gun 42 � Perforate interval.4.1045E-10459-put(up and shoot interval 45 10238-1 02 41'on line delay.pull up end shoot interval e6 10018- 10021 on time deter Good indication al,guns fired.Pooh.MU&R14.nith WFT SurgeFrat Packer- g t[ Cement Retainer 170;&correct to towner element on SurgePrac Packer Pub to 10.996-Mower element depth)to straddle across Frac Port 45_Drop ll'2"atom',rum ball&set packer Continue pumping I bpm&could see frac port open at- 1200psi.Increase rate to verify iclacivity darn coil wi no who response_2 I bpm at-3450psi into Frac Port 45.Line up to pump Acid Treatment.Pump Acid Treatment per pump schedule.Pp atm ax treetop pressure of-7300psr circ- pressure.Initial infectivity 36pm @ 720Cpsi Increased rate to-5,26pm iru 0000pa'nehen Acid hit Formation Adjust pump rate to maintain-7000psl treating pressure.Final Infectivity into Frac Port 455 3hpm 18,7150psl See Log for details.Pull up to equalize WFT Surgefrac packer&l et elements relax.'"In progress'".PERFORATING;ACID TREATMENT IN PROGRESS.Slink 1%KCL ed SafeLube:41,5+22.40+20=123-5bsloDiesa1.145 bbls39;Shelf KCL.70 bbts3c KCL+F103: 86 4+77.8=164.'2 bbls36r ACL+F103+1167.74+7.2=14.6 bbtuETCH Acid'.20-20.20=60 bblsl S%VDA Diverting Acid.10+10=20 Dols 7.24117 AW117221 CTU4I4 2C0"Coil Job Objective:Acid StimPerforeted interval 42:11409'-€1412-and intervel43,10484--10987 w1 HES 2.5"Millenium Gone 6 SPF 60'phasing using time delay fuse between guns.MU&RIH with HES 2.51x 22'pert gun 4.2. Perforate interval em 10456-10459poll up and shoot interval 05 13238'-10241'on time delay,putt up and shoot interval'06 10018'-10021'on time delay.Good indicator,all guns fired.Pooh MUS RIP with WFD 5orgnFrac Packer.Tag TO and tie in.PU to.sleeve 45."In progress".PERFORATING.Slick 196 KCL,y,r SafeLube-41.5+40+50'50 Methanol- 7. ' • CTU014 2.00`Coil Job Objective:Acid StimPer/grated interval e2;1 1 40 9--1 1412'and interval N3;10984-10987 we'HES 25`Msllenium Guns.6 SPF.60'phasing coop time delay fuse between guns.MU&914 with HES 2.5"x 22 peri gun 02. Perforate interval 04.10456-17459,pull up and shoot interval fry 10238-10241 on time dela;,pull up end shoot interval CO 10018-10021-en time delay.Good icdicalon at guns fired.Pooh_MU&R14 with AFT SurgeFrat Packer.Tag Cement Retainer RC}&correct to lower element on SorgaFrac Pacleer.Putt to 10,996'{loner element depth!to straddle across Frac Port XS.Drop 11Z aluminum ball&set packer,Continue pumping tbpm S.could see frac port open at- I2'30psi_Increase rate to verify'njectivit,down coil wi no whp response.2 I bpm at-3450psi into Frac Port 45-Line up to pump Acid Treatment Pomp Acid Treatment per pump schedule.Pump at max treating pressure o. 7000psi c'rc- pressure.Initial infectivity 3bpm @ l200psi.Increased rate to-4.2bpm`cl 7000pei when Acid hit formation Adjust pump rate to maintain-7000pei treating pressure.Final Infectivity into Fra_Port 05 3bpm @ 7150psi See Log to deta Is Poll up to egoalice SOFT SurgeFrat packer&let elements relax."'Continue on 08118117"-PERFORATING,ACID TREATMENT;IN PROGRESS.Stick 191 KCL wt Safelube 41.5+22«40+70.123 5 bbseOiesol 145 bble336 Slick KCL.70 hbte30b KCL « F103:86 4 .78-164 2 bbls394 KCL.F103.067-74+7.2-14.6 bbtsETCH Acid.20«20-20.60 bbls15°VDA Diverting Acid.10-.10=20 bkts N112121117• 3131. CTLIei 4 2.09'Coal/oh Objective;Acid SimPerfarm a wiper trip to orifine at 6830.Dry drift from 9803 to TO Bring pump online at 12142'end these 30bbt Powervis pill bade to eurface-'""in progress.'"FILL CLEAN OUT 1,3-3,11. r CTUe14 2-00-Coil Job Objective:Acid Stim.ertorm a wiper trip to orifice at 6830.Dry drift from 9800"to TD-Bring pump online at 12143'and chase 306b1 PcwerVis pill back to surface.MU Logging BHA and RtH""In progress"'.FILL CLEAN OUT CTU414 2.00"Coil Job Objeoticc Acid St mPerfe m a wiper trip to orif ce at 6830.Dry drift from 9800 to TD.Bong pump online at;2142"and chase 30bbi PcwerVia pill hack to surface-Ran HES Memory 09/CCL lin 2.90`carrier,logged from PBTD to 9800`.Good data+38 correction tied referenced to tubing tally.Painted RED&WHITE flag @ 9702 Electronic 9716 Mechanica€.Perforated interval el;11979-11982 w;HES 2 5`Mltenium Guns,6 SPE 60'phasing with t:me delay fosses above guns 2&3.""Continued on c 8!t 7117".LOG-JEWELRY--DEPTH CONTROL:PERFORATING.50/50 Methanol-4251X01;5 KCl w1 SafeLube-1486 e 58+13.3 6,11111 • A7,111,111 CT11P14 2!00-Coil Job Object ye Acid Shan er orm a u/per trip to orifice et 6835.Dry drift from 9800 to T0.Bring pump online at 12147 and chase 30bki PowerVis pill back to surface"10.progress'"FILL CLEAN OUT CTUe142.00'Codi Job Objective:Acid Sim:er orm a wiper trip to orifice et 6830 Dry drift from 9800 to TD.Bring pump online et 12142'and chase 30651 PowerVis pill back to sorrace.Ran HES Memory CRJCCL lin 22.90`carrier,togged from 0010 to 4800-Gored data+30'correction tied referenced to tubing tally Painted RED&WHITE flag @9700-Electronic 9716 Mechanical Perforated intervalel;11979'-11982'wc HES 2.5`Mileoum Guns,6SPE 60'phasing with time deity fuses above guns 2&3'"'in progress"".FILL CLEAN 0117;100-JEWELRY-DEPTH CONTROL:PERFORATING,50/50 Methanol-425110k 1n:,KCL w7 SafeLube-1486.56.13.3 02,1 6:22117 • A1,1:10222 LRS Test Unit 1 Inlet Well 1303.Outlet Welt L3-O5-Acid Ftov:back with Coil Current Barriers:Inlet Piping Vessel,Outlet 55c/Continue from MISR 8115117.Continue flowing 13703 with CTU.Monitor and Divert Gel Sweeps to tanks SI Assist CTU es needed.Line op to POP Cancel POP Assist CTU.SB for CTU.Continue on VvSR 08717117 FLOWBACK 1 0 ixrr,c.i CTU414 2.00-'Coi1100 Objective:Acid StimComplete Weekly BOP test.VU'WFO 3.'S-nein&motor.Se€down at 10246.Begin milling from 10246'down to 12146 without seeing any motor work but setting down in frac s..ec-/es.Clean up by cured og gel sweeps to ASRC test unit throughout entire job'"Ccotinu .'081161977. ACID TREATMENT T • LRS Test Unit 1 inlet Weil 13-03,Outlet lWetl13-05.Acid Flmvbacb;with Cod.Current Barriers:Inlet Piping Vessel,Outlet 55V Cart from 43SR 8/14017-SB for Coil_End SB for Cob.POP/3-03,Monitor and Divert Get Sc'ecps to tacks. Continue on WSR.08/16/17 STANDBY:FLOWBACK • <.. CTUdi 4 2.007 Coil Job Objective.Acid StimUtRU CTU.Perform Weekly BOP test MU CTS I0k CTC and PT treating lines to SSOOpsi.Cut o€€CPS CTC and MU',WO CTC and MHA,."3.70-mill&n+.otor.RIH and set down 0010246 Begin milting from 13246 down to 12146 without seeing any motor work but setting down 3n frac sleeves.Clean up by pumping gal sweeps to ASRC test unit throughout entire job.'""Continued on 08/16117."ACID TREATMENT 21501 $ N O V 15 2016 WELL LOG TRANSMITTAL#903459977 A To: Alaska Oil and Gas Conservation Comm. November 10, 2016. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED E Anchors g e, Alaska 99501 " o i� M K BE RE: Production Profile: L3-03 Run Date: 8/2/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 L3-03 Digital Log file, Interpretation Report 1 CD Rom 50-029-23535-00 Production Profile (Final Field Print) 1 Color Log 50-029-23535-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 ; `'' `1 Office: 907-275-2605 SCAWE® Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: (X)Alzadia..:1) STATE OF ALASKA likLASKA OIL AND GAS CONSERVATION COMM!, REPORT OF SUNDRY WELL OPERATIO S 1. Operations Performed Abandon ❑ Plug Perforations Q Fracture Stimulate ❑ Pull Tubing El Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Repair Well El Re-enter Susp Well ❑ Other: ,c"t C15 P lik 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 215-018 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory El AK 99519-6612 Stratigraphic El Service ❑ 6. API Number: 50-029-23535-00-00 7. Property Designation(Lease Number): ADL 0034631 8. Well Name and Number: LISB L3-03 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL 11.Present Well Condition Summary: Total Depth: measured 12875 feet Plugs measured 12185/12420 feet RECEIVED true vertical 8779 feet Junk measured feet MAY 1 7 2016 Effective Depth: measured 12185 feet Packer measured 9532 feet true vertical 8859 feet Packer true vertical 8563.8 feet AO py^C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 50-130 50-130 1490 470 Surface 4095 13-3/8"68#L-80 48-4143 48-3832 5020 2260 Intermediate 9207 9-5/8"47#L-80 45-9252 45-8325 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"13.5#13Cr85 42-9656 42-8669 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12165'-12830'Cement Plug in Tubing,some should in Annulus through Fracturing Sleeve @ 12221'. Treatment descriptions including volumes used and final pressure: 75 Bbls 2%KCL,5 Bbls Mudpush II Cement,10 Bbls 8.6 ppg Bimodal Cement,5 Bbls Mudpush II Cement,28 Bbls Diesel,3588 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 331 16938 95 3 1889 Subsequent to operation: 450 10054 P51 3 1270 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory El Development Q Service El Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data El GSTOR Cl WINJ El WAG ❑ GINJ El SUSP El SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature lQ, - C_ Phone +1 907 564 4424 Date 5/16/16 Form 10-404 Revised 5/2015 L 5:133116 , (...2-,A6 RBDMS 1v MAY 1 8 2016 Submit Original Only • • 13.c, 0 0 0 0 o ) r, coco in O N C() CO CO U y 0 0 0 0 0 0 i O) N N- N N CD 00 N O O m <- LO o r- O o) O N LO O O N M CO N O C) CO CO 00 CO CO r- N- CO CO CO CO 00 CO CO 1 1 1 1 1 1 1 H CA M O O O to CO CO (3) N LO 'Zr O r- co co co OMNOoj � (fl MLO " C) 0 p M 4-1 Qrn O O In C) O N M Lf) c O CO c d' C)) (3) dyi O In O J 0 co 0 OD 00 L J M COCn 2 M .N N � N 00 N O r U M v M t C)C) CO C N- 0.)W tC) () 0rn W � Q U W W V o a Z Z W W W W W E O D F- Z Z Z_ D 0 co Z J J J • •I a) f6 m LC) M 6) CA Or--- Lf) M O M N y N- C) CO CO LC) — M O V CO O CO C) O O O O a) CO CO CO N- CO CO C) C) C) O) (0 CO CO CO CO > I- 0. 0 I� N- CO CO CO CO CD rn .0 CA 0 10 v (O CO IC) V CO V 10 c- N- LC) CO O CD C O N 0 N CO CO I,- LC) v N CO Cr) y W o como0000C000 > o Co C0 6) (A CA CA O CO CO CO OO 0 > 2 I- W 0 O• 0 Z w w0 a. W o m ~ ~ J 0 ggY CO 00 ‹ Y Y g L tj') c- O '— 6) CO — LC) O N O J J J Q Q fn W G! O 0) 0 0 0 0 Lc, ap = = N N N N O_ _0 _0 _iW W Z Z Z Z O _10 Q Q Q = 00 CL d 0 0 0 W oec Z O Z t w W w D < j < () M 2 2 2 O u) cn cn cn coo .1—, I : c) 0_ Q J i- = M r M N O O CV LC) O CO LY CO M LC) N LC) CO CO a v CO CO CO CO CO • 0cr) v— N 65 C) o 0 0 '— '— N (N (N L 2 2 2 O u) cn cn to a) a 0 0 0 C 200000000 ( ( ( al I— I I— H H I— I— I— a Q a. tWWWWWWWWCOMM 0. 0 a) m a- a) F- m LC) LC) LC) LO LO LC) L0 LC) (O CC) CO C 0 0 0 0 0 0 0 0 0 0 0 W Z O N N N N N N N N N N N Z IQ W M M M N N N N N N Z a J 0 OW W w W d V < 0 J F- 1 _1 -I0 0r' 0L J_ J_ O Q Q LL w LL L_ L¢L co IL w a) E a7 • CO O M O CM M M CM M M M 99999999999 w CL w 0 w N W LL N M M M M M M M M M M M 030_ 0_ 0_ 0 _100w ILO_ a0 -' 00w a J J J J J J J J J J J < < m m LL U cn U) a- w 0 • Packers and SSV's Attachment LISB L3-03 SW Name Type MD TVD Depscription L3-03 PACKER 9090.77 8188.52 7" Baker HRD-E ZXPN LTP L3-03 TBG PACKER 9532.41 8563.8 4-1/2" HES TNT Perm Packer L3-03 PACKER 9648.98 8663.15 7" Baker HRD-E ZXP LTP L3-03 PACKER 9905.49 8879.34 4-1/2" HES Water Swell Packer L3-03 PACKER 10071.06 8992.77 4-1/2" HES Water Swell Packer L3-03 PACKER 10289.74 9081.43 4-1/2" HES Water Swell Packer L3-03 PACKER 10590.69 9084.43 4-1/2" HES Water Swell Packer L3-03 PACKER 10808.92 9057.17 4-1/2" HES Water Swell Packer L3-03 PACKER 11078.33 9017.51 4-1/2" HES Water Swell Packer L3-03 PACKER 11710.54 8931.82 4-1/2" HES Water Swell Packer L3-03 PACKER 12124.82 8866.75 4-1/2" HES Water Swell Packer L3-03 PACKER 12319.4 8844.12 4-1/2" HES Water Swell Packer L3-03 PACKER 12572.42 8816.89 4-1/2" HES Water Swell Packer L3-03 PACKER 12798.86 8788.84 3-1/2" HES Swell Packer • • \ u 15 \ _ § 7 = C e % CO // a) § 13 / = o c / I // r e .a I k ¥ « aeS \ 0E o_1 = 0 E e o e = I mac § o a � o / n 2222Oo .E = § GcCc 7 gO = o . o &. b o b E - R e 2 \ / / 0 \ f / f o \CL § § \ § % = 2 \ E c o 2 o e o I 7 % 7 U) c o E e e / �.E _ I. \ k a Lo % .c / ± C >- I- E E \ { Jo § E % cu o U) _ _ E " / o 2 N c o 0 ® § E a o c,- ,- \ \ / 0_ / R c, 0_ - C / C 0 / co / \ \ W ino ® =\ \ 0 2 E L'' o c = b $ m F c 1,1 CO E \ E '6 7 \ ) / - S/ @ 0 co tn k % / 0 I_ E % f $ m@ j o z i 2 § 2 5 / 2 ƒ / \ » _Q \ .g a / '3 5 c o E _ a)Ce / \ ) G \ \ / q o_\ § S % a _ - R ® a ? ® �• Z / / @ � � E 3 / » al �¢ / �• ¢7 � 777a) / / \ / a) CI / TCN t / I w / c ® _I .E $ t $ m t ° 2 . m Ce c = / m E r m $ 0 2 2 > L_ , _ • / COS M % m a) U I & _ I E a= s o e m e e = _3 5 5 E d W 0 2 _ o £ S \ \ k E 5 I m .... m 00 = E G U 7 I o e O _.d ._ - '6 e - E _ — ¥ = E . a /O ~ a •E \ \ f = cn 4 / c o $ ® ~ = 5 > ± ® > ° a Cr G - $ -I o 9 ) ; % z j f ® / _o § § O. = g E O % = c U U J E / k k f / -0 a_ r E E 2 ¥ k 7 R k/ NI-o ® c O O m O t O O m % - o o 2 \ D H « O t 2 ƒ \ \ k $ 2 < e o cn m co co / \ / cc,——— / / 4 4 < 1H1±ri. aW4-1/16" WEI1HEAD= FP.0 0 L 3-0 3 SA NOTES: WELL ANGLE>70'@ 10236'-MAX AC1UATOR= BAKER C DOGL : 12.6'@ 1026T''"CIROME TBG& LNR- OKB.ELEV= 69.55I 1 BF.as.'= 48,15' KOP= 86120'COW, -in' MS.1c Angle;-- -fob.611033' 2247' -14-1/2'HES X NW,0=3.813' tum ICI=-- 10037 91.5#,A-53, II Datum TV D= 8900'SS ID=19.124" & GAS LFT MANDRELS 13-3/8'CSG,684,L-80 BTC,ID= 12A15" - 4143' /"411 ST MJ TVD DEV TYPE VLV LATCH FORT DATE 4 4343 4010 27 NAG COKE RK 16 08/07/15 3 6830 6211 28 MAG SO RK 20 08/07/15 TOP OF CEMENT(03/29/15) H -4200' s. .11' 2 8156 7376 28 MG DMY RK 0 06/08/15 r 1 8972 8088 31 WAS DMY RK 0 01/30/16 0 . TOP 7'OF LNR - 9091' .. 4/.., ? IV fel 9091' 9-5/8-X 7'BKR HRD-E ZXPN LTP,D=7 34" 9106' -9-5/8"X 7"BKR HMC HGR ID=6.18" 9-5/8'CSG,47#,L-80 TUN AM TOPIBTC, - 9252' ID=8 681' Illig k.; Is* 9466' H4-1/2"I-ES X NIP,IJ=3,813' Minimum ID =3.71" @ 9857' 4-1/2" FRAC PORT SLEEVES 0 Ic 9497' _4-1/2"f•DPG-C SAPPHIRE GAUGE.ID=3.879" I $14 ... iilli lit& - 9532' _7"X 4-1/2-I fM-MIT PKR D=3.856' -.7....4?' 44 9569' 4-1/2-HES X NP,ID=1813" C 9839' -4-1/r HES X NIP,D=3.813" k TBG, 12.6#,13CR-85 VAM TOP, - 9656'2' OM •-1 9649' -7'X 5'BKR I-ROE ZXPN LTP,O=4.32- 4-1/ ..olf Ii7462 9888' -4-1/2'VVLEG,ID=3.958' ifb r 0152b ,ID-3 r pf958" AO A -ELMO TT NOT LOGGED 9873' -7'X 5'BKR FLEX-LOCK HGR,I)=4,33' 7"LNR,268,L-80 VAM TOP HOBTC-M - 9820' 9683' -5'X 4-1r2"X0,ID=3.910" _0383 bpf.ID=6,276 IN=MI 4-1/2" FRAC PORT SLEEVES ..11I.. 4-1/r 2. L PAC iv NO LTH SEAT SZ. ACTUAL SIZE 0/C DATE RSI-t EVOTF3EVE - -10131' .7 •imm 7.. NO DEPTH ID 10 9857 3.71" 5.625" 0 08/04/15 11 9905 3,920"' PLUG 9 10023 171" 5.625" 0 08/04/15 10 10071 3.920" .7.',.11111474 8 10242 3.71" 5.625" 0 08/04/15 9 10290 3 920' ,Nic. 7 10460 171" 5.625" 0 08/04/15 8 10591 3.920' •im. 6 10719 171" 5.625' 0 08/04/15 7 10809 3.920' .:.gin,......-. 5 10989 171" 5.625" 0 08/04/15 6 11078 3,920' 4 11414 171" 5.625" 0 08/04115 5 11711 3.920' 4-1/2"WFD CMT - 12185 ,:::,111111.7.. 3 11984 171" 5.625' 0 08/04/15 4 12125 3920' RET(04/24/16) CTMD 2 17771 3.71" 5.625' C 04/24/16 .:.111111- 3 12319 3.92(T 1 12447 3.71' 5.625" C 04124/16 4-1/2"WFD CEP - 12420' Num so 2 12572 1920" '-' PA 12678 MA 5590° C 06/05/15 7.-..-:. '-' '1 12799 2.992" (02/10/16) NI um wi '1 =3-1/2"SWELL FKR PBTD - 12777' k:" 12561' -4-1/2'BKR SI-IFT TOOL V ERFICAT1ON SUB,ID=3.89" 1111Ir 4-1/2"LNR, 13 5#, 13CR-80 HYD 521, - 12791' •mum 12777' -4-1/2'SLB CRC VALVE,0=115' ... .0152 bpf,0=3 958" 12791' j-4-1/2'X 3-1/2"XO,E)=2.992' 3-1/2"LNR,9 2#,L-80 TNAM TOP, 12858' UU MI .0087 bpf,ID=2.992' er.3 DAM REV BY CONVENTS : DA IE REV BY CONLENTS LISBURNE UNIT 06/08/15 PPR 272.INTIAL COM PLET1ON 04/27/16 JO/JM) SET WFD CMT RETANER(04/24/16). WEU L3-03 11/19/15 MS/JMD.UPDATE)MN 1.) _ PERMIT No: 2150180 12/01/15 MS/JPA) ADDED RSH AR ND: 50-029-23535-00 02/12/16 JTC/JMD FULLE)DREAMCA Ta-ER(12/23/15) SEC 22,T11N,R15E,346'RA_&567 FWL 02/12/16G1W/JkleGLV 00(01/30/16) , , 02/12/16 JTC/JMD SET WFD C1BP(02/10/16) BP Exploration(Alaska) 21 50 18 RECEIVED • • 27181 MAY 1 7 2016 WELL LOG TRANSMITTAL#903142514 A G To: Alaska Oil and Gas Conservation Comm. May 13, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 M.K.BENDER RE: Production Profile: L3-03 /Run Date: 2/24/2016CA��E The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 L3-03 Digital Log file, Interpretation Report 1 CD Rom 50-029-23535-00 Production Profile (Final Field Print) 1 Color Log 50-029-23535-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: vitga.4140eitteet , ,� • • 21 50 18 • 26987 MAR 2 9 201u WELL LOG TRANSMITTAL#903018032 Ao c9 9 To: Alaska Oil and Gas Conservation Comm. March 25, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 g �y y 4/ X201 co SCANNED `� �; .v1.K.BENDER RE: Production Profile: L3-03 Run Date: 12/29/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 L3-03 Digital Log file, Interpretation Report 1 CD Rom 50-029-23535-00 Production Profile (Final Field Print) 1 Color Log 50-029-23535-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: inval2 a.47cL, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMSON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations Q Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: G 6 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 215-018 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23535-00-00 7. Property Designation(Lease Number): ADL 0034631 8. Well Name and Number: LISB L3-03 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL 11.Present Well Condition Summary: Total Depth: measured 72875 feet Plugs »_: measured 12420 feet 8�, a true vertical 8779 feet Junk measured feet [ Effective Depth: measured 12420 feet Packer measured 9532 feet 1v4� R 0 2 2015 true vertical 8833 feet Packer true vertical 8563.8 feet AO G CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 49-129 49-129 1490 470 Surface 4095 13-3/8"68#L-80 48-4143 48-3832 5020 2260 Intermediate 9207 9-5/8"47#L-80 45-9252 45-8325 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"13.5#13Cr85 42-9656 42-8669 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED . *r 0 5 3 ,1 h; Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 286 16785 136 3 2049 Subsequent to operation: 332 13787 199 3 1867 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer ft— Signature l Phone +1 907 564 4424 Date 3/2/16 Form 10-404 Revised 5/2015 vi-L-/ /b A�C•y�,� RBDMS (.t, MAR 0 4 20169 Submit Original Only • • Q o 0 0 0 0 0 0 edN. OWIr My — Tr N ti MDO Co p N cr Co CO 00 U E CD CD ea CD O N NO CD N N v 0 Co N O r O m r In CO N- O O O N MD CD O r CD (NJ CO N O CD CO CO r CO C'r) CO N- I CO M CO CO CO CO OD Ci i I i I I i i CA CO D OD CMO a) M N r CO N C10 coco 0) OM N O v- CI) CO N Co N N. CO Co .L r v cn co cq cq 2,9 V co 1 1 I 1 1 1 1 Q O (7) CO Co O O N J v v a) a N v Cr :C2 Ca u) I— J o o o OD Cao J CO M M M , r r N N C4t CO Co N MD N ul Oa N rdO - N OD •CO C') UJ 00 r c- OV V) C CN N , 4 M 4 c) c) titN - C CO 0 CV CO OD W CC Q C W U W O O � CC tx W W Z Z a W W W W m ODS— Z _ZZD U U) Z J J J • • • d a) a) m CO co 0) 0) CO N- CO Cr) CO co N O N- M C) N- N- ' Q) OO a CC) N d x- CO [f CO co a) N- 0) 00 CO CO r co co N r CO Gco co 00) O 00) 00) co co CO co co 0coc 0. O I� r I� CO CO CO CO 0) 0) t. 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U J a w 0_ J J J J J J J J J J J < < m m LL U (/) m o re , • • Packers and SSV's Attachment LISB L3-03 SW Name Type MD TVD Depscription L3-03 PACKER 9090.77 8188.52 7" Baker HRD-E ZXPN LTP L3-03 TBG PACKER 9532.41 8563.8 4-1/2" HES TNT Perm Packer L3-03 PACKER 9648.98 8663.15 7" Baker HRD-E ZXP LTP L3-03 PACKER 9905.49 8879.34 4-1/2" HES Water Swell Packer L3-03 PACKER 10071.06 8992.77 4-1/2" HES Water Swell Packer L3-03 PACKER 10289.74 9081.43 4-1/2" HES Water Swell Packer L3-03 PACKER 10590.69 9084.43 4-1/2" HES Water Swell Packer L3-03 PACKER 10808.92 9057.17 4-1/2" HES Water Swell Packer L3-03 PACKER 11078.33 9017.51 4-1/2" HES Water Swell Packer L3-03 PACKER 11710.54 8931.82 4-1/2" HES Water Swell Packer L3-03 PACKER 12124.82 8866.75 4-1/2" HES Water Swell Packer L3-03 PACKER 12319.4 8844.12 4-1/2" HES Water Swell Packer L3-03 PACKER 12572.42 8816.89 4-1/2" HES Water Swell Packer L3-03 PACKER 12798.86 8788.84 3-1/2" HES Swell Packer , ' S • ■ -5 _ >,- as _c- C _1 � Qb . c. k » Q = a9 %-0 2 2 � G0 � o A \ 2 = / w o ® 1.0 g c 2 ■ N- Nr q 7 2 a q » a U o a) 3 £ 9 % k _ 2 ƒ 2 06 k / a) 3 a) 2 CO 73 E IE2E/ k � / t % a a f a 0 o -) / � \ �o o .c c ° � . 2E cri 06 (0 =0 E— 2 $ = C6 2 m 0 2 E e a i- _ ■ / : c0b � \ R ° o c 2 Uc = a- aE o - L_ � Ls 2 >- � k �� ° 232E as E s- < i- k cNi k as k ( \ 0. 20_ / a- 0 " ■ ® \ O22 m > m _ _@ m f sa c < 2 G # q m ® 2 m q - orb % 8 � 2 = fes \ QOc - 5 ° VI % .E $ 2 % 0 / t -0JIQ 3 -I m7 mo_c@bL QQ � a co $ £ $ �� £ 2Ro 6 0 E t � CO t ° k/ o % k u k o 0 . m o _ ¥ * ° 0- m » CIL 0 o & o Ora_ 2 C _k 0 ¥ % re 0 ~ _C � 0 � Ek / Lra ,- o / 2 / / $ _ @ c a o cts t < Ea2 2 : § ® 2 .E°wg CI . moo @ » ow = _ M m e oAl # 2 / E < :m f o \ / 7 -0 b ƒ i CO k = - 1- .0 '- o \ 0 _1:3 ..0 / E 03 $ % / o \ 0 : I $ . o k lb R m m E : c _ R@ 0 § / 2 k / \ 5 3 I k / E \ 4 � L Q ° _1 0 6 2 \ 2 \ - . g 0 2 ± o o I . R S = U 1- « f * � � kk22tR * / R / $ 2 / $ � 0 I % ! 0 2 0 2 » -) a : O C Q % m ! 2 \ u Q CD c I- / � & o 5 co a) a cot % \ CV CV < TREE CNV 4-1/16" III INBJJ-EAD= FMC L 3- 0 3NOS: WELL ANGLE>70•141 10236'°"MAX ACTUATOR= BAKB2 C _ DOGLEG: 12.6°E 10267'""CFROM E TBG&LNR"" . EL �___ OKE. EV 69.55' 2 [I BF EI/(L 48.15' KOP 861' 20"GOND, H ^r12$' Max Angle 100 11033' 2247' H4-1/2•HES X NP,D=3.813" Datum MD= 10032'f Ncea 91.5#,A-53, Datum TVD= 8900'SS D=19.124" 13-3/8•CSG,68#,L-80 BTC,D=12.415" - 4143' SSS ST MD TVD DEV TYPE VLV LATCH FORT (ATE 4 4343 4010 27 MUG DOME RK 16 08/07/15 TOP OF CEMENT(03/29/15) H -4200' 1 [ 3 6830 6211 28 MMG SO RK 20 08/07/15 iv"; E1'k+ 2 8156 7376 28 WAG DMV RI( 0 06/08/15 ,tItei f 1 8972 8088 31 MING DMY RK 0 01/30/16 ITOP 7"OF LNR H 9091' J ,4 ,116 iN » . �.!4..%,`4 8091' 9-5/8'X r BKR HRDE ZXPN LIP,D=7.34' i �* r�!� y4,P. ♦e I 9106' H9-5/8"X 7"BKR HMc HGR,D=6.18' 9-5/8'CSG,47#,1-80 TCWAMTOP/BTC, -{ 8262' ,41,el 4,i D=8.681` eN, �1 k ri ;i I 9466' H4-1/2"HESXN?D=3.813' I I II Minimum ID =3.71"@ 9857' " 4-112" FRAC PORT SLEEVES % �elig f I 9497' 144-1/2-nDr csAP EGnuGE,o=3.879" rjte iIk►= ��16. 0632' __1 7"X 4-1/2"HES TNT PCR D=3.856" tie I' I 9569' --(4-112'HES X NP,D=3.813" �* 4. t �* 't ' III 9639' H4-112'HES X NP,D=3.813J • ♦e, t I` ►. e+► R� 0649' H7'X 5"BKR HRD-E ZXPN LIP,D=4.32' I 4-1/2"TBG,12.6#,13CR 85 VAM TOP, H 9656' 't n M0656' H4-1/2'WLEG,D=3.958' .0152 bpi,13-3.958` lt. . eN .; H B_MD TT NOT LOGGED I lik e �` 9673' H7'X 5"BKR FLEX-LOCK HGR,D=4.33' J it r LNR,26#,L-80 VAM TOP HGBTC-M H 9820' ® _ 0683• --15-X 4-112"XO,ID=3.910" .0383 bpf.D=6.276 IN • 4-112"FRAC PORT SLEEVES 4-1JZ"FES S1NELL PACKERS FISH EVOTREVE -I 10131• NONo aTPn-I SEAT SZ. ACTUAL SIZE 0/C DATE DEPTH D , 10 9857 3.71" 5.625" 0 08/04/15 11 9905 3.92(r �� ••- 9 10023 3.71' 5.625" 0 08/04/15 10 10071 3.920" 8 10242 3.71" 5.625" 0 08104/15 9 10290 3.920" •in is 7 10460 3.71" 5.625' 0 08/04/15 8 10591 3.920' .so al 6 10719 3.71" 5.625" 0 08/04/15 7 10809 3.920" •• 5 10989 3.71" 5.625' 0 08/04/15 6 11078 3.920' 4 11414 3.71" 5.625' 0 08/04/15 5 11711 3.920 , 3 11984 3.71" 5.625' 0 08/04/15 4 12125 3.920" aim. 2 12221 3.71' 5.625" 0 08104/15 3 12319 3.920" 4 112'WFD CBP 12420' :• _ 1 12447 3.71" 5.625" 0 08/)4/15 2 12572 3.920" PA 12678 WA 5.590" C 06/05/15 "1 12799 2.992" (02/10/16) MI-IN "1=3-1/2"SWILL PCR P 113 -I 12777' '-.- 12661' H4-1/2"BKR SHFT TOOL VERIFICATION SUB,D=3.89" 4-1/2"LN,13.5#,13CR-80 HYD521, -I 12791' •MIN a 12777' -14-12"SLB CRC VALVE,D=1.15" .0152 bpf,ID=3.958' 12791' H4-12"X 3-1/2"XO,D=2.992' 3-12'LN,9.2#,1-80 BTNAM TOP, 12858' 1■■ mim .0087 bpf,D=2.992" `. DATE FEV BY GOMIS NTS DATE REV BY COMMENTS LISBURNE UNIT 06/08/15 PKR 272 INITIAL COMPLETION 11/19/15 MS/JMD UPDATED MND WILL: L3-03 09/04/15 CJWJM3 SET EVOTREVE PLUG(08/19/15) 12/01/15 MS/JIM ADDED FISH PERMIT Nb:"2150180 09/04/15 DU/JMD TREE CIO(08/22/15) 02/12/16 JTC/JMa PILL®DREAMCATCHER(12/23/15) API No: 50-029-23535-00 11/09/15 JMG/JM?FULLED EVOTREVE RUG(10/16/15 02/12116 GTW/JA.0 GLV GO(01/30/16) SEC.22,T11N,R15E,346'FN.&562'FML 11/09115 DJS/JMD GLV 00(10/25/15) 02/12/16 JTCIJMD SET WFD CBP(02/10/16) 11/09/15 J110/J10 SET DREAMCATCHER(10/25/15) BP Exploration(Alaska) • • 0 > 2 U GM VQ ® E a ) f O IX 77, 0 0.6 >, H Q:: * OD CO N- m v () o c°i v CO * M V CO O M O CO CO O C) E CD LID Q) E C O -a M.5 cz -; CO CO M O o 0 0 o E 'a LLL E 000 = _ C, U) Q e1 C C) r n N CO LO O) N C) O Cc t :: C * e 7 O CO (D C) a7 N. � LC (OD 0 't V CO C T ( L CO N V W v E C O O rn Q M (D n rn co C c^cotS X c N N V N r r r O O O CL) U W > TO to - Fiiz0 o OO o o M I M W , _NO N O O CO O) M Q Q ( cooO 0 V V' N- r r C vi a 2 N a) L L C a s 3 0 m m _ _ 'o E.� E O in Ln as G O a co In N. 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U E >,.N CO o C , u) O _EC T 0_(71 L N O '- a) -c2 S, ❑ n 2 15 LNmNmO C CO-C_COO 0 - 0LL N ;2 1= N Un 0_ n.0 U) C) H e r nm m - a) _ C cz m o 0_ • C ❑,_=_-- -0.0 LL 00 U N -N O• C 30 O a) C o_2 5(3) N O Lcl)cc a N LL O YU L N N N U N N = O O O O U a o_ Qa) • E o C = .-. ._ E O Ny >''R 4 N EE O U N 0- E U) N U.L C L U) U • 0 E O O n O O O N C E m > o =L U)ru 7• ` -0 O C a) O O C N it C _ O C N O 'O O C O N H o) Z STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate Q Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 215-018 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23535-00-00 7. Property Designation(Lease Number): ADL 0034631 8. Well Name and Number LISB L3-03 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL 11.Present Well Condition Summary: RE CEIVED Total Depth: measured 12875 feet Plugs measured feet 2 true vertical 8779 feet Junk measured feet NOV 4 2015 Effective Depth: measured 12777 feet Packer measured 9532 feet true vertical 8792 feet Packer true vertical 8563.8 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 49-129 49-129 1490 470 Surface 4095 13-3/8"68#L-80 48-4143 48-3832 5020 2260 Intermediate 9207 9-5/8"47#L-80 45-9252 45-8325 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"13.5#13Cr8 42-9656 42-8669 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9671-12799 Treatment descriptions including volumes used and final pressure: Please See Attached Report. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: New Well Subsequent to operation: 1281 23688 1387 1600 813 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-405 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 044CiaL Phone +1 907 564 4424 Date 11/23/15 rpForm 10-404 Revised 5/2015 /1 /Cb� III C1/20/4, RBDMS DEC 0 12015 /L/�y Submit Original Only • d Q,O O o o O M o m N O 0 0 N N f- Nr 0 0 p N 0 00 O C.) N O2 V N cs N CD 00 N O O m tf) CO N- 0) 0) O N If) 0) O - 0) N M N o 0) 00 CO O01Or- N- QD M O 0o OD O 00 CI i I i i i H 0) 0) O 0) CO 0 CO 0 O N of Y- 0 -4 - CO O O iJ N CO Nr N CO CID U) V. 0) 0) " CN0) C.) 4". Q 0CD 0) 00 0 0) O N CD CD (NIMot 3 U) o u) OCD °° ODS C) I• 0 co-J OD cn .N N it N '0 a) bo _ N M • CM 0) bo Oo r r N fM t N (V 4 M 4 s coo 0`)) 0 Q) r� T O �t0)) ( 0 00) W C �o U W W VCiu_ CLCCIYCLZ Z c LL1 W W W m U J Z_ L� Z J J F- • • a, N m CO Lc) co O) a) CO N- LU Cr) CD CO N t a) M a- NI.- a— CA CO • O N T- T r- T O d' CO CO a> N- 0) 03 OO u) r- M CD [F OD O• OO 00 CDCD CD00) 00) 00) CO OO 0OD 00 C0 0OD 00 a. O T- NTN '- CDCDM00o) 0) .0 O) O QD tt CO CO U) v CO v U) O ui o o) — o tri ai CN a W 00 T- T- OO I� tf) N CD CO T- W 0 CO 0) 000000) CO Co 00 > • CO00C) o) a) o) a) Oo000OO 0 w a ce w o Luz U w 55Y ° o U > CO O O Y Y 0 T- O T- 0) CO to 0) N 0) J U U Lill_ w « `nrs0) 00N. NN- r. 0) J J J ¢ Q m w re 4-1 N JO Z OD a) O O O O N N N U U U W o a a W a oz w w w a a 000 I- I- < J < 03C 2220cocoUUU — I �+ M a. Q J g C M co,L_, a- N O O N 'f) O CO Y.1 p � ' M M Lf) N Lf) CO CO N- O d O O '— CO CO CO 1- I. a- M CO G 0) 00000a- r- N N (NI 03 J L a) O - JH O d J o_ — = It 2 2 2 0 co co co co co d a 0 U c .2 00000000000 aUn �n <nCnV) CnfnC/ fnfnU) 0 t m a o cn cn UD Ul cn U, UD o 0 C O O O O O O O 0 0 0 0 w Z O N N N N N N CV N N N N Z U Q w COs. CO M N U, N N N N N (-1 W O J O W LL. LU 0. N- N N- N- N- N- N- N- N- N- N- a. < O J f- -J J J Ce l O m O D w J -1 Q 0 w w < < cn aacnare a> E aS M C') C') M M M M M M M M 0 0 0 0 0 0 0 0 0 0 0 i i i i i I i i Cr) CO CO CO Cr) M M M CO CO M m a a a U J O NU' w a JJJJJJJJJJJ < < m m a u m co a Q • • Packers and SSV's Attachment LISB L3-03 SW Name Type MD TVD Depscription L3-03 PACKER 9090.77 8188.52 7" Baker HRD-E ZXPN LTP L3-03 TBG PACKER 9532.41 8563.8 4-1/2" HES TNT Perm Packer L3-03 PACKER 9648.98 8663.15 7" Baker HRD-E ZXP LTP L3-03 PACKER 9905.49 8879.34 4-1/2" HES Water Swell Packer L3-03 PACKER 10071.06 8992.77 4-1/2" HES Water Swell Packer L3-03 PACKER 10289.74 9081.43 4-1/2" HES Water Swell Packer L3-03 PACKER 10590.69 9084.43 4-1/2" HES Water Swell Packer L3-03 PACKER 10808.92 9057.17 4-1/2" HES Water Swell Packer L3-03 PACKER 11078.33 9017.51 4-1/2" HES Water Swell Packer L3-03 PACKER 11710.54 8931.82 4-1/2" HES Water Swell Packer L3-03 PACKER 12124.82 8866.75 4-1/2" HES Water Swell Packer L3-03 PACKER 12319.4 8844.12 4-1/2" HES Water Swell Packer L3-03 PACKER 12572.42 8816.89 4-1/2" HES Water Swell Packer L3-03 PACKER 12798.86 8788.84 3-1/2" HES Swell Packer • • Schlumberger FracCAT Treatment Report Well :L3-03 Field :Lisburne Formation :Wahoo 5,6&7 Well Location : County :Prudhoe Bay State :Alaska Country :United States Prepared for Client :BP Exploration Alaska Client Rep : David Wages Date Prepared :July 12,2015 Prepared by Name :Michael Hyatt Division :Schlumberger Phone :7705976685 Pressure(All Zones) Initial Wellhead Pressure(psi) 395 Initial BHP at Gauge(psi) 4,563 Final Surface ISIP(psi) 7,665,Screenout Final ISIP at Gauge(psi) 10,065,Screenout Surface Shut in Pressure(psi) 6,364 BH Shut in Pressure(psi) 10,065 Maximum Treating Pressure(psi) 7,665 Treatment Totals(All Zones As Per FracCAT) Total Slurry Pumped 3,737 Total YF135FIexD Past Wellhead(bbls) 1,479 (Water+Adds+Proppant)(bbls) Total WF128 Past Wellhead(bbls) 1,709 Total Freeze Protect Past Wellhead 0 (bbls) Total Proppant Pumped(lbs.) 69,990 Total Proppant in Formation(lbs.) 59,570 Total 28%SXE Pumped(bbls) 304 Total 20%VDA Pumped(bbls) 192 Total S100 Sand Pumped(lbs) 2,000 Total Chemical Additives Invoiced Past WH Invoiced Past WH F103(gal) 134 133.5 M275(lbs.) 30 30 L065(gal) 134 133.5 J569(lbs.) 880 880 L071 (gal) 263 262 J134(lbs.) 0 0 J604(gal) 124 124 M002(lbs.) 44 44 J580(lbs.) 5,063 4,783 J511 (lbs.) 152 152 Disclaimer Notice This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment.The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services, Freedom from infringement of patents of Schlumberger or others is not to be inferred. • • Schlumberger Client.BP Exploration Alaska Well.L3-03,Stages 1-6 Formation: Wahoo 5,6&7 District Prudhoe Bay DataFRAC: As Measured Pum . Schedule As Measured Pump Schedule StepStepSlurry Slurry Pump Fluid Max Prop Prop # Name Volume Rate Time Fluid Name Volume Proppant Name Conp Conc Mass (bbl) (bbl/min) (min) (gal) (PPA) (PPA) (lb) 1 Injection 34.7 31.5 2.4 WF128 1822 0.0 0.0 15 Calibratio 2 100.0 40.2 2.5 YF135FIexD 4061 0.0 0.0 34 3 Displace 193.0 40.0 5.2 WF128 8208 ment 0.0 0.0 68 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Injection 31.5 40.3 3757 4803 29 2 Calibration 40.2 40.3 3427 4393 3036 3 Displacement 40.0 40.3 2991 3118 71 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 327.7 10.0 14090 0 Average Treating Pressure: 3198 psi Maximum Treating Pressure: 4803 psi Minimum Treating Pressure: 29 psi Average Injection Rate: 39.3 bbl/min Maximum Injection Rate: 40.3 bbl/min Average Horsepower: 3130.9 hhp Maximum Horsepower: 4697.2 hhp Maximum Prop Concentration: 0.0 PPA • • Schiumberger Client.BP Expnaska Well L3 03,Stages 1-6 i Formation: Wahoo 5,6&7 District:Prudhoe Bay Stase 1 : As Measured Pum . Schedule As Measured Pump Schedule Ste StepSlurry Slurry Pump Fluid Max Prop P Prop # Name Volume Rate Time Fluid Name Volume Proppant Name Cone Conc Mass (bbl) (bbl/min) (min) (gal) (PPA) (PPA) (Ib) 1 PAD 41.0 27,7 2,0 WF128 1920 WF128 0.0 0.0 16 2 28%SXE 38.0 6.5 6.1 28%SXE 1596 28%SXE 0.0 a 0 0 3 20%VDA 24.0 6.8 3.6 20%VDA 1008 20%VDA 0.0 0.0 0 4 28%SXE 38.0 6.9 5.6 28%SXE 1596 28%SXE 0.0 0.0 0 5 20%VDA 24.0 6.9 3.5 20%VDA 1008 20%VDA 0.0 0.0 0 6 Displace 65.0 33.2 2.4 WF128 2344 WF128 0.0 0.0 20 2.332" 7 15,0 21.1 1,3 WF128 727 WF128 0.0 0.0 6 Ball 8 Displace 171.0 24.0 14.1 WF128 7180 WF128 0.0 0.0 60 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 PAD 27.7 39.5 2305 2961 295 2 28%SXE 6.5 7.1 879 923 715 3 20%VDA 6.8 7.1 828 871 704 4 ,28%SXE 6.9 7.0 782 808 604 5 20%VDA 6.9 7.0 742 762 621 6 Displace 33.2 40.1 4448 5593 540 7 2.332"Ball 21.1 39.9 2664 5593 698 8 Displace 24.0 36.8 2278 4083 207 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (lb) 416.0 38.6 12261 0 Average Treating Pressure: 2189 psi Maximum Treating Pressure: 5593 psi Minimum Treating Pressure: 207 psi Average Injection Rate: 20.5 bbl/min Maximum Injection Rate: 40.1 bbl/min Average Horsepower: 1630.2 hhp Maximum Horsepower: 5473.0 hhp Maximum Prop Concentration: 0,0 PPA II • Schiomberger Client:BP Exploration Alaska Well:L3-03,Stages 1-6 Formation: Wahoo 5,6&7 District:Prudhoe Bay Stale 2: As Measured Pum . Schedule As Measured Pump Schedule Slurry Slurry Pump Fluid Max Prop Prop S#p Name Volume Rate Time Fluid Name Volume Proppant Name Prop Conc Mass (bbl) (bbl/min) (min) (gal) Conc (PPA) (Ib) (PPA) 1 PAD 100.0 37.4 2.7 WF128 4203 0.0 0.0 35 2 28%SXE 38.0 8.3 5.6 28%SXE 1596 0.0 0.0 2 3 20%VDA 24.0 6.4 3.8 20%VDA 1008 0.0 0.0 -0 4 28%SXE 38.0 6.0 4.1 28%SXE 1596 0.0 0.0 0 5 20%VDA 24.0 6.4 4.1 20%VDA 1008 0.0 0.0 0 6 Displace 65.0 34.9 2.1 WF128 2579 0.0 0.0 22 2.332" 7 15.0 9.4 2.0 WF128 681 Ball 0.0 0.0 6 8 Displace 171.0 8.7 27.7 WF128 7160 0.0 0.0 60 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 PAD 37.4 39.8 2304 2540 1133 2 28%SXE 8.3 19.8 745 1392 475 3 20%VDA 6.4 6.5 560 607 429 4 28%SXE 6.0 6.5 489 541 315 5 20%VDA 6.4 6.5 474 1523 263 6 Displace 34.9 40.1 4309 5202 422 7 2.332"Ball 9.4 23.9 954 2001 584 8 Displace 8.7 38.4 713 2599 71 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 461.9 52.1 14854 0 Average Treating Pressure: 1538 psi Maximum Treating Pressure: 5202 psi Minimum Treating Pressure: 71 psi Average Injection Rate: 18.2 bbl/min Maximum Injection Rate: 40.1 bbl/min Average Horsepower: 1141.8 hhp Maximum Horsepower: 5106.2 hhp Maximum Prop Concentration: 0.0 PPA . . SchiumbergerWell:L3-03,Stages 1-6 Formation, Wahoo 5,6&7 District:Prudhoe Bay Stage 3: As Measured Pum . Schedule As Measured Pump Schedule Ste Ste Slurry Slurry Pump Fluid Max Prop Prop p Name Volume Rate Time Fluid Name Volume Proppant Name Prop Conc Mass (bbl) (bbl/min) (min) (gal) Conc (PPA) (Ib) (PPA) 1 PAD 100.0 38.4 2.7 WF128 4245 0.0 0.0 35 2 28%SXE 38.0 6.9 6.2 28%SXE 1596 0.0 0.0 1 3 20%VDA 24.0 6.4 3.8 20%VDA 1008 0.0 0.0 0 4 28%SXE 38.0 6.3 6.2 28%SXE 1596 0.0 0.0 0 5 20%VDA24.0 6.5 3.7 20%VDA 1008 0.0 0.0 0 6 Displace 62.0 36.4 2.1 WF128 2210 0.0 0.0 18 2.412" 7 15.0 14.6 1,6 WF128 684 Ball 0.0 0.0 6 8 Displace 167.0 10,1 25.6 WF128 7036 0.0 0.0 59 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 PAD 38.4 40.2 2426 2573 1134 2 28%SXE 6.9 19,8 634 1334 338 3 20%VDA 6.4 6.5 556 619 303 4 28%SXE 6.3 6.5 521 552 312 5 20%VDA 6.5 6.5 497 513 479 6 Displace 36.4 42.2 4892 5923 251 7 2.412"Ball 14,6 36.7 1518 4795 552 8 Displace 10.1 39.2 672 2474 245 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 468.0 51.9 14271 0 Average Treating Pressure: 1594 psi Maximum Treating Pressure: 5923 psi Minimum Treating Pressure: 245 psi Average Injection Rate: 18,8 bbl/min Maximum Injection Rate: 42.2 bbl/min Average Horsepower: 1274.1 hhp Maximum Horsepower: 6119,2 hhp Maximum Prop Concentration: 0.0 PPA • . Schiomberger Client.BP Exploration Alaska Well:L3-03,Stages 1-6 Formation: Wahoo 5,6&7 District:Prudhoe Bay Stase 4: As Measured Pum • Schedule As Measured Pump Schedule Slurry Slurry Pump Fluid Max Prop Prop Step Name Volume Rate Time Fluid Name Volume Proppant Name Prop Conc Mass (bbl) (bbl/min) (min) (gal) Conc (PPA) (PPA) (Ib) 1 PAD 100.0 38.4 2.7 WF128 4263 0.0 0.0 36 2 28%SXE 38.0 6.8 6.0 28%SXE 1596 0.0 0.0 1 3 20%VDA 24.0 6.4 3.8 20%VDA 1008 0.0 0,0 0 4 28%SXE 38.0 5.3 12.8 28%SXE 1596 0.0 0.0 C 5 20%VDA 24.0 5.7 4.7 20%VDA 1008 0.0 0.0 C 6 Displace 58.0 31.6 2.2 WF128 2242 0.0 0.0 19 2.497 7 175.9 12.8 25.0 WF128 7621 Ball 0.0 0.0 64 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 PAD 38.4 39.3 2284 2432 1015 2 28%SXE 6.8 18.2 612 1290 501 3 20%VDA 6.4 6.5 554 /576 429 4 28%SXE 5.3 6.5 441 544 134 5 20%VDA 5.7 6.4 397 455 134 6 Displace 31.6 39.6 4258 5814 203 7 2.497'Ball 12.8 35.1 1154 4731 59 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 475.4 57.2 14239 0 Average Treating Pressure: 1560 psi Maximum Treating Pressure: 5814 psi Minimum Treating Pressure: 59 psi Average Injection Rate: 18.4 bbl/min Maximum Injection Rate: 39.6 bbl/min Average Horsepower: 1222.3 hhp Maximum Horsepower: 5642.8 hhp Maximum Prop Concentration: 0.0 PPA ID • Schiumberger Client:BP Exploration Alaska Well:L3-03,Stages 1-6 Formation, Wahoo 5,6&7 District:Prudhoe Bay Stage 5: As Measured Pum . Schedule As Measured Pump Schedule Ste StepSlurry Slurry Pump Fluid Max Prop Prop #p Name Volume Rate Time Fluid Name Volume Proppant Name Cone Conc Mass (bbl) (bbl/min) (min) (gal) (PPA) (Pb) (PPA) 1 PAD 71.0 35.2 2.2 YF135FIexD 2931 0.1 0.0 1 2 PAD 125.0 40.0 3.1 YF135FIexD 5292 0.1 0.0 1 3 PAD 26.1 40.0 0.7 YF135FIexD 1065 100 Mesh Sand 1.2 0.2 686 4 PAD 125.0 40.0 3.1 YF135FIexD 5193 1.3 0.0 357 5 1,0 PPA 50.1 40.0 1.3 YF135FIexD 1984 CarboLite 20/40 1.1 0.5 1690 6 2.0 PPA 50.0 40.0 1.3 YF135FIexD 1922 CarboLite 20/40 2.0 0.8 3500 7 3.0 PPA 49.8 40,0 1.2 YF135FIexD 1821 CarboLite 20/40 3.1 2.2 5124 8 4.0 PPA 250.0 40.0 6.3 YF135FIexD 9023 CarboLite 20/40 4.0 2.0 2754' 9 2.667 Ball 15.0 40.0 0.4 YF135FIexD 605 0.1 0.0 1 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step I Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 PAD 35.2 40.1 2565 2863 776 2 PAD 40.0 40.1 2738 2798 2703 3 PAD 40.0 40.1 2713 2728 2700 4 PAD 40.0 40.1 2810 2862 2712 5 1.0 PPA 40.0 40.1 2871 2896 2860 6 2.0 PPA 40.0 40.0 2900 2915 2886 7 3.0 PPA 40.0 40.1 2842 2893 2763 8 4.0 PPA 40.0 40.1 2711 3048 2601 9 2.667 Ball 40.0 40.1 3135 3221 3055 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Pb) 762.0 19.5 29835 38906 Average Treating Pressure: 2758 psi Maximum Treating Pressure: 3221 psi Minimum Treating Pressure: 776 psi Average Injection Rate: 39.5 bbl/min Maximum Injection Rate: 40,1 bbl/min Average Horsepower: 2682.2 hhp Maximum Horsepower: 3146.3 hhp Maximum Prop Concentration: 4.0 PPA • • Schiomberger Client:BP Exploration Alaska Well:L3-03,Stages 1-6 Formation, Wahoo 5,6&7 District:Prudhoe Bay Stage 6: As Measured Pum • Schedule As Measured Pump Schedule StepStepSlurry Slurry Pump Fluid Max Prop Prop # Name Volume Rate Time Fluid Name Volume Proppant Name Prop Conc Mass (bbl) (bbl/min) (min) (gal) Conc (PPA) (PPA) (Ib) 1 PAD 160.9 37.4 4.9 YF135FIexD 6638 0.0 0.0 0 2 PAD 125.0 38.2 3.3 YF135FIexD 5128 0.0 0.0 0 3 PAD 26.1 39.9 0.7 YF135FIexD 1048 100 Mesh Sand 1.0 0.4 953 4 PAD 125.0 39.9 3.1 YF135FIexD 5123 1.0 0.0 0 5 1.0 PPA 50.1 39.9 1,3 YF135FIexD 1984 CarboLite 20/40 1.0 0.2 1661 6 2.0 PPA 50.0 39.9 1.3 YF135FIexD 1947 CarboLite 20/40 2.1 0.1 3592 7 3.0 PPA 49.8 39.9 1.2 YF135FIexD 1854 CarboLite 20/40 3.0 0.5 5195 8 4.0 PPA 150.4 39.9 3.8 YF135FIexD 5548 CarboLite 20/40 4.0 0.0 19680 9 flush 88.7 38.9 3.1 WF128 6668 CarboLite 20/40 0.0 0.0 3 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 PAD 37.4 40.1 3523 3990 2212 2 PAD 38.2 40.0 3111 3206 2738 3 PAD 39.9 40.0 3194 3215 3157 4 PAD 39.9 40.0 3254 3312 3157 5 1.0 PPA 39.9 40.0 3325 3347 3312 6 2.0 PPA 39.9 39.9 3321 3357 3272 7 3.0 PPA 39.9 39.9 3206 3272 3124 8 4.0 PPA 39.9 40.0 3055 3208 2989 9 flush 38.9 40.0 3861 6985 1 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 826.0 22.6 35939 31084 Average Treating Pressure: 3320 psi Maximum Treating Pressure: 6985 psi Minimum Treating Pressure: 1 psi Average Injection Rate: 39.0 bbl/min Maximum Injection Rate: 40.1 bbl/min Average Horsepower: 3176.1 hhp Maximum Horsepower: 5122.1 hhp Maximum Prop Concentration: 4.0 PPA • • Schiomberger Client BP Expnaska Well:L3-03,Stages 1-6 Formation: Wahoo 5,6&7 District:Prudhoe Bay Section 8: Job Messages Message Log Message Treating Annulus # Time g Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 1 6:00:00 arrive location 06:00 0 C 0 0 0 2 6:15:00 pre rig up meeting 0 0 0 0 0 3 8:30:00 Crank pumps 0 0 0 0 0 4 10:15:15 Prime pumps test trips 0 0 0 0 0 5 10:47:33 Low PT BP 310 -49 0 0 0 6 10:55:10 Remark 304 -49 0 0 0 7 11:11:03 BP check valve test 3802 -48 0 0 0 8 - 11:16:18 global test trip at 7,000 good 7378 -49 0 0 0 9 11:27:11 high BP PT good 26 lbs 5 min 8200 -49 0 0 0 10 12:16:16 OPEN WELLHEAD 370 63 0 0 0 11 12:19:42 Start Propped Frac Automatically 631 1977 0 0.4 0 12 12:19:42 Start DataFRAC Automatically 631 1977 0 0.4 0 13 12:19:42 Started Pumping 631 1977 0 0.4 0 14 12:20:34 SLEEVE SHIFT 194 2363 2.8 4.9 0 15 12:31:14 cleaning cold gel out of PCM to open tank on 328 2492 7.9 6.9 0 surface 16 13:00:25 Started Pumping 4830 2921 7.9 40.2 0 17 13:05:09 Stage at Perfs: Injection 3111 3027 198.2 40.3 0 18 13:06:15 Stage at Perfs:Calibration 3021 3017 242.5 40.5 0 19 13:24:39 wait on BP shower trailer to be replaced 125 2903 327.3 0 0 20 13:34:53 shower trailer spotted and tested 73 2928 327.3 0 0 21 13:37:12 Deactivated Extend Stage 78 2919 327.4 1.6 0 22 13:37:20 Start Treatment Automatically 651 2944 0 4 0 23 13:37:20 Start Stage 1 Automatically 651 2944 0 4 0 24 13:37:57 Stage at Perfs:Displacement 2337 2983 8.9 25.3 0 25 14:01:00 Sleeve shift 1255 2926 239.2 12.4 0 26 14:04:42 Stage at Perfs:PAD 3094 3048 329.4 36.7 0 27 14:08:35 Stage at Perfs:28%SXE 483 3030 372.1 5.4 0 28 14:08:39 Stage at Perfs:28%SXE 480 3029 372.5 5.5 0 29 14:08:48 Stage at Perfs:20%VDA 475 3028 373.3 54 0 30 14:09:00 Stage at Perfs:Displace 469 3025 374.4 5.5 0 31 14:14:58 sleeve shifted 3200 psi 2002 3018 406.9 5.4 0 32 14:15:54 Start Propped Frac Automatically 1404 2928 0 24 0 33 14:15:54 Start Stage 2 Automatically 1404 2928 0 24 0 34 14:16:24 Stage at Perfs:2.332"Ball 2065 2975 14.9 35 0 35 14:16:50 Stage at Perfs:Displace 2430 2952 31.8 39.8 0 36 14:35:43 Activated Extend Stage 469 2969 207.6 6.5 0 37 14:36:18 Deactivated Extend Stage 667 3034 210.7 5.5 0 38 14:38:39 Remark 1174 2948 279.3 12.4 0 39 14:40:36 first two acid tubes are empty 576 3023 292.1 5.5 0 40 14:43:56 Stage at Perfs:PAD 542 2944 310.2 5.4 0 41 15:01:37 Stage at Perfs:28%SXE 385 2934 406.5 5.5 0 42 15:02:31 Stage at Perfs:20%VDA 372 3033 411.4 5.4 0 43 15:02:32 Stage at Perfs:Displace 374 3036 411.5 5.4 0 44 15:03:21 sleeve shift 3151 top pressure 1159 total slurry 2189 3105 415.9 5.4 0 45 15:14:05 Start Propped Frac Automatically 2482 3013 0 38.7 0 46 15:14:05 Start Stage 3 Automatically 2482 3013 0 38.7 0 47 15:14:24 Stage at Perfs:2.332"Ball 2569 2989 12.6 40.2 0 • • Schiumberger CientWell:L3-03,Stages 1-6 Formation, Wahoo 5,6&7 District Prudhoe Ba Message Log Message Treating Annulus # Time g Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 48 15:14:48 Stage at Perfs:Displace 2567 2989 28.7 40.1 0 49 15:39:23 ball away 1055 2906 293.8 12.1 0 50 15:45:16 Stage at Perfs:PAD 351 3018 327.5 5.4 0 51 16:02:51 Remark 1470 2994 423.3 5.5 0 52 16:02:53 Stage at Perfs:28%SXE 1805 3025 423.5 5.4 0 53 16:03:10 Stage at Perfs:28%SXE 574 2856 425 5.5 0 54 16:03:12 Stage at Perfs:20%VDA 636 3015 425.2 5.4 0 55 16:03:13 Stage at Perfs:Displace 681 2991 425.3 5.5 0 56 16:04:21 2987 top psi 643 2980 431.5 5.5 0 57 16:05:58 Start Propped Frac Automatically 2423 3017 0 39.1 0 58 16:05:58 Start Stage 4 Automatically 2423 3017 0 39.1 0 59 16:06:15 Stage at Perfs:2.412"Ball 2406 2998 11.1 39.2 0 60 16:06:40 Stage at Perfs:Displace 2375 2983 27.4 39.2 0 61 16:30:53 first acid tubes left location 143 3044 215.6 1.9 0 62 16:39:20 Stage at Perfs:PAD 3222 2953 338.4 34.8 0 63 16:39:49 2019 ball away 964 2899 345.7 12.1 0 64 16:55:20 Stage at Perfs:28%SXE 73 2983 432.7 5.5 0 65 16:55:37 Stage at Perfs:20%VDA 72 2985 434.2 5.4 0 66 16:55:39 Stage at Perfs:28%SXE 72 2984 434.4 5.4 0 67 16:55:44 Stage at Perfs:20%VDA 71 2983 434.8 5.5 0 68 16:55:46 Stage at Perfs:Displace 72 2984 435 5.5 0 69 17:02:26 Ball Seat 435 3076 471.3 5.4 0 70 17:33:20 Deactivated Extend Stage 979 2992 474.9 8.4 0 71 17:33:20 Start Propped Frac Manually 979 2992 474.9 8.4 0 72 17:33:20 Start Stage 5 Automatically 979 2992 474.9 8.4 0 73 17:33:32 Activated Extend Stage 1176 3000 2.1 10.5 0 74 17:33:59 Stage at Perfs:2.497"Ball 2216 3023 11.7 29.6 0 75 17:35:32 Deactivated Extend Stage 2756 3025 71 40 0 76 17:38:33 good gel sample 2698 3016 191.6 40 0 77 17:38:34 Stage at Perfs:PAD 2734 3015 192,2 39.9 0 78 17:38:40 Started Pumping Prop 2710 3015 196.2 40.1 0 79 17:39:38 Stopped Pumping Prop 2769 3019 234.9 39.9 0 80 17:40:06 Stage at Perfs:PAD 2773 3016 253.6 40 0 81 17:42:21 Started Pumping Prop 2855 3012 343.5 40.2 0 82 17:43:18 Stage at Perfs:PAD 2870 3005 381.6 40 1 83 17:43:58 Stage at Perfs:PAD 2908 3013 408.2 39.9 1.9 84 17:47:08 Stage at Perfs:PAD 2671 2985 534.8 40.1 4 85 17:48:23 Stage at Perfs:1,0 PPA 2626 3029 584.8 40.1 4 86 17:49:39 Stage at Perfs:2.0 PPA 2645 3017 635.5 39.9 4 87 17:50:53 Stage at Perfs:3.0 PPA 2805 3006 684.8 39.9 4 88 17:51:10 Stopped Pumping Prop 2835 3004 696.1 40.1 4 89 17:51:31 Started Pumping Prop 2865 3006 710.1 39.9 0 90 17:51:35 Stopped Pumping Prop 2882 3004 712.8 40 0.1 91 17:52:41 Remark 3318 2996 756.7 40 0 92 17:52:49 Start Propped Frac Automatically 3173 2992 0 40.2 0 93 17:52:49 Start Stage 6 Automatically 3173 2992 0 40.2 0 94 17:55:25 Activated Extend Stage 3925 3005 103.9 40.1 0 95 17:56:39 Lower Pump Rate 2357 2963 146.7 12.3 0 96 17:57:40 Deactivated Extend Stage 2943 2971 160.8 24.3 0 97 17:58:05 Stage at Perfs:4.0 PPA 2908 2947 173.1 32.7 0 • • Schlumberger Client:BP Exploration Alaska Well:L3-03,Stages 1-6 Formation, Wahoo 5,6&7 District,Prudhoe Ba Message Log Message Treating Annulus # Time g Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 98 17:58:29 Stage at Perfs:2.667 Ball 3146 3012 187.4 39.8 0 99 18:00:57 Started Pumping Prop 3202 3017 285.8 39.9 0 100 18:02:22 Stage at Perfs:2.667 Ball 3209 2998 342.3 39.9 0 101 18:05:31 Stage at Perfs:PAD 3313 2951 467.9 39.8 1 102 18:06:10 Stage at Perfs:PAD 3352 3047 493.8 39.8 1.5 103 18:09:13 Stage at Perfs:PAD 3016 2982 615.5 39.9 4 104 18:10:25 Stage at Perfs:PAD 3004 2962 663.4 39.8 4 105 18:11:39 Stage at Perfs:1.0 PPA 3122 3061 712.6 40 4 106 18:12:19 Stopped Pumping Prop 3221 3045 739.2 40.1 0 107 18:12:54 Stage at Perfs:2.0 PPA 3425 3045 762.4 40.1 0 108 18:16:45 Remark 5083 2891 824.6 1.6 0 109 18:17:01 screen out 4980 2885 824.6 0 0 110 18:17:15 Started Pumping 4902 2880 824.6 0 0 111 18:17:27 screen out 4847 2907 824.6 0 0 112 18:21:54 wellhead closed 6394 3040 825.7 0 0 113 18:29:47 Started Pumping 83 1639 825.7 4.3 0 114 18:39:02 cleaning out surface equipment 88 -45 825.9 4.3 0 115 18:59:00 fanning pumps 79 -46 825.9 4 0 • 0 Schlumberger Client:BP Exploration Alaska Well,L3-03,Stages 1-6 Formation: Wahoo 5,6&7 District Prudhoe Bay Section 9: Acid Additive Components 28% SXE System: 12,768 gal Material Code Conc. Unit Quantity Unit 28% HCI H028 700 gal/1,000gal 8,938 gal Water 149 gal/1,000gal 1,902 gal Acid (36% HCI) H036 526 gal/1,000gal 6,716 gal Iron Control L058 10 lbs/1,000gaI 128 lbs Corrosion Inhibitor A262 5 gal/1,000gal 64 gal Inhibitor Aid A201 20 gal/1,000gaI 255 gal LVT-200 J510 295 gal/1,000gal 3,767 gal Emulsifier U108 5 gal/1,000gal 64 gal 20% VDA System: 8,064 gal Material Code Conc. Unit Quantity Unit 20% HCI H020 1000 gal/1,000gaI 8,064 gal Water 366 gal/1,000gal 2,951 gal Acid (36% HCI) H036 518 gal/1,000gal 4,177 gal Iron Control L058 10 lbs/1,000gal 81 lbs Corrosion Inhibitor A270 6 gal/1,000gal 48 gal Inhibitor Aid A201 20 gal/1,000gal 161 gal Methanol 10 gal/1,000gal 81 gal Non-emulsifier W054 5 gal/1,000gal 40 gal VDA Additive J557 75 gal/1,000gal 605 gal • • Schlumberger Client:BP Exploration Alaska Well:L3-03,Stages 1-6 Formation: Wahoo 5,6&7 District:Prudhoe Bay Section 10: Planned Pump Schedule ATTACHMENT 1:PUMP SCHEDULE Pressure Test 8000 Max WHT Pressure 7000 Slurry Rate 40 Proppant Density Well Name L3-03 AFE Pump Trips 6650 Ann Pressure 3000 Fluid Type VF126FIexD Proppant Used STEP STAGE AVERAGE COMMENTS FLUID PUMP CF DIRTY VOLUME DIRTY VOLUME PROPPANT CLEAN VOLUME a a PPA TYPE RATE RATE STAGE CUM STAGE CUM STAGE CUM 512E GROSS CUM (BPM) (BPM) (BBL) (BBL) (GAL) (GAL) (LOS) (LBS) (BBL) (BBL) 1 Injection test WF128 10 10.0 30 30 1260 1260 30 30 HARD SHUTDOWN,MONITOR PRESSURE TILL CLOSURE. 0.0 ---- 2 Calibration Tea YF128FloxD 40 40.0 100 130 4200 5460 100 130 3 Flush WF128 40 40.0 193 323 8106 13566 193 323 HARD SHUTDOWN,MONITOR PRESSURE TILL CLOSURE FLUID PUMP CF DIRTY VOLUME DIRTY VOLUME PROPPANT CLEAN VOLUME STEP STAGE AVERAGE COMMENTS TYPE RATE RATE STAGE CUM TOT JOB STAGE CUM STAGE CUM 512E GROSS CUM a N PPA (BPM) (BPM) (BBL) (BBL) (BBL) (GAL) (GAL) (LBS) (LBS) (BBL) (BBL) 4 1 PAD WF128 40 40.0 24 347 1008 14574 0 24 347 51 ACID 28%SXE 6 5.0 38 385 1596 16170 38 385 61 ACID 20%VDA 6 5.0 24 409 1008 17178 24 409 71 ACID 28%SXE 5 5.0 38 447 1596 18774 38 447 6 1 ACID 20%VDA 5 -5.0 24 471 1008 19782 24 471 9 1 DISPLACE WF128 40 40.0 69 540 2886 22668 _69 540 10 1 1 Ba8,2252" DISPLACE 548120 8 5.0 16 655 630 23298 15 555 11 2 PAD WF128 40 40.0 174 729 7316 30614 174 729 12 2 PAD WF128 40 40.0 100 829 4200 34814 100 829 132 ACID 28%SXE 5 5.0 38 867 1596 36410 38 867 14 2 ACID 20%VDA 5 5.0 24 891 1008 37418 24 891 15 2 ACID 28%SXE 5 5.0 38 929 1596 39014 38 929 18 2 ACID 20%VDA 5 5.0 24 953 1008 40022 24 953 17 2 DISPLACE WF128 40 40.0 65 1018 2738 42760 65 1018 16 2 28511,2.332" DISPLACE WF128 5 5.0 15 1033 630 43390 15 1033 19 3 PAD WF128 40 40.0 171 1204 7172 50562 171 1204 m SD to reload Balls 21 3 PAD WF128 40 400 100 1304 4200 54762 100 1304 22 3 ACID 28%SXE 5 5.0 38 1342 1596 56358 38 1342 23 3 ACID 20%VDA 5 5.0 24 1366 1008 57366 24 1366 24 3 ACID 28%SXE 5 5.0 38 1404 1596 58962 38 1404 25 3 ACID 20%VDA 5 5.0 24 1428 1008 59970 24 1428 26 3 DISPLACE WF128 40 40.0 62 1480 2594 62564 62 1490 27 3 3 8511,2.412" DISPLACE WF128 5 5.0 16 1505 630 6319415 1505 28 4 PAD WF128 40 40.0 167 1672 7021 70214 167 1672 29 4 PAD WF128 40 40.0 100 1772 4200 74414 100 1772 30 4 ACID 28%SXE 5 5.0 38 1810 1596 76010 38 1810 31 4 ACID 20%VDA 5 5.0 24 1834 1008 77018 24 1834 32 4 ADO 28%SXE 5 5.0 38 1872 1596 78614 38 1872 33 4 ACID 20%VDA 5 5.0 24 1896 1008 79622 24 1896 34 4 DISPLACE WF128 5 5.0 68 1954 2443 82065 58 1954 35 5 4B511,2.497" DISPLACE 1NF128 40 40.0 173 2127 7287 89352 173 2127 36 8D to reload Balls 35 6 PAD YF128FIexD 40 40.0 125 2252 5250 946020 0 125 2021 36 6 .5 FLAT YF128FIexD 40 39.1 26 2277 1050 95652 514 514 100 Mesh 24 1978 37 6 PAD YF128FIeeD 40 40.0 126 2402 5250 100902 0 0 125 2252 38 6 1 FLAT YF128FIexD 40 38.3 60 2452 2100 103002 2011 2011 20/40 C{roe 48 2300 39 6 2 FLAT YF128FlexD 40 36.7 50 2502 2100 105102 3859 5870 20/40 C-Life 46 2346 40 5 3 FLAT YF128FIexD 40 35.3 50 2662 2100 107202 5562 11431 20/40 C-Lite 44 2390 41 6 4 FLAT YF728FloxD 40 34.0 250 2802 , 10500 117702 35685 47116 20/40 C-Lite 212 2603 43 6 68511,2.587" DISPLACE YF728FIexD 40 40.0 15 2817 630 118332 0 47116 15 2618 44 6 PAD YF128F(nsD 40 40.0 125 2942 5250 123582 0 47116 125 2743 45 6 .5 FLAT YF128FIexD 40 39.1 25 2967 1050 124632 514 47630 100 Mesh 25 2768 486 PAD YF128FIeeD 40 40.0 125 3092 5250 129882 0 47630 125 2893 47 6 1 FLAT YF128FlexD 40 38.3 50 3142 2100 131982 2011 49641 20/40 C-Lite 48 2941 48 6 2 FLAT YF128FIexD 40 36.7 50 3192 2100 134082 3859 53499 20/40 C-Lite 46 2987 49 6 3 FLAT YF128FIexD 40 35.3 50 3242 2100 136182 5562 59061• 20/40 C-Life 44 3031 50 0 4 FLAT YF128FIexD 40 34.0 250 3492 10500 146682 35685 94745 20/40 C-Life 212 3243 52 6 6 Ball,2.677" DISPLACE WF128 40 40.0 167 3669 7015 153697 0 94745 167 3410 63 7 FLUSH LVT200 40 40.0 33 3692 1386 155083 0 94745 33 3443 SD and obtain ISIP 616 min SIP. ------ WATHOWK FLUSH INFORMATION WELL AND TREATING PRESSURE INFORMATION 16ODEL AND FRAC ORIENTATION INFORMATIOI DaIaFRAC= 293 bbls VOL TO TOP OF LINER=1140.0 GIP GRADIENT= 0.70 BHP=6265 psi NO Pert H,4.= MAIN JOB= 5464 bbls Extm 400 bbls -UNDFRFLUSH>-40.0 FLUID SG= 1.000 ♦TBG ERIC=2303 psi Plain Strain,E'= TOTAL JOB= 5757 bbls FLUSH VOL a 180 FRCT1ON LOSS))L)= 025 a PERF FRIC=0500 psi Youngs Mod.,Es 0.00 6157 blots -vrth contingency MD TO Ng Tail= 9656 -HYD HEAD=3881 psi Angle Trough Peds= GENERAL JOB INFO ND TOP PERF= 8950 EST.MAX WHP=5186 psi Well Azimuth(9North)= TANKS REQUIRED PIPE TIME(min)=3.5 MD TOP PERF= 9211 Fracture Azimuth(I/North). 15.4 <-400 bbl per tank pumpable(BP) PAO/SLURRY RATIO TUBING HANGER= Well Onentation-Preferred=0• TOTALS FOR 7 STAGES Stage 1 Stage 6 41% UPPER TUBING SIZE= 4.5000 0.0152 bbls./11 Porosity= Water 6157 bbls Stage 2 Stage MIDDLE TUBING SIZE= 4.500 00152 Ebls10 Resenuir Pressure=3795 YF gel 3310 bbls Stage 3 Stage 8 LOWER TUBING SIZE= bbls.,lt Permeability= WF gel 2760 bila Stage 4 Stage 9 LENGTH MIDDLE TBG= 0 Temperature=184 SXE 456 blots 19,152 gal Stage 5 41% Stage 10 LENGTH LOWER TBG= VDA 208 bbla 12,096 gal Stage Port MD 0ispiac4 Seat Size CASING SIZE= 4.5000 0.0152 bblsAt Mineral oil 66 bbls name ft volume in Proppant 375.919 lb Stage 1 12678 192.7 bbls PA Pump time 06.25:00 hh:mm:sa Stage 2 12447 169.2 bbls 2.332 Total fluid 6814 blots Stage 3 12221 185.8 bbls 2.412 Stage 4 11984 182.2 bins 2.497 Stage 5 11414 1735 bbls 2.587 Stage 6 10988 167.0 bbls 2677 Stage 7 10719 162.9 bbla 2.767 Stage 8 10460 159.0 bila 2.857 Stage 9 10242 155.7 bbls 2.947 Stage 10 10023 152.3 bila 3.037 Stage 11 9657 149.6 bola 3.137 NOTES: •Flush volume of DataFRAC stages is including the surface equipment volume(-7-10 bbls)and additional Fluid for overdisplacing x-linked fluid into perfs. • • Schlumberger Client BP Exploration Alaska Well:L3-03,Stages 1-6 Formation, Wahoo 5,6&7 District:Prudhoe Bay Section 11 : Job Plots L3-03 Stages 1-6 Pressure Test Treating Pressure BP Exploration Alaska Annulus Pressure L3-03 Stages 1-6 07-12-15 - BHP 10000 — Slurry Rate Prop Concentration • 50 — BH Prop Concentration 9000— — PCM Vlsc 45 8000 '' 40 4T 7000 35 6000 30 9 5000 25 j g 4000 20 /— g- 3000 15 2000 10 1000 it 5 0 ri • 0 10:30:22 10:51:12 11:12:02 11:32:52 11:53:42 Time-hh:mm:ss ©Schlumberger 1994-2012 Schlumberger L3-03 Stages 1-6 DataFRAC — Treating Pressure BP Exploration Alaska Annulus Pressure 07- Stages 1-6 07-11 22-15 - BHP 10000 — Slurry Rate Prop Concentration 50 — BH Prop Concentration 9000 — t•t..M vise 45 8000 40 7000 .....m1MILa monimm 35 lIMMI 6000 30 '� 5000 I -��I� 4000 I 25 j iI' 20 3000 '� 15=1111111111 MI Ia 2000 lialigINIONIi A 10 1000 Ii I IMINIME 5 01- IIIPMEIMIEF 0 12:02:48 12:27:48 12:52:48 13:17:48 13:42:48 Time-hh:mm:ss ©Schlumberger 1994-2012 Schlumberger • • Schlumberger Client:BP Exploration Alaska Well:L3-03,Stages 1-6 Formation: Wahoo 5,6&7 District.Prudhoe Bay L3-03 Stages 1 &2 treating Pressure BP Exploration Alaska L3-03 Stages 1-6 Annulus Pressure 07-12-15 — BHP 10000 — Slur Rate 50 — Prop Concentration 9000 — BH Prop Concentration — PCM Visc 45 8000 40 7000 in li MENU k.g - 35 6000 i ll �' 30 5000�' IMO 25 I MEMg4000-' — --r — 3000�. 1�>1111111 20 r 15 2000 1IUIIIII1_- 10 1000 .. . EWElf- ��Irimm�_ _. 0 0 13:29:41 13:58:51 14:28:01 14:57:11 15:26:21 Time-hh:mm:ss ©Schlumberger 1994-2012 Schlumberger L3-03 Stages 3&4 — Treating Pressure BP Exploration Alaska L3-03 Stages 1-6 Annulus Pressure 07-12-15 BHP 10000 — Slurry Rate 50 — Prop Concentration 9000 — BH Prop Concentration — PCM Visc 45 8000 rr40 -J ----'7000 ' r \V-- 35 - 6000 30 -- 1 • 5000 - 25 4000—f'� ( L 20 3000 -^4. r-� r r_.� r --�. ® • �,sr ► ., _ w 95 1 2000 1 10 1000 5 • 0 44-01 ill 0 14:58:26 15:40:06 16:21:46 17:03:26 17:45:06 Time-hh:mm:ss ©Schlumberger 1994-2012 Schlumberger • Schlumberger Client:BP Exploration Alaska Well:L3-03,Stages 1-6 Formation: Wahoo 5,6&7 District:Prudhoe Bay L3-03 Stages 5&6 — Treating Pressure BP Exploration Alaska L3-03 Stages 1-6 — Annulus Pressure 07-12-15 - BHP 10000 — Slurry Rate 50 — Prop Concentration 9000 — BH Prop Concentration Illi 45 8000 . • 40 7000' • III_ I 35 �- 6000 ([( lir rt30 A 5000 lyill 25 I 4000■� 20 3000 ���� 1 f, 15 2000 1 10 1000 5 0 Ara-1 _ n fl it 0 17:32:28 17:49:08 18:05:48 18:22:28 18:39:08 Time-hh:mm:ss ©Schlumberger 1994-2012 Schlumberger m L3-03 DataFRAC POD Additives BP Exploration Alaska C7 L3-03 Stages 1-6 E 07-12-2015 45 to co 01 10 — - J511L Conc O ^^- JBOI Conc 50 N. - U28 Conc '"G To — J888 Cone Cf Prop Con `-- Clean Fluitl Rate -g- 8 _ slurry Rat -40 .0::1 ED POD Road Gale'os 41 POD Deck Gab'os '13 6- 73 -30 3 a o • 4- et: 20 m co E CD m m m cn 2 -10 a Q 0 I 44#61r y -0 c a 12:02:48 12:23:38 12:44:28 13:05:18 13:26:08 33 a Time-hh:mm:ss J ©Schlumberger 1994-2012 SChlunthOP9Br • Schlumberger Client BP Exploration Alaska Well:L3 03,Stages 1 6 Formation: Wahoo 5,6&7 District:Prudhoe Bay L3-03 Stage 1-4 POD Additives BP Exploration Alaska L3-03 Stages 1-6 07-12-2015 J511L Conc -- J604 Conc 10 isiati ' .- J569 Cane SO 1 Prop Con an Finer:-. 1 — POD Road SlurryRabGa Po 8" ill , r POD Ga P Rona o. -40 6- -30 I 4, R f' 20 2- 1 – -10 . 0 _ 1 1 � ii = 13:14:54 14:13:14 15:11:34 16:09:54 17:08:14 Time-hh:mm:ss ©Schlumberger 1994-2012 Schlumberger L3-03 Stage 5-6 POD Additives BP Exploration Alaska L3-03 Stages 1-6 07-12-2015 10 — J511L Conc J604 Conc 50 — U28 Conc tt 18110kai 11 1144 4 J569 Cone Prop Con I Mr �p, Clean Fluid Rate ./ — Blurry Rate -40 .a POD Road Gab ray POD Deck Gate tot 6Pill M , -30 I 8. sir 4- .,w,. -20 A 11) 4 a 1 r 2 2 . SAI f M 10 II I' g I iliAll1 3. 17:31:53 17:44:23 17:56:53 18:09:23 18:21:53 Time-hh:mm:ss ©Schlumberger 1994-2012 Schlumberger i • Schlumberger Client:BP Exploration Alaska Well:L3-03,Stages 1-6 Formation: Wahoo 5,6&7 District:Prudhoe Bay L3-03 DataFRAC PCM Additive Plot BP Exploration Alaska L3-03 Stages 1-6 07-12-2015 N 5 • 50 0 N L065 Conc Ts 1 —1 .571 Conc 0 Prop Can 1411 4- 77— J5so coon R +i• Clean Fluid Rate-40 - I1 w I Slurry Race y I ' PCM Visc � 13- E 3- 30 3 R 01U1 00 2- 1 _, -20 n g I o a Qo Fr :93 1 10 a m J r N • 0 ...w.».. • O C 12:04:39 12:29:39 12:54:39 13:19:39,- 3:19:3r — 13:44:39 d Time-hh:mm:ss ©Schlumberger 1994-2012 Schlumberger L3-03 Stages 1-4 PCM Additive Plot BP Exploration Alaska L3-03 Stages 1-6 07-12-2015 N o 5 :111150 O N L085 Cono L071 Cons E Prop Con 4- 1...... 3seo ca -40 Clean Fluid Rate CD I Ir Slurry Rab pL PC• 1 s Lp 3 iT 30 m °' " rr 05 2- -20 n a a < o 1114111411111 co Q c 1 1414111011010 i I Li II11 IIIL 0— �� _ � n 0 it 13:29:11 14:27:31 15:25:51 16:24:11 17:22:31= m Time-hh:mm:ss ©Schlumberrier 1994-2012 Schlumberger i 0 Schlumberger Client BP Exploration Alaska Well:L3-03,Stages 1-6 Formation: Wahoo 5,6&7 District:Prudhoe Bay L3-03 Stages 5-6 PCM Additive Plot BP Exploration Alaska L3-03 Stapes 14 07-12-2016 to 5 • 50 y - L065 Conc - L071 Conc. Prop Con a 4 — ""c"c -40 -73 ,t, i It'' 0 riligil!qr. Slurry Rate X ep �" wJ"`„,. Sw A`:. . „, t.„,..* I PCM Vise al t 11 i `l" � _c 3- is -30 � m 2- : 1! a a Q1- .'r Ill is 0 6 17:28:11 17:44:51 18:01:31 18: 18:11 18:34:51to m Time-hh:mm:ss ©Schlumberger 1994-2012 Schiumb8rger • • Schlumberger FracCAT Treatment Report Well :L3-03,Stage 7 Field :Lisburne Formation :Wahoo 5 County Prudhoe Bay State :Alaska Country :United States Prepared for Client :BP Exploration Alaska Client Rep :David Wages Date Prepared :15 July 2015 Prepared by Name :Michael Hyatt Division :Schlumberger Phone :770-597-6685 Pressures Initial Wellhead Pressure(psi) 495 Initial BHP at Gauge(psi) 3315 Final Surface ISIP(psi) 7,870,Screenout Final ISIP at Gauge(psi) 9,805,Screenout Surface Shut in Pressure(psi) 2,450 BH Shut in Pressure(psi) 6,150 Maximum Treating Pressure(psi) 7,870 Treatment Totals Total Slurry Pumped 850 Total YF135FIexD Past Wellhead(bbls) 643 (Water+Adds+Proppant)(bbls) Total WF120 Past Wellhead(bbls) 168 Total Freeze Protect Past Wellhead 0 (bbls) Total 20%VDA Past Wellhead(bbls) 6 Total Proppant Pumped(lbs.) 32,114 Total Proppant in Formation(lbs.) 13,035 Total Chemical Additives Invoiced Past WH Invoiced Past WH F103(gal) 32 31 M275(lbs.) 18 15 L065(gal) 36 35 J569(lbs.) 330 310 L071 (gal) 65 64 J134(lbs.) 10 0 J604(gal) 60 59 M002(lbs.) 21 16 J580(lbs.) 1,243 1,086 J511 (lbs.) 145 42 Disclaimer Notice This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment.The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue,Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. • • Schlumberger Client BP Exploration Alaska Well.L3-03 Stage 7 Formation:Wahoo 5 District Prudhoe Bay Section 1 : Stage 7: As Measured Pump Schedule As Measured Pump Schedule Ste Ste Pro Slurry Slurry Pump Fluid Max Prop Prop #p Name Volume Rate Time Fluid Name Volume Proppant Name Conp Conc Mass (bbl) (bbl/min) (min) (gal) (PPA) (Ib) (PPA) Pum1 Ch mp 16.6 8.5 2.2 WF120 697 0.0 0.0 0 2 Ball Drop 3.4 10,1 0.3 WF120 142 0.0 0.0 0 3 Displace 148.2 5.2 28.8 WF120 6225 0.0 0.0 0 Ball 4 20%VDA 6.0 4.1 1.4 20%VDA 252 0.0 0.0 0 5 PAD 83.9 32.5 3.4 YF135FIexD 3524 0.0 0.0 0 6 PAD 250.0 40.3 6.2 YF135FIexD 10500 0.0 0.0 0 7 1.0 PPA 50.1 40.2 1.2 YF135FIexD 2029 CarboLite 20/40 1.0 0.6 1697 8 2.0 PPA 50.0 40.1 1.2 YF135FIexD 1946 CarboLite 20/40 2.0 1.5 3521 9 3.0 PPA 49.8 40.1 1.2 YF135FIexD 1861 CarboLite 20/40 3.0 0.8 5234 10 4.0 PPA 165.8 40.1 4.1 YF135FIexD 6019 CarboLite 20/40 4.0 0.0 21639 11 Displace 26.6 37.3 1.3 YF135FIexD 1114 CarboLite 20/40 0.0 0.0 24 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Pump Check 8.5 10.7 1530 1829 14 2 Ball Drop 10.1 10.1 1839 1859 1812 3 Displace Ball 5.2 10,1 1646 1958 1438 4 20%VDA 4.1 4,2 1859 1871 1840 5 PAD 32.5 40.3 3932 4386 1863 6 PAD 40.3 40.4 4211 4312 4095 7 1.0 PPA 40.2 40.3 4231 4240 4205 8 2.0 PPA 40.1 40.2 4172 4204 4122 9 3.0 PPA 40.1 40.1 4062 4121 3985 10 4.0 PPA 40.1 40.1 3972 4237 3896 11 Displace 37.3 40.3 4923 6349 46 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 850.3 51.6 34309 32114 Average Treating Pressure: 3628 psi Maximum Treating Pressure: 6349 psi Minimum Treating Pressure: 14 psi Average Injection Rate: 32.3 bbl/min Maximum Injection Rate: 40.4 bbl/min Average Horsepower: 3216,2 hhp Maximum Horsepower: 5292.4 hhp Maximum Prop Concentration: 4.0 PPA • • Schlumberger Client BP Exploration Alaska Well:L3-03 Stage 7 Formation:Wahoo 5 District:Prudhoe Bay Section 2: Stage 7: Job Messa s es Message Log Message Treating Annulus / Time g Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 1 11:06:44 Wellhead open 489 2021 0.0 0.0 0.0 2 11:06:50 Start Propped Frac Automatically 488 2020 0.0 0.0 0.0 3 11:06:50 Start Stage 7 Automatically 488 2020 0.0 0.0 O.0 4 11:06:50 Started Pumping 488 2020 0.0 0,0 0.0 5 11:10:14 ball away 19.5 tot slurry 1812 3063 19.5 10.1 0.0 6 11:16:56 Activated Extend Stage 1520 3010 55.4 5.1 0.0 7 11:38:21 Ball Seat 1869 3041 164.6 5.1 0.0 8 11:38:43 Ball Seat 1923 3043 166.6 6.8 0.0 9 11:39:05 Deactivated Extend Stage 1839 3045 168.2 3.9 O.0 10 11A0:15 Stage at Perfs:Pump Check 1875 3035 173.1 4.2 0.0 11 11:4120 Activated Extend Stage 2461 3054 179.7 7.6 O.0 12 11:42:07 Stage at Perfs:Ball Drop 3604 3084 190.1 23.1 0.0 13 11:42:15 Stage at Perfs:Displace Ball 3816 3092 193.5 27.4 0.0 14 11:43:50 GOOD SAMPLE 4313 3107 253.4 40.3 0.0 15 11:46:02 Stage at Perfs:20%VDA 4183 3158 342.0 40.2 0.0 16 11:46:11 Stage at Perfs:PAD 4158 3160 348.0 40.2 0.0 17 11:48:16 Stage at Perfs:PAD 4210 3156 431.9 40.2 0.0 18 11:50:10 Started Pumping Prop 4239 3139 508.5 40.2 0.0 19 11:54:30 Stage at Perfs:PAD 3910 3153 682.2 40.0 4.0 20 11:55:45 Stage at Perfs:1.0 PPA 3902 3177 732.3 40.0 4.0 21 11:57:00 Stage at Perfs:2.0 PPA 4007 3094 782.4 40.1 4.0 22 11:58:15 Stage at Perfs:3.0 PPA 4484 3133 832.5 40.2 O.C. 23 11:58:22 Activated Extend Stage 4764 3147 837.2 40.3 0.0 24 11:58:52 Stopped Pumping Prop 4864 3143 850.2 2.2 0.0 25 12:00:44 WELLHEAD SHUT 125 3044 850.3 -0.2 0.0 26 12:02:55 Deactivated Extend Stage 45 2902 850.3 -0.1 0.0 27 12:49:20 FANNING PUMPS -6 13 850.3 -5.0 0.0 • • Schlumberger Client BP Exploration Alaska Well.L3-03 Stage 7 Formation Wahoo 5 District,Prudhoe Bay Section 3: Acid Additive Components 20% VDA System: 252 gal Material Code Conc. Unit Quantity Unit 20% HCI H020 1000 gal/1,000gal 252 gal Water 366 gal/1,000ga1 92 gal Acid (36% HCI) H036 518 gal/1,000gal 131 gal Iron Control L058 10 lbs/1,000gal 3 lbs Corrosion Inhibitor A270 6 gal/1,000gal 2 gal Inhibitor Aid A201 20 gal/1,000gal 5 gal Methanol K046 10 gal/1,000gal 3 gal Non-emulsifier W054 5 gal/1,000gal 1 gal VDA Additive J557 75 gal/1,000gal 19 gal • • Schlumberger Client:BP Exploration Alaska Well:L3-03 Stage 7 Formation:Wahoo 5 District:Prudhoe Bay Section 4: Planned Pump Schedule ATTACHMENT 1:PUMP SCHEDULE Pressure Test 0000 Max WHT Pressure 7000 Slurry Rate 40 Proppant Density Well Name L3-03 AFE Pump Tris 6850 Ann Pressure 3000 Fluid Type YF728FIexD Proppant Used STEP STAGE AVERAGE COMMENTS FLUID PUMP CF DIRTY VOLUME DIRTY VOLUME PROPPANT CLEAN VOLUME 8 9 PPA TYPE RATE RATE STAGE CUM STAGE CUM STAGE CUM SIZE GROSS CUM (BPM) (BPM) (BBL) (BBL) (GAL) (GAL) (LBS) (LBS) (BBL) (BBL) 52 7 ACID 20%VDA 5 5.0 6 6 252 252 0 0 6 6 53 7 PAD YF128FIexD 40 40.0 125 131 5250 5502 0 0 125 131 54 7 .5 FLAT YF128FIexD 40 39.1 25 156 1050 6552 514 514 100 Mesh 24 155 55 7 PAD YF128FIexD 40 40.0 125 281 5250 11802 0 0 125 280 se 7 r 1 FLAT -----YF128FIexD 40 38.3 50 331 2100 13902 2011 2011 20140C-Lite 48 328 57 7 2 FLAT YF728FIexD 40 36.7 50 381 2100 16002 3859 5870 20/40 Cite 46 374 58 7 r 3 FLAT YF128FIexD 40 35.3 50 431 2100 18102 5562 11431 20/40 C-Lite 44 418 59 7 ' 4 FLAT YF128FIexD 40 34.0 250 681 _ 10500 28602 35685 47116 20/40 C-L 212 631 61 7 7 Ball,2.767' DISPLACE YF728FIexD 5 5 183 844 8846 35448 0 47116 ' 163 794 TOTALS - 844 47630 794 SD and obtain ISIP 8 15 min SIP. WATER VOL FLUSH INFORMATION )HELI AND TREATING PRFSSURE INFORMATION MODEL AND FRAC.ORIENTATION INFORMATIO( DataFRAC= 0 bbls VOL TO TOP OF LINER=1140.0 ISIP GRADIENT= 0,70 BHP=6265 psi TVD Pad H,5.= MAIN JOB= 794 bbls Extra 400 bbls -UNDERFLUSH>-40.0 FLUID SG= 1.000 5 180 ERIC=2303 psi Plain Strain,E.= TOTAL JOB= 794 bbls FLUSH VOL=180 FRICTION LOSS(X1_ 0.25 0 PERF ERIC=0500 psi Youngs Mod.,E.0.00 1194 bbls -vnth contingency - MD TO Tbg Tail= 9656 -HYD HEAD=3881,si__- Angle Through Perla= GENERAL JOB INFO TVD TOP PERF= 8950 EST.MAX WHP=5180 pd Well Azimuth(BNarth)= TANKS REQUIRED PIPE TIME(mint=3.5 MD TOP PERF= 9211 Frecture Azimuth(BNorth)= 3.0 <=400 bbl per tank pumpable(BP) PAD/SLURRY RATIO TUBING HANGER= Well Orientation-Pre/ened=Cr TOTALS FOR 7 STAGES Stage 1 Stage fi #DIVl01 UPPER TUBING 517E= 4.5000 0.0152 bbleA Porosity= Water 1194 Able Stage 2 Stage 7 MIDDLE TUBING SIZE= 4.500 0.0152 bblsrt Reserwir Pressure=3795 VF gel 794 bbls Stage 3 Stage 8 LOWER TUBING SIZE= bbls./5 Permeability= WF gel 443 bbls Stage 4 Stage 9 LENGTH MIDDLE TBG= 0 Temperature= 184 SXE 0 bbls 0 gal Stage 5 7E/1V/01 Stage 10 LENGTH LOWER MG= VDA 0 bbls 0 gal Stage Port MD DIapla c4 Seat Size CASING SIZE= 4.5000 0.0152 bola Ilt Mineral oil 0 bbls name ft volume in Proppant 47,630 lb Stage 1 12878 192.7 bbls PA Pump time 00:45:00 hh:mm:ss Stage 2 12447 189.2 bbls 2.332 Total Suid 1237 bole Stage 3 12221 1858 bole 2.412 Stage 4 11984 182.2 bole 2.497 Stage 5 11414 173.5 bbls 2.587 Stage 6 10989 167.0 bole 2.677 Stage 7 10719 162.9 bole 2.767 Stage 8 10460 159.0 bbls 2.857 Stage 9 10242 155.7 bbls 2,947 Stage 10 10023 152.3 Able 3.037 Stage 11 9857 149.6 bbls 3.137 NOTES: a Flush volume of DataFRAC stages is including the surface equipment volume(=7-10 bbls)and additional fluid for overdisplacing x-linked fluid into perfs. • • Schlumberger Client.BP Exploration Alaska Well,L3-03 Stage 7 Formation,Wahoo 5 District.Prudhoe Bay Section 5: Job Plots L3-03 Stage 7 — Treating Pressure BP Exploration Alaska Annulus Pressure L3-03 Stage 7 7.15.15 - BHP 10000 • — s' lurry Rate 50 — Prop Concentration — BH Prop Concentration — PCM Visc il 8000- 40 Ill 6000--- ' 30 I 4000 I 20 I i 2000 —` 1 10 a 3 0 A 0 11:04:55 11:25:45 11:46:35 12:07:25 12:28:15 Time-hh:mm:ss ©Schlumberoer 1994.2012 Schlumberger • • Schlumberger Client:BP Exploration Alaska Well.L3-03 Stage 7 Formation,Wahoo 5 District Prudhoe Bay R L3-03 Stage 7 POD Additives BP Exploration Alaska L3.03 Stage 7 ED 07-15-2015 . EC1 To a) 10 50 vi J511L Conc M J604 Conc `< ID — U28 Conc n J569 Cone E $- — Propcon -40 A d — Clean Fluid Rate Slurry Rate CD t; -- POD Road Gate POS _ i:+ POD Deck Gate PDs 6 6 j44M�4N � -30 3 a) o R 4- -20 E a coa) A3 la al Z.33 210 CD 0Ii ,j ,...." !IF< o 0 lis -a 11:30:57 11:39:17 11:47:37 11:55:57 12:04:17 3 a Time-hh:mm:ss 3 J ©Schlumberger 1994-2012 Schlumberger • • Schlumberger Client:BP Exploration Alaska Well:L3-03 Stage 7 Formation:Wahoo 5 District:Prudhoe Bay L3-03 Stage 7 PCM Additive Plot BP Exploration Alaska 1.E-03 Stage 7 07-10-2015 10 50 L088 Cone L071 Cone 8 fi i Pr80Con 40 4Jr4 / �' Clean Flwtl R.,,, s / Slurry Rate lb \`// — PCM Vtsc "30 i t 4- -20 N d- 2 1 -10 .3 0 _, ..�, -0 11:15:58 11:28:28 11:40:58 11:53:28 12:05:58 Time-hh:mm:ss ©Schlumberger 1994-2012 Schlumberger • • Schlumberger L3-03 Stace 8 Treatment Report Well :L3-03,Stage 8 Field :Lisburne Formation :Wahoo 5 County :Prudhoe Bay State :Alaska Country :United States Prepared for Client :BP Exploration Alaska Client Rep :Ken Bulloch Date Prepared :27 July 2015 Prepared by Name :Jimmy Kelley Division :Schlumberger Phone :907-659-6115 Pressures Initial Wellhead Pressure(psi) 50 Initial BHP at Gauge(psi) 3180 Final Surface ISIP(psi) 8,200,Screenout Final ISIP at Gauge(psi) 10,065,Screenout Surface Shut in Pressure(psi) 4,650 BH Shut in Pressure(psi) 8,750 Maximum Treating Pressure(psi) 8,200 Treatment Totals Total Slurry Pumped 1033 Total YF128FIexD Past Wellhead(bbls) 537 (Water+Adds+Proppant)(bbls) Total WF128 Past Wellhead(bbls) 487 Total Freeze Protect Past Wellhead 0 (bbls) Total Proppant Pumped(lbs.) 24,685 Total Proppant in Formation(lbs.) 14,685 Total Chemical Additives Invoiced Past WH Invoiced Past WH F103(gal) 37 37 M275(lbs.) 18 15 L065(gal) 60 60 J569(lbs.) 193 193 L071 (gal) 95 95 J134(lbs.) 40 0 J604(gal) 53 53 M002(lbs.) 11 11 J580(lbs.) 1,449 1,185 J511 (lbs.) 24 24 D206(gal) 1 1 J475(lbs) 137 137 Disclaimer Notice This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment.The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. • • Schiumberger Client,BP Exploration Alaska Well:L3-03 Stage 8 Formation:Wahoo 5 District:Prudhoe Bay Section 1 : Stage 8: As Measured Pump Schedule As Measured Pump Schedule Ste StepSlurry Slurry Pump Fluid Max Prop P Prop Name Volume Rate Time Fluid Name Volume Proppant Name Cone Conc Mass (bbl) (bbl/min) (min) (gal) (PPA) (Ib) (PPA) 1 PAD 406.8 26.2 19.5 WF128 17087 0.0 0.0 0 2 PAD 275.0 56.6 4.9 YF128FIexD 11550 0.0 0.0 0 3 1.0 PPA 48.0 60.4 0.8 YF128FIexD 1954 CarboLite 20/40 1.1 1 1395 4 2.0 PPA 48.1 60,4 0.8 YF128FIexD 1877 CarboLite 20/40 2.1 2 3198 5 3.0 PPA 48.1 59.3 0.8 YF128FIexD 1804 CarboLite 20/40 3.0 3 4950 6 4.0 PPA 128 58,7 3.1 YF128FIexD 5376 CarboLite 20/40 4.1 4 15142 7 Flush 80 57.5 0.2 WF128 3360 0.0 0,0 0 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 PAD /26.2 48.1 1801 3990 38 2 PAD 56,6 60.4 4840 5216 4034 3 2.0 PPA 60.4 60.5 5218 5225 5206 4 3.0 PPA 60.4 60,6 5178 5211 5061 5 4.0 PPA 59.3 60.3 4978 5042 4919 6 4.0 PPA 58.7 59.4 5226 /5845 4866 7 Drop Ball 57.5 57.6 6070 6162 5893 8 Flush 47.4 57.5 6939 8365 6040 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (lb) 1033.4 31.1 42321 24685 Average Treating Pressure: 3813 psi Maximum Treating Pressure: 8365 psi Minimum Treating Pressure: 38 psi Average Injection Rate: 45.4 bbl/min Maximum Injection Rate: 60.6 bbl/min Average Horsepower: 4968.5 hhp Maximum Horsepower: 8715.1 hhp Maximum Prop Concentration: 4.1 PPA • • Schlumberger Client BP Exploration Alaska Well:L3-03 Stage 8 Formation,Wahoo 5 District Prudhoe Bay Section 2: Stage 8: Job Messa s es Message Log Message Treating Annulus Total SlurrySlurryRate Prop.Conc. #� Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 1 Arrive on location 630 0 0 0.0 0.0 0.0 2 7:04:02 Coil spotting on L3-10 0 0 0.0 0.0 0.1 3 7:49:30 Rigged up waiting on company man to start pumps 0 D 0.0 0.0 0.1 4 8:30:04 Starting Pumps 1 0 0.0 0.0 U.S 5 8:38:35 POD primed 1 0 0.0 0.0 0.1 6 8:48:43 Priming pumps 61 1 0.0 0.0 0.1 7 8:48:55 LRS pop-off skid not on location yet 62 1 0.0 0.0 0.1. 8 9:46:52 Pressure test safety meeting with coil 76 3 0.0 0.0 0.1 9 9:49:22 Clear pressuring up 83 3 0.0 0.0 0.1 10 9:50:41 bumping acid side pressure 1699 3 0.0 0.0 0.1 11 9:51:04 bleeding pressure to 300 2235 3 0.0 0.0 0.1 12 9:51:57 Start low PT 275 3 0.0 0.0 0.1 13 9:57:01 ,9ood low PT 269 3 0.0 0.0 0.1 14 10:00:40 Start high PT 8334 3 0.0 0.0 01 15 10:02:44 All pumps tripped 8277 3 0.0 0.0 0.1 16 10:02:53 Global shutdown trip tested 8273 3 0.0 0.0 0.1 17 10:05:54 Good high PT 8221 3 0.0 0.0 0.1 18 10:06:34 Negative check valve test 8213 3 0.0 0.0 0.1 19 10:07:06 Good check valve test 8199 3 0.0 0.0 0.1 20 10:07:24 Bleeding lines 8196 3 0.0 0.0 0.1 21 10:10:15 starting safety meeting 25 3 0.0 0.0 0.1 22 10:38:52 LRS pressure testing line 53 3 0.0 0.0 0.1 23 11:21:01 LRS PT lines 56 5 0.0 0.0 0.1 24 11:41:27 Loading balls 56 4 0.0 0.0 0.1 25 11:51:38 2.847"ball loaded 56 4 0.0 0.0 0.1 26 11:52:37 2.937'ball loaded as second ball 55 3 0.0 0.0 0.1 27 11:57:16 LRS still pressure testing 55 3 0.0 0.0 0.1 28 12:09:37 LRS making one final adjustment to PRV 55 3 0.0 0.0 0.1 29 12:12:13 LRS pop-off test complete 54 3 0.0 0.0 0.1 30 12:21:45 Clearing ground for pressuring up 68 5 0.0 0.0 0.1 31 12:23:56 Pressuring up lines to 1000 129 4 0.0 1.0 0.1 32 12:26:55 Increasing IA to 2500 1155 -0 0,0 0.0 0.1 33 12:27:47 Opening SSV 46 -1 0.0 0.0 0.1 34 12:29:15 WH open initial pressure 50 psi 54 0 0.0 0.0 0.1 35 12:30:45 Start Propped Frac Automatically 54 0 0.0 0.0 0.1 36 12:30:45 Start Stage 8 Automatically 54 0 0.0 0.0 0.1 37 12:30:45 Started Pumping 54 0 0.0 0.0 0.0 38 12:30:48 Activated Extend Stage 55 0 0.0 0.0 0.1 39 12:31:02 Fluid sucking down the well 56 -1 0.0 0.0 0.1 40 12:32:52 Closing and opening master valve to confirm turns 56 -1 15.9 9.8 0.1 41 12:33:14 WH closed 71 -0 17.7 0.4 0.1 42 12:33:29 WH open 68 -1 19.4 20.2 0.1 43 12:34:49 Start Pumping 15x 58 -1 33.2 9.1 0.1 44 12:35:09 Waiting for IA to increase 58 0 36.2 8.9 0.1 45 12:35:47 Start Pumping 15x 58 -0 41.2 0.0 0.1 46 12:36:29 increasing rate to 20 66 11 43.3 5.4 0.1 47 12:38:33 Ball away 76 bbl 1106 1132 78.0 20.8 0.1 • 0 Schlumberger Client:BP Exploration Alaska Well:L3-03 Stage 8 Formation:Wahoo 5 District:Prudhoe Bay Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. I Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 48 12:39:48 Zeros on pod 897 1828 104.1 20.9 0.1 49 12:42:55 Stage at Perfs:PAD 782 2551 169.6 21.1 0.0 50 12:45:17 28#gel 752 2551 219.4 21.0 0.1 51 12:45:30 Starting XL Chems 1673 2607 223.9 21.0 0.0 52 12:45:43 Ball on seat 224 2443 2637 228.4 20.8 0.1 53 12:46:42 increasing rate to 40 bpm 2447 2639 248.9 20.8 0.0 54 12:48:17 setting XL sample to confirm pad 3325 3011 296.5 38.8 0.1 55 12:50:19 Bringing rate to 60 bpm 3625 2996 378.9 43.9 0.1 56 12:50:55 Deactivated Extend Stage 4054 3010 406.8 48.8 0.1 57 12:51:14 good XL 9.4 4110 3012 422.4 49.5 0.1 58 12:54:03 Stage at Perfs:PAD 5148 3044 577.3 60.2 0.0 59 12:55:46 Started Pumping Prop 5214 3055 680.9 60.3 0.1 60 12:58:33 Activated Extend Stage 4817 3033 847.6 59.2 4.1 61 12:58:38 Stage at Perfs:2.0 PPA 4944 3037 852.5 58.6 4.1 62 12:59:27 Stage at Perfs:3.0 PPA 5085 3015 900.4 59.1 4.0 63 13:00:17 Stage at Perfs:4.0 PPA 5405 3008 949.2 58.9 0.1 64 13:01:06 Stage at Perfs:4.0 PPA 5799 3026 997.2 57.8 -0.1 65 13:01:13 Stopped Pumping Prop 5843 3038 1003.9 57.6 -0.0 66 13:01:15 Deactivated Extend Stage 5992 3025 1005.8 57.5 0.1 67 13:01:25 Dropping rate 55 6168 3036 1015.4 57.8 0.1 68 13:01:45 Pop-off blew 8069 3176 1031.2 16.4 0.1 69 13:03:30 Watching pressure 5453 2795 1033.4 0.0 0.1 70 13:09:58 Shutting well 4770 2562 1033.4 0.0 0.1 71 13:11:55 Wellhead Master Shut 23.5 turns 4747 2535 1033.4 0.0 0.0 72 13:15:43 WH Shut 4660 4659 2497 1033.4 0.0 0:1 • • Schlon erger Client:BP Exploration Alaska u Well.13-03 Stage 8 Formation:Wahoo 5 District,Prudhoe Bay Section 5: Job Plots L3-10 Stage 8 Pressure Test — Treating Pressure BP E�ploratagetian8Alaska L3-10 S Annulus Pressure 07-27-2015 BHP 9000 — `.,lorry Rate 70 Prop Concentration 8000- — BH Prop Concentration 65 PIA,vtsc 60 7000- 5 55 .� 6000- 45 11 5000- 40 35 4000- .CELL 3000 — �. 2530 R 20 t3{ 2000- 15 1000---___., 10 3• 5 0 1,....,.1.—. $- 0 09:42:05 09:52:30 10:02:55 10:13:20 10:23:45 Time-hh:mm:ss ©Schlumberger 1994-2012 Schlumberger L3-10 Stage 8 — r,3:, :),„Exloration Alaska Treating Pressure Stage 8 •^ Annulus Pressure 07-27-2015 — BHP 10000 t l..ry Rale 70 Prop Concentration 9000- 8H Prop Concentration 8000- — PCSI VI. 60 7000- 50 6000- • 40 S 5000- 4000- __--, 30 i. 3000- 44........ 20 2000- 1000 10 3. 0 _ me/ ,,,, 0 12:20:01 12:36:41 12:53:21 13:10:01 13:26:41 Time-hh:mm:ss ©Schlumberger 1994-2012 Schlumberger • • Schlumberger Client:BP Exploration Alaska Well:L3-03 Stage 8 Formation,Wahoo 5 District.Prudhoe Bay L3-03 Stage 8 PCM Additive Plot BP Exploration Alaska L3-03 Stage 8 07-27-2015 7 - r 70 - L065 Con: L071 Con: - Prop Con 6 - J5 80Conc -60 N Clean Fluid Rai- Slurry Rate Ol — — PCM Visc 1 5- CI -50 i 2) 4" -40 aC- m P 3 -30 o 70 j 2- ._. .� -20 c Et 110 ul �r � 0- rr -. Ai0 12:09:10 12:25:50 12:42:30 12:59:10 13:15:50 Time -hh:mm:ss ©Schlumberger 1994-2012 SC+hhi eryer • • Schlumberger Client:BP Exploration Alaska Schlumberger Well:L3-03 Stage 8 Formation:Wahoo 5 District:Prudhoe Bay L3-03 Stage 8 POD Additives BP Exploration Alaska L3-03 Stage 8 07-27-2015 9 90 J475 Cone To T J5t1L Cone 0 J604 Cone C E 853- — U28 Cone -oo 53 1 — J589 Cone v Prop Con C H Clean Fluid Rate Slurry Rate 7p 7- — POD Road Gab Pos .70 C1 cn — POD Deck Gate Pos 13 G .15 X 6- 11 1 „ -60 0 illi11cra a 8_ 50 3 0 0 -^ 4- 40 f0m at co of 3- -30 m o co 11 I Q 2 1Iw1N 2U >_ a a irall111111111 1 a III s. J 0 i 11 0 12:19:02 12:35:42 12:52:22 13:09:02 13:25:42 Time -hh:mm:ss ©Schlumberger 1994-2012 Schlumberger • • Schlumberger FracCAT Treatment Report Stage 9-11 Well :L3-03 Stage 9-11 Field :Lisburne Formation :Wahoo 5,6&7 Prepared for Client :BP Exploration Alaska Client Rep :Dan Scarpella Date Prepared :July 31,2015 Prepared by Name :Jimmy Kelley Division :Schlumberger Phone :9076596115 Pressure Initial Wellhead Pressure(psi) 28 Initial BHP at Gauge(psi) 3,720 Final Surface ISIP(psi) 195 Final ISIP at Gauge(psi) 3,820 Surface Shut in Pressure(psi) 116 BH Shut in Pressure(psi) 3,730 Maximum Treating Pressure(psi) 5,865 Treatment Totals(As Per FracCAT) Total Slurry Pumped 2625 Total YF128FIexD Past Wellhead(gal) 59,802 (Water+Adds+Proppant)(bbls) Total WF128 Past Wellhead(gal) 38,842 Total Freeze Protect Past Wellhead 20 (bbls) Total 20/40 CarboLite Pumped(lbs.) 20,218 Total Proppant in Formation(lbs.) 22,218 Total 100 Mesh Pumped(lbs.) 2,000 Total 20%VDA Pumped(bbl) 96 Total 28%SXE Pumped(bbl) 152 Total Chemical Additives Invoiced Past WH Invoiced Past WH F103(gal) 102 96 M275(lbs.) 27 26 L065(gal) 103 95 J569(lbs.) 55 55 L071 (gal) 197 183 J134(lbs.) 65 0 J604(gal) 179 156 M002(lbs.) 35 35 J580(lbs.) 2,772 2,742 J511 (lbs.) 126 71 J475(lbs) 605 605 J622(lbs.) 210 210 D206(gal) 4 4 Disclaimer Notice This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment.The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values,The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. • • Schlumberger Client:BP Exploration Alaska Well:L3-03,Stage 9-11 District:Prudhoe Bay Formation,Wahoo 5,6&7 Stale 9 As Measured Pum • Schedule As Measured Pump Schedule Slurry Slurry Pump Fluid Max Prop Prop Step tep Name Volume Rate Time Fluid Name Volume Proppant Prop Conc Mass it Name Conc (bbl) (bbl/min) (min) (gal) (PPA) (PPA) (lb) 1 Drop ball 269.8 15.4 30,1 WF128 11331 0 0 0 2 PAD 100 53,5 1,9 YF128FIexD 4200 0 0 0 Fiber w/100 3 101,1 59.5 1.7 YF128FIexD 4211 100 Mesh Sand 0.2 0.25 800 Mesh 4 PAD 100 59.5 1.7 YF128FIexD 4197 0.1 0 153 5 .5 PPA 193.5 59,4 3.3 YF128FIexD 7959 CarboLite 20/40 0.6 0.5 3858 6 1 PPA 100,2 59.5 1.7 YF128FIexD 4041 CarboLite 20/40 1 1 3797 7 1.5 PPA 100.2 59.6 1.7 YF128FIexD 3957 CarboLite 20/40 1.5 1.5 5693 8 2 PPA 80.9 59.2 1,4 YF128FIexD 3135 CarboLite 20/40 2 2 6032 9 Drop Ball 9 59 0.2 YF128FIexD 354 CarboLite 20/40 2 0 598 10 Displace 330,3 51.7 6.6 YF128FIexD 13872 CarboLite 20/40 1.5 0 87 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step I Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Drop ball 15.4 43.8 1838 3528 16 2 PAD 53.5 58.9 4314 4898 3534 3 PAD 59.5 59.8 5104 5194 4903 4 PAD 59.5 59.5 5180 5277 5145 5 .5 PPA 59.4 59.5 5344 5437 5194 6 1 PPA 59.5 59.8 5145 5194 5117 7 1.5 PPA 59.6 59.7 5104 5124 5080 8 2 PPA 59,2 59.5 5132 5189 5088 9 Drop Ball 59.0 59.1 5204 5214 5193 10 Displace 51.7 59.5 4983 5827 3809 As Measured Totals Pump Clean Slurry Time Fluid Proppant (bbl) (min) (gal) (Ib) 1385.1 50,1 57258 21018 Average Treating Pressure: 4433 psi Maximum Treating Pressure: 5827 psi Minimum Treating Pressure: 16 psi Average Injection Rate: 48,7 bbl/min Maximum Injection Rate: 59.8 bbl/min Average Horsepower: 5869.4 hhp Maximum Horsepower: 8461,9 hhp Maximum Prop Concentration: 2.0 PPA • ! Schiumberger Client:BP Exploration Alaska Well L3-03,Stage 9-11 District:Prudhoe Bay Formation.Wahoo 5,6&7 Stage 10 As Measured Pum • Schedule As Measured Pump Schedule Slurry Slurry Pump Fluid Max Prop Prop Step Step Name Volume Rate Time Fluid Volume Proppant Prop Conc Mass # Name Name Conc (bbl) (bbl/min) (min) (gal) (PPA) (PPA) (Ib) 1 Fiber w/100 130.4 40.7 3.2 YF128FIexD 5442 100 Mesh 0.4 0.25 600 Mesh Sand 2 PAD 169.5 40.1 4.7 WF128 7120 0 0 0 3 28%SXE 9 5 3.5 28%SXE 378 0 0 0 4 20%VDA 12 5.2 2.3 20%VDA 506 0 0 0 5 28%SXE 19 5.2 3.6 28%SXE 798 0 0 0 6 20%VDA 0 5.2 0 20%VDA 0 0 0 0 7 20%VDA 11.9 5.2 2.3 20%VDA 498 0 0 0 8 28%SXE 18.2 5.2 3.5 28%SXE 766 0 0 0 9 20%VDA 13.1 5.2 2.5 20%VDA 550 0 0 0 10 28%SXE 19.1 5.2 3.7 28%SXE 803 0 0 0 11 20%VDA 12.9 5.2 2.5 20%VDA 542 0 0 0 12 Flush 152 5 30.7 WF128 6384 0 0 0 13 Drop Ball 1 8.4 0.1 WF128 42 0 0 0 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Fiber w/100 40.7 40,9 3609 3804 3414 2 PAD 40.1 41.1 3146 3414 1488 3 28%SXE 5.0 5.2 1545 1794 1515 4 20%VDA ,5.2 5.2 1515 1525 1497 5 28%SXE 5.2 5.2 1401 1495 1345 6 20%VDA 5.2 5.2 1401 1495 1345 7 20%VDA 5.2 5.2 1325 1347 1281 8 28%SXE 5.2 5.2 1261 1304 1222 9 20%VDA 5.2 5.2 1183 1222 1144 10 28%SXE 5.2 5.2 1091 1146 1040 11 20%VDA 5.2 5.2 1012 1043 969 12 Flush 5.0 7.9 846 1080 788 13 Drop Ball 8.4 9.5 1115 1134 1089 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 568.2 62.4 23834 600 • • Schlumberger Client:BP Exploration Alaska Well:L3-03,Stage 9-11 District:Prudhoe Bay Formation:Wahoo 5,6&7 Average Treating Pressure: 2259 psi Maximum Treating Pressure: 3804 psi Minimum Treating Pressure: 788 psi Average Injection Rate: 23.8 bbl/min Maximum Injection Rate: 41.1 bbl/min Average Horsepower: 1828.2 hhp Maximum Horsepower: 3791.2 hhp Maximum Prop Concentration: 0.4 PPA • • Schiumberger Client:BP Expaska Well L3-03,Stage 9-11 District:Prudhoe Bay Formation.Wahoo 5,6&7 Sta•e 11 As Measured Pum . Schedule As Measured Pump Schedule Max Step Slurry Slurry Pump Fluid Fluid Proppant Prop Prop Prop Step# Name Volume Rate Time Name Volume Name Conc Conc Mass (bbl) (bbl/min) (min) (gal) (PPA) (PPA) (Ib) 1 PAD 100 35.8 3.1 YF128FIexD 4196 0 0 0 Fiber 2 w/100 101.1 39.9 2.5 YF128FIexD 4238 100 Mesh 0.2 0.25 600 Mesh Sand 3 PAD 164 39.2 4.5 WF128 6890 0,0 0 8 4 28%SXE 19 5.2 3.6 28%SXE 796 0 0 0 5 20%VDA 12 5.2 2.3 20%VDA 504 0 0 0 6 28%SXE 0 5.2 0 28%SXE 0 0 0 0 7 28%SXE 19 5.2 3.6 28%SXE 799 0 0 0 8 20%VDA 12 5.2 2.3 20%VDA 506 0 0 0 9 28%SXE 19 5.2 3.6 28%SXE 799 0 0 0 10 20%VDA 12.2 5.2 2.3 20%VDA 513 0 0 0 11 28%SXE 17.5 5.2 3.3 28%SXE 733 0 0 0 12 20%VDA 7.6 5.2 1.5 20%VDA 319 0 0 0 13 Displace 50 6.9 7.2 WF128 2100 0 0 0 14 Flush 118.4 7.1 16.7 WF128 4975 0 0 0 15 Freeze 20 7.1 2.9 LVT 649 0 0 0 Protect Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 PAD 35.8 40.1 2282 2541 1145 2 Fiberw/100 39.9 39.9 2392 2449 2290 3 PAD 39.2 39.9 2493 2739 1150 4 28%SXE 5.2 5.8 1118 1214 1101 5 20%VDA 5.2 5.2 1113 1122 1102 6 28%SXE 5.2 5.2 1113 1122 1102 7 28%SXE 5.2 5.2 1077 1104 1025 8 20%VDA 5.2 5.2 988 1025 958 9 28%SXE 5.2 5.2 944 957 938 10 20%VDA 5.2 5.2 930 940 916 11 28%SXE 5.2 5.2 911 917 908 12 20%VDA 5.2 5.2 908 915 876 13 Displace 6.9 8.9 1038 1220 890 14 Flush 7.1 7.1 562 891 380 15 Freeze Protect 7.1 7.1 404 451 127 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 671.9 59.6 28018 600 • • Schlumberger Tient:BP Exploration Alaska Well:L3-03,Stage 9-11 District:Prudhoe Bay Formation:Wahoo 5,6&7 Average Treating Pressure: 1674 psi Maximum Treating Pressure: 2739 psi Minimum Treating Pressure: 127 psi Average Injection Rate: 23.8 bbl/min Maximum Injection Rate: 40.1 bbl/min Average Horsepower: 1306.8 hhp Maximum Horsepower: 2676.3 hhp Maximum Prop Concentration: 0.2 PPA • • Schlumberger Client.BP Exploration Alaska Well L3-03,Stage 9-11 District,Prudhoe Bay Formation:Wahoo 5,6&7 Sta s e 9-11 Job Messa•e Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (bbl) (psi) (psi) ) (bbl/min) (PPA) 1 7:25:15 Arrived on location 630 0 0 0.0 0.0 0.0 2 7:25:23 Rigging up to L3-03 0 0 0.0 0.0 0.0 3 7:39:30 Finished rigging up 0 0 0.0 0.0 0.0 4 8:37:46 Firing pumps 0 0 0.0 0.0 0.0 5 9:24:48 priming pumps 0 0 0,0 0.0 0.0 6 9:38:22 priming pumps 85 746 0.0 5.2 D.0 7 10:16:13 getting ready for PT 62 745 0.0 0,0 0.0 8 10:19:00 Pressuring up 169 746 0.0 1.5 0.0 9 10:19:43 bleeding down to 300 1291 747 0.0 0.0 0,0 10 10:20:45 Start low PT 237 748 0.0 0.0 0.0 11 10:21:30 bleed off pressure 32 747 0.0 0.0 0.0 12 10:27:38 replacing o-ring -30 746 0.0 0.0 0.0 13 10:49:41 Re-prime lines 44 746 0.0 0.0 0.0 14 10:50:30 pressuring up lines 43 746 0.0 0.0 0.0 15 10:52:05 bleeding down to 300 967 745 0.0 0,0 0.0 16 10:53:51 Start low PT 265 745 0,0 0.0 0.0 17 10:57:51 good low PT 262 745 0.0 0.0 0.0 18 10:58:24 Increasing to high PT 643 744 0.0 0.0 0.0 19 11:02:24 Start high PT 8285 248 0.0 0.0 0.0 20 11:07:43 Good high PT 8251 248 0.0 0.0 0.0 21 11:07:54 Check valve test 8251 248 0,0 0.0 0.0 22 11:08:32 good check valve test 8245 248 0.0 0.0 0.0 23 11:08:56 bleeding line 3562 249 0.0 0,0 0.0 24 11:09:58 safety meeting 146 249 0.0 0.0 0.0 25 11:15:38 Safety meeting 153 249 0.0 0.0 0.0 26 11:38:48 Loading 2.937'ball 162 235 0,0 0.0 0.0 27 11:47:44 pressuring up IA 164 550 0.0 0.0 0.0 28 11:49:46 28#gel 164 1072 0.0 0.0 0.0 29 11:52:00 Opening SSV 165 1784 0.0 0.0 0.0 30 11:52:16 Pressuring up lines 326 1869 0.0 0.0 0.0 31 11:52:44 Opening WH 853 2031 0,0 0.0 0.0 32 11:53:00 Start Propped Frac Automatically 841 2136 0.0 0.0 0.0 33 11:53:00 Start Stage 9 Automatically 841 2136 0.0 0,0 0.0 34 11:53:00 Started Pumping 841 2136 0.0 0.0 D.0 35 11:53:03 Activated Extend Stage 839 2157 0.0 0.0 0.0 36 12:00:01 SSV confirmed open 814 2703 0.2 0.0 0.0 37 12:00:25 WH open 10 psi 5 2702 0.3 1.9 0.0 38 12:01:07 pumping 174 2713 2.0 2.4 0.0 39 12:01:38 pressuring up van 1261 2755 4.9 7.9 0,0 40 12:03:00 ball away 16 bbl 1315 2734 17,8 9,8 0.0 41 12:03:08 Shutdown to reload balls 1271 2729 19.1 9.8 0.0 42 12:04:55 Loading 3.027' 575 2683 19.7 0.0 0.0 43 12:05:24 Loading 3.227'ball 535 2679 19.7 0.0 0.0 44 12:06:25 pumping 468 2673 19.7 0.0 0.0 45 12:17:56 starting xl adds 1598 2537 131.3 10.0 0.0 46 12:21:23 Stage at Perfs:Drop ball 1543 2536 166.0 10.0 0.0 47 12:23:09 increasing rate to 20 bpm 1610 2552 183.9 10,2 0.0 • • Schlumberger Tient:BP Exploration Alaska Well:L3-03,Stage 9-11 District:Prudhoe Bay Formation:Wahoo 5,6&7 Message Log Message Treating Annulus I Time g Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 48 12:24:56 going to 60 2276 2619 215.0 20.5 0.0 49 12:25:03 ball seat 190 2513 2608 217.4 21.4 0.0 50 12:26:36 Deactivated Extend Stage 3639 2666 269.8 44.9 0.0 51 12:26:44 9.5 pH 3750 2671 275.9 46.5 0.0 52 12:28:26 sand falling 4929 2820 368.2 59.2 0.0 53 12:28:28 Started Pumping Prop 4911 2813 370.2 59.4 0.0 54 12:29:35 Stage at Perfs:PAD 5190 2906 436.6 59.6 0.2 55 12:30:13 9.6 pH 5181 2952 474.4 59.4 0.1 56 12:31:07 Fiber on bottom 5156 3014 527.9 59.5 -0.1 57 12:31:17 Stage at Perfs:PAD 5169 3027 537.8 59.5 -0.0 58 12:31:42 28#gel 5273 3059 562.6 59.5 -0.0 59 12:32:14 Activated Extend Stage 5365 3099 594.3 59.3 0.4 60 12:32:24 extending.5 to 175bb1 5385 3111 604.2 59.2 0.5 61 12:32:52 pressuring up van 5424 3143 631.9 59.4 0.5 62 12:32:59 Stage at Perfs:PAD 5452 3148 638.8 59.1 0.5 63 12:33:05 fiber past perfs 5433 3157 644.7 59.3 0.5 64 12:34:40 Stage at Perfs:.5 PPA 5236 3050 738.7 59.5 0.5 65 12:35:06 Deactivated Extend Stage 5178 3077 764.5 59.5 0.5 66 12:37:15 pH 9.5 5101 3002 892.4 59.4 1.5 67 12:37:55 Stage at Perfs:1 PPA 5081 3040 932.1 59.8 1.5 68 12:39:36 Stage at Perfs:1.5 PPA 5180 3041 1032.0 59.1 2.0 69 12:40:07 Activated Extend Stage 5266 3068 1062.5 59.0 0.0 70 12:40:11 Stopped Pumping Prop 5264 3069 1066.4 59.2 -0.0 71 12:40:51 ball away 1092 5448 3032 1106.0 59.4 0:0 72 12:41:18 Stage at Perfs:2 PPA 5588 3008 1132.7 59.3 0.0 73 12:42:21 dropping rate at 1225 5786 3065 1195.0 59.2 0.0 74 12:42:31 easing off rate to keep 5800 5822 3074 1204.8 58.6 0.0 75 12:42:40 Stage At Perfs 5852 3080 1213.5 57.8 0.0 76 12:42:50 Stage At Perfs 5767 3062 1223.1 57.3 0.0 77 12:43:02 Remark 5555 3012 1234.5 56.6 0.0 78 12:46:11 Started Pumping Prop 3863 3024 1368.2 40.6 0.0 1 12:46:36 Deactivated Extend Stage 3794 3028 1385.1 40.8 0.1 2 12:46:36 Start Propped Frac Manually 3794 3028 1385.1 40.8 0.1 3 12:46:36 Start Stage 10 Automatically 3794 3028 1385.1 40.8 0.1 4 12:46:55 fiber falling 3757 3031 12.9 40.5 0.1 5 12:47:32 Activated Extend Stage 3693 3040 38.0 40.6 0.1 6 12:49:48 Deactivated Extend Stage 3411 3067 130.4 40.8 0.2 7 12:50:06 cutting xl 3370 3070 142.6 40.9 -0.0 8 12:50:27 fibers on bottom 3339 3074 156.9 40.9 0.0 9 12:50:42 Stage At Perfs 3321 3030 167.2 40.9 -0.0 10 12:52:18 Stopped Pumping Prop 3201 3053 232,7 41.0 -0.0 11 12:53:27 Activated Extend Stage 3078 3068 279.8 41.1 0.0 12 12:53:44 Switching to acid pumps 2404 3057 291.4 40.9 0.0 13 12:53:47 Stage At Perfs 649 2995 293.4 39.3 0.0 14 12:54:28 Deactivated Extend Stage 1613 3018 299.9 2.3 0.0 15 12:54:31 Activated Extend Stage 1549 3054 300.0 1.4 0.0 16 12:57:59 Deactivated Extend Stage 1517 3017 308.9 5.2 0.0 17 12:58:02 Activated Extend Stage 1506 3016 309.1 5.2 0.0 18 13:00:17 Deactivated Extend Stage 1483 3007 320.9 5.2 0.0 19 13:01:02 bleeding OA 1458 3005 324.8 5.3 0.0 • 0 Schiumberger Client BP Exploration Alaska Well:L3-03,Stage 9-11 District Prudhoe Bay Formation,Wahoo 5,6&7 Message Log Message Treating Annulus # Time g Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 20 13:03:58 Activated Extend Stage 1339 3033 340.2 5.2 0.0 21 13:06:11 Deactivated Extend Stage 1282 3007 351.8 5.2 0.0 22 13:06:14 Activated Extend Stage 1294 3007 352.1 5.2 0.0 23 13:09:40 Deactivated Extend Stage 1208 3002 370.0 5.2 0.0 24 13:09:46 Activated Extend Stage 1209 3002 370.6 5.2 0.5 25 13:12:10 Deactivated Extend Stage 1152 3040 383.1 5.2 0.0 26 13:12:12 Activated Extend Stage 1139 3025 383.3 5.2 0.0 27 13:15:49 Deactivated Extend Stage 1045 3005 402,2 5.2 0.0 28 13:15:51 Activated Extend Stage 1028 3005 402.4 5.2 O.0 29 13:18:17 Deactivated Extend Stage 974 3017 415.2 5.2 0.0 30 13:19:39 flushing acid lines with water 929 3006 422.3 5.2 0.0 31 13:20:23 swapping to POD Side 925 3001 426.2 5.2 0.0 32 13:27:38 Stage at Perfs:20%VDA 827 3011 462.5 4.9 0.0 33 13:29:28 Stage at Perfs:20%VDA 827 3010 471.5 4.9 0.0 34 13:31:56 Stage at Perfs:28%SXE 877 3010 483.5 4.9 0.0 35 13:34:10 SXE on perfs 855 3004 494.5 4.9 0.0 36 13:35:49 Stage at Perfs:20%VDA 797 3025 502.5 4.9 0.0 37 13:38:15 Stage at Perfs:28%SXE 800 3021 514.4 4.9 0.0 38 13:41:59 Stage at Perfs:20%VDA 810 3014 532.7 4.9 0.0 39 13:44:39 Stage at Perfs:Flush 848 3011 545.7 4.9 0.0 40 13:47:12 pressuring up cement van 844 3005 558.2 4.9 0.0 41 13:48:33 Stage At Perfs 851 3003 564.8 4.9 0.0 • • Schlumberger Client BP Exploration Alaska Well:L3-03,Stage 9-11 District Prudhoe Bay Formation:Wahoo 5,6&7 Acid Blend Formulation 28% SXE System: 6,384 gal I Material Code Conc. Unit Quantity Unit 28% HCI H028 700 gal/1,000gal 4,469 gal Water 149 gal/1,000gal 951 gal Acid (36% HCI) H036 526 gal/1,000gal 3,351 gal Iron Control L058 10 lbs/1,000gal 62 lbs Corrosion Inhibitor A262 5 gal/1,000gal 32 gal Inhibitor Aid A201 20 gal/1,000gal 128 gal LVT J510 295 gal/1,000gal 1,883 gal Emulsifier U108 5 gal/1,000gal 32 gal 20%VDA System: 4,032 gal Material Code Conc. Unit Quantity Unit 20% HCI H020 1000 gal/1,000gal 4,032 gal Water 366 gal/1,000gal 1,476 gal Acid (36% HCI) H036 518 gal/1,000gal 2,089 gal Iron Control L058 10 lbs/1,000gal 40 lbs Corrosion Inhibitor A270 6 gal/1,000gal 24 gal Inhibitor Aid A201 20 gal/1,000gal 81 gal Methanol K046 10 gal/1,000gal 40 gal Non-emulsifier W054 5 gal/1,000gal 20 gal VDA Additive J557 75 gal/1,000gal 302 gal • • Schlumberger Client,BP Exploration Alaska Well L3 03,Stage 9-11 District.Prudhoe Bay Formation.Wahoo 5,6&7 Stage 9-11 Post Job Plots L3-03 Stage 9-11 Pressure Test BP Exploration Alaska L3-03 Stage 9-11 Treating Pressure 07-31-2015 —^ Annulus Pressure BHP 9000 — Slurry Rate • 50 Prop Concentration BH Prop Concentration 8000 — PCM Visc 7000- 40 6000- 30 5000- 8 4000- 20 ! 3000- 2000- �. 10 1000- 0 0 10:45:34 10:55:59 11:06:24 11:16:49 11:27:14 Time -hh:mm:ss ©Schlumberger 1994-2012 Schlumberger • • Schlumberger Client BP Exploration Alaska Well L3-03,Stage 9-11 District,Prudhoe Bay Formation,Wahoo 5,6&7 L3-03 Stage 9 BP Exploration Alaska L3-03 Stage 9-11 Treating Pressure 07-31-2015 Annulus Pressure BHP - Slurry Rate 7000 �— Prop t.oncentration 70 BH Prop Concentration — PCM Visc 6000 60 5000 ....---o• 50 4000 V 40 = ...... z.e,..43 3000 30 2000 ' r1/4„,.... 20 E. 1000 V — 10 0 • ...a.O�rl 'r' T 0 11:48:40 12:09:30 12:30:20 12:51:10 13:12:00 Time -hh:mm:ss ©Schlumberger 1994-2012 Schlumberger • • Schlumberger Client BP Exploration Alaska Well:L3-03,Stage 9-11 District,Prudhoe Bay Formation:Wahoo 5,6&7 L3-03 Stage 10&11 BP Exploration Alaska L3-03 Stage 9-11 - Treating Pressure 07-31-2015 - Annulus Pressure - BHP 6000 Slurry Rate Prop Concentration 60 - BH Prop Concentration — PCM Visc 5000 50 4000 40 1 3000 30 1.13 iv ,i141 2000 1 20 m E. 1000 10 0, _ 0 12:48:15 13:25:45 14:03:15 14:40:45 15:18:15 Time -hh:mm:ss ©Schlumberger 1994-2012 Schlumberger • • Schloniherger Client BP Exploration Alaska Well.L3-03,Stage 9-11 District.Prudhoc Bay Formation',Wahoo 5,6&7 L3-03 Stage 9-11 BP Exploration Alaska — TreatingPressure L3-03 Stage 9-11 07-31-2015 ^°^^^ Annulus Pressure 8000 — RHP 80 - Slurry Rate 7000 — Prop Concentration BH Prop Concentration 70 — PCM Vise 6000 60 500050 1. kr."-' flAiljill--- 4.-4.'...".-"4"" 1-0 --,-, $ 4000 .---‘—') 40 3000 i 30 2000 - 20 1000 r- 10 =' 0 -- J 0 11:46:20 12:44:40 13:43:00 14:41:20 15:39:40 Time-hh:mm:ss ©Schlumberger 1994-2012 Schlumberger • • Schlomherger Client:BP Exploration Alaska 77�� Well:L3-03,Stage 9-11 District:Prudhoe Bay Formation:Wahoo 5,6&7 L3-03 Stage 9 POD Additives BP Exploration Alaska L3-03 Stage 9-11 07-31-2015 7 • 1 70 Jonc Jnt `®' U2nc 6- J:605:0:DDap4icce:ocoo; ncPn60CidRa.Srte PdOaEePaa_ � PkOatePos550 3 I 4 I 40 i F !' 3- 0 30 1 2- lialAIMIN20 2U fil O. II- N 'MarLIN B. r 10 11:53:20 12:14:10 12:35:00 12:55:50 13:16:40 Time -hh:mm:ss ©Schlumberger 1994-2012 Schlumberger II Schlumberger Client:BP Exploration Alaska Well:L3-03,Stage 9-11 District:Prudhoe Bay Formation:Wahoo 5,6&7 L3-03 Stage 10&11 POD Additives BP Exploration Alaska L3-03 Stage 9-11 07-31-2015 7 70 J511LConc j J604 Cone ^^ U28 Conc 6- = J589 Cone s' Prop Con -60 1Clean Fluid Rat, Slurry Rate POD Road Gate Poe POD Deck Gate P 5 50 :41 22 1 1 4- r....6.— -40 1 ii 1 3- -30 4 2' -20 .Q g 1 B. 1- -10 I !"_— vo--. 12:52:56 13:26:16 13:59:36 14:32:56 15:06:16 Time -hh:mm:ss ©Schlumberger 1994-2012 Schlumberger • III Schlumberger Client BP Exploration Alaska Well L3-03,Stage 9-11 District.Prudhoe Bay Formation.Wahoo 5,6&7 L3-03 Stages 9-11 PCM Additive Plot BP Exploration Alaska L3-03 Stages 9-11 07-31-2015 7 , 70 L065 Cone Loll Conc Prop Con 6- �,y,� J580 Conc = Clean Rath Rani 6U Slurry Rate PCM Vise 1 5- 50 -40 I ti3 .1 0 i -30 9 1. 2,./. -20 i 1- hWWII -10 iiiii 0 tio 11:42:49 12:41:09 13:39:29 _ 14:37:49 15:36:09 Time -hh:mm:ss ©Schlumberger 1994-2012 Schlumberger I I a_I_= CNV 4-1/16" ----- - `"a` 'D • L 3-0 3 S Y NOTES: WELL ANGLE>TO'@ 10236'""MAX ACTUATOR= BAKER DOGLEG: 12.6'@ 10267'""CHROME TBG 8 LNR"" OKB ELEV= 69.55' f BF ELEV= 2 48.15' 2243' H 4-112"DREA MCA TCHER(10/25/15) ity_______1 KOP= 861' 20'COND, H ^-128' I Max Angle= 100'@ 11033' 2247' -14-1/2"HES X NIP,ID=3 813" Datum MD= 10032' 91 5#,A-53, Datum TVD= 8900'SS ID=19 124" H GAS LFT MANDRELS 13-3/8"CSG,68#,L-80 BTC,D=12-415" --) 4143' 11 ST MD TVD DEV TYPE VLV LATCH FORT DATE 4 4343 4010 27 MAG DOME RK 16 08/07/15 TOP OF CEMENT(03129115) -L -4200' 3 6830 6211 28 MMU SO RK 20 08/07/15 * *,c- 2 8156 7376 28 MIMU DI1A1 RK 0 06/08/15 *. t *; 1 8972 8088 31 MAG SPFAG RK 0 10/25/15 `► r4. .t TOP 7"OF LNR -{ 9091' I +�' k' ii1 9091' __9-5/8"X 7"BKR HRD-E ZXPN LTP,D=7.34" ' i;;0-44.i 9106' -9-5/8"X 7"BKR HMC HGR,ID=6.18' 9-5t8'CSG,47#,L-80 TCWVAM TOP/BTC, H 9252' ` r* ID=8.681" �! u L_9466' -4-1/2-HESS X NP,13=3.813" Minimum ID = 3.71" @ 9857' .. 4-1/2" FRAC PORT SLEEVES1",'.....!r+ 9497' ..44-1/2"NDPGC SAPPHIRE GAUGE,D=3.879" r +. r� 15 9532' _17"X 4-1/2"HES TNT PKR,D=3.856" LSA* P-'4:' 9569' -I 4-1/2"HES X NP,D=3.813" ., Ir-, , ? 9639' --I4-1/2"HES X NP,D=3.813' 0. : !+. 9649' --(7'X 5"BKR HRD-E ZXFN LIP,D=4.32" 4-112'TBG, 12.6#, 13CR-85 VAM TOP, H 9656' Dy/ 9656' H4-1/2'WLEG,ID=3.958" .0152 bpf,ID-3.958' 1..* --I ELMD TT NOT LOGGED 9673' --17'X 5"BKR FLEX-LOCK HGR D=4.33" 7"LNR,26#,L-80 VAM TOP HC/BTC-M - 9820' - ® ® 9683' -5"X 4-1t2'XO,OD=3.910" 0383 bpf. ID=6.276 4-1/2" FRAC PORT SLEEVES 4-1/2"HES SWELL PACKERS MD DEPTH SEAT SZ. ACTUAL SIZE 0/C DATE r MD DEPTH 0 cal t10 9857 3.71" 5-625" 0 08/04/15 11 9905 3-920" 9 10023 3.71" 5.625" 0 08/04/15 10 10071 3.920" 8 10242 3.71" 5.625' 0 08/04/15 9 10290 3.920" 122 7 10460 3.71" 5.625" 0 08/04/15 8 10591 3.920" 6 10719 3.71" 5.625" 0 08/04/15 7 10809 3.920" Cgt=121 5 10989 3.71" 5.625" 0 08/04/15 6 11078 3.920" 4 11414 3.71" 5-625" 0 08/04/15 5 11711 3.920" 3 11984 3.71" 5.625" 0 08/04/15 4 12125 3 920" ® 2 12221 371" 5.625" 0 08/04/15 3 12319 3.920" 1 12447 3.71" 5.625" 0 08/04/15 2 12572 3 920" .. PA 12678 N/A 5 590" C 06/05/15 '1 12799 2.992' '1 =3-1/2"SWELL PKR PBTD - 12777' .' ii :/-- 12561' I--I4-1/2"BKR SHF(-TOOL VERIFICATION SUB,D=3.89" 4-1/2"LNR, 13.5#,13CR-80 HYD 521, H 12791' \ � 12777' -{4 112"SLB CRC VALVE D=1.15' .0152 bpf,ID=3.958" / 12791' H4-1/2"X 3-1/2"XO,D=2.992" 3-1/2"LNR,9.2#,L-80 IBTNAM TOP, - 12858' Cal .0087 bpf,ID=2.992" i+ DATE REV BY COMMENTS DATE REV BY CONVENTS LISBURNE UMT 06/08/15 PKR 272 INITIAL COMPLETION 11/19/15 MS/JMD UFDA IED MWD WELL. L3-03 09/04/15 CJWJMD SET EV OTREV E PLUG(08/19/15) PERMIT No:"150180 09/04/15 DU(JM) TREE C/O(08/22115) AR No: 50-029-23535-00 11/09/15 JMG/JMD PULLED EVOTREV E R-UG(10/16/15) SEC.22,T11 N,R15E,346'FM. &562'EVIL 11/09/15 DJS/JMD GLV C/O(10/25/15) 11/09/15 JMG/JM)SET DREAMF:ATCHET2(10/25/15) __ _ BP Exploration(Alaska) • ! Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. C]Q l.6-- O 0 1 Well History File Identifier Organizing(done) Two-sided ❑ Rescan Needed RE CAN: OVERSIZED: NOTES: Color Items: ❑ Maps: Grayscale Items: ‹s: ❑ Poor Quality Originals: ❑ Other: El Other: r BY: ATP Date: I ) W 15 /s/ (4 f Project Proofing BY: Maria Date: I ' W /S /s/ imp Scanning Preparation 5 x 30 = /50 + czs = TOTAL PAGES / 78/ C-' (Count does not include cover sheet) Ai • BY: AD Date: 11/ I /s/ Production Scanning Stage 1 Page Count from Scanned File: / r J (Count does include covers eet) Page Count Matches Number in Scanning Preparation: YES i/V' NOOBY: � Date: (/Ai/5 /s/Stage 1 If NO in stage 1, page(s) discrepancie///s were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michel Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc • • o - 0 0 C. N o 9 11 . o Lgo 1 \ M O I --. N a a N d d d ,. M z C @ , (N6 • co N (n• u)N u)• (n OJ M1 p o� 0_ ! m � -�° M ° O L 21 v 2I Q 2 73 I a �I u �I o 0 0 N mI J Q• J M co -' J o ,- Q• M O �_ (h J N 0 o . I D I o M 0 0 D O O o M o o O J I- is 10 Q m m O m a J N N0 N O N Q N J N a "O •b J m N a. m w O I m @ m o1 m OI m NOI m 0' LI OI in of la N Lo CL o Z @ 'I Z Z E E E 1 0� oa o0 0 1 o p E F� Q a) m aci cc aci ,I c _I aci U ofw Moco l 71 01=I o1U co1 >- C O @ m 1 U U c I U c 0 < m>` c co I'll d(j LLa CO Ila' C W a-U JU J c J C JU co m l.L 0 O aNUUU1 l 1 l l I _O a U m - ao aUIa0 amaO m co 2 co 2 aa)J o o UCO UI I m Um m cIm ro Q 6. CI p p cO en @ 1 @ 1rc1Q m � o cl) - ' CO@� a) ai cI ai a) m aim ui @C Z c c • m 6- Q m, comQ pO ce N a E 0 O- n- ••,' (NO p0- .6:(NO • U� 0 ()((N 0CV 0 .,m• p� �lj B CO E! 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W N N N N N N N N N N N - WE a '1 O Y9 'CO O O (O CO (0 (0 O CO (0 (0 a- I N N N N N N N N N N N H V `o 0 I- N CO W 't w C N CL N Ie 0 C cn 1 _ in I co E Z a N Y w O N N Z Q O_ Q U ," - 0 U U U U U U U U U U ` o J U E V a _o ' a C7 d 0 '0 0 0 0 0 0 0 0 0 0 8' E o o 0 a 2 w w w w LU w w W w W ? 0 a CD c0.1 i i • o o '" 9 0 o N O _ IA O co O kli co Z O N o N U o o N d z H ` ✓ O z 1 7 d co as 1 Rs J co O N a_ O z 0 U W o Ce 0 W w J V m o Z Qlo J o C G o r g a, O a r E w 1 o v V U d 0 J co E 1 7 Q el J O to bA — (n V 0., Z to I 1 2N a I W < 1 COW '= 0 m d D p toa Q 1111 Q ° z E 0 Q a> 0 1 E Z LO d • 0) oo , N- N N co CO r II co N O co > I m T F O O LO CD N d N > f0a' E 0 N , d W c f0 O N V o CV g m c c U N Q 1 d 0 E o m mE E a 0 0 Q 00 00 21 50 18 bp • • Date 09/23/2015 2 6 7 0 Transmittal Number: 93460 DATA LOGGED /23/2015 M.K.BENDER BPXA WELL DATA TRANSMITTAL RECEIVED Enclosed are the materials listed below. SEP 2 4 2015 (BPXA/BHI MWD LOG DATA) AOGCC If you have any questions,please contact Analisa Steger at the PDC at 564-5439; analisa.steger@gmail.com; gancpdc@bp.com. Or as usual Joe Lastufka 564-4091. Delivery Contents for L3-03 from Baker Hughes 1 CD-ROM Containing Digital log and survey data. 1 Hard copy log of each type: • 1:600 TVDSS • 1:240 TVDSS • 1:600 MD • 1:240 MD • 1:240 MD Azimuthal Res Log 1 Hard copy of Directional Survey fALL1 6_,ed(44 Please Sign and Return one py of this transmittal to; gancpdc@bp.com Analisa Steger Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Meredith Guhl 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage,AK 99519-6612 • 215018 • 26270 BAKER PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc BP Exploration (Alaska) Inc. c EI Y/ fl (mandatory) Petrotechnical Data Center, LR2-1 EC WELL NAME L3-03 900 E. Benson Blvd. (mandatory) Anchorage,Alaska 99508 SEP 2 4 2015 FIELD Prudhoe Bay to acknowledge receipt of this data. (mandatory) AOGCC COUNTY North Slope Borough LOG TYPE LWD Rotary (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: Jul,2015 TODAYS DATE: 18-Sep-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Paul Canizares EMAIL: Paul.Canizares(c ilbakerhughes.com (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL CD CD ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #UI-1-1-IN I S #OF COPIES #OF COPIES #OF COPIESk 1 BP North Slope 1 1 EOA,PBOC,PRB-20(Office 109) � Attn:D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 East Benson Boulevard Anchorage,AK,99519 2 ConocoPhillips Alaska Inc. 0 1 1 1 Attn:Ricky Elgaricio/Sandra Lemke ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska I 1 I 1 I 1 I 1 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 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. 1 1 1 1� J Petrotechnical Data Center,LR2-1 �j.J�/-(�.SJr-rte— � � 900 E.Benson Blvd. es650 4t), `�� Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 3 5 3 3 0 TOTALS FOR ALL PAGES: 0 3 5 3 3 0 C -np cnrrrr Z w 0 .' y y a o • cam' oom w wNaN 419 W MIMI O o rr w w CD U) CO3 "' o o C w o 3 CD CD -. 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O CO N O O O O O O -,.1 8 O O - O O C) N N Wb N 0 W 0 W V O A O O O W 0 W Co A A v W co N N N A A 0) N Co A 0) CO Co N C.) 0) V -4 V 0 co — -4 N co -4 co c0 N N) N N CO CO > a W a =a 0 0in A A A A A A A A A A CO W CO CO W W CO W CO W CO W W W W W W 0 PJ Co N) -. —, —, — O O O O O CO 0 (D CO CO V -4 0) 0) (n CP A A W CO N N CO 01 W 0 Co 0) A N 0 J N -, 0) -+ 0) -) V N V N V C.) 0 C.) CO A �. -X W 0 W O 0 N A 0 0 — O N W N N V N A N 0 (D N (n V -+ V C2 0 CC CO (0 0 CO A 0 CO 0 O A V (n Na V O co Is N CO co (C W (n A W N 0 CO A 0) O V N 0 V N co CO 01 N A CO (O CJ V W CO V 01 CO V • • • cn Co j O 0 N N N O O o m CD 0 - 30 cn o rt m x vCT - - 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 „� O) O) (T A 03 N - o co W V 0) O) N (T 11 A A A W -co W N N N N C'') co co_ coON J N CONW COCN 000 COCN N CD 0 CO A CO(11 IV N co co V CT W CO 00) CVD CCO W COO W A V W W N V CAD A N W A CO N 00)) -. 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M CO O co O) CO N N U) N W W M '- N U) N O W W W co (O CC N- co Ca 0 O O W N M V 6 coN0 up N a N (0 •-• h 6 U) co- (o (0 (O (o (0 (o co- U) ( CO Z z ; o C F o O C co U) 4 n W M CO O N U) M M U) n U) M V CO N U) Ni- N N N O) M n M O 0) 0 Oi O) n (D O) c _0 0) V M O 0) W CO U) V M N O N U) CO CO W CO n n n n n n N n n a CO co CO- CO- CO- W OJ W CO- CO- CO- OJ W N CO- O a m E Lo m m Z U) 0) 0) N M CO 0 U) N O CO $E'' N- CO o M ' CO O sY n 0 n 00 N '- NLi N 0o P) r` (•) 0 0 0) co 0) co co U) co 0 0 0 Ops W n W U) M N o 0) W n Z z 0) W W W W W aO co W r n n a cd co oo co ao co co co co co co co co (0 0) .o 8 z o Q Q Q U E O U m W W W o W• 0 7 000 n W 0) 0 s} 0) 0) (0 (0 W 2 2 0 -.1 u7 O U) co O) - co V4 co O N N NLLCY CC N O o) r N- O c6 0) O N N O) M LU LU fr - ; V co co co co co co 4 .4a 4 .4 ' N U) 13 co co M M M M M M M M M M M Z Z Z E , 'N o d O] W Q Q V a g co o W ro n tip W co sf U) co co U) U) co v NN 0) 0) j " 0▪ r Q CO W N CO O .- (0 M M 0) n U) 0 a N n Q 6 O) O) n n O (O (O U) (o n n n N o 2_ W O) 0) 0) 0) 0a) 0) 0 0) 0) 0) O) 0) > (6 U V ., 0a) 0 CO e a E (COM E sU) N ' 0 Q ` 7 Q O N CO a 0 0 W fl' Q ^ n.0 p N-r " 0 0 0 O A U) ,..1, � C NZJ J J J 0 0) N 01N n U) N N 0 N U) 0 a) a N CO st U) U) CO N M W CO 0 C 0 E Q0) uV N0) cocco (O co 6 V co N N aQ n W co co N- N CO v U) conco co ' 0 O �':i •- N N N N N N N NO O c 0 c 2 — L ri V d a Q of a o c rn c o E •o :3 0 0 a .....0 0 .01 w C)0 a if) ?i 'S o Co t) . o co • Hunt, Jennifer L (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Thursday, August 20, 2015 2:12 PM To: Hunt, Jennifer L (DOA) Subject: PBU L3-03 / PTD # 215-018 Hi Jennifer, Please reference the following well: Well Name: PBU L3-03 Permit#: 215-018 API #: 50-029-23535-00-00 Date of Test: 8/15/15 Type of Test: IPT (Initial Production Test) Choke Size: 64 Choke Unit: 64ths Production Method: Flowing Duration (Hours Tested): 8 Top Reference (Top Perf MD): 9857' Bottom Reference (Bottom Perf MD): 12678' Tubing Flowing (Pressure): 0 Casing Pressure: 1750 Total Test (Rate f/ 0, W, G): 473 / 309 /7067 24-Hour Rate (0, W, G): 1420 / 926 /21202 Gravity (Oil, API): 29.3 Deg GOR (Gas-Oil Ratio): 14930 This well began Production on: 8/12/2015 Method of Operations on this date: Flowing 1 RBDMS1 AUG L 1 2015 • Or 7 g� • 77, ,v THE STATE Alaska Oil and Gas ®f Conse ation Commission TASKA t 333 West Seventh Avenue 0:1'144 101 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 XX, Main: 907.279.1433 ALAS' Fax: 907.276.7542 WWW.aogcc.alaska.gov David Wages Well Interventions Engineer i5 v IT BP Exploration(Alaska), Inc. a P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, L3-03 Sundry Number: 315-405 Dear Mr. Wages: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, aid,/ Cathy P. Foerster Chair DATED this /V day of July, 2015 Encl. TA A.,iA V E oSTATE OF ALASKA Jii„i 2 6 2i:i. ALASKA OIL AND GAS CONSERVATION COMM N Q�S 7 f `� IS APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AO GC 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate Q • Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: • 5. Permit to Drill Number: 215-018 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development a 99519-6612Stratigraphic 0 Service ❑ 6. API Number: 50-029-23535-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No I21 L3-03 . 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0034631 • /iPc, c 4$31 Z d -1,V./c PRUDHOE BAY,LISBURNE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12875 . 8779 - 12858 8781 Casing Length Size MD TVD Burst collapse Structural Conductor 80 20”91.5#H-40 49-129 49-129 1490 470 Surface 4095 13-3/8"68#L-80 48-4143 48-3832 5020 2260 Intermediate 9207 9-5/8"47#L-80 45-9252 45-8325 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"13.5#13Cr85 13Cr85 42-9656 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program a Exploratory 0 Stratigraphic 0 Development H Service 0 14.Estimated Date for Commencing Operations: _ 15. Well Status after proposed work: �//L/lam v7-L, Oil m Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG 0 Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Wages,David Email David.Wages@bp.com Printed Name .Wages, /David Title Well Interventions Engineer Signature Z-17/ Phone 907.564.5669 Date 67z 1$ COMMISSION USE ONLY Conditions of appro .1:Notify Commission so that a representative may witness Sundry Number: 315- yoS Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Poo ii-) fov v1-7 ct-7-r c r--, rCqz rii,rcc/ fo 7`h -c --cr C pc c c.5 C I C t✓Y, /Ccr I 0/3Clc5,,,-C re-V iS7'- j wrti'w. F- cfcci--5 _ Gv-� q ' wr1/ 45 �t1c-i -E(-1 ,rve f / f ac:�- ;-jc25- ZS-3 - Spacing Exception Required? Yes 0 No 137 Subsequent Form Required: /7) — 4 6)4 APPROVED BYTHE Approved by: / i' ✓ COMMISSIONER COMMISSION Date: 7 le-.l c Y 1- -7/6/15- ORIGINAL , --,.0.,s...-- Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 1 months from the date of approval. Attachments in/Duplicate RBDMS) JUL • q 2Q1 t-.i 7/6/zor; 7fr 4r . • • Date: June 16, 2015 Subject: L3-03 Fracture Stimulation From: David Wages Engineer, BP Alaska o: 907.564.5669 c: 713.380.9836 To: Chris Wallace Attached is BP's proposal and supporting documents to fracture stimulate the Lisburne interval of well L3-03. Well L3-03 is a Lisburne producer with two penetrations of zones 5.2-7.3 as a U shaped infill well in an —700 acre open area. The well will be stimulated with a combination of acid stages and hydraulic fracture stages. The Wahoo 7 and any conductive faults will be stimulated with an acid job (see pump schedule below), whereas the matrix areas of Wahoo zones 5 and 6 will receive a fracture treatment. - We are requesting a variance to sections 20 AAC 25.283, a, 3-4 which require identification of fresh - water aquifers and a plan for basewater sampling. Please direct questions or comments to David Wages . Affidavit of Notification (20 AAC 25.283,a, 1) Partners notified 6/11/2015: ConocoPhillips Exxon Mobil Chevron Department of Natural Resources Plat Identifying Wells (20 AAC 25.283, a, 2, A-C) and Faults (20 AAC 25.283, a, 11) L _1 - -I- a - `'{_ 3 L2 - ti' . Faults Throw Mag and Dir A. 1 40-50 5 U.,* , '"i' 8 2 30-40 N 1' 'r'-_-„ ,, - - ,,;.- 3 15-205W Iii 15 k" 'M` ill 4 20-25 NE '.' 13 'N.,,, ,,, 5 20 25 SW `,� ti . .... . 6 10 16 NW i'ti- 7 10-15 SE 8 30 40 S S ` 9 40-45 S ., 10 25-30 NW El , ,, ,,,,,_,„, ._ 1.2' -. s4 11 60-70 NW 12 15-20 W ` 13 20_25s 14 5 10 E .,,.. ._.. .....r,,,,_ } 4 `1 15 15-20 SE 'T. '" 16 25-30 W ^t` .' 17 5-10 E i 1. .. --/- _ ..-. • Ill } Red lines indicate approximate length and location of fracs. Blue lines indicate location of Acid stimulations. Producers within 'h mile of L3-03: L3-02 Per the plat above, there are no water wells within 'h mile of the subject well. The above map shows 4 faults of concern, 6, 5, 4, and 3. Faults 3 and 7 are well away for stimulation chemicals. The remaining faults are either further away or roughly parallel to the primary fracture plane. The well will be stimulated with a combination of acid stages and hydraulic fracture stages. The Wahoo 7 and any open faults (where we took losses while drilling) will be stimulated with an acid job (see pump schedule below), whereas the matrix areas, including of Wahoo zones 5 and 6 will ! ! receive a fracture treatment. Given the above information, all fracturing fluids should remain within the matrix areas of zones 5 and 6. Exemption for Freshwater Aquifers(20 AAC 25.283,a,3-4) Well L3-03 is in the East Operating Area of Prudhoe Bay. Per Area Injection Order No.4 dated July 11, 1986 where ARCO (BP) Alaska requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within the Eastern Operating Area of the Prudhoe Bay Unit for purposes of enhanced hydrocarbon recovery and the disposal of non-hazardous oil field waste fluids. Finding #5 specifies that: "Within the Project Area, injection into, though, or above fresh water aquifer or underground source of drinking water will not occur." To / comply with this finding, the operator must confirm integrity of the well that will be injected in per the injection order and the integrity of wells within �/z mile radius per 20 AAC 25.283. These requirements will be met and proven in this document, thus allowing BP exemption from 20 AAC 25.283, a, 3-4 which require identification of freshwater aquifers and establishing a plan for basewater sampling. Detailed Casing and Cement Information (20 AAC 25.283,a,5-6) Well L3-03 was spudded on 3/13/15. A 16" hole was drilled to 4143' MD (3840' TVDss) where 13-3/8" 68#/ft, L-80, BTC csg was run and cemented in place with 916 bbls of 11 ppg LiteCRETE* lead and 124 bbls of 15.8 ppg Class G tail cement with good returns (478 bbls cmt) to surface. After cement was set, the casing was tested to 3500 psi for 30 min for a good test. A LOT to 14.41 ppg EMW was performed after the shoe was drilled. A 12-1/4" intermediate#1 hole was drilled to 9252' MD (8330'TVDss), where 9-5/8", 47#/ft, L-80, TCII casing was run and cemented in place with 277 bbls of 11.5 ppg LiteCRETE* lead and 84 bbls of 15.8 ppg Class G tail cement. Plug was not bumped on calculated strokes for 96% pump efficiency, and an additional 3 bbl displacement (1/2 shoe track volume)was pumped without plug bump. Total losses from cement exit shoe to cement in place was 5 bbl. 9-5/8" casing was tested to 4340 psi for 30 minutes for a passing test per BP Tubular Test Criteria CRT-AK-10-45. A FIT to 11.5 ppg EMW was performed when the shoe was drilled out. A USIT run on 4/5/15 indicated that we have isolated the Ivishak from the West Sak 1/Ugnu per BP requirements, with 200 ft TVDss of good isolation. A 8-1/2" intermediate #2 hole was drilled to 9820' MD (8808' TVDss). A 7", 26 #/ft, L-80 VTHC liner was run and cemented in place with 35.3 bbls 15.8 ppg Class G cement. Plug was bumped with 0 losses from cement exit shoe to cement in place. 7" liner top packer was pressure tested to 4000 psi for 30 minutes for a passing test. A USIT run on 4/5/15 indicated that we have isolated the Lisburne from the Ivishak per BP requirements, with 105 ft TVDss of good isolation. A 6-1/8" production hole is planned to be drilled to 12,982' MD. A 4.5", 13.5 #/ft, 13Cr, Hydril 521 sliding sleeve and swell packer completion will be run. About 10 sliding sleeves and 16 water swell packers are planned to be run; the final sliding sleeve and swell packer count is subject to change based on findings during drilling (faults, logs, fluid contacts, etc). 4.5", 12.6#, 13Cr-85, VAM Top tubing is planned to be set, with the packer at 9540' MD. Drilling operations on L3-03 are anticipated to be finished on 6/16/15. • Accurate Pressure Ratings of Tubulars and Schematic(20 AAC 25.283, a,8) TTS- CNY4-1116' SAfl1..TES D _... FMC J M D DRAFT L3-Q3 SAFETY NOTES:StB_L ANGLE'70'41r 10298'•'"MAX ,AGTI..WToR- __... °OGLE& 32.6'441028r•••cFRORIETBG&LN ' R" OKS H c:,; __T 69 55' I 81 14 FV= 48 15' 'IMP- 881' 20'COIO, -115 M9.An - 100.1111033 91.5#,4-53, ( 2247' H4.1/2"HES X Fs+,D=3.813' Datum = 10032' D=19.124' DMuntNVD- 8900 55 ""'"`""'" GAS UFT AIAN URELS 113-3/8'COG 684,L-80 BTC,0=12.415' 1-1-iii87-1., ST 583 TVO DEV TYPE VLV LATCH FORT Q 1E- _.... 4 4343 4010 27 PAO DOR FKP - 06/08/15 (TOP OF CEMENT(0329115) H ,.4201' I 3 6830 6211 28 WC Me P3< 0 088))811$ 2 8156 7376 28 MIA) OW RK 0 050515 �� 1_6972 8088 31 MG owe _ RK 0 06108/15 V C TOP rOF UV' ........978)1'_.._ 578'X r w FRI1EZXPN LTA D•7-34' ei.�a I• 98108' 9-576"X r HNC C HGR O=6.16'J 9-518"CSG,.474.L-80 TCVIAM 7061876 H92/f"2' Fv D=a,aor 0 F. k i2;FIL XNP,D=1013" Minimum ID=3.813"(�2247' r �+ q- it 4-1/2"HES X NIPPLE 9497 4 ,;2't,L`PG.CSAPM- GA Ix,D=3.879" IA ��,- 9532' -I r X 4-1/2-HI9311NTMRG=3.Bee• I ot9569' 4-112' B Fx rip,D=3.813" I 4 0639"1.-{e_lrrtr.axl,sRn=:n1.r� flig 9649' -17 X 5.BAR FAD-F 7XPN OA D+432" I 641'.4=112'TSG,12.84.13CR•1 VAM10P, 91ae' ►eZ n ►�7 9668' Na 1�2'W1.EG,0=3.956.1 .01$2 t+Dt.0-3.958• • 1 -'- II Haw 11 NOT LOOGw I ,� R, 9673' H T.x 5'8118 FLEX-LOCK t1C R.0=4.33` I r LI26#,L-80 VASA TOP HGBTC�M 8626' t 9883• 115`X 4-1t2"XO,ID=3.910' .0383 bpf.D=6.276 •NO IN 4-1/2"FRAC PORT SLEEVES 4-112'1*0 3WELL PACKHi9 - _ - ' •.• NJ ttH111 SEA Ihi. AURALSILL LA: LA le N:) U14'III 11 ,-•_:. 10 9857 3.137" 5.625" C 068)5/15 11 9905 3.920' .m. 9 10023 2.947' 5.825' C 06805/15 10 10071 3.920"1 _'' 8 10242 2.857• 5.825' C 06005/15 9 10290 3970" ,-;Ili,_, 7 10480 2.767' 5.625" C 08105/15 8 10591 3920" ... 8 10/19 2677` 5.825` C 06105/15 7 10809 3.920" '•_.x, 5 10989 2.587' 5.825` C 068975/16 6 11078 3.920' •m• 4 11414 2.497" 5.625' C 06/05/15 5 11711 3.920"1 '-'1=''''' 3 11984 2.412" 5.825' C 068)5/15 4 12125 3.920" •1.• 2 12221 2.332 5.625' C 06105/15 3 12319 3.92)' 1 1244/ 2.252` 5.625' C [181)5/15 2 12572 3.820' PIA 12078 NIAA 5.590" C 068)5/15 7 12799 2.992" •m• '1=3.1/2"SWELL P01 MID + 12777' ''lir'- 12581' -j41/2'B1CR SHIFT T00 NOTIFICATION SLB.L=3.89' I 4-12"LIFI 13.54,13CR-$I 11YD 521 1--: 12791' • ell�•_ 12777 4112'SLB CRC VALVE,D=9.15' 0152I5pf.D=3.958' - ,V 12791' 4-1/2'X3.1/2"XO,D^2.992' I 3-112"LSR 92#.1-80 BTNAM TOP, -I 12858' ism 0067 tat,13=2.992' g j21 MO- REV[3Y COMMENTS ENTS l I It---i-4--v Ky' coIMIENTS LISBl13F UV K10U15 P84R272 INTTAI...COMPLETION W191.-1.3-03 06717/IS MI) ORRGI-CCORRECTORS HERATPat''150180 as 1141 811079736 I',00 SIC 72,I t 1IµR14,146'14.11.4 St,/!WI ( BP Exploration(Alaska) Name/Size Weight Grade ID Burst,psi Collapse,psi 13-3/8" Surface 68# L-80 12.415" 5020 2260 9-5/8" Production 47# L-80 8.681" 6870 4760 7" Liner Production#1 26# L-80 6.276" 7240 5410 4-1/2" Liner Production #2 13.5# 13Cr80 3.92" 9020 8540 4-1/2" Tubing 12.6# 13Cr85 2.958" 8430 7500 • • Wellhead: FMC manufactured wellhead, rated to 5000 psi. Tree: 4-1/16" 10,000psi Tubing head adaptor: 13-5/8" 5,000psi x 4-1/16" 10,000psi Tubing Spool: 13-5/8" 5,000psi w/2-1/16" side outlets Casing Spool: 13-5/8" 5,000psi w/2-1/16" side outlets • • Geological Frac Information (20 AAC 25.283,a,9) Formation MD MD TVDss TVDss TVD Frac Lithological Desc. Top Bot top bot Thickness Grad TKVK/BSAD 9632 9824 8579 8743 164 0.711 Shale TLSB 9824 9858 8743 8771 28 0.58 Carbonate TLWH72 9858 9881 8771 8790 19 0.56 Carbonate TLWH71 9881 9911 8790 8814 24 0.54 Carbonate TLWH70 9911 9929 8814 8828 14 0.56 Carbonate w/Shale Bot TLWH63 9929 9976 8828 8862 34 0.58 Carbonate TLWH62 9976 10022 8862 8893 31 0.56 Carbonate TLWH61 10022 10087 8893 8932 39 0.55 Carbonate TLWH60 10087 10137 8932 8958 26 0.56 Carbonate w/Shale Bot TLWH54 10137 10165 8958 8971 13 0.58 Carbonate TLWH53 10165 10218 8971 8992 21 0.58 Carbonate TLWH52 10218 N/A 8992 9027** 35** 0.56 Carbonate Invert 10424 10424 9025 9025 N/A N/A N/A TLWH52* 10824 N/A 8986 8951** 35** 0.56 Carbonate FIt 3* 10934 10934 8971 8971 N/A N/A N/A TLWH53* 11054 10824 8952 8986 34 0.58 Carbonate TLWH54* 11141 11054 8938 8952 14 0.58 Carbonate TLWH60* 11345 11141 8909 8938 39 0.56 Carbonate w/Shale Bot FIt 4* 11429 11429 8898 8898 N/A N/A N/A TLWH61 * 11705 11345 8863 8909 46 0.55 Carbonate TLWH62* 11915 11705 8829 8863 34 0.56 Carbonate Frac Zone* 12000 12000 8815 8815 N/A N/A N/A TLWH63* 12212 11915 8786 8829 43 0.58 Carbonate Frac Zone* 12250 12250 8782 8782 N/A N/A N/A TLWH70* 12312 12212 8775 8786 11 0.56 Carbonate w/Shale Bot TLWH71 * 12520 12312 8752 8775 23 0.54 Carbonate TLWH72* 12698 12520 8733 8752 19 0.56 Carbonate TLSB/BKVK* 12858 12698 8711 8733 22 0.58 Carbonate w/Kavik top TD* 12875 8709 N/A TLWH51 9027** 9012** 15** 0.56 Carbonate TLWH50 9012** 8995** 17** 0.58 Carbonate w/Shale Bot WH50 Shale 0.711 Shale *Invert Section **Estimated (well trajectory never crossed) The shale layer between Wahoo formation 5, 6 and 7 have an anticipated frac gradient of —0.71 psi/ft ✓ Mechanical Information of nearby wells(20 AAC 25.283,a, 10) Per plat above, the following wells have been reviewed for casing and cement information: L3-02 Spud Date: 9/13/1986 7" 29#/ft, L-80 production liner set at 13,215' MD in a 8-1/2" hole, cemented with 103 bbls (420 sacks) of 14 ppg 35% Pozzolan/65% Class G cement. Plug was bumped, and liner was tested to 3000 psi. 3-1/2" x 2-7/8" tubing set at 12,285' MD, packer at 12,270' MD and 11,860' MD Perforations: 24 intervals from 12,172' to 12,840' MD • • Summary Hydraulic Fracture Program (20 AAC 25.283,a, 12) (Detailed program included) -g7$ � 4 s..s Tvb = Topo�'—Ss�ial/•wc�g./ r All Bra ct//G4/' _r_pa t,t s MD Profile Expanded L3-03 e-�,ne:° —P.` " �Ne'CSe�_' - t South ®SI?sae. OM Swig P«a,rs North 8709- "i101 C-85116'1VOss -... I - � r k 10U93S. Fit.114M I ,.•.'� " a. n FM MO FCP 9.0V aAOfVOs .. ..omP ip lj� cel Kavik `-r �mMetawo 1. aoo.. '...1.,.— Y A '�- t„u.arosny MAIM fir _�� .rn—. 7,8-/?r /d- ezen IH C7_U+ t 60 .� A �/ S(SD%14'7a7a1TVW i .+r'�,, �, (l Ai�'/1 IIS / Si. na oosair aluiva. 5 8850 I� 4 A- I lone F II A I I 8999 X na4K01k14y7a9ay1Vaal , ttt C TL61A1v4/4461'laeBatYax _,,,....I 8950 • ir......._—. ,MI I 9800- • F . F F —!11111 J—a--'""1 SOU I '1411110011;1- Invert ut low 51 stave 5.11 684 I I #10424./ Zaae4 I I II HI0 . , . . . . 8 , , , . , , , , , , , ,i . , J 0 -9150506 , 1 4 ' a 9 8 9 $ _ _ _ _ _ w v _ _ _ 8 8 8 8 $ 4 8 4 = = 8 8 0 0 _ _ Measured Depth Above is a cross-section of the wellbore. Sliding sleeves or fracports are labelled with grey rectangles and the swell packers (external casing swell packers) are labelled with the black rectangles, both of which are along the wellbore. Sleeves that will receive an acid treatment are labelled with an "A" in the blue box above the sleeve whereas the sleeves with a "F" above them are the sleeves that will receive a hydraulic fracture treatment with sand laden fluid. L3-03 will receive 6 acid stimulations throughout the lower completion as well as 5 frac treatments. / Every acid treatment will have the same pump schedule and every sand frac will have the same pump schedule per below. Acid treatment schedule: FLUID PUMP DIRTY VOLUME CLEAN VOLUME STAGE AVERAGE COMMENTS TYPE RATE STAGE CUM TO7 J06'.STAGE CUM TOT JOB a PPA IBM 18811 (BBC1 [BBL) [BBL) (BBL) [661) Comments_ :Hyd Fracport i Mania 2n 7 i Vol to Pat 176 -- - 5 0 i Hyd Fracport i Pad i WF 127 i 40 24 24 i 330 24 24 s 330 6 1 0 i Hyd Fracport i 20%SXE i 28%SXE i 5 38 62 368 1 N/A NIA F NIA Max Rate per Rosso. 7 0 :Hyd Fraepon: 20%VOA i 20%VOA i 5 24 86 1 392 ! NTA NIA ___N!Au • Max Rate per Presse HO i 0 HFraoporti 2800 SXE 287 SXE; 5 38 124 430 NTA N/A } } NIA Max Rate per Pressure 9 i 0 i Hyd Fracport; 20%VOA i 20%VOA; 5 24 148 1 454 NIA NSA I. NTA Max Rate per Pressure 10 1 0 :Hyd Fracport: Over/lush i WF 128 i 40 52 200 1 506 52 76 I 382 Max Rate per Ressue1Time 11 1 0 i Hyd Fracport i OF.Drop Ball i WF 128 i 5 11 211 1 517 11 87 I 393 Compensate for Bel Fall 12 0 :Hyd Fracport: Ocodlush 1 WF 128 : 5 162 374 , 680 162 250 : 556 Ball Lard+100bbls,increase rate cher ball land Hydraulic fracture treatment schedule: FLUID PUMP DIRTY VOLUME _ PROPPANT CLEAN VOLUME STAGE AVERAGE COMMENTS TYPE RATE STAGE GUM TOT JOB STAGE CUM SIZE STAGE CUM TOT JOB • PPA (BPM] ,(BOLI (BOL) (LOS) LBS (BBL( (BBL) (BBL) Comments to Pae:.. 162 ) (B .SCO.)oa4Ba4. 37 0 Fracport a5 'ad YE 128 : 40 250 250 : 2233 0 0 250 : 250: 1,738 OropRMetoLardBa 38 1 Fracport 45 -gyp add : YF 128 40 52 302 2285 2,095 2,095 20-40 50 i 300: 1,788 39 3 Fracport 45 add : YF 128 i 40 55 357 1 2340 6.144 8,238 20-40 49 1 349 i 1,037 40 5 Fracport 05 . : YE 128 40 58 415 1 2398 11,038 18,276 20-40 48 i 398: 1,884 41 7 Fracport a5 : YF 128 i 40 125 540 2523 26.297 46,574 20-40 96 1 493 i 1,981 42 9 Fracport 05 : YF128 i 40 175 715 2896 47.794 94,388 20-40 126 i 619 : 2,107 43 0-_-__.Fracport v5 Al. , YF128 : 40 30 745 • 2728 0 94.368 30 : 649: 2,137 I7rop,ate to Orop Bal Bal • S The final pump schedule will include the above acid/fluid/sand volumes per the respective stage: Stage Desc. Zone/fault Treated Frac Frac TVD TVD Frac height length Frac top bottom 1 Acid WH 7 N/A N/A N/A N/A 2 Acid WH 7 N/A N/A N/A N/A 3 Acid Fault in WH6 and 7 N/A N/A N/A N/A 4 Acid Fault in WH6 N/A N/A N/A N/A 5 Frac WH5 and 6 210' 175' 8786' 8995' 6 Frac WH5 and 6 • 210' 175' 8986' 8995' 7 Frac WH5 and 6 270' 150' 8828' 8995' 8 Frac WH5 and 6 - 270' 150' 8828' 8995' 9 Frac WH5 and 6 _ 270' 150' 8828' 8995' 10 Acid WH 6 N/A N/A N/A N/A 11 Acid WH 7 N/A N/A N/A N/A The maximum horizontal stress has been determined to be nearly parallel to the wellbore, this is based on image logs taken while drilling as well as historical information. Image logs of the two faults and two fault clusters crossed while drilling in the Lisburne show these as perpendicular. The maximum horizontal stress means that the induced hydraulic fractures will be parallel to the wellbore as well as perpendicular to the faults. This means that care need to be taken when placing swell packers and in determining which faults would receive a sand frac treatment. Per the above cross- section, drilling did not see losses when crossing faults 4 and 5 whereas faults 6a and 6b caused significant losses. This information combined with the image logs taken indicate that faults 6a and 6b are non-sealing faults that may be a conductive pathways into the confining layers. Faults 4 and 5 did not cause losses and appeared closed on the image logs, for this reason and to improve the chances of success, a sand frac treatment is planned for these intervals. Maximum Anticipated Treating Pressure: 6500 psi Due to the horizontal nature of the well, we are unable to specify a MD for the frac height. The above values were calculated using modeling software. Surface pressure is calculated based on a closure pressure of —0.58 psi/ft or 5200 psi, this combined with the anticipated net pressure to be built and the friction gives a surface pressure of 6500 psi at the time of flush. The frac height is primarily based on closure pressure differences between the confining shale layers harder, more brittle carbonate reservoir. Average confining layer stress is anticipated to be —0.7 psi/ft. Half length is based on confining layer stress as well as leak-off and formation modulus. Given the values, the above half lengths are calculated. Pressure Test Information (20 AAC 25.283,a,7) Per the frac program, the both the tubing and the IA will be pressure tested. The IA will be tested to 4500 psi and the tubing will be tested to 5000 psi (110% of max differential of 4500 psi). PRV setting procedures and annulus monitoring: Maximum Allowable Treating Pressure: 7300 psi Stagger Pump Kickouts between: 6935 psi and 6570 psi (90%to 95%of MATP) Global Kickout: 6935 psi(95%of MATP) IA pop-off set pressure: 3375 psi(75%of MIT-IA) Treating line test pressure: 8300 psi • • Sand Requirement 377,500#20/40 Carbolite Minimum Water Requirement 6,000 bbls (pump schedule: 5490 bbls) SXE Acid Requirement 19,200 gal VDA Acid Requirement 12,000 gal IA Hold Pressure 3000-3200 psi (IA pop-off @ 3375 psi) OA Monitor and maintain open to atmosphere There are three overpressure devices that protect the surface equipment and the wellbore from overpressure. Each individual frac pump has an electronic kickout that will kick the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are set between 90% and 95% of the maximum allowable treating pressure. There is the primary pressure transducer in the treating line that will trigger a global kickout which will kick all the pumps into neutral. Finally, there is a manual kickout that is controlled from the frac van. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. /�; L3-03 Rig Up cf)Traesaver mougated on wen Inner iautrloa Luz 1.01 ►MI 4.2M111-71—M4 D�xttcmer� 1 071 tIP.2I1JE hue `j pump for de pra sure :eatrol 41;111 Cklean s Track :a[izsilo • . 1 Fr_,T.3i1: PLC: ■ — Frac Tank Fr_:Tank L — — Fray Tank • • Chemical Disclosure(20 AAC 25.283, a, 12) CAS Number Chemical Name Mass Fraction - Water(Including Mix Water Supplied by CtrentY• -82% 66402-68-4--- ----- Ceramic materials and wares,chemicals -14% 7647-01-0 --._- Hydrochloric acid --_-- ---_ -3 Yo..... ... 64-18-6 =orm is acid <1% 9000-30-0 Guar gum ,1 Y. 149879-98-1 Erucic amidopropyt dinelhyl betaine <1% 67-48-1 2-h dtoxy-N,N,N-aineUryletloMmiium chloride <1% 67-63-0 Propan-2-ol --- ._._ <1% 107-21-1 Ethylene Glycal <01% 7727-54-0 Diammonium pe oxidmiphate <0-1% 67-56-1 Methanol <0.1% 61790-660-1 Am ines,tallow alkyl,acetates <0.1 K 129898-01-7 2-Propenorc acim polymer with sodium phosphnate <0.1% 6381-77-7 Sodium erythmrbate <01 X 111-76-2 2-mutoxyecbancl <0.1.X 1310-73-2 Sodium hydroxide limpuritgi <0.1 X 65322-65-8 1-(1-Napbthytmetnyt(quinolinrum chloride <0.1 X 75-12-7 Formamide <.0.1 K 25038-72-6 Ynryfide ne ddoride/meth latrybte copolymer <0.01% 64742-94-5 --._. Heavy aromatic naphtha .....__.._._....... <0.01% 72480-70-7 Benzyl qui oinum chloride ---.._..___ _.._._...--...<0.01 68131-39-5 C12-15 alcohol ethyoxylated <0.01% ..__-------�_ 34398-01-1(3E0) _._..____..._ Linear C11 alcohol ethoxy$ate(3eo) _ <0.01% w 34398-01-117E01 _---_ .._.._._.__Linear C11 alcohol ethoz5 ate(leo} -_._-- ..__.f__... <001%__...._..-- 68153-30-0 Amine treated saneaite day <0.01% . 11138-66-2 Gum xanthan <0.01% 78330-21-9 Alcohol C11-14,ethox3lated <0.01% 64-19-7 Acetic add <0.01 K ---Reaction product of:acetophenone,hoemaldehyde cydbt exy amaw,methanol and acetic ---- 224635-63-6 and <0.01% 1330-43-4 Sodium temraborate <0.01% 7647-145 Sodium chloride <0.01% 9003-11-6 .....-_.__.... Methyl asinine polymer with oikane <0.01% 91053-39-3 Diatomaceous earth,calcined <0.01% 107-197 -_—_--- -.._ Pr_opargyl _..._. -.. .... .._.._._-...__..�_.........._<0.01% 30846-35-6._.___. . E ayfatedpra90 to 14_nonlrR et al-formalddryde resp <.0.01% 61790-12-3 Fatty acids,tall-ad <0.01% 10043-52-4 Caloum Code <0.01% 78330-19-5 Alcohol,C7-9-iso,CS,ethoxytated <0.01% 8002-09-3 Pine al <0.01 K 78330-20-8 Alcohol,C9-11-64,CIO,ethoxyrlated <0_01 X 68989-00-4 Quaternary'ammonium compounds chlorides derivatives <0.01% 95-63-i1,2,4 trinettrykienzene <0.001% _-- ...52624-57-4 TrinethyldPopane ,,mopoxyiated <0001%_ 78330-23-1 A@coholsC 11-14iso-C13-riches ethoxytated proporg3lated <0.001% 7631-86-9 Siicon Dioxide <0.001 Y. 10377-60-3 Magnesium nitrate <0_001% 25322-68-3 Pofyfoxy-1,2-e anedly1),a-hydro-w-hydroxy-Ethane-1,2-diol,ethoxylated <0.001 Y. 587742-9 4etfrytoct-1-yn-3ot <0.001% 98-86-2 I Acetophenone <0.001% 139-07-1 Benz ylauryidiimethyfammonium chloride <0.001% 26172-55-4 T___._.._-_ ._._._..._.._5 foro-2-methyl-2h-isotivazdot-3one..-.......-_.__...._ .._......_<11001 Y --_. 14807-96-6 -__ _-_ ---_ _.... Mag_tletlara sauna h.ydrate.Oat) -.... -._. ._<0.001% 50-00-0 Formaldehyde(impurity) <0-001 K 778630-3 Magnesium chloride <0.001 K 26062-79-3 Ammonium,diaipldimethyl-,chloride,polymers <0-001 K 71011-03-5 fatty amine carboxylate <0.001% 91-20-3 _-.. Naphthalene _.. _.-... <11001% 111-46-6 2,2"-oxydiethanol(impurity) <0.001% 9002-84-0 poly(tetrafluoroeti ylene) <0.001% 139-08-2 Dimethytbentylmynstylammonaxrr chloride <0.001% - 2682-20-4 2ruthyFNresothwml-methyl <0.001% 100-44-7 Chlorounethylbenzene -,.._. <0.0001% 14464-461 Cristobalite ._. <0.0001% 14808-60-7 -_.. Quartz,Crystalline silica _ <0.0001% _._ ..... � 744740-7 Potassium chloride(impurity) � <0.0001%......._.___. 143-18-0 Potassium oleate t <0-0001% 122-18-9 eenzyldimethylammordum chloride <0_0001% 127-08-2 Acetic acid,potassium salt i <0.0001 34 Ictal I,0% RECOVED 41, JUN 26 2Ji STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION k.. AFFIDAVIT OF NOTICE OF OPERATIONS LBefore me, the undersigned authority, on this day personally appeared ��pt t)t C/1 le:5, who being duly sworn states: 1. My name is David Wages. I am 18 years of age or older and I have personal knowledge of the facts stated in this affidavit. 2. I am employed as an Engineer by BP Exploration(Alaska) Inc. ("BPXA")and I am familiar with the Application for Sundry Approvals to stimulate the L3-03 Well (the "Well") by hydraulic fracturing as defined in 20 AAC 25.283(m). 3. Pursuant to 20 AAC 25.283(1), BPXA prepared a Notice of Operations regarding the Well, a true copy of which is attached to this Affidavit as Attachment 1 ("Notice of Operations"). 4. On June 11, 2015, the Notice of Operations was sent to all owners, landowners, surface owners and operators within a one-half mile radius of the current or proposed wellbore trajectory of the Well. The Notice of Operations included: a. A statement that upon request a complete copy of the Application for Sundry Approvals is available from BPXA; b. BPXA's contact information. Signed this 25nd day of June,2015. aing - 1 L_ (Signature) / STATE OF ALASKA THIRD JUDICIAL DISTRICT Subscribed and sworn to or affirmed before me at AThi\xittAintl e / on the 2- day of the_ , 20 /,S. • • gnature of Officer .4:'1 N:14 Title of Ofticer NOTARyi A1I3LIc4 To: Well Services Operls Team Lead Date: . 6/1/2015 Wireline Operations Team Lead VER1 AFE: X3:016C6-C: PREPOST From: David Wages-Well Intervention Engineer IOR: 1184 Est.Cost: $1800K Subject: 3-10 -Post Drill Procedure Attached is the post rig procedure for the 3-10 ulti-staged frac completion. The first stage is initiated via hydraulic frac port which all umping of balls to open subsequent stages. The post rig procedure includes the following major steps: Category Step Description O 1 PT Tree,PPPOT-T, Pull TWC S 2 Pull B&R,Pull DCRV,Pull DGLV, install Circ valve,set DGLV, Pull RHC, Set Evo-trieve, Circ packer fluid, Pull Circ valve and install DGLV,MIT-IA,MIT-T,Pull Evo-trieve F A/SL 2 Circ Pkr fluid F 3 Acidize and Fracture Stimulation Treatment C 4 Post frac FCO S 5 D&T,Install Plug O 6 Install TWC,Change out WH,Pull TWC S 7 Pull Plug T 8 Post frac flowback Last Test: New completion.No test yet. Max Deviation: 40° at tubing tail, liner is horizontal. Perf Deviation: —100° @ 10,555' MD in horizontal liner. Min. ID: 3.813"X Nipples at 8847', 8915', 8987' MD Last Downhole Ops: Grassroots drill, set liner&ran tubing. TWC & B&R Installed. Latest H2S value: New well, no data. Closest offset: 50 ppm BHT & BHP: 185° F & 2700 psig @ 88400' TVDSS Contacts Office Home Cell David Wages 564-5669 713-380-9836 Josh Allely 564-5732 907-350-7362 • Valve Shop PT Tree to 10,000 psi, PPPOT-T, Pull TWC 1. Pressure test tree and valves to 10,000 psi. • Monitor tubing hanger packoff void during test 2. PPPOT-T to 5,000 psi unless already done. 3. Pull TWC 4. Ensure bonnet is installed on tree so SL can RU to the well. Pull B&R, Pull DCRV, set DGLV, Pull RHC, Set Evo-trieve, Pull DGLV and Slickline install Circ valve in Sta 1, Circ packer fluid, Pull Circ valve and install DGLV in Sta 1, MIT-IA, MIT-T, Pull Evo-trieve Please note: • A 4-1/16"10K Tree was left on the well, so that the rig's substructure could be moved off. We will use this as our frac tree. • A 5K Production Tree will be installed after the well is hydraulically fractured and cleaned up to ASRC. 5. Pull B&R 6. Pull DCRV in station 4 7. Pull dummy in Sta #1 @ 8317' 8. Install Circ valve in Sta #1 9. Install Dummy GLV in station 4 10. Pull RHC 11. RIH and set Evo-trieve @ —8940', between X-profiles in the tubing tail. 12. Circ Packer fluid 13. Pull Circ valve in Sta #1 14. Install dummy in Sta #1 @ 8317' 15. MIT-IA to 4500 psi • IA tested to 4000 psi using rig • Hold 2000 psi on tubing during MIT-IA 16. MIT-T to 5000 psi • Tree and adaptor flange is rated to 10,000 psi and has been tested to 10,000 psi. • Do not hold pressure on IA per AOGCC Regulations. 17. Pull Evo-trieve Fullbore Circ Packer fluid Assist 18. Circulate 9.8 ppg NaCI per schedule below: • WB (IA+Tbg)Volume to Sta #1 GLV: 572 bbls • 5 bbl methanol spear as required • 537 bbls 9.8 ppg Inhibited NaCI • 35 bbls Diesel • U tube diesel to allow fluid levels to equalize. • Max Rate: 3 bpm • Max Pressure: 3000 psi Fullbore Hydraulic Fracture Treatment 19. Frac treatment per pump schedule. L3-10 Post rig procedure 6/4/2015 2 of 8 • • • Pressure testing Maximum Allowable Treating Pressure: 7300 psi Stagger Pump Kickouts between: 6935 psi and 6570 psi (95% to 90% of MATP) Global Kickout 6935 psi (95% of MATP) IA pop-off set pressure 3375 psi (75% of MIT-IA) Treating Line Test Pressure 8300 psi Sand Requirement 377,500# 20/40 Carbolite Minimum Water Requirement 6,000 bbls (pump schedule: 5490 bbls) SXE Acid Requirement 25,400 gal VDA Acid Requirement 16,000 gal IA Hold Pressure 3000-3200 psi (IA pop off set at 3375 psi) OA Monitor and maintain open to atmosphere Coiled Tubing Post frac Mill and C/O See Appendix A for Mill and C/O procedure Slickline D&T, Install LGLVs 20. Drift and tag fill. 21. Install Generic GLV design Testers Post frac flowback 22. See Appendix B for Post Frac Flowback Slickline Install plug 23. Install Plug in X-nipple @ 2196' Valve Shop Change out Tree 24. Install TWC 25. Change out 10,000 psi tree and THA to 5,000 psi production tree and Adaptor 26. Test tree and connections to rated working pressure. 27. Pull TWC Slickline Install Deep GLVs, Pull Plug 28. Install Deep GLV design per rates obtained from welltest 29. Pull plug in X-nipple @ 2196' L3-10 Post rig procedure 6/4/2015 3 of 8 • • Appendix A - CT FCO Procedure Notes: • This is a generic Mill out procedure for a post frac Mill/FCO. Specific info such as amount of proppant left in tubing and estimated sand top will not be known until after the job is pumped. • The objective of this procedure is to get the well cleaned and the seats milled out to facilitate post frac well test. • Recommend reviewing PE Manual section for Coiled Tubing Fill Cleanouts for specifics on reversing rates, speeds and CT loading. Planned Procedure 1. MIRU CT 2. MU BHA to Mill Frac seats. 3. RIH down to estimated sand top and begin cleaning out with slick 2% KCL. 4. Continue down to 9100' CTMD. At this point we are -100' above the heel sleeve. Ensure CT is clean as it is expected that returns will begin to fall off as the nozzle nears the slots. If returns begin to fall off, reducing BHP by lowering rate may keep returns at a manageable level. 5. Slowly continue to clean out until returns fall off to -80%. If returns are still good even after the nozzle is past the slots (not likely but possible), continue to clean out until returns show trace amount of Carbolite. a. If necessary, we can mill the seats without taking returns. 6. FP to 2500'. 7. Pump a gel pill at surface out to the tanks to ensure CT is clean if necessary. 8. RDMO. L3-10 Post rig procedure 6/4/2015 4 of 8 • i Appendix B - Test Separator Additional Flowback Procedure 1. MIRU ASRC. RU equipment to in a manner that allows CT to RU if an additional FCO is necessary. 2. POP the well to ASRC at minimum choke. Flow the initial returns to the flowline as long as the shake-outs meet the returned fluid/solids management guidelines. 3. Limit flow to 500 bpd 4. If solids are < 1%, increase the production rate to 1000 BLPD. 5. Flow bottoms up and sample for solids production. If solids are still below 1%, allow well to flow to 1500 BLPD. Flow bottoms up and sample for solids production. If solids are still below 1% continue to increase the flow rate in 500 BPD increments. The objective is to achieve maximum drawdown. Watch returns and do not continue to open choke if solids > 1%; allow well clean up before choke is opened further. 6. Once at FOC, stabilize the well for 4 hrs. Obtain a 3 hr purge, 8 hr welltest. L3-10 Post rig procedure 6/4/2015 5 of 8 • • . Appendix C — Contingent CT FCO Procedure Notes: • This is a generic FCO procedure for a frac FCO following a screenout. Specific info such as amount of proppant left in tubing and estimated sand top will not be known until after the job is pumped. • The objective of this procedure is to get the well cleaned to allow stimulation operations to continue. • Recommend reviewing PE Manual section for Coiled Tubing Fill Cleanouts for specifics on reversing rates, speeds and CT loading. Planned Procedure 9. MIRU CT 10. MU BHA to cleanout. 11. RIH down to estimated sand top and begin cleaning out with slick 2% KCL. 12. Continue down beyond sleeve that the screenout occurred on. Ensure CT is clean as it is expected that returns will begin to fall off as the nozzle nears the slots. If returns begin to fall off, reducing BHP by lowering rate may keep returns at a manageable level. 13. Slowly continue to clean out until returns fall off to —80%. If returns are still good even after the nozzle is past the slots (not likely but possible), continue to clean out until returns show trace amount of Carbolite. 14. FP to 2500'. 15. Pump a gel pill at surface out to the tanks to ensure CT is clean if necessary. 16. RDMO. L3-10 Post rig procedure 6/4/2015 6 of 8 . • • Tubemove Analysis Effective Differential Pressure(psi) 0 m • 3 g — Z n 0 o .. m E. --" j g— -D1 1 f-. --)....--•\pm Gc m ' 0 0 w JN i \143J 00 1 -J (T - e N N 'J O O = o O C O 0 O.D. p 36' 8 • 0: 11.11111111111111 D.4 o wilionnisINEMINNE Fj y •(D 0 l H S O -0 @ \\ \\ I i t d M ri 8 Sg r; • • WBD "WEE= cm4-V16' L3-1 WaLH6AD= SAFETY NATES:WELL ANGLE,.791•la 8639''^YAX *IMO DRAFT DOGLEG_ 10.8'ilt 9474"'"'CHROME TEG 6 LAIR'" ACTUATOR= OKE.flEV 69.112 V Yr BF ELEV= V KOP= 20-C0 Dl1GTOR 126' 2195' 4-1./7'WS x+4:'D 3 4-13'.� Max Angle=101•a10366' 944,14-40, y r 1111.. Datum ND_ 9332' D=19.124" . Datum TVP 400 A GAS LFT MA143REIS I,; =1 ' ' H _., ST M3 1V0 L1EV TYPE VLV LATCH POM DATE 4 4064 4,374 8 64616 OCR-1 14SP 0 '05116/15 Ies-nmA-ma TOPOFC VT 1-1-:-.13„9.43 6251 6218 1 MAG OWPK0 05/16/15 r t~: 11,9,1OW FE 2 7368 7331 12 941G O0 05116/15 MKIimum ID=3,813" 2196' 'moi+ 44 1 8317 8177 35 Kowa OW PK 0 05/16/15 44 4-112"HES XNIPPLE AO.--I :iie.:,:::� 83W _a5r6'X7-eF�rrDEZXT4Lw,n=5.1TOP r OF Ld•Ai ... 8369' '4 8375' _9=5/8'x r 8KR WRAC HGR,D'818ffJ 5-58"CSG,418,1-80 VAM'TOP.I)=8.681' -i 8531' ti ' 4kg* II" 6$12' -14-11T HES X MP.13=31$13' lela 6643' -41/2'NDPCTCSIACAUGE D•3.679' �.4 14/IMRETO SURFACE 11,7,111 111D P. CIA 88m Hr X 4-112^HES TNT PM,O.3-856' ■ 88'16' 1--1411/2'HBs x MP,a•3.1113'..:j C1 9. ., �, ? a-1!YHPRrran,n.%a,a-1 06, ' ' .-. NRH 9001' ' 9007'$j7'X5'NCR If113.EZXPLTP 16;4340'M....vl 4=1t2.111E 1263.13CR-85 VAM tC3P, 9004' ,..*, 1 .'"�!• 9004' W.EG,U=3958' O152l r.t1,3.956 r "' a y --lam)TT NOT LOGGED 7t. ' 1, 9024' -i F'X 5'BKR CO FLEX-LO 3(i-le O=429" 1 7'LTV,260,1-80 VAM TOP NC/BTCM 9174' _, 9034' H5-A4-1rz.XO BUBFi9G,O=3.90- .05&3 bV1 ID'6.276 �.-. .IN• 4-112"FRAC PORT SLEEVES RIZ SWILL PA479i# ".....'-' IV STH SEATS/. ACTUAL SEM 0/C DATE PID DEPH SIZE. V 11 9211 325' 5.63 C 05/14/15 11 9300 4-112" 3.920' as um• 10 9376 3.12" 5.63 C 05/14/15 10 9434 4-1/2" 1920" AIM 8 9520 3.04' 5163 C 05/14/15 9 957; 4-1/7' 3920' • • 6 9694 2.94' 503 C 05114/15 8 9742 41/7 3.920" 7 9839 221' 503 C 05/14/15 7 10022 412" 3.92P -,-'-' 6 10080 2.70' 5.63 C ',05/14/15 6 10460 4-1/2' 1920" •111111111 5 10402 2.66" 503 C 05/14/15 5 10762 4-112" 3.820' •- 4 10677 2 60" 563 C 05/14/15 4 10978 4-112. 3920 •MIN_ 3 10031 2.50" 863 C 05/14/15 3 11217 4-12" 1920' 2 11107 2.41' 5.63 C 05/14/15 2 , 11501 4-117 3.920' 1 11439 2.31' 5.63 C 05/14/15 1 1 11603 3-1/7 2 992" --- PA 11756 11/A 563 C 04/14/15 ._1111 --- 11492 4-1n"®KR SFIFT TOOL V ER FICATION SUE,ID-3.8W 1,'2`LNR,13 54-,1308-90 -{ ),2I, --1 11795' •c•4/,-• 015D bpi,11-192- 4,-.:.. 11781' H4-V2'SLB CIRC VALVE D=1.15"(TUTU) 3-112'LAIR 9.2#,L-80 VAM TOP. I-I 116162' 0g '=' 11793' --14-1/2"x 3=1/7 X0,10.2 992" I !.l7tPt.D=2.392' IlATE REV BY; COMMENTS BATE REV BY 1 COMMENTS LLSOURNE UNIT 86/17115 PNR 272 MTIAL COMPLETION WELL 4310 05112/15 4A) ,I]31;TI04X#441.111]At; RAO No"2150430 05121/95 .Mwl} ITJII'e 10 SPA 11 I KJ4 lA1111 All No.50 029 23.53&00 06101/15 PJC; ICOND CTOFC TBG/L1,81 UPI.4115 - SEC.22,T11N,R15E,459 Ft&8 767 FAL 11p Exploration(Alaska) L3-10 Post rig procedure 6/4/2015 8 of 8 . • • T 1 T I cr, ‘-i cp a) I N 40 0 0 0 0 oo- a. Iu u_ u. I-1- 0 0 0 >-• E • u u IV) cr) cr) v' (..) C.) 0 o i i --, (..) .. 1 a on V) .C • N+., c13 71) I_1 %-1 `71: ... . 4 4 : 1 • .-- v, _c v) c.4.1 - c a) on < .+, 4-, vs .,.= 4,, •,-_- _1 r-4 u Z o_ Z Z Z U CU cc z = c -e-, , ' r .;_ t3 u !ilL) 4— (A CI' !7:( <0 c m 47t moC a_ a ,_ U a) a) > 0-6 a) cu c' co o 4-, , (..) Ln _ 0 o o 46 't- a., I 0 bp to C Tr 1_c 1 4= w ! • _c .- < c .z-.- c ,...,r`i. D c.7) ,:Es la 0 Ln 0 1 , 0 ,,-; c) .) _c 0.. (I) V Vl!' U L!/) 4-, a. .- m •- .. '43 = ro ca. 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' c i• 13 1.0•i Q U i j d as L.,n IL N c, I a - ; i 0 d .MEM NM 0 a ° 1 v H c L a Li o C N I a. !t L.> O Cr Ti �.i - •Q I Q a ' o CL N y = v i M +u-, I~ °' a Q an Q. 1 Llc c ! 3 .o 1 d '. c, c, a : a S ° _ ' cLc a v vim ! q. '� 0 cb is 3 o U z' n y' 1 Ln 0- Y mac, �"-'? h 3 'mo i v ; c o o. N I,-, i u o y �j h � 1 civ i +.. c u CD .� ° c v),Cl- Q , c WIUI ! H 1 ° o rn v N� vy 4o a C:•... v 1 U h > N v L > I v o +, •i 1 o Cr) o > v u c �j 1 a of h ,v •in � c ! I 0 j 1 3 c!•° j v CO _, o o- 0.'s Icc a,� OI * h a Ia ° o " v Ln '. c'`� v o'4, u ' c v . . , cv c o! SI c v '"0 'v -- zs =•, �.c -•� 1 -. alp c = 0 t L. Q i 26002 $ SchlumbergerTransmittal#: 30JUN15-SP01 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery 'Tit4/2015 ;vI. K.BENDER Customer: BP Exploration Alaska Inc Dispatched To: Makana Bender Well No: L3-03 Date Dispatched: 30-Jun-15 APIN: 50-029-23535-00-00 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Delivered To: 30JUN15-SPO r AOGCC Makana Bender 9 Total Contents on CD N/A Color Log Prints: 8 Pathfinder 1" MD SGR x x Pathfinder 1"MD SGR MAD Pass x x Pathfinder 1'TVD SGR RECEIVED x x Pathfinder 1"TVD SGR MAD Pass x x Pathfinder 5'MD SGR JUN 3 0 ritj x x Pathfinder 5'MD SGR MAD Pass x x Pathfinder 5'TVD SGR AOGCC x x Pathfinder 5'TVD SGR MAD Pass x x Digital Data N/A Contents on CD x Survey N/A N/A ASP Final Survey EOW CD 1 Contents on CD Graphics:PDF x Data:DLIS/ASCII x Please sign and email a copy to: Please sign and email a copy to: AlaskaPTSPrintCenterslb.com gancpdcic'Dbp.com Alaska PTS Print Center ATTN: Merion Kendall Received By: 17)jvaLAS-te.k. 4/) 6,,,,,,,,,at to 0 O cc r0113 I (4 _ �'`�o Qpm; a Q s Y in G.) 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Q C) D) a) O O O) D) a) O O ! _ NNNNNN NNN N 01 0 0 0 0 0 0 0 0 0 v CU O O O O O O O O O ~ U) U) )() In U) U) U) U) in f+ O at CCO ct ill _coQ u C u to U 1= �" g E a, .� Y y Z "�•I W� O' C E dl , ya, a < co Q ,- V m Q M Q 70 7 d OBD M Z O' M G N 0 0 0 r ro a+ F- a Q N w LL J J Z X J J z Y �r fCD� ri N i C N re 8 C/a E 1 igIt a` a Q • 0 STATE OF ALASKA • M A Zr'. ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: _ ®Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended lb. Well Class 20AAC 25.105 20AAC 25.110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL D Other No. of Completions One• - ® Development 0 Service 2. Operator Name: 5. D e Comp_`,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 66/8/2015 215-018 • 315-198 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage,Alaska 99519-6612 •3/15/2015 50-029-23535-00-00 4a. Location of Well(Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: • 6/2/2015 PBU L3-03 4933' FSL, 4718' FEL, Sec. 22,T11N, R15E, UM - 8. KB(ft above MSL): 69.55. . 15. Field/Pool(s) Top of Productive Horizon: 3651' FSL, 5080' FEL, Sec. 15,T11 N, R15E, UM GL(ft above MSL): 21.4' • Prudhoe Bay/Lisburne Total Depth: 9. Plug Back Depth(MD+TVD) 1130' FSL, 710' FEL, Sec. 09, T11 N, R15E, UM 12777' - 8792' - 4b. Location of Well(State Base Plane Coordinates, NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 707811 • y- 5961949 ' Zone- ASP4 •12875' - 8779' • ADL 028322&034631 - TPI: x- 707331 y- 5965935 Zone- ASP4 11. SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 706339 Y- 5968667 Zone- ASP4 None 18. Directional Surve Y: ®Yes ❑ No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1823' _ 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD/GR, MWD/GR/RES, MWD/GR/RES, USIT, GR/RES/NEU/DEN/Pef/Image/Spectral GR N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 49' 129' 49' 129' 30" 1800#Poleset(Approx.) 13-3/8" 68# L-80 48' 4143' 48' 3832' 16" 2758 sx LiteCrete, 618 sx Class'G' 9-5/8" 47# L-80 45' 9252' , 45' 8325' 12-1/4" 893 sx LiteCrete,407 sx Class'G' , 7" 26# L-80 9091' 9820' 8189' 8809' 8-1/2" 170 sx Class'G' 4-1/2" 13.5# 13Cr80 9649' 12858' 8663' 8781' 6-1/8" Uncemented Sliding Sleeves w/Swell Packers 24. Open to production or injection? , ®Yes 0 No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD) (MD+TVD of Top&Bottom; Perforation Size and Number): 4-1/2"Sliding Sleeves w/Swell Packers - 4-1/2", 12.6#, 13Cr85 9656' 9532'/8563' 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. 9857' 8840' . 12447' 8830' WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ®No 10023' 8964' 12678' 8805' - 10242' 9069' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 10460' 9094' 2200' 155 Bbls Diesel 10719' 9069' 10989' 9032' 1 (o(t le 11414' 8970' 4 11984' 8887' ` " I tv.YY 12221' 8855' ! .., � .. 27. PRODUCTION TEST Date First Production Method of Operation(Flowing, Gas Lift,etc Not on Production N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ® No - Sidewall Core(s)Acquired? 0 Yes ® No _ If Yes to either question, list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None - Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit Original Only V' L �,``s`/ f/i��� RBDM3J JUL - 1 2015 ,��5f ,.� . 29. GEOLOGIC MARKERS(List all formations andr rs encounter 30. inkFORMATION TESTS NAME M TVD Well Tested? Wes ®No - Permafrost Top 19' 19' If yes, list intervals and formations tested,briefly summarizing test Permafrost Base 1866' 1842' results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Ugnu 5440' 4987' None . West Sak 7097' 6445' Coleville Mudstone 9504' 8540' HRZ 9072' 8173' LCU/Sadlerochit 9286' 8354' Zone 2B 9374' 8429' Zone 2A 9484' 8523' Zone 1B 9520' 8553' Zone 1A 9592' 8615' Kavik/Base of Sadlerochit 9632' 8649' Lisburne 9824' 8812' Wahoo 7 9858' 8841' Wahoo 6 9929' 8898' Wahoo 5 10137' 9027' Wahoo 6(invert) 11345' 8978' Wahoo 7 12312' 8845' Lisburne 12698 8802' Kavik 12858' 8781' - Formation at Total Depth: Kavik(From Base) 12858' ' 8781' 31.List of Attachment: Summary of Daily Drilling Reports, LOT/FIT Summary,Well Schematic Diagram, Surveys, Cement Report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Email: David.Minge@bp.com David Minge,564-4061 Printed Name: Joe Lastufka Title: Drilling Technologist / Signature: _. hone 564-4091 Date: IQ/241"/(6 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only TREE= CNV41/16' • L3-03 3-0 3 SGL 6 •,WELL AN CHROME 70°TBG 2 LNRt MAX V1A3Ll-EAD= FMC ACTUATOR= DIB.a.EV= 69.55' BE REV= 48.15' KOP= 561' 20"COND, -I -128' Max Angle= 100°@ 11033' 91.5#,A-53, I ' 2247' -14-1/2"HES X NP,D=3.813" Datum MD= 10037 Datum TVD= 8900'SS D=19.124" GAS LFT MANDRELS 13-3/8"CSG,68#,L-80 BTC,D=12.415" -1 4143' " ST MD ND DB/ TYPE VLV LATCH FORT DATE 4 4343 4010 27 MMG OCR RKP - 06/08/15 77 3 6830 6211 28 WIG DMY RK 0 06/08/15 TOP OF CBNENT(03/29/15) - -4200' 2 8156 7376 28 MMG DMY RK 0 06/08/15 11* '.ir [ 1 8972 8088 31 MAG DMY RK 0 06/08/15 SI 0,1 TOP 7"OF LNR 9091' k 0 04 ®_y 9091• __19-5/8"X 7"BKR HRD-E ZXPN LTP 0=7.34' 0 .ii1y. 40 Ilk ire 9106' -19-5/8"X 7"BKR HMC HGR,D=6.18' iii 9-5/8"CSG,47#,L-80 TCWAMTOP/BTC, 9252' ` ' ID=8.681• • L 9466' 1H4-1/2"FES X MP,D=3.813" Minimum ID =3.813" @ 2247' �l 4-112" HES X NIPPLE ., ' 9497• A4-1/2"NDPG-CSAPPHREGAUGE,D=3.879" S .. 10., 4 9532' 7"X 4-1/2"FRES TNT PKR,ID=3.856" irl pi ' ' 9569' -14112"FES X NP,D=3.813" ifi I I 9639' -14-1/T FES X NP,D=3.813" e. • 4, 9649' -17'X 5"BKR HRD-E ZXPN LTP,D=4.32' 4-1/2'TBG,12.6#,13CR-85 VAM TOP, - 9656' 1: 6.4 ' 9656' -14-1/2"VVLEG,D=3.958" 0152 bpf,D-3.958" / HELM?TT NOT LOGGED i9673' H 7'X 5'BKR FLEX-LOCK HGR,ID=4.33" 7"LNR,26#,L-80 VAM TOPHCIBTC-M -1 9820' 12I 9683' -{5"X 4-1/2"XO,D=3.910" -0383 bpf.D=6.276 sr so m 4-112" FRAC PORT SLEEVES 4-1/2"FRES SWELL PACKERS ---'-• NO DEPTH SEAT SZ. ACTUAL SIZE 0/C DATE NO 0137ni D = 10 9857 3-137' 5.625" C 06/05/15 11 9905 3.920" 9 10023 2.947" 5.625" C 06/05/15 10 10071 3.920" 1,74 ''' 8 10242 2.857" 5.625" C 06/05/15 sr EN um 9 10290 3.920" ,., 7 10460 2-767" 5.625" C 06/05/15 8 10591 3-920" ismin 6 10719 2.677" 5.625" C 06/05/15 7 10809 3.920" .:. 5 10989 2.587" 5-625" C 06/05/15 6 11078 3.920" mi gm a 4 11414 2.497" 5-625" C 06/05/15 5 11711 3-920" 3 11984 2.412" 5.625" C 06/05/15 4 12125 3.920" 2 12221 2.332- 5.625" C 06/05/15 3 12319 3.920" m 1 12447 2.252- 5.625" C 06/05/15 is 2 12572 3.920' _ Bk 12678 NA 5.590" C 06/05/15 '1 12799 2.992" m m is `1=3-1/2"SWELL PKR PBTD -j 12777' = 11.4 12561' -4-1/2"BKR SHIFT TOOL V ERF! ATION SUB,D=3.89' 41/2"LNR 13.5#,13CR 80 HYD 521, -{ 12791' _•�asm•_. 12777' H4-1/2"SLB CRC VALVE,D=1.15' .0152 bpf,D=1958" 12791' H4-1/2"X 3-1/2"XO,D=2.992" 3-1/2"LNR,9.24,L-80 BTNAM TOP, - 12858' ••■ .0087 bpf,ID=2.992' tX..N4 DATE REV BY COMMENTS NITS DATE REV BY COMMENTS LISBURNE UNIT 06108/15 PKR 272 INITIAL COMPLETION VVHL: L3-03 06/17/15 JMD DRLG HO CORRECTIONS PERMIT No: 2150180 06/22115 DMJM) RNAL ODE APPROVAL AR No: 50-029-23535-00 SEC.22,T11N,R15E,346'FTI.&562'PM. BP Exploration(Alaska) • BP AMERICA % ' " s LOT / FIT Summary ;-.� 7, Well Name: L3-03 Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD-Ft) (TVD-Ft) (ppg) (psi) (BHP)(psi) (ppg) 03/22/15 LOT 4,173.00 3,889.78 9.80 919.00 2,899.25 14.35 03/31/15 FIT 9,252.00 8,340.20 10.40 480.00 4,985.88 11.51 05/24/15 FIT 9,820.00 8,809.00 8.50 630.00 4,519.70 9.88 Page 1 of 1 • • North America-ALASKA-BP Page 1 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud DateRme:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UW:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/11/2015 06:00 - 08:30 2.50 MOB P PRE CONTINUE TO PREP FOR RIG MOVE -REMOVE REMAINING 4"DP FROM PIPE SHED -SECURE PRT CRANES AND PIPE IN SHED 08:30 - 12:00 3.50 MOB P PRE PREPARE RIG FLOOR FOR SKIDDING -PJSM -SECURE FORUM CRANE PLACE IDL IN TRAVEL POSITION -MOVE WALKWAYS FROM ROOF AND SECURE -COMPLETE PRE-SKIDDING CHECKLIST 12:00 - 14:00 2.00 MOB P PRE SKID RIG FLOOR 14:00 - 15:00 1.00 MOB P PRE PREPARE TO LOWER DERRICK -PJSM -OPEN V DOOR WINDWALLS -PREP DERRICK CYLINDERS -SECURE LINES AND SHEAVES IN DERRICK 15:00 - 16:00 1.00 MOB P PRE LOWER DERRICK 16:00 - 20:00 4.00 MOB P PRE PREPARE TO SEPARATE MODULES -SEPARATE INTERCONNECTS -JACK MUD MODULE INTO PLACE 20:00 - 22:00 2.00 MOB P PRE BEGIN STAGING MODULES ON POINT MAC 1 ACCESS ROAD -MOVE MUD MODULE INTO PLACE ALONG ACCESS ROAD -JACK DRILL MODULE INTO PLACE -MOVE DRILL MODULE DOWN ACCESS ROAD PAST MUD MODULE 22:00 - 00:00 2.00 MOB P PRE MOBILIZE UTILITY MODULE ON ACCESS ROAD -REMOVE TEMPORARY WELLHOUSE -JACK UTILITY MODULE INTO PLACE -STAGE UTILITY MODULE ONTO ACCESS ROAD -ALL MODULES PREPPED TO MOVE TO L3-03 3/12/2015 00:00 - 06:00 6.00 MOB N WAIT 1.05 PRE STAGE AND PREPARE UTILITY,DRILLAND MUD MODULES AT PM1 ACCESS/WEST DOCK ROAD. WAIT FOR SECURITY FROM NORDIC 1 RIG MOVE SIMOPS: -MOVE DUMMY WELLHOUSE FROM PM1-122 AND SPOT ON L3-03. 06:00 - 20:00 14.00 MOB P PRE MOVE ALL THREE RIG MODULES SIMULTANEOUSLY TO L3-03 20:00 - 00:00 4.00 MOB P PRE MODULES ARRIVE ON L3 -SPOT DRILL MODULE OVER L3-03 Printed 6/24/2015 9:13:40AM • • North America-ALASKA-BP Page 2 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/13/2015 00:00 - 06:00 6.00 MOB P PRE SPOT MODULES ON L3-03 -SPOT AND MATE UP UTILITY MODULE AND MUD MODULE TO DRILL MODULE -CLEAR SNOW IN CELLAR AREA DUE TO BLOW -INSTALL GRATING AND PREPARE WELLHOUSE -SET CENTER SUPPORT BEAMS DOWN AND SHIM WEIGHT BEARING PADS 06:00 - 10:30 4.50 MOB P PRE MATE MODULES -HOOK UP INTERCONNECTS -HOOK UP STEAM TO RIG FLOOR TO WARM UP LUBE OIL -NIPPLE UP RISERS TO WELLHEAD AND ADJUST -PLUG IN MODULES -CLEAN RIG -PREPARE TO RAISE DERRICK 10:30 - 12:00 1.50 MOB P PRE RAISE DERRICK,SKID RIG FLOOR -PJSM FOR RAISING DERRICK -RAISE DERRICK,MAX WEIGHT 592K -PREP FLOOR FOR SKIDDING -SKID RIG FLOOR -SLIDE HAUNCH INTO POSITION 12:00 - 14:00 2.00 MOB P PRE CONTINUE TO RIG UP -COMPLETE UTILITY MODULE INTERCONNECT -RIG UP MANRIDERS -CLOSE FAST LINE HATCH 14:00 - 16:30 2.50 MOB P PRE BRIDAL DOWN -PJSM FOR BRIDALING DOWN -BRIDAL DOWN -HOOK BLOCKS TO TOP DRIVE -CALIBRATE BLOCKS 16:30 - 00:00 7.50 RIGU P PRE NIPPLE UP DIVERTER -PJSM FOR NIPPLING UP -NIPPLE UP DIVERTER -RIG UP SURFACE LINES AOGCC REPRESENTATIVE BOB NOBLE WAIVED WITNESS OF DIVERTER TEST AT 18:30 -BEGIN OFFLOADING MAXDRIL-N FLUID TO PITS -ACCEPT RIG 03/13/2015 18:00. -TESTED H2S,LEL,AND FIRE ALARMS 3/14/2015 00:00 - 01:00 1.00 RIGU P PRE PERFORM DIVERTER FUNCTION TEST -KNIFE VALVE OPEN:33 SECONDS -DIVERTER BAG CLOSED:41 SECONDS -PERFORM ACCUMULATOR DRAWDOWN TEST 01:00 - 03:30 2.50 RIGU P PRE CONTINUE TO RIG UP -SET WALKWAY SYSTEM ON ROOF -SET UP TROLLY SYSTEM UNDERNEATH TOOL CRANE -PERFORM RIG EVACUATION DRILL AND HOLD AFTER ACTION REVIEW Printed 6/24/2015 9:13:40AM • • North America-ALASKA-BP Page 3 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) _ (usft) 03:30 - 05:30 2.00 RIGU P PRE -MAKE UP 5"HEAVY WEIGHT AND 5" DRILLPIPE STANDS -CHANGE OUT SWABS AND LINERS TO 6" 05:30 - 07:00 1.50 RIGU P PRE MAKE UP BHA#1 -PJSM FOR MAKING UP BHA -PREPARE FLOOR TO MAKE UP BHA -MAKE UP BHA TO 48'MD W/16"BIT,1.5 BEND MOTOR,AND UBHO SUB -SPOT E-LINE TRUCK,RIG UP GYRO DATA 07:00 - 09:00 2.00 RIGU P PRE RIH WITH 16"SURFACE DRILLING BHA#1 -TAG FILL AT 105'MD -FILL LINES AND HOLE -PRESSURE TEST LINES TO 3500 PSI FOR 5 MIN,NO LEAKS -WASH DOWN 10'AND GYRO -TAG SOLID GROUND AT 128'MD(BOTTOM OF CONDUCTOR) 09:00 - 16:30 7.50 DRILL P SURF DRILL 16"SURFACE HOLE FROM 128'TO 510' MD(510'TVD) (382'IN 7.5 HRS=51 FPH WITH CONNECTIONS AND GYRO) -550-600 GPM,630 PSI ON/550 PSI OFF,60-70 RPM -1-2K TQ ON,1K TQ OFF,8-10K WOB PUW=61K,SOW=61K,ROT=58K -GYRO SURVEY EVERY STAND -BACKREAM 90'PRIOR TO RUNNING GYRO DUE TO HEAVY GRAVEL -SEEPAGE LOSSES,-10 BBLS/HOUR -MW 8.7 PPG IN/OUT SIMOPS:BUILDING 5"DP STANDS OFFLINE 16:30 - 17:00 0.50 DRILL P SURF POOH ON ELEVATORS FROM 510'MD TO 47' MND TO PERFORM SHORT TRIP FOR BHA#2 -MONITOR WELL FOR 10 MINS PRIOR TO PULLING OFF BOTTOM-STATIC -PU W=55K,SOW=55K AT 418'MD 17:00 - 17:30 0.50 DRILL P SURF PERFORM BIT CHECK -BIT IN GOOD CONDITION -DRAIN MOTOR -BROKE OFF UBHO ABOVE MOTOR _ 17:30 - 20:30 3.00 DRILL P SURF PU BHA#2 -PICK UP MWD AND SCRIBE TO MOTOR -PICK UP UBHO AND SCRIBE TO MWD AND MOTOR -PU 6 JTS OF 8"COLLARS AND HYD JARS 20:30 - 21:00 0.50 DRILL P SURF RUN IN HOLE WITH 16"SURFACE DRILLING BHA#2 TO 510'MD -WASHED DOWN AT 2 BPM,NO FILL OBSERVED ON BOTTOM -PERFORM MWD SURVEYS AT 395'MD AND 485'MD TO COMPARE TO GYRO SURVEYS Printed 6/24/2015 9:13:40AM 110 • North America-ALASKA-BP Page 4 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth ' Phase Description of Operations (hr) _ (usft) 21:00 - 00:00 3.00 DRILL P SURF DRILL 16"SURFACE HOLE FROM 510'MD TO 650'MD(650'TVD) (140'IN 3 HRS=47 FPH WITH CONNECTIONS AND GYRO) -600 GPM,1210 PSI ON, 1100 PSI OFF -70 RPM,1-2K TQ ON,1K TQ OFF,8-12K WOB -PUW=82K,SOW=82K,ROT=80K SURVEY EVERY STAND -BACKREAM 30'PRIOR TO CONNECTIONS TO WIPE HOLE CLEAN -SEEPAGE LOSSES,—10 BBLS/HOUR -MW 8.6 PPG IN,8.6 PPG OUT 3/15/2015 00:00 - 06:00 6.00 DRILL P SURF DRILL 16"SURFACE HOLE FROM 650'MD TO 900'MD(900'TVD) (250'IN 6 HRS=42 FPH WITH CONNECTIONS AND GYRO) -500 GPM,1050 PSI ON, 900 PSI OFF -50 RPM,2K TQ ON,1K TQ OFF,20-30K WOB -PUW=90K,SOW=90K,ROT=90K -MWD AND GYRO SURVEY EVERY STAND -WIPE 30'PRIOR TO CONNECTIONS TO WIPE HOLE CLEAN -MW 8.8 PPG IN,8.8 PPG OUT 06:00 - 12:00 6.00 DRILL P SURF DRILL 16"SURFACE HOLE FROM 900'MD TO 1186'MD(1185'TVD) (286'IN 6 HRS=48 FPH WITH CONNECTIONS AND GYRO) -500 GPM,1400 PSI ON, 1100 PSI OFF -50 RPM,2K TQ ON,1K TQ OFF,20-35K WOB -PUW=93K,SOW=93K,ROT=90K -MWD AND GYRO SURVEY EVERY STAND -WIPE 30'PRIOR TO CONNECTIONS TO WIPE HOLE CLEAN -MW 8.8 PPG IN,8.8 PPG OUT 12:00 - 15:00 3.00 DRILL P SURF DRILL 16"SURFACE HOLE FROM 1186'MD TO 1270'MD(1269'TVD) (84'IN 3 HRS=28 FPH WITH CONNECTIONS AND GYRO) -500 GPM,1390 PSI ON, 950 PSI OFF -35K WOB -PUW=98K,SOW=95K,ROT=93K -MWD AND GYRO SURVEY EVERY STAND -WIPE 30'PRIOR TO CONNECTIONS TO WIPE HOLE CLEAN -MW 8.6 PPG IN,8.7 PPG OUT -UNABLE TO OBTAIN CONSISTENT CLEAN SURVEYS WITH MWD TOOL.DECISION MADE TO PULL OUT OF HOLE AND CHANGE OUT MWD 15:00 - 17:30 2.50 DRILL P SURF PULL OUT OF HOLE ON ELEVATORS FROM 1270'MD TO 665'MD TO CHANGE OUT MWD -MONITOR WELL FOR 10 MINUTES BEFORE PULLING OFF BOTTOM:STATIC -PU=88K,SO=88K AT 665'MD -NO TIGHT SPOTS ON TRIP OUT OF HOLE -HOLE TOOK PROPER FILL Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP Page 5 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth , Phase Description of Operations (hr) (usft) 17:30 - 20:00 2.50 DRILL N DPRB 1,271.05 SURF LAY DOWN BHA TO MAKE UP NEW MWD -LAY DOWN 1 DRILL COLLAR -RACK BACK JAR STAND AND NON-MAG COLLAR STAND -DRAIN MOTOR AND FLUSH MWD -BREAK OFF BIT AND LAY DOWN MWD AND MOTOR -BIT GRADE:1-2-WT-G-E-I-NO-DTF 20:00 - 20:30 0.50 DRILL P SURF -SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT -MONITOR WELL -UPDATE TOTCO SYSTEM 20:30 - 23:30 3.00 DRILL N DPRB 1,271.05 SURF MAKE UP 16"SURFACE DRILLING BHA#3 WITH NEW MWD TOOL -PICK UP MOTOR WITH 1.8 DEGREE BEND -PICK UP PONY SUB AND NON-MAG STAB -PICK UP NEW MWD -MAKE UP BIT AND SCRIBE MWD TO MOTOR -MAKE UP UBHO AND ORIENT TO MWD 23:30 - 00:00 0.50 DRILL P SURF RUN IN HOLE WITH 16"SURFACE DRILLING BHA#3 FROM 296'MD TO 760'MD -RUN IN HOLE ON ELEVATORS -PU 84K,SO 84K AT 665'MD -NO TIGHT SPOTS DURING TRIP IN HOLE 3/16/2015 00:00 - 01:00 1.00 DRILL P SURF CONTINUE TO RUN IN HOLE WITH 16" SURFACE DRILLING BHA#3 FROM 760'MD TO 1270'MD AFTER PERFORMING SHORT TRIP TO CHANGE OUT MWD AND MOTOR -RUN IN HOLE ON ELEVATORS -PU 84K,SO 84K AT 665'MD -NO TIGHT SPOTS DURING TRIP IN HOLE -NO FILL OBSERVED ON BOTTOM 01:00 - 11:00 10.00 DRILL P SURF DRILL 16"SURFACE HOLE FROM 1270'MD TO 1894'MD(1869'TVD) (624'IN 10 HRS=62 FPH WITH CONNECTIONS) -650 GPM,1950 PSI ON,1560 PSI OFF -60 RPM,5K TQ ON,2K TQ OFF -30K WOB -PUW=110K,SOW=101K,ROT=107K -SURVEY EVERY STAND -WIPE 30'PRIOR TO CONNECTIONS TO WIPE HOLE CLEAN -MW 8.7 PPG IN,8.7 PPG OUT -BEGIN TO OBTAIN CONSISTENT CLEAN SURVEYS AT 1465'MD -BEGIN RIGGING DOWN GYRO AT 09:30 11:00 - 12:30 1.50 DRILL P SURF CIRCULATE 2X BOTTOMS UP -650 GPM,1600 PSI -60 RPM,3K TQ -PUW=113K,SOW=102KAT 1850'MD -RECIPROCATE FULL STAND WHILE CIRCULATING 12:30 - 13:00 0.50 DRILL P SURF PERFORM SHORT TRIP FROM 1894'MD TO 1234'MD -MONITOR WELL FOR 10 MINUTES PRIOR TO PULLING OUT OF HOLE-STATIC -PUW=105K,SOW=94KAT 1234'MD -NO TIGHT SPOTS ON TRIP OUT -NO SWABBING OBSERVED Printed 6/24/2015 9:13:40AM i North America-ALASKA-BP Page 6 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UW:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To ' Hrs Task Code NPT I NPT Depth j Phase Description of Operations (hr) (usft) 13:00 - 13:30 0.50 DRILL P SURF RIG SERVICE -SERVICE TOP DRIVE AND ST-80 13:30 - 14:30 1.00 DRILL P SURF RUN IN HOLE ON ELEVATORS FROM 1234'MD TO 1894'MD -NO TIGHT SPOTS ON RUN IN HOLE -WASH DOWN LAST STAND AT 3 BPM,NO FILL OBSERVED 14:30 - 18:00 3.50 DRILL P SURF DRILL 16"SURFACE HOLE FROM 1894'MD TO 2252'MD(2206'TVD) (358'IN 3.5 HRS=100 FPH WITH CONNECTIONS) -650 GPM,1790 PSI ON,1620 PSI OFF -60 RPM,5K TQ ON,4K TQ OFF -10-15K WOB -PUW=123K,SOW=106K,ROT=113K -SURVEY EVERY STAND -WIPE 30'PRIOR TO CONNECTIONS TO WIPE HOLE CLEAN -MW 8.8 PPG IN,8.9 PPG OUT 18:00 - 00:00 6.00 DRILL P SURF DRILL 16"SURFACE HOLE FROM 2252'MD TO 2637'MD(2556'TVD) (385'IN 6 HRS=64 FPH WITH CONNECTIONS) -650 GPM,1820 PSI ON,1690 PSI OFF -60 RPM,9K TQ ON,4K TQ OFF -10-20K WOB -PUW=132K,SOW=110K,ROT=120K -SURVEY EVERY STAND -WIPE 30'PRIOR TO CONNECTIONS TO WIPE HOLE CLEAN -MW 8.8 PPG IN,8.9 PPG OUT -TOP OF SV6 AT 2574'MD 3/17/2015 00:00 - 06:00 6.00 DRILL P SURF DRILL 16"SURFACE HOLE FROM 2637'MD TO 3100'MD(2936'TVD) (463'IN 6 HRS=77 FPH WITH CONNECTIONS) -750 GPM,2370 PSI ON,2170 PSI OFF -60 RPM,6K TQ ON,5K TO OFF -20K WOB -PUW=138K,SOW=118K,ROT=123K -SURVEY EVERY STAND -WIPE 30'PRIOR TO CONNECTIONS -MW 8.9 PPG IN,8.9 PPG OUT 06:00 - 12:00 6.00 DRILL P SURF DRILL 16"SURFACE HOLE FROM 3100'MD TO 3633'MD(3399'ND) (533'IN 6 HRS=89 FPH WITH CONNECTIONS) -825 GPM,2850 PSI ON,2630 PSI OFF -60 RPM,10K TQ ON,8K TQ OFF -25K WOB -PUW=165K,SOW=115K,ROT=130K -SURVEY EVERY STAND -WIPE 30'PRIOR TO CONNECTIONS -MW 8.9 PPG IN,8.9 PPG OUT -SV5 AT 3462'MD Printed 6/24/2015 9:13:40AM 411 • North America-ALASKA-BP Page 7 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UVVI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task 1 Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 18:30 6.50 DRILL P SURF DRILL 16"SURFACE HOLE FROM 3633'MD TO SURFACE SECTION TD AT 4153'MD(3840' ND) (520'IN 6 HRS=87 FPH WTH CONNECTIONS) -850 GPM,2950 PSI ON,2880 PSI OFF -60 RPM,10K TQ ON,7K TQ OFF -15K WOB -PUW=175K,SOW=124K,ROT=144K -SURVEY EVERY STAND -WIPE 30'PRIOR TO CONNECTIONS -MW 8.9 PPG IN,8.9 PPG OUT -SV4 AT 3705'MD 18:30 - 20:30 2.00 DRILL P SURF CIRCULATE 2.5X BOTTOMS UP AT TD -850 GPM,2700 PSI -60 RPM,7K TORQUE -SLOWLY PULL OUT OF THE HOLE WHILE RACKING BACK ONE STAND EVERY 20 MINUTES -SHAKERS CLEANED UP BY 1.5 BOTTOMS UP -MONITOR WELL 20:30 - 21:00 0.50 DRILL P SURF -GREASED WASH PIPE AND TOP DRIVE 21:00 - 23:30 2.50 DRILL P SURF PULL OUT OF HOLE ON ELEVATORS FROM 4153'MD TO 1894'MD TO PERFORM PLANNED SHORT TRIP TO BASE OF THE PERMAFROST AFTER REACHING TD -MONITOR WELL FOR 10 MINUTES BEFORE PULLING OFF BOTTOM:STATIC -PU 180K,SO 115K AT 3750'MD -BEGIN PULLING OUT OF THE HOLE WITH 60 FT/MIN RUNNING SPEED,INDICATIONS OF SWABBING OBSERVED -ADJUST RUNNING SPEED TO 30 FT/MIN,NO INDICATIONS OF SWABBING -TIGHT HOLE AT 2750'MD WITH 30K OVERPULL,WIPED SPOT TWICE AND THEN PULLED THROUGH WITH NO OVERPULL -15 BBLS/HOUR LOSSES WHILE PULLING OUT OF THE HOLE 23:30 - 00:00 0.50 DRILL P SURF RUN BACK IN HOLE ON ELEVATORS FROM 1894'MD TO 2560'MD -MONITOR WELL FOR 10 MINUTES BEFORE RUNNING BACK IN:STATIC -PU 132K,SO 106KAT 2460'MD -NO TIGHT SPOTS OBSERVED -8 BBLS/HOUR LOSSES WHILE RUNNING IN HOLE 3/18/2015 00:00 - 02:00 2.00 DRILL P SURF CONTINUE TO RUN BACK IN HOLE TO TD ON ELEVATORS FROM 2560'MD TO TD AT 4153' MD AFTER PERFORMING PLANNED SHORT TRIP TO BASE OF THE PERMAFROST -PU 128K,SO 100KAT 2560'MD -NO TIGHT SPOTS OBSERVED -WASHED DOWN LAST STAND,NO FILL OBSERVED ON BOTTOM -8 BBLS/HOUR LOSSES WHILE RUNNING IN HOLE Printed 6/24/2015 9:13:40AM • • North America-ALASKA-BP Page 8 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 03:30 1.50 DRILL P SURF CIRCULATE 1.5X BOTTOMS UP -900 GPM,3000 PSI -60 RPM,8K TORQUE -SLOWLY PULL OUT OF THE HOLE WHILE RACKING BACK ONE STAND EVERY 20 MINUTES -SHAKERS CLEANED UP BY 1X BOTTOMS UP 03:30 - 07:30 4.00 DRILL P SURF PULL OUT OF HOLE ON ELEVATORS FROM 4153'MD TO 665'MD -MONITOR WELL FOR 10 MINUTES BEFORE PULLING OFF BOTTOM:STATIC -PU 174K,SO 122K AT 4153'MD -PULL OUT OF THE HOLE AT 30 FT/MIN,NO INDICATIONS OF SWABBING -PULLED 30K OVER AT 2610'MD,DROPPED DOWN AND PULLED BACK THROUGH WITH NO OVERPULL -MULTIPLE SPOTS BETWEEN 1920'MD-1600' MD WITH 20K OVERPULL -3 BBLS/HOUR LOSSES WHILE PULLING OUT OF THE HOLE 07:30 - 11:00 3.50 DRILL P SURF LAY DOWN BHA#3 -PJSM FOR LAYING DOWN BHA -MONITOR WELL FOR 10 MINUTES:STATIC -PUW=90K,SOW=87KAT 665'MD -STAND BACK HEAVY WEIGHT AND LAY DOWN COLLARS AND BHA TO PIPE SHED -CLEAN CLAY OFF OF STABILIZERS AND BIT -BIT GRADE:4-4-WT-A-E-2-ER-TD 11:00 - 12:00 1.00 CASING P SURF CLEAN AND CLEAR RIG FLOOR -REMOVE SMALL BHA TOOLS FROM FLOOR 12:00 - 15:00 3.00 CASING P SURF RIG UP TO RUN 13-3/8"CASING -HOLD PJSM ON RIGGING UP TO RUN CASING -REMOVE BX ELEVATORS AND INSTALL VOLANT TOOL -INSTALL 6'BAIL EXTENSIONS AND SIDE DOOR ELEVATORS -REMOVE MASTER BUSHINGS AND INSTALL PS-21'S DRESSED WITH 13-3/8"SLIP INSERTS -RIG UP 14"POWER TONGS TO MAKE UP SHOE TRACK Printed 6/24/2015 9:13:40AM North America-ALASKA-BP Page 9 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 00:00 9.00 CASING P SURF RUN 13-3/8",68#,L-80,BTC CASING TO 2272' MD -CHECK FLOATS-HOLDING -BACKERLOCK SHOE TRACK -USE BEST OF LIFE 2000 PIPE DOPE -TORQUE CONNECTIONS TO 21,500 FT-LBS W/VOLANT TOOL -1 CENTRALIZER LOCKED DOWN 5'FROM PIN ON JOINT A,AND 1 LOCKED DOWN MIDWAY ON JOINT B -RUNNING 95 CENTRALIZERS FREE FLOATING ON JOINTS 1-92 -RIH AT 50 FPM FROM SURFACE TO 500'MD, REDUCED SPEED TO 30 FPM FROM 1000'MD TO 2272'MD -BREAK CIRCULATION EVERY 10TH JOINT AT 5 BPM FOR 5 MINUTES FOR THE FIRST 1000' MD -OBTAIN PU AND SO WEIGHTS EVERY 10TH JOINT -DID NOT CIRCULATE FROM 1000'MD TO 2272'MD WHILE RUNNING THROUGH THE PERMAFROST PER PLAN -PUW=200K,SOW=105K AT 2272'MD -MW=8.9 PPG IN,9.1 PPG OUT -MUD LOSSES WHILE RIH:57 BBLS 3/19/2015 00:00 - 08:30 8.50 CASING P SURF CONTINUE TO RUN 13-3/8",68#,L-80,BTC CASING FROM 2272'MD TO 4143'MD -USE BEST OF LIFE 2000 PIPE DOPE -TORQUE CONNECTIONS TO 21,500 FT-LBS WI VOLANT TOOL -RUN 95 CENTRALIZERS FREE FLOATING ON JOINTS 1-92 -30 FT/MIN RUN SPEED -OBSERVED INCREASED DRAG,WASHED DOWN FROM 2272'MD TO 2477'MD AT 5 BPM TO CIRCULATE AN ANNULAR VOLUME, OBSERVED SIGNIFICANT AMOUNT OF SAND AND CLAY AT SHAKERS -WASHED DOWN FROM 2935'MD TO 3050'MD STAGING PUMPS UP TO 8 BPM -WASH DOWN FROM 3105'MD TO 3330'MD STAGING PUMPS UP TO 8-10 BPM -STACKED OUT WEIGHT AT 3285'MD,PICKED UP,SAT BACK DOWN,TOOK NO WEIGHT AND CONTINUED RUNNING -WASH DOWN FROM 3530'MD TO 3860'MD STAGING PUMPS UP TO 8 BPM, CONTINUE TO OBSERVE SIGNIFICANT AMOUNT OF SAND AND CLAY AT SHAKERS -WASH DOWN LAST FULL JOINT,HANGER WITH 30'PUP JOINT,AND LANDING JOINT AT 3 BPM -PUW=305K,SOW=175K WITH PUMPS ON -MW=9.2 PPG IN,9.3 PPG OUT -MUD LOSSES WHILE RUNNING IN HOLE:36 BBLS Printed 6/24/2015 9:13:40AM • • North America-ALASKA-BP Page 10 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual©69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 13:00 4.50 CEMT P SURF STAGE UP TO CEMENTING RATE IN 1/2 BPM INCREMENTS TO FINAL CIRCULATING RATE OF 10 BPM. -@ 5 BPM,136 PSI,13%RETURN FLOW -@ 6 BPM,180 PSI,14%RETURN FLOW -©7 BPM,155 PSI,14%RETURN FLOW -@ 8 BPM,155 PSI,14%RETURN FLOW -@ 9 BPM,168 PSI,15%RETURN FLOW -@ 10 BPM,184 PSI,16%RETURN FLOW -CONDITION MUD TO 9.1 PPG,14 PV,18 YP -INITIAL PRESSURE AT CEMENTING RATE: 184 PSI -FINAL PRESSURE AT CEMENTING RATE AFTER HOLE CONDITIONED:123 PSI -CIRCULATE TOTAL OF 3 TIMES BOTTOMS-UP -RECIPROCATED PIPE 15 FT AT SURFACE AT 5 FT/MIN -MUD LOSSES:5 BBL 13:00 - 14:00 1.00 CEMT P SURF -RIG UP CEMENTING LINES ON FLOOR -HELD PJSM ON CEMENTING 13-3/8" SURFACE CASING -REVIEWED PRESSURE CROSSCHECK Printed 6/24/2015 9:13:40AM • i North America-ALASKA-BP Page 11 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/me:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task , Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 20:30 6.50 CEMT P SURF CEMENT 13-3/8"SURFACE CASING AS FOLLOWS: -FILL LINES WITH WATER AND PRESSURE TEST TO 3000 PSI FOR 5 MINUTES -PUMP 100 BBLS OF 10 PPG MUDPUSH II SPACER @ 5 BPM,200 PSI -RELEASE BOTTOM PLUG -PUMP 916 BBLS OF 11 PPG LITECRETE LEAD CEMENT @ 6 BPM,EXCESS VOLUME 450%IN THE PERMAFROST AND 40%BELOW THE PERMAFROST(YIELD 1.91 CU.FT/SK) -PUMP 124 BBLS OF 15.8 PPG CLASS G TAIL @5 BPM -DROP TOP PLUG -RECIPROCATED PIPE 15 FT AT SURFACE WHILE PUMPING CEMENT AT 6 BPM -STOPPED RECIPROCATING AND LANDED HANGER ON LANDING RING TO DROP BOTTOM PLUG,BEFORE MUDPUSH REACHED THE SHOE,AND BEFORE LEAD CEMENT REACHED THE SHOE -STOPPED RECIPROCATING AND LANDED HANGER ON LANDING RING PERMANENTLY AT 830 BBLS OF LEAD CEMENT AWAY AS HOOKLOADS BEGAN TO DECREASE. PERFORM DISPLACEMENT WITH RIG PUMPS AND 9.1 PPG MAXDRIL-N MUD PER SLB CADE -200 BBLS DISPLACED AT 10 BPM:ICP 81PSI 19%RETURN FLOW,FCP 250 PSI 20% RETURN FLOW -360 BBLS DISPLACED AT 7 BPM:ICP 200 PSI 16%RETURN FLOW,FCP 875 PSI 14% RETURN FLOW -25 BBLS DISPLACED AT 5 BPM:ICP 825 PSI 7%RETURN FLOW,FCP 860 PSI 7%RETURN FLOW -REDUCE RATE TO 2 BPM PRIOR TO PLUG BUMP:FINAL CIRCULATING PRESSURE 800 PSI -BUMP PLUG AND INCREASE PRESSURE TO 1300 PSI,CHECK FLOATS-GOOD -TOTAL DISPLACEMENT VOLUME 593 BBLS (MEASURED BY STROKES @ 96%PUMP EFFICIENCY) -GOOD LEAD CEMENT RETURNS OBSERVED AT SURFACE AT 137 BBLS INTO DISPLACEMENT -TOTAL OF 478 BBLS OF LEAD CEMENT RETURNSTO SURFACE -MINIMAL LOSSES FROM CEMENT EXIT SHOE TO CEMENT IN PLACE. 20:30 - 00:00 3.50 CEMT P SURF -CLEAR FLOOR AND FLUSH OUT STACK, CLEAN FLOW BOX -RIG DOWN LANDING JOINT -BEGIN TO NIPPLE DOWN RISER AND DIVERTER Printed 6/24/2015 9:13:40AM North America-ALASKA-BP Page 12 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. WWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase i Description of Operations (hr) (usft) 3/20/2015 00:00 - 04:30 4.50 WHSUR P SURF ND DIVERTER -NIPPLE DOWN RISERS AND DIVERTER BAG -NIPPLE DOWN KNIFE VALVE -RIG DOWN VOLANT TOOL,BAIL EXTENSIONS,AND POWER TONGS -REMOVE MOUSE HOLE -NIPPLE DOWN DIVERTER LINE 04:30 - 06:30 2.00 WHSUR P SURF NIPPLE UP FMC 13-5/8"GEN 5 WELLHEAD 06:30 - 09:00 2.50 BOPSUR N HMAN 4,153.00 SURF NU BOP -NU HIGH PRESSURE RISER AND STACK -DISCOVERED THAT RISER WAS TOO SHORT -RACK BACK STACK,NIPPLE DOWN RISERS AND SWITCH OUT SHORT RISERS 09:00 - 17:00 8.00 BOPSUR P SURF NU BOP -NU RISERS AND STACK -INSTALL HOLE FILL LINE -HOOK UP KOOMY HOSES TO ANNULAR -INSTALL FLOW LINE -INSTALL SECONDARY VALVES ON OA AND IA 17:00 - 18:00 1.00 BOPSUR P SURF RIG UP TO TEST BOPS -PJSM FOR TESTING BOPS -FILL STACK,CHOKE,TOPDRIVE,AND SAFETY VALVES 18:00 - 00:00 6.00 BOPSUR P SURF BEGIN TO TEST BOPE TO 250 PSI LOW,4000 PSI HIGH FOR 5 MINUTES LOW/5 MINUTES HIGH -TEST WITH 5"TEST JOINT -ALL TESTS CHARTED,BOP TEST CHARTS ATTACHED TO NEXT DAYS REPORT -WITNESS WAIVED BY AOGCC REPRESENTATIVE JEFF JONES 19:30 3/20/15, SEE REMARKS 3/21/2015 00:00 - 00:30 0.50 BOPSUR P SURF FINISH TESTING BOPE TO 250 PSI LOW,4000 PSI HIGH FOR 5 MINUTES EACH -TEST WITH 5"TEST JOINT -NO FAILURES -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS -WITNESS WAIVED BY AOGCC REPRESENTATIVE JEFF JONES 19:30 3/20/15, SEE REMARKS 00:30 - 03:00 2.50 BOPSUR P SURF -RIG DOWN AND BLOW DOWN BOPE TESTING EQUIPMENT -PULL TEST PLUG AND SET WEAR RING -BREAK DOWN TEST JOINT AND TEST STUMP -CLEAN AND CLEAR RIG FLOOR -PREPARE PS-21S -INSTALL BX ELEVATORS -BRING BHA TOOLS TO RIG FLOOR 03:00 - 07:00 4.00 CLEAN P SURF MAKE UP 12-1/4"INTERMEDIATE SECTION#1 DRILLING BHA TO 816'MD -HOLD PJSM ON MAKING UP BHA -MAKE UP 12-1/4"PDC BIT,RSS AND MWD -PLUG IN TO MWD TOOLS -MAKE UP FLOAT SUB AND FILTER SUB -MAKE UP NON-MAG COLLARS -MAKE UP JARS Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP Page 13 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(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 CLEAN P SURF RUN IN HOLE ON ELEVATORS WITH 12-1/4" INTERMEDIATE SECTION#1 DRILLING BHA FROM 816'MD TO 2120'MD -RUN IN HOLE ON ELEVATORS PICKING UP 5" HEAVY WEIGHT SINGLES -MAKE UP GHOST REAMER AT 2056'MD -FILL PIPE AND SHALLOW TEST MWD TOOLS 11:00 - 12:30 1.50 CLEAN P SURF REPLACE PRESSURE RELIEF VALVE ON ACCUMULATOR SYSTEM -BUILD STANDS OFFLINE -SERVICE FLOOR EQUIPMENT 12:30 - 14:00 1.50 CLEAN P SURF CONTINUE TO RUN IN HOLE WITH 12-1/4" INTERMEDIATE SECTION#1 DRILLING BHA FROM 2120'MD TO 3900'MD -RUN IN HOLE ON ELEVATORS WITH 5" STANDS 14:00 - 15:00 1.00 CLEAN P SURF CIRCULATE SURFACE TO SURFACE PRIOR TO CASING TEST -750 GPM,1740 PSI -PU 171K,SO 126K,ROT 146K 15:00 - 16:30 1.50 CLEAN P SURF PRESSURE TEST 13-3/8"CASING TO 250 PSI LOW FOR 5 MIN/3500 PSI HIGH FOR 30 MINUTES EACH -TEST APPROVED BY BP WTL RICH BURNETT 16:30 - 21:00 4.50 CLEAN P SURF WASH DOWN TO FLOAT COLLAR AT 4053'MD AND DRILL OUT SHOE TRACK TO 4130'MD -750 GPM, 1800 PSI ON,1700 OFF -75 RPM,12K TORQUE ON,7K TORQUE OFF -PU 172K,SO 130K,ROT 147K 21:00 - 22:00 1.00 CLEAN P SURF CIRCULATE SURFACE TO SURFACE PRIOR TO DISPLACING TO NEW LSND MUD -845 GPM,2100 PSI -PU 172K,SO 128K,ROT 147K 22:00 - 23:00 1.00 CLEAN P SURF DISPLACE 9.0 PPG MAXDRIL-N WITH 9.8 PPG LSND -760 GPM,1450 PSI -ROTATE 75 RPMS,RECIPROCATED PIPE 30' -PUMPED 40 BBL HIGH VISCOSITY 9.8 LSND SPACER 23:00 - 00:00 1.00 CLEAN P SURF SLIP AND CUT DRILL LINE -HOLD PJSM ON SLIP AND CUT OPERATIONS -SLIP AND CUT 54' 3/22/2015 00:00 - 00:30 0.50 CLEAN P SURF COMPLETE SLIP AND CUT 54'OF DRILL LINE 00:30 - 03:00 2.50 DRILL P SURF DRILL OUT SHOE TRACK AND 20'OF NEW HOLE TO 4173'MD -650-750 GPM,1100 PSI ON,1000 PSI OFF -75 RPM,5-9K TORQUE 03:00 - 04:00 1.00 DRILL P SURF CIRCULATE BOTTOMS UP -750 GPM,1400 PSI -75 RPM,8K TORQUE 04:00 - 06:00 2.00 DRILL P SURF RIG UP AND PERFORM LOT -MUD WEIGHT:9.8 PPG,3832'TVD,4173'MD -PUMP 4.6 BBLS TO 919 PSI,BLEED BACK 2.1 BBLS -LOT EMW=14.41 PPG -NOTIFIED ODE OF LOT RESULTS AND GIVEN PERMISSION TO PROCEED AHEAD Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP • Page 14 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 12:00 6.00 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE#1 FROM 4173'MD TO 4801'MD(4418'TVD) (628'IN 6 HRS=105 FPH WITH CONNECTIONS) -922 GPM,2225 PSI ON,2225 PSI OFF.150 RPM,11K TO ON,10K TQ OFF,20K WOB -PUW=200K,SOW=134K,ROT=149K -ECD ACTUAL=10.3 -SURVEY EVERY STAND -MW=9.8PPG IN,9.8 PPG OUT -PUMPED 35-BBL HIGH VIS SWEEP AT 4717' MD WITH 10%INCREASE IN CUTTINGS -SV3 AT 4213'MD,3894'TVD -SV2 AT 4440'MD 4096'TVD 12:00 - 18:00 6.00 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE#1 FROM 4801'MD TO 5372'MD(4927'TVD) (571'IN 6 HOURS=95 FPH WITH CONNECTIONS) -922 GPM,2400 PSI ON,2385 PSI OFF,150 RPM,12K TQ ON,11K TQ OFF,20K WOB PUW=215K,SOW=136K,ROT=161K -ECD ACTUAL=10.3 PPG,CALCULATED=10.1 PPG -SURVEY EVERY STAND -MW=9.8PPG IN,9.8 PPG OUT -PUMPED 35-BBL HIGH VIS SWEEP AT 5290' MD WITH 100%INCREASE IN CUTTINGS -SV1 AT 4866'MD,4476'TVD 18:00 - 00:00 6.00 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE#1 FROM 5372'MD TO 6070'MD(5541'TVD) (698'IN 6 HOURS=116 FPH WITH CONNECTIONS) -922 GPM,2621 PSI ON,2590 PSI OFF,150 RPM,12-15K TQ ON,11K TQ OFF,20K WOB -PUW=240K,SOW=143K,ROT=168K -ECD ACTUAL=10.37 PPG,CALCULATED= 10.14PPG -SURVEY EVERY STAND -MW=9.8PPG IN,9.8 PPG OUT -PUMPED HIGH VIS SWEEP AT 5753'MD WITH 75%INCREASE IN CUTTINGS -PUMPED LUBE PILL AT 5850'MD WITH MINOR REDUCTION IN TORQUE -UG4 AT 5440'MD,4987'TVD -UG4AAT 5512'MD,5051'TVD -UG3 AT 5760'MD,5269'TVD Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP Page 15 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/me:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual i69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/23/2015 00:00 - 06:00 6.00 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE#1 FROM 6070'MD TO 6750'MD(6139'TVD) (680'IN 6 HOURS=113 FPH WITH CONNECTIONS) -922 GPM,2850 PSI ON,2850 PSI OFF,150 RPM,15K TQ ON,13K TQ OFF,20K WOB -PU=265K,SO=155K,ROT=185K -ECD ACTUAL=10.44 PPG,CALCULATED= 10.14PPG -SURVEY EVERY STAND -MW=9.8 PPG IN,9.9 PPG OUT -PUMPED HIGH VIS SWEEP AT 6225'MD WITH 50%INCREASE IN CUTTINGS -PUMPED HIGH VIS SWEEP AT 6604'MD WITH 50%INCREASE IN CUTTINGS -UG1 AT 6468'MD,5892 TVD 06:00 - 12:00 6.00 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE#1 FROM 6750'MD TO 7264'MD(6591'TVD) (514'IN 6 HOURS=86 FPH WITH CONNECTIONS) -922 GPM,3070 PSI ON,3070 PSI OFF,150 RPM,16K TQ ON,14K TQ OFF,20K WOB -PU=286K,SO=158K,ROT=193K -ECD ACTUAL=10.6 PPG,CALCULATED=10.52 PPG -SURVEY EVERY STAND -MW=10.2 PPG IN,10.2 PPG OUT -WEIGHTED UP TO 10.2 PPG PRIOR TO 7300' MD PER PLAN -UG_MA AT 6840'MD,6219'TVD -UG_MB1 AT 6862'MD,6269'TVD -UG_MB2 AT 6965'MD,6319'TVD -UG_MC AT 7050'MD,6382'TVD -WS2 AT 7097'MD,6445'TVD 12:00 - 18:00 6.00 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE#1 FROM 7264'MD TO 7905'MD(7155'TVD) (641'IN 6 HOURS=107 FPH WITH CONNECTIONS) -922 GPM,3425 PSI ON,3386 PSI OFF,150 RPM,16-23K TQ ON,16-21K TQ OFF,20K WOB -PU=265K,SO=167K,ROT= 201K -ECD ACTUAL=10.94 PPG,CALCULATED= 10.55 PPG -SURVEY EVERY STAND -BACKREAM 25'PRIOR TO CONNECTIONS -MW=10.3 PPG IN,10.3 PPG OUT -PUMPED HIGH VIS SWEEP AT 7465'MD WITH 25%INCREASE IN CUTTINGS -WS1 AT 7307'MD,6630'TVD -CM3 AT 7504'MD,6803'TVD Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP • Page 16 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/me:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual i69.55usft(above Mean Sea Level) Date From-To ! Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 22:30 4.50 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE#1 FROM 7905'MD TO 8248'MD(7457'TVD) (343'IN 6 HOURS=57 FPH WITH CONNECTIONS) -922 GPM,3470 PSI ON,3400 PSI OFF,100 RPM,16-24K TQ ON,16-19K TQ OFF,20K WOB -PU=260K,SO=179K,ROT= 207K -ECD ACTUAL=10.87 PPG,CALCULATED= 10.55 PPG -SURVEY EVERY STAND -BACKREAM 25'PRIOR TO CONNECTIONS -MW=10.35 PPG IN,10.35 PPG OUT -PUMPED HIGH VIS SWEEP AT 7952'MD WITH 50%INCREASE IN CUTTINGS -CM2 AT 8097'MD,7324'TVD 22:30 - 00:00 1.50 DRILL N WSEQ 8,248.00 INTI REPAIR MUD PUMP#2 VALVE SEAT AND LINER WASHOUTS -REPLACE WASHED OUT VALVE SEAT ASSEMBLY -REPLACE SWAB AND LINER -PUMP AT 460 GPM WITH PUMP#1 -RECIPROCATE PIPE 30' 3/24/2015 00:00 - 00:30 0.50 DRILL N WSEQ 8,248.00 INTI CONTINUE TO REPAIR MUD PUMP#2 VALVE SEAT AND LINER WASHOUTS -REPLACE WASHED OUT VALVE SEAT ASSEMBLY -REPLACE SWAB AND LINER -PUMP AT 460 GPM WITH PUMP#1 -RECIPROCATE PIPE 30" 00:30 - 04:30 4.00 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE#1 FROM 8248'MD TO 8502'MD (254'IN 6 HOURS=63.5 FPH WITH CONNECTIONS) -922 GPM,3470 PSI ON,3400 PSI OFF,100 RPM,16-24K TO ON,16-19K TQ OFF,20K WOB -PU=260K,SO=179K,ROT= 207K -ECD ACTUAL=10.85 PPG,CALCULATED= 10.63 PPG -SURVEY EVERY STAND -BACKREAM 25'PRIOR TO CONNECTIONS -MW=10.35 PPG IN,10.35 PPG OUT -PUMP 40 BBL 2PPG OVER WEIGHTED SWEEP AT 8405'MD -75%INCREASE IN CUTTINGS OBSERVED AT SHAKERS 04:30 - 07:30 3.00 DRILL N WSEQ 8,502.00 INTI REPLACE ALL 3 SWABS ON MUD PUMP#1 -PUMP AT 420 GPM WITH PUMP#2 -RECIPROCATE PIPE Printed 6/24/2015 9:13:40AM North America-ALASKA-BP • Page 17 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UW1:500292353500 Active datum:L3-03 Actual @69.55usft(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 INTI DRILL 12-1/4"INTERMEDIATE HOLE#1 FROM 8502'MD TO 8720'MD(7869'TVD) (218'IN 4.5 HOURS=48.4 FPH VV1TH CONNECTIONS) -922 GPM,3640 PSI ON,3640 PSI OFF,120 RPM,15-20K TO ON,13-18K TQ OFF,17K WOB -PU=277K,SO=196K,ROT= 215K ECD ACTUAL=10.9 PPG,CALCULATED=10.7 PPG -SURVEY EVERY STAND -NO BACKREAMING AT CONNECTIONS -MW=10.4 PPG IN,10.4 PPG OUT SLOW PUMP RATES:8400'MD,7592'TVD -MP1:30/40 SPM;264/305 PSI -MP2:30/40 SPM;260/300 PSI -CM1 AT 8570'MD,7741'TVD,7671'TVDSS 12:00 - 18:00 6.00 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE#1 FROM 8720'MD TO 8974'MD(8089'TVD) (254'IN 6 HOURS=42.3 FPH WITH CONNECTIONS) -922 GPM,3740 PSI ON,3730 PSI OFF,120 RPM,10-17K TO ON,10-17K TQ OFF,20K WOB -PU=278K,SO=200K,ROT=227K -ECD ACTUAL=10.91 PPG,CALCULATED= 10.73 PPG -SURVEY EVERY STAND -BACKREAM 25'AT CONNECTIONS -MW=10.4 PPG IN,10.4 PPG OUT -PUMP 40 BBL HIGH VIS SWEEP AT 8990'MD -75%INCREASE IN CUTTINGS OBSERVED A SHAKERS 118:00 - 23:30 5.50 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE#1 FROM 8974'MD TO SECTION TD AT 9258'MD(8330' TVD) (284'IN 5.5 HOURS=51.6 FPH WITH CONNECTIONS) -922 GPM,3780 PSI ON,3760 PSI OFF,150 RPM,12-20K TQ ON,9-18K TQ OFF,20K WOB -PU=273K,SO=203K,ROT=230K -ECD ACTUAL=10.88 PPG,CALCULATED= 10.71 PPG -SURVEY EVERY STAND -NO BACKREAMING AT CONNECTIONS -MW=10.4 PPG IN,10.4 PPG OUT SLOW PUMP RATES:8874'MD,8003'TVD -MPI:30/40 SPM;250/300 PSI -MP2:30/40 SPM;260/310 PSI -THRZ AT 9072'MD,8173'TVD,8103'TVDSS -BHRZ SILT AT 9220'MD,8298'TVD,8228' TVDSS PLANNED INTERMEDIATE 1 CASING PT AT 9253'MD;-20'-45'MD ABOVE THE TSAD 23:30 - 00:00 0.50 DRILL P INTI SERVICE TOP DRIVE,GREASE WASHPIPE AND ST-80 Printed 6/24/2015 9:13:40AM North America-ALASKA-BP Page 18 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:OOAM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual f69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/25/2015 00:00 - 03:00 3.00 DRILL P INTI CIRCULATE THE HOLE CLEAN PRIOR TO SHORT TRIP-TOTAL OF 4 BOTTOMS UP -922 GPM;3750 PSI -160 RPM;15K TORQUE -PUMP 40 BBL HIGH VIS SWEEP AT 9528'MD -75%INCREASE IN CUTTINGS OBSERVED SLOW PUMP RATES:9258'MD,8330'TVD -MPI:30/40 SPM;184/253 PSI -MP2:30/40 SPM;185/255 PSI 03:00 - 05:00 2.00 DRILL P INTI SHORT TRIP FROM 9258'MD TO 7660'MD MONITOR THE WELL FOR 10 MIN;STATIC PUMP OUT OF THE HOLE THROUGH THE HRZ,FROM 9258'MD TO 9000'MD -42 GPM;50 PSI;PULLED AT 40 FPM. PULL ON ELEVATORS FROM 9000'MD TO 7660'MD. -PU 300K;SO 200KAT 9000'MD. -PULL 40K OVER AND WIPED CLEAN AT 8745' MD -PULL 50K OVER AND WIPED AT 8636'MD,NO SIGNIFICANT OVERPULL OBSERVED AFTER WIPING. -OBSERVED 30K DRAG FROM 7840 TO 7660' MD 05:00 - 10:00 5.00 DRILL P INTI RUN BACK IN THE HOLE FROM 7660'MD TO 7950'MD AND CIRCULATE THE HOLE CLEAN. -970 GPM;3750 PSI -160 RPM;10-13K TORQUE;RECIPROCATING FULL STAND -CIRCULATE 4 BOTTOMS UP; -PUMP 40 BBL HIGH VIS SWEEP AT 7900'MD -50%INCREASE IN CUTTINGS OBSERVED 10:00 - 10:30 0.50 DRILL P INTI BACKREAM FROM 7640'MD TO 7385'MD -MONITOR THE WELL FOR 5 MIN;STATIC -963 GPM;3625 PSI -150 RPM;8-16K TORQUE -BACKREAMING AT 400 FT/HR. 10:30 - 12:00 1.50 DRILL N WSEQ 7,385.00 INTI REPLACE SWAB ON MUD PUMP#2 -PUMP AT 420 GPM WITH PUMP#1 -RECIPROCATE PIPE 12:00 - 13:00 1.00 DRILL P INTI CIRCULATE HOLE CLEAN BEFORE PULLING OUT OF THE HOLE -PUMP 40 BBL 2PPG OVER,WEIGHTED SWEEP AT 7385'MD -75%INCREASE IN CUTTINGS OBSERVED AT SHAKERS -972 GPM;3700 PSI -150 RPM;8-15K TORQUE;RECIPROCATING PIPE AT 400 FT/HR. 13:00 - 14:00 1.00 DRILL P INTI ATTEMPT TO PULL OUT OF THE HOLE ON ELEVATORS -PULL 30-40K OVER;ATTEMPT TO WIPE HOLE-NO IMPROVEMENT IN DRAG NOTED. -RUN IN THE HOLE TO 7835'MD. Printed 6/24/2015 9:13:40AM • • North America-ALASKA-BP Page 19 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task I Code ' NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 22:30 8.50 DRILL P INTI BACKREAM FROM 7835'MD TO 5782'MD -MONITOR THE WELL FOR 5 MIN;STATIC -922 GPM;3370 PSI AT 7835'MD -160 RPM;8-10K TORQUE;206K ROTATING WEIGHT -BACKREAMING SPEEDS FROM 700 FT/HR; DROPPING TO 400 FT/HR TO MANAGE ECDS 22:30 - 00:00 1.50 DRILL P INTI PULL OUT OF THE HOLE ON ELEVATORS FROM 5782'MD TO 4266'MD -MONITOR THE WELL FOR 5 MIN;STATIC -MUD WEIGHT;10.4 PPG IN 10.4 PPG OUT -PU 160K,SO 137KAT 4380'MD -NO INDICATIONS OF SWABBING WHILE PULLING,HOLE TAKING PROPER FILL. 3/26/2015 00:00 - 00:30 0.50 DRILL P INTI CONTINUE TO PULL OUT OF THE HOLE ON ELEVATORS FROM 4266'MD TO 3912'MD -MUD WEIGHT;10.4 PPG IN 10.4 PPG OUT -PU 160K,SO 137KAT 4380'MD -NO INDICATIONS OF SWABBING WHILE PULLING,HOLE TAKING PROPER FILL. 00:30 - 01:30 1.00 DRILL P INTI CIRCULATE 2 BOTTOMS UP AT 3912'MD -910 GPM;2600 PSI -160 RPM;7K TORQUE;133K ROTATING WEIGHT -PUMP 40 BBL 4OPPB WALNUT SWEEP TO CLEAN CLAY OFF GHOST REAMER/BHA -ECD ACTUAL FROM 11.01 PPG TO 10.89 PPG AFTER SWEEP 01:30 - 04:00 2.50 DRILL N WSEQ 3,912.00 INTI INSPECT AND CHANGE SAVER SUB ON TOP DRIVE AFTER BACKREAMING CHANGE LINERS,SWABS,VALVES AND SEATS ON MUD PUMPS 04:00 - 08:30 4.50 DRILL P INTI RUN IN THE HOLE ON ELEVATORS WITH 12.25"DRILLING ASSEMBLY FROM 3912'MD TO 8119'MD -FILL PIPE EVERY 20 STANDS -ENCOUNTERED TIGHT HOLE AT 8119'MD; -SET DOWN 40K,PICKED UP 30K OVER TO PULL FREE -ATTEMPT TO WORK THROUGH SEVERAL TIMES;NO CHANGE -ESTABLISH CIRCULATION AND WASH STAND DOWN -420 GPM; 1170 PSI -ABLE TO WORK THROUGH WITH NO ISSUES AFTER WASHING DOWN. -CONTINUE TO RUN IN THE HOLE ON ELEVATORS TO 8341'MD. 08:30 - 10:00 1.50 DRILL P INTI CIRCULATE 1 BOTTOMS UP;ROTATING AND RECIPROCATING 1 STAND -920 GPM;3600 PSI -160 RPM;14K TORQUE Printed 6/24/2015 913:40AM • North America-ALASKA-BP Page 20 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 11:00 1.00 DRILL P INTI RUN IN THE HOLE ON ELEVATORS WITH 12.25"DRILLING ASSEMBLY FROM 8341'MD TO 8972'MD -ENCOUNTERED TIGHT HOLE AT 8972'MD; -SET DOWN 30K -ATTEMPT TO WORK THROUGH SEVERAL TIMES;NO CHANGE ESTABLISH CIRCULATION;WASH AND REAM STAND DOWN -910 GPM;1100 PSI -60 RPM;15K TORQUE -ABLE TO WORK THROUGH WITH NO ISSUES AFTER REAMING DOWN. -CONTINUE TO RUN IN THE HOLE ON ELEVATORS TO TD AT 9258'MD. -NO FILL NOTED ON BOTTOM -FAULT PICKED AT 9009'MD 11:00 - 18:30 7.50 DRILL P INTI CIRCULATE HOLE CLEAN AT SECTION TO WITH 7.5 BOTTOMS UP WHILE RACKING BACK STANDS FROM 9258'MD TO 8909'MD -920 GPM;3900 PSI -160 RPM;15K TORQUE;229K ROTATING WEIGHT -PU 280K;SO 205K -MUD WEIGHT:10.4 PPG IN,10.4+PPG OUT -100 FT/HR(BACKREAMING)-600 FPH (RECIPROCATING) -PUMP 30 BBL LOW-VIS/35 BBL HIGH-VIS SWEEP -75%INCREASE IN CUTTINGS OBSERVED A SHAKERS -PUMP 35 BBL 2 PPG OVER,WEIGHTED SWEEP -50%INCREASE IN CUTTINGS OBSERVED A SHAKERS -PUMP 60 BBL HIGH-VIS SWEEP -25%INCREASE IN CUTTINGS OBSERVED A SHAKERS 18:30 - 19:00 0.50 DRILL P INTI RUN IN THE HOLE TO THRZ ON ELEVATORS, FROM 8909'MD TO 9098'MD -MONITOR THE WELL FOR 10 MIN;STATIC -PU 280 K;SO 200K -NO ISSUES PASSING THROUGH 8972', SHORT TRIP TROUBLE DEPTH. _ 19:00 - 19:30 0.50 DRILL P INTI ATTEMPT TO PULL OUT OF THE HOLE ON ELEVATORS,FROM 9098'MD TO 8780'MD -PU 280K;SO 193K -ENCOUNTERED TIGHT HOLE AT 8780'MD; PULLED 50K OVER -ATTEMPT TO WORK THROUGH SEVERAL TIMES 19:30 - 20:00 0.50 DRILL P INTI RUN IN THE HOLE ON ELEVATORS,FROM 8780'MD TO 9000'MD -MONITOR THE WELL FOR 10 MIN;STATIC -PU 285 K;SO 196K 20:00 - 21:30 1.50 DRILL P INTI BACKREAM FROM 9000'MD TO 8814'MD -913 GPM;3400 PSI -160 RPM;0-18K TORQUE -PU 282K;SO 193K;ROT 223K -BACKREAM I N G AT 400 FT/HR. Printed 6/24/2015 9:13:40AM North America-ALASKA-BP Page 21 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual i 69.55usft(above Mean Sea Level) Date From-To Hrs : Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:30 - 22:00 0.50 DRILL P INTI ATTEMPT TO PULL OUT OF THE HOLE ON ELEVATORS,FROM 8814'MD TO 8626'MD -PU 282K;SO 193K -ENCOUNTERED TIGHT HOLE AT 8626'MD; PULLED 50K OVER -ATTEMPT TO WORK THROUGH SEVERAL TIMES -RUN BACK IN THE HOLE TO 8814'MD 22:00 - 23:00 1.00 DRILL P INTI CIRCULATE A BOTTOMS UP;ROTATING AND RECIPROCATING FROM 8814'MD TO 8719'MD -913 GPM;3400 PSI -160 RPM;10-17K TORQUE -PU 285K;SO 193K;ROT 220K -RECIPROCATING PIPE AT 400 FT/HR -NO INCREASE IN CUTTINGS OBSERVED AT BOTTOMS UP 23:00 - 23:30 0.50 DRILL P INTI ATTEMPT TO PULL OUT OF THE HOLE ON ELEVATORS,FROM 8719'MD TO 8151'MD -PU 280K -INCREASE IN DRAG NOTED;PULLING UP TO 50K OVER 23:30 - 00:00 0.50 DRILL P INTI CIRCULATE THE HOLE CLEAN; RECIPROCATING FROM 8151'MD TO 8065'MD -915 GPM;3325 PSI -RECIPROCATING PIPE AT 800 FT/HR 3/27/2015 00:00 - 00:30 0.50 DRILL P INTI CONTINUE TO CIRCULATE THE HOLE CLEAN; RECIPROCATING FROM 8151'MD TO 8065'MD -915 GPM;3325 PSI -RECIPROCATING PIPE AT 400 FT/HR -NO INCREASE IN CUTTINGS OBSERVED AT BOTTOMS UP 00:30 - 02:00 1.50 DRILL P INTI PULL OUT OF THE HOLE ON ELEVATORS, FROM 8065'MD TO 6818'MD -PU 280K;SO 175KAT 8065'MD -HOLE FILL ERRATIC -TROUBLESHOOT TRIP TANKS -CONFIRM WELL NOT FLOWING OR SWABBING 02:00 - 03:00 1.00 DRILL P INTI CIRCULATE A BOTTOMS UP TO CONFIRM NO HOLE FILL ISSUES -900 GPM;3000 PSI -NO ROTATION;RECIPROCATING PIPE AT 300 FT/HR -NO INCREASE IN CUTTINGS OBSERVED AT BOTTOMS UP -MONITOR THE WELL FOR 10 MIN;STATIC 03:00 - 05:00 2.00 DRILL P INTI PULL OUT OF THE HOLE ON ELEVATORS, FROM 6818'MD TO 13-3/8"CASING SHOE AT 4143'MD -PU 235K;SO 160KAT 6800'MD -HOLE TAKING PROPER FILL. 05:00 - 06:30 1.50 DRILL P INTI CIRCULATEAHIGH-VISSWEEPAND3 BOTTOMS UP AT THE 13-3/8"CASING SHOE, 4143'MD -MONITOR THE WELL FOR 10 MIN;STATIC. -915 GPM;2550 PSI -160 RPM;5K TORQUE -PU 158K;SO 132K;ROT 140K -RECIPROCATING PIPE AT 800 FT/HR -20%INCREASE IN RETURNS OBSERVED AT THE SHAKERS WITH THE SWEEP. Printed 6/24/2015 9:13:40AM 4111 • North America-ALASKA-BP Page 22 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:30 - 09:00 2.50 DRILL P INTI CONTINUE TO PULL OUT OF THE HOLE ON ELEVATORS,FROM 4120'MD TO 816'MD -MONITOR THE WELL FOR 10 MIN;STATIC -PU 140K;SO 140K AT 4120'MD -HOLE TAKING PROPER FILL. 09:00 - 09:30 0.50 BOPSUR P INTI PERFORM WEEKLY BOPE FUNCTION TEST -FUNCTION ANNULAR,LOWER RAMS,UPPER RAMS,HCR KILL AND HCR CHOKE 09:30 - 12:00 2.50 DRILL P INTI PULL AND LAY DOWN 12-1/4"DRILLING BHA. -MONITOR THE WELL FOR 10 MIN:STATIC -STAND BACK 5"HWDP AND DRILLING JARS IN DERRICK -LAY DOWN 6-3/4"COLLARS AND REMAINDER OF BHA TO PIPE SHED BIT GRADE:1-1-CT-A-X-I-WT—TD SEE ATTACHED PHOTOS OF BIT 12:00 - 13:00 1.00 DRILL P INTI CLEAN AND CLEAR RIG FLOOR OF ALL BHA TOOLS AND EQUIPMENT. PREP CASING RUNNING EQUIPMENT IN THE PIPE SHED. FUNCTION TEST BLIND/SHEAR RAMS RIG WENT ON HIGH LINE POWER 13:00 - 14:00 1.00 CASING P INTI PICKUP SHEAR JOINT AND WEAR RING RUNNING TOOL. DRAIN STACK. RUN IN THE HOLE AND BACK OUT LOCK DOWN SCREWS. PULL WEAR RING. 14:00 - 16:00 2.00 BOPSUR P INTI CHANGE UPPER PIPE RAMS FROM 2-7/8"x 5" VBR TO 9-5/8"CASING RAMS -INSPECT AND CHANGE OUT DOOR SEALS 16:00 - 17:00 1.00 BOPSUR P INTI MAKE UP 9-5/8"TEST JOINT AND RIG UP TEST EQUIPMENT ON RIG FLOOR RUN AND SET TEST PLUG. 17:00 - 17:30 0.50 BOPSUR P INTI PRESSURE TEST UPPER 9-5/8"CASING RAMS;250/4000 PSI FOR 5 CHARTED MIN EACH. -GOOD TEST;SEE ATTACHED TEST CHART 17:30 - 18:00 0.50 BOPSUR P INTI RIG DOWN TEST JOINT AND TEST EQUIPMENT. DRAIN STACK AND PULL TEST PLUG BLOW DOWN LINES Printed 6/24/2015 9:13:40AM North America-ALASKA-BP Page 23 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UW:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (usft) 18:00 - 22:30 4.50 CASING P INTI RIG UP TO RUN 9-5/8",47#,L-80,VAMTOP/ TCII INTERMEDIATE 1 CASING STRING -PJSM WITH RIG CREWAND DOYON CASING CREW ON RIGGING UP TO RUN CASING -RIG UP VOLANT TOOL AND TORQUE TURN EQUIPMENT -INSTALL PS-21 INSERTS -REMOVE BAILS AND PICK UP LONG BAILS. -INSTALL LONG BAILS AND 4'BAIL EXTENSIONS -RIG UP 9-5/8"SIDE-DOOR ELEVATORS -MAKE UP 2 PART 9-5/8"LANDING JOINT AND LAY DOWN TO PIPE SHED -MAKE UP SHEAR JOINT WITH CLOSED FOSV -MAKE UP CROSSOVER FROM VAMTOP TO 4-1/2"IF AND FOSV - VERIFY ELEVATOR ID AND CASING COLLAR OD PRIOR TO RUNNING CASING. 22:30 - 00:00 1.50 CASING P INTI RUN 9-5/8",47#,L-80,VAMTOP/TCII INTERMEDIATE 1 CASING STRING FROM SURFACE TO 121'MD. -PICK UP AND MAKE UP 9-5/8"SHOE TRACK -BAKER-LOK SHOE TRACK CONNECTIONS -MAKE UP BTC CONNECTIONS TO THE MARK -CHECK FLOATS;GOOD 3/28/2015 00:00 - 12:00 12.00 CASING P INTI RUN 9-5/8",47#,L-80,VAMTOP/TCII INTERMEDIATE 1 CASING FROM 121'MD TO 4136'MD AT 12:00 -MAKE UP CROSSOVER FROM TC-II TO 4-1/2" IF AND FOSV -USE VOLANT TOOL TO TORQUE TURN VAMTOP CONNECTIONS TO 15,900 FT-LBS -USE VOLANT TOOL TO TORQUE TURN TCII CONNECTIONS TO 17,500 FT-LBS -USE JET LUBE SEAL GUARD PIPE DOPE ON ALL CONNECTIONS -RUN FREE FLOATING CENTRALIZER ON EVERY JOINT ABOVE SHOE TRACK TO 50' OUTSIDE 13-3/8"SHOE. -FILL CASING EVERY 10TH JOINT -RUN IN THE HOLE AT 100 FT/MIN -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT -PU 199K,SO 175KAT4136'MD -AVERAGE 10 JOINTS PER HOUR UNANNOUNCED D2,KICK WHILE TRIPPING DRILL,AND AAR AFTER RUNNING ALL OF THE VAMTOP. CREW RESPONDED APPROPRIATELY AND SECURED THE WELL IN 2 MIN 30 SEC. DISCUSSED CHANGING ELEVATORS TO HANDLE THE 5"SAFETY JOINT STAGE UP PUMPS AT 1 BPM AND CIRCULATE A BOTTOMS UP AT THE 13-3/8"CASING SHOE -FINAL CIRCULATING PRESSURE AT 7 BPM; 233 PSI MUD LOSSES WHILE RUNNING IN THE HOLE SINCE MIDNIGHT-22 BBLS. Printed 6/24/2015 9:13:40AM North America-ALASKA-BP Page 24 of 63 Operation Summary Report Common Well Name:L3-03 ,AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 00:00 12.00 CASING P INTI CONTINUE TO RUN 9-5/8",47#,L-80, VAMTOP/TCII INTERMEDIATE 1 CASING FROM 4136'MD TO 7534'MD AT MIDNIGHT -USE VOLANT TOOL TO TORQUE TURN TCII CONNECTIONS TO 17,500 FT-LBS -USE JET LUBE SEAL GUARD PIPE DOPE ON ALL CONNECTIONS -RUN FREE FLOATING CENTRALIZER ON EVERY JOINT ABOVE SHOE TRACK TO 50' OUTSIDE 13-3/8"SHOE. -ADJUST RUNNING SPEED AS NEEDED TO MAINTAIN PROPER DISPLACEMENTS: -100 FT/MIN FROM 4136'MD TO 4737'MD -60 FT/MIN FROM 4737'MD TO 4939'MD -40 FT/MIN FROM 4939'MD TO 7534'MD -FILL ON FLY AND BREAK CIRCULATION EVERY 5 JOINTS FOR 5 MIN -STAGE PUMP RATES UP TO 7 BPM IN 1 BPM INCREMENTS -CIRCULATE A BOTTOMS UP OVER 6 JOINTS PRIOR TO ENTERING THE WS1 FORMATION AT 7307'MD -STAGE PUMP RATES UP TO 7 BPM IN 1 BPM INCREMENTS AND CIRCULATE EACH JOINT DOWN FOR 10 MIN. -FINAL CIRCULATING PRESSURE AT 7 BPM;410 PSI -MUD WEIGHT:10.3+PPG IN,10.6 PPG OUT -PU 357K,SO 251 K AT 7534'MD -AVERAGE 7 JOINTS PER HOUR OVER 12 HOURS MUD LOSSES WHILE RUNNING IN THE HOLE FOR THE DAY-42 BBLS(-1.75 BPH OVER 24 HRS) Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP Page 25 of 63 Operation Summary Report Common Well Name:L3-03 'AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/me:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) _ 3/29/2015 00:00 - 08:00 8.00 CASING P INTI CONTINUE TO RUN 9-5/8",47#,L-80, VAMTOP/TCII INTERMEDIATE 1 CASING FROM 7534'MD TO 9252'MD -USE VOLANT TOOL TO TORQUE TURN TCII CONNECTIONS TO 17,500 FT-LBS -USE JET LUBE SEAL GUARD PIPE DOPE ON ALL CONNECTIONS RUN FREE FLOATING CENTRALIZER ON EVERY JOINT ABOVE SHOE TRACK TO 50' OUTSIDE 13-3/8"SHOE. -TOTAL CENTRALIZERS RUN=125;STOP RINGS=4 -ADJUST RUNNING SPEED AS NEEDED TO MAINTAIN PROPER DISPLACEMENTS: -40 FT/MIN FROM 7534'MD -FILL ON FLY AND BREAK CIRCULATION EVERY 5 JOINTS FOR 5 MIN -STAGE PUMP RATES UP TO 7 BPM IN 1 BPM INCREMENTS AT 7800'MD,BROOMSTICK TREND INDICATED AN INCREASE IN DRAG FROM MODEL;CIRCULATE A BOTTOMS UP OVER 6 JOINTS FROM 8200'MD TO 8400'MD(CM3) -STAGE PUMP RATES UP TO 7 BPM IN 1 BPM INCREMENTS AND CIRCULATE EACH JOINT DOWN FOR 10 MIN. -FINAL CIRCULATING PRESSURE AT 7 BPM;360 PSI FROM 8118'MD TO THE THRZ AT 9072'MD, CIRCULATE A BOTTOMS UP OVER 7 JOINTS -STAGE PUMP RATES UP TO 7 BPM IN 1 BPM INCREMENTS AND CIRCULATE EACH JOINT DOWN FOR 10 MIN. -FINAL CIRCULATING PRESSURE AT7 BPM;471 PSI MAKE UP LANDING JOINT AND WASH TO BOTTOM -ENCOUNTERED 11'OF FILL ON BOTTOM -STAGE UP PUMPS TO 6 BPM IN 1 BPM INCREMENTS WHILE WASHING STRING TO BOTTOM;350-506 PSI -MUD WEIGHT:10.5 PPG IN,10.5 PPG OUT -TOTAL LOSSES DURING CASING RUN=53 BBLS(-1.6 BPH FOR 33.5 HR RUN) -AVERAGE 7 JOINTS PER HOUR -FINAL PICKUP=447 KLBS,SO=272 KLBS, PARKER 272 TD/BLOCKS=35 KLBS Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP Page 26 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:00 - 12:00 4.00 CEMT P INTI CIRCULATE HOLE CLEAN AND CONDITION MUD FOR CEMENT AND RECIPROCATE PIPE 15'STROKES AT 1000 FT/HR -STAGE PUMPS UP TO CEMENTING RATE IN 1BPM INCREMENTS UP TO 7 BPM -@ 2 BPM;325 PSI -@ 3 BPM;365 PSI -@ 4 BPM;385 PSI -@ 5 BPM;420 PSI -@ 6 BPM;445 PSI -@ 7 BPM;440 PSI -INITIAL PRESSURE AT CIRCULATING RATE: 420 PSI -FINAL PRESSURE AT CIRCULATING RATE AFTER HOLE CONDITIONED:377 PSI -CIRCULATED A TOTAL OF 2.5 BOTTOMS UP -MUD WEIGHT:10.3+PPG IN,10.3+PPG OUT -CUT MUD YIELD POINT BACK FROM 20 TO 18 -MUD LOSSES WHILE CIRCULATING:5 BBL SIMOPS: -MIRU SLB CEMENTERS. PRESSURE TEST LINES TO 250 PSI LOWAND 4500 PSI HIGH FOR FIVE MIN EACH TO LEAKTIGHT CRITERIA (PASS) • Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP Page 27 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) " Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. WWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 17:00 5.00 CEMT P INTI CEMENT 9-5/8",47#,L-80,VAMTOP/TCII INTERMEDIATE 1 CASING AS FOLLOWS: -PUMP 50 BBLS OF 11.0 PPG MUDPUSH II SPACER @ 5 BPM,400PSI ICP,310 PSI FCP -UNSTING VOLANT TOOL AND DROP BOTTOM PLUG -PUMP 277 BBLS(893 SACKS)OF 11.5 PPG LITECRETE LEAD CEMENT @ 5 BPM,EXCESS VOLUME 40%(YIELD 1.74 CU.FT/SK),500 ICP, 200 FCP -PUMP 84 BBLS(407 SACKS)OF 15.8 PPG CLASS G TAIL CEMENT @ 5 BPM,EXCESS VOLUME 40%(YIELD 1.16 CU.FT/SK),200 CIP, 100 FCP -UNSTING VOLANT TOOL AND DROP TOP PLUG -SLB KICK OUT PLUG WITH 10 BBLS 8.33 PPG FRESH WATER;5 BPM,50 PSI PERFORM DISPLACEMENT WITH RIG PUMPS AND 10.3+PPG LSND MUD PER SLB CADE -650 BBLS DISPLACED AT 7 BPM:ICP 242 PSI, FCP 244 PSI -11.4 BBLS DISPLACED AT 2 BPM:ICP 244 PSI,FCP 791 PSI -REDUCE RATE TO 2 BPM IN ANTICIPATION OF PLUG BUMP:FINAL CIRCULATING PRESSURE 791 PSI -DID NOT BUMP PLUG ON CALCULATED STROKES FOR 96%PUMP EFFICIENCY; PUMPED AN ADDITIONAL 3 BBL(1/2 SHOE TRACK VOLUME)AND SHUT DOWN DISPLACEMENT WITHOUT PLUG BUMP. -BLEED OFF AND CHECK FLOATS(PASS) -TOTAL DISPLACEMENT VOLUME 671.4 BBLS (MEASURED BY STROKES @ 96%PUMP EFFICIENCY) -RECIPROCATE PIPE 15'STROKES DURING ALL PUMPING,EXCEPT WHEN NEW FLUID ROUNDS CORNER.LANDED HANGER WHEN DISPLACEMENT RATE REDUCED TO 2 BPM. -TOTAL LOSSES FROM CEMENT EXIT SHOE TO CEMENT IN PLACE:5 BBLS CEMENT IN PLACE AT 17:00(LEAD CEMENT- 500 PSI COMPRESSIVE STRENGTH AT 17:00 ON 3/30/15) FIELD ESTIMATE TOC 4710'MD(650'ND ABOVE UG4) 17:00 - 18:30 1.50 CEMT P INTI ESTABLISH INJECTION DOWN THE 13-3/8"X 9-5/8"ANNULUS FOR FREEZE PROTECT. -CLOSE ANNULAR PREVENTER ON LANDING JOINT AND INITIATE INJECTION DOWN OA(TO CONFIRM INJECTIVITY). 17:45 BREAKDOWN AT 1275 PSI,PUMP 7 BBLS 10.3+PPG LSND -MAINTAIN INJECTIVITY THROUGHOUT DAY WITH REGULAR INJECTION DURING OTHER TASKS. ALL DETAILS OF PUMPING IN FINAL TIME SUMMARY ENTRY FOR DAY Printed 6/24/2015 9:13:40AM S • North America-ALASKA-BP Page 28 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 22:00 3.50 CEMT P INTI RIG DOWN CASING RUNNING AND CEMENTING EQUIPMENT ON FLOOR -BLEED AND BLOW DOWN ALL SURFACE LINES -RIG DOWN CEMENT HOSE AND CLEAN OUT CEMENT MANIFOLD -LAY DOWN VOLANT TOOL -REMOVE SIDE DOOR ELEVATORS -LAY DOWN BAIL EXTENSIONS AND LONG BAILS -INSTALL SHORT BAILS. SIMOPS: -CONTINUE TO INJECT DOWN THE ANNULUS EVERY HOUR AT 2 BPM -DRAIN AND FLUSH MUD GAS SEPARATOR, PER L2RA FOR SHAKER REPAIR. -REPAIR SHAKER#3 22:00 - 00:00 2.00 CASING P INTI RIG UP BX ELEVATORS AND LAY DOWN 9-5/8" LANDING JOINT TO THE PIPE SHED. -DRAIN STACK FOR PACK-OFF INSTALL -MOBILIZE 9-5/8"CASING PACK-OFF TO RIG FLOOR -PICK UP AND MAKE UP PACK-OFF RUNNING TOOL ON RIG FLOOR THROUGHOUT THE DAY,PUMP FOLLOWING VOLUMES DOWN OA TO MAINTAIN INJECTIVITY: 17:45-7 BBLS 10.3+PPG LSND,2 BPM,1275 PSI BREAKOVER PRESSURE 18:45-20 BBLS 10.3+PPG LSND,2 BPM,1400 PSI BREAKOVER PRESSURE 20:15-5 BELS 10.3+PPG LSND,2 BPM,1320 PSI BREAKOVER PRESSURE 21:30-3 BBLS 10.3+PPG LSND,2 BPM,1475 PSI BREAKOVER PRESSURE 22:35-2 BBLS 10.3+PPG LSND,2 BPM,1080 1 PSI BREAKOVER PRESSURE 23:45-2 BBLS 10.3+PPG LSND,2 BPM,1150 PSI BREAKOVER PRESSURE 3/30/2015 100:00 - 02:00 2.00 WHSUR P INTI FMC REPRESENTATIVE ON LOCATION TO SET AND TEST 9-5/8"PACK-OFF -RUN PACK-OFF ON 5"HWDP -DRAIN STACK AND VISUALLY CONFIRM PACK-OFF LANDED. RUN IN LOCK DOWN SCREWS TO ENGAGE SEALS. -PERFORM PRESSURE CROSSCHECK AND TEST PACK-OFF TO 250 PSI LOW FOR 5 MIN AND 5000 PSI HIGH FOR 30 MIN;GOOD TEST SIMOPS: -MAINTAIN INJECTIVITY THROUGHOUT DAY WITH REGULAR INJECTION DURING OTHER TASKS. ALL DETAILS OF PUMPING IN FREEZE PROTECT TIME SUMMARY Printed 6/24/2015 9:13:40AM • • North America-ALASKA-BP Page 29 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 'X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual t69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 04:00 2.00 BOPSUR P INTI CHANGE OUT UPPER RAMS FROM 9-5/8" SOLID RAMS TO 2-7/8"X 5-1/2"VARIABLE BORE RAMS. BARRIERS FOR RAM CHANGE OUT: -CLOSED BLIND-SHEAR RAMS -10.3 PPG STATIC KWF COLUMN CONTINUOUSLY MONITORED WITH CIRCULATION THROUGH CHOKE AND KILL LINES. SIMOPS: -TOP OFF SURFACE CONDUCTOR X 13-3/8" ANNULUS WITH 9 BBLS OF 11.OPPG LITECRETE CEMENT -BLOW DOWN ALL LINES AND RIG DOWN SLB -CLEAN OUT CELLAR. 04:00 - 07:30 3.50 BOPSUR P INTI RIG UP AND PRESSURE TEST UPPER 2-7/8"X 5-1/2"VARIABLE BORE RAMS WITH 5"TEST JOINT -INSTALL TEST PLUG AND RIG UP TEST EQUIPMENT ON RIG FLOOR -250 PSI LOW/4000 PSI HIGH FOR 5 CHARTED MIN EACH. 07:30 - 09:30 2.00 BOPSUR P INTI RIG DOWN AND BLOW DOWN ALL TEST EQUIPMENT -CLEAN AND CLEAR RIG FLOOR -PULL AND LAY DOWN TEST PLUG -CHANGE OUT INSERTS ON PS-21S FOR BHA. -BLOW DOWN CHOKE MANIFOLD AND KILL LINES -MOBILIZE SHORT BHA TOOLS TO THE FLOOR -INSPECT SAVER SUB 09:30 - 10:30 1.00 WHSUR P INTI INSTALL 9.75"ID WEAR RING AND LAY DOWN TEST JOINT 10:30 - 15:00 4.50 DRILL P INTI PICK UP 8-1/2"ROTARY STEERABLE DRILLING ASSEMBLY AND RUN IN THE HOLE TO 804'MD. -PJSM WITH RIG CREW,DIRECTIONAL DRILLER AND WSL -NEW SECURITY 8-2/4"MM65D PDC BIT WITH 6X13 NOZZLES(SERIAL#12633467) -BAKER AUTOTRAK ROTARY STEERABLE WITH GR/RES/PWD/DIR/DEN/NEU -SHALLOW HOLE TEST DIRECTIONAL TOOLS AT 804'MD,500 GPM,1200 PSI,GOOD TEST -HOLD UNANNOUNCED KICK WHILE DRILLING(D2)DRILL+AAR -PU 77K;SO 77K Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP Page 30 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM I Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 20:00 5.00 DRILL P INTI RUN IN HOLE ON ELEVATORS WITH 8-1/2" INTERMEDIATE SECTION#2 DRILLING BHA FROM 804'MD TO 8380'MD -PU 288K;SO 165K AT 8380'MD -FILL PIPE EVERY 20 STANDS SIMOPS: THROUGHOUT THE LAST 24HRS,PUMP FOLLOWING VOLUMES DOWN OA TO MAINTAIN INJECTIVITY: 17:45-7 BBLS 10.3+PPG LSND,2 BPM,1275 PSI BREAKOVER PRESSURE 18:45-20 BBLS 10.3+PPG LSND,2 BPM,1400 PSI BREAKOVER PRESSURE 20:15-5 BBLS 10.3+PPG LSND,2 BPM,1320 PSI BREAKOVER PRESSURE 21:30-3 BELS 10.3+PPG LSND,2 BPM,1475 PSI BREAKOVER PRESSURE 22:35-2 BBLS 10.3+PPG LSND,2 BPM,1080 PSI BREAKOVER PRESSURE 01:10-2 BBLS 10.3+PPG LSND,2 BPM,1025 PSI BREAKOVER PRESSURE 02:35-2 BBLS 10.3+PPG LSND,2 BPM,1000 PSI BREAKOVER PRESSURE 03:45-2 BBLS 10.3+PPG LSND,2 BPM,900 PSI BREAKOVER PRESSURE 04:40-2 BBLS 10.3+PPG LSND,2 BPM,890 PSI BREAKOVER PRESSURE 05:50-2 BBLS 10.3+PPG LSND,2 BPM,900 PSI BREAKOVER PRESSURE 07:20-2 BBLS 10.3+PPG LSND,2 BPM,905 PSI BREAKOVER PRESSURE 08:10-2 BBLS 10.3+PPG LSND,2 BPM,890 PSI BREAKOVER PRESSURE 09:35-2 BBLS 10.3+PPG LSND,2 BPM,900 PSI BREAKOVER PRESSURE 10:30-2 BBLS 10.3+PPG LSND,2 BPM,890 PSI BREAKOVER PRESSURE 11:25-2 BBLS 10.3+PPG LSND,2 BPM,880 PSI BREAKOVER PRESSURE 12:35-2 BBLS 10.3+PPG LSND,2 BPM,976 PSI BREAKOVER PRESSURE 13:35-2 BBLS 10.3+PPG LSND,2 BPM,980 PSI BREAKOVER PRESSURE 14:30-2 BBLS 10.3+PPG LSND,2 BPM,970 PSI BREAKOVER PRESSURE 15:30-2 BBLS 10.3+PPG LSND,2 BPM,980 PSI BREAKOVER PRESSURE FREEZE PROTECT THE 13-3/8"X 9-5/8" ANNULUS WITH 122 BBLS DIESEL: -AT 17:00 HRS INJECT 11 BBLS OF 13.8 PPG LSND AT 2 BPM;990-672 PSI -PUMP 122 BBLS OF DIESEL;IIP 700 PSI,FIP 1000 PSI -BLEED OFF OA PRESSURE TO 150 PSI AND SHUT-IN. -TOTAL VOLUME PUMPED 199 BBLS(DOES NOT EXCEED 110%ANNULAR VOLUME). HELD CASING PICK STRATEGY MEETING FOR TD IN THE TOP OF THE LISBURNE Printed 6/24/2015 9:13:40AM North America-ALASKA-BP • Page 31 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040;981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task i Code NPT NPT Depth Phase Description of Operations (hr) (usft) FORMATION WITH TOWN AND RIG PERSONNEL. HELD A 7"LINER RUNNING PLANNING MEETING. 20:00 - 23:00 3.00 CASING P INTI RIG UP AND PRESSURE TEST 9-5/8"47# CASING -PJSM;REVIEWED PRESSURE CROSSCHECK CHECKLIST -CIRCULATE AIR OUT OF LINES AND LINE UP TO PUMP DOWN THE KILL LINE AND THROUGH THE DRILL STRING. -TEST TO 250 PSI LOW FOR 5 MINUTES AND 4340 PSI HIGH FOR 30 MINUTES -MUD WEIGHT:10.3+PPG -PUMP 9.2 BBLS TO 4000 PSI,BLEED BACK 9 BBLS -LOST 35 PSI AFTER 15 MIN AND 10 PSI IN THE SECOND 15 MIN -PRESSURE TEST MET BP TUBULAR TEST CRITERIA PER CRT-AK-10-45 -RECEIVED ATP FROM BP ROTARY WTL JIM WILLINGHAM -RIG DOWN AND BLOW DOWN LINES 23:00 - 00:00 1.00 DRILL P INTI WASH IN THE HOLE WITH 8-1/2"DRILLING ASSEMBLY ON 5"DRILLPIPE FROM 8380'MD TO 9046'MD -PU 297K,SO 177K -400 GPM;1395 PSI 3/31/2015 00:00 - 00:30 0.50 DRILL P INTI CONTINUE TO WASH IN THE HOLE WITH 8-1/2"DRILLING ASSEMBLY ON 5"DRILLPIPE FROM 9046'MD TO TOP OF PLUGS AT 9165' MD -PU 297K,SO 177K -400 GPM;1395 PSI -TAGGED PLUGS 5'HIGH;LANDING COLLAR AT 9170'MD 00:30 - 02:30 2.00 DRILL P INTI DRILL OUT PLUGS,FLOAT COLLAR AND CEMENT FROM 9165'MD TO 9236'MD -500 GPM,2056 PSI -60 RPM,16-18K TORQUE -PU 297K,SO 177K,ROT 213K 02:30 - 05:00 2.50 DRILL P INTI CIRCULATE CEMENT OUT OF THE SHOE TRACK. -500 GPM,2018 PSI -60 RPM;18-21KTORQUE;ROTATING WEIGHT 213K -RECIPROCATING A FULL STAND AT 800 FT/HR. -HELD PRE-SPUD MEETING WITH MALLORY CREW. -FOCUSED ON WELL CONTROL AND POTENTIAL DRILLING PROBLEMS. -HELD TABLE TOP H2S DRILL WITH MALLORY CREW. -COVERED PROCEDURE AND SCENARIOS. -DISCUSSED SPECIFIC DUTIES AND RESPONSIBLITIES. -TALKED OVER WHAT WE CAN AND CANNOT DO ACCORDING TO PROCEDURE. Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP Page 32 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor.PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:00 - 07:00 2.00 DRILL P INTI DRILL OUT SHOE,AND 20'OF NEW HOLE FROM 9236'MD TO 9278'MD -575 GPM,2500 PSI -60 RPM,21K TORQUE -PU 302K,SO 180,ROT 215K 07:00 - 08:00 1.00 DRILL P INTI PULL UP INTO SHOE AND CIRCULATE BOTTOMS UP -575 GPM,2470 PSI 60 RPM,21K TORQUE -MUD WEIGHT:10.4 PPG IN/OUT 08:00 - 09:00 1.00 DRILL P INTI RIG UP AND PERFORM FIT TO 11.5 PPG EMW -MUD WEIGHT:10.4 PPG,8325'TVD,9252'MD -PUMP 2 BBLS TO 480 PSI,BLEED BACK 2 BBLS -FITAPPROVED BY ODE,SEE ATTACHED CHART 09:00 - 23:30 14.50 DRILL P INT2 DIRECTIONAL DRILL 8-1/2"INTERMEDIATE 2 HOLE FROM 9278'MD TO 9820'MD(542'14.5 HRS=37 FPH WITH CONNECTIONS) -INSTANTANEOUS ROP=75-100 FPH -PU 325K,SO 180K,ROT 222 -ECD:ACTUAL=11.25 PPG,CALC=11.11 PPG -575 GPM,2488 PSI,120-150 RPM, 15-24KFT-LBS OFF BOTTOM TORQUE,17-25K FT-LBS ON BOTTOM,5-12 KLBS WOB -MW IN/OUT=10.4 PPG -BACKREAM 15 FT PRIOR TO CONNECTIONS -NO LOSSES WHILE DRILLING AHEAD -OBSERVED REVERSE DRILLING BREAK AT 9819'MD. 23:30 - 00:00 0.50 DRILL P INT2 CIRCULATE BOTTOMS UP FOR SAMPLES -575 GPM,2470 PSI -120 RPM,15-25K TORQUE -MUD WEIGHT:10.4 PPG IN/OUT -LISBURNE TOP CONFIRMED BY SAMPLES AT 9819'MD 4/1/2015 00:00 - 01:30 1.50 DRILL P INT2 CIRCULATE HOLE CLEAN FOR PLANNED SHORT TRIP -575 GPM,2440 PSI -120 RPM,15-25K TORQUE -MUD WEIGHT:10.4 PPG IN/OUT 01:30 - 02:30 1.00 DRILL P INT2 PULL OUT OF THE HOLE FOR PLANNED SHORT TRIP FROM 9820'MD TO 9-5/8" CASING SHOE AT 9252'MD -MONITOR WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM(STATIC) -PUMP OUT OF THE HOLE FROM TD TO TOP OF KAVIKAT 1 BPM 40 FT/MIN -PULL OUT OF THE HOLE ON ELEVATORS FROM TOP OF KAVIK TO SHOE -NO ISSUES WHILE PULLING OUT OF THE HOLE 02:30 - 03:30 1.00 DRILL P INT2 TRIP IN THE HOLE FROM 9-5/8"CASING SHOE TO TD AT 9820'MD -WASH DOWN LAST STAND AT 2BPM,NO FILL OBSERVED ON BOTTOM Printed 6/24/2015 9:13:40AM North America-ALASKA-BP Page 33 of 63 Operation Summary Report Common Welt Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/me:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:30 - 05:30 2.00 DRILL P INT2 CIRCULATE HOLE CLEAN -575 GPM,2425 PSI -150 RPM,15-25K TORQUE -PUMPED 3OBBL HIGH VIS SWEEP,MINIMAL INCREASE IN CUTTINGS BACK AT SHAKERS -PERFORM 290BBL DILUTION WHILE CIRCULATING HOLE CLEAN 05:30 - 07:00 1.50 DRILL P INT2 PULL OUT OF THE HOLE FROM 9820'MD TO CASING SHOE AT 9252'MD -MONITOR WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM(STATIC) -PUMP OUT OF THE HOLE FROM TD TO TOP OF KAVIK AT 1 BPM 40 FT/MIN -PULL OUT OF THE HOLE ON ELEVATORS FROM TOP OF KAVIK TO CASING SHOE -NO ISSUES WHILE PULLING OUT OF OPEN HOLE 07:00 - 08:00 1.00 DRILL P INT2 CIRCULATE BOTTOMS UP - 575 GPM,2300 PSI -70 RPM,19K TORQUE -HELD UNANNOUNCED D1 KICK WHILE TRIPPING DRILL 08:00 - 15:30 7.50 DRILL P INT2 PULL OUT OF THE HOLE ON ELEVATORS FROM 9252'MD TO BHAAT 804'MD -MONITOR WELL FOR 10 MIN PRIOR TO PULLING BHA INTO BOP STACK(STATIC) 15:30 - 18:00 2.50 DRILL P INT2 LAY DOWN BHA FROM 804'MD TO SURFACE -BIT GRADE:1-1-WT-A-X-I-NO-TD 18:00 - 22:00 4.00 DRILL P INT2 CHANGE OUT UPPER RAMS TO 7"CASING RAMS -BARRIERS WHILE CHANGING OUT RAMS: TESTED BLIND RAMS AND KWF MONITORED BY CIRCULATING ACROSS MUD CROSS UNDER BLIND RAMS. -PULL WEAR BUSHING -SET TEST PLUG -TEST CASING RAMS TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 MIN EACH -PULL TEST PLUG AND SET WEAR BUSHING 22:00 - 22:30 0.50 DRILL P INT2 CLEAN AND CLEAR RIG FLOOR 122:30 - 00:00 1.50 CASING P INT2 RIG UP CASING CREW -CHANGE OUT PS-21 AND BX ELEVATOR INSERTS,VERIFY PROPER SIZE LIFTING EQUIPMENT -RIG UP CASING TONGS AND FILL UP HOSE 4/2/2015 00:00 - 01:00 1.00 CASING P INT2 FINISH RIGGING UP LINER RUNNING EQUIPMENT Printed 6/24/2015 9:13:40AM North America-ALASKA-BP Page 34 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:00 - 16:30 15.50 CASING P INT2 RUN 7",26#,L-80,INTERMEDIATE 2 LINER TO 706'MD -CHECK FLOATS -USE JET LUBE SEAL GUARD PIPE DOPE -TORQUE CONNECTIONS TO 11950 FT-LBS -RUN 12 CENTRALIZERS -FILL LINER EVERY JOINT PU 56K,SO 56K MAKE UP LINER HANGER/PACKER ASSEMBLY -ADD PAL MIX -CIRCULATE 1X LINER VOLUMES AT 7 BPM, 100 PSI -CONTINUE IN HOLE TO 9252'MD(9-5/8" SHOE)ON 5"DRILL PIPE -CIRCULATE 1X BOTTOMS UP AT 7 BPM,625 PSI -PU 262K,SO 174K RUN INTO OPEN HOLE WITH LINER AND RUN TO BOTTOM AT 9820'MD SET LINER ON BOTTOM AND PULL INTO TENSION -PU 275K,SO 180K -MUD WEIGHT:10.4 PPG IN,10.4 PPG OUT -NO LOSSES WHILE RIH -TOP OF LINER AT 9091'MD -NO ISSUES WHILE RUNNING IN THE HOLE 16:30 - 21:00 4.50 CASING P INT2 STAGE UP TO CEMENTING RATE IN 1 BPM INCREMENTS TO FINAL CIRCULATING RATE OF 7 BPM. -@ 2 BPM,285 PSI -@ 3 BPM,340 PSI -@ 4 BPM,397 PSI -@ 5 BPM,469 PSI -@ 6 BPM,572 PSI -@ 7 BPM,680 PSI -CONDITION MUD TO 10.4 PPG,10 PV,18 YP -INITIAL PRESSURE AT CEMENTING RATE: 680 PSI -FINAL PRESSURE AT CEMENTING RATE AFTER HOLE CONDITIONED:650 PSI -CIRCULATE TOTAL OF 3 TIMES BOTTOMS-UP -MUD LOSSES:0 BBL 21:00 - 23:00 2.00 CASING P INT2 REVIEW PRESSURE CROSSCHECK WITH SLB AND PRESSURE TEST CEMENT LINES TO 250 PSI LOW AND 4500 PSI HIGH FOR 5 MIN EACH -OBSERVED 2 FAILED LOW TORQUE VALVES 23:00 - 00:00 1.00 CASING P INT2 DROP 1-1/2"SETTING BALL AND PUMP DOWN WITH RIG PUMPS -ONCE BALL IS ON SEAT PRESSURE UP TO 3000 PSI -SET DOWN 50K TO CONFIRM HANGER SET -PRESSURE UP TO 4000 PSI -PICK UP STRETCH PLUS 1'TO CONFIRM HRD-E RELEASED FROM LINER HANGER _ 4/3/2015 00:00 - 00:30 0.50 CASING P INT2 ESTABLISH CIRCULATION STAGE PUMPS UP TO CEMENTING RATE -7 BPM,650 PSI Printed 6/24/2015 9:13:40AM i 4110 North America-ALASKA-BP Page 35 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT ' NPT Depth Phase Description of Operations (hr) (usft) 00:30 - 06:00 5.50 CASING P INT2 CEMENT 7"INTERMEDIATE 2 LINER AS FOLLOWS: -HOLD PJSM AND BATCH UP CEMENT CEMENT WET AT 01:00 -PUMP 35 BBLS OF 12 PPG MUDPUSH II SPACER @ 5 BPM,480-400 PSI -PUMP 3 BBL CEMENT TO RIG FLOOR AND DROP BOTTOM WIPER DART -PUMP 35.3 BBLS OF 15.8 PPG CLASS G TAIL @ 5 BPM,530-330 PSI, EXCESS VOLUME 40% (YIELD 1.17 CU.FT/SK) -LINE UP AND WASH UP CEMENT LINES TO PITS,DROP UPPER DRILL PIPE WIPER DART PERFORM DISPLACEMENT WITH CEMENTERS -145 BBLS DISPLACED AT 7 BPM:ICP 240 PSI, FCP 880 PSI,SLOWED DOWN TO 3BPM 5BBL BEFORE BOTTOM PLUG LATCH BUT DID NOT OBSERVE LATCH -20 BBLS DISPLACED AT 3 BPM:ICP 330 PSI, FCP 547 PSI,OBSERVED TOP PLUG LATCH AT 153 BBLS DISPLACED -10.5 BBLS DISPLACED AT 2 BPM:ICP 530 PSI,FCP 640 PSI,PLUG BUMPED AT 175.5 BBLS DISPLACED -DISPLACEMENT FLUID:175.5 BBL OF 10.4 PPG,LSND -REDUCE RATE TO 2 BPM PRIOR TO PLUG BUMP:FINAL CIRCULATING PRESSURE 640 PSI,CEMCADE SIMULATED FINAL CIRCULATING PRESSURE 575 PSI -CIPAT02:28 -TOTAL LOSSES FROM CEMENT EXIT SHOE TO CEMENT IN PLACE:0 BBLS -INCREASE PRESSURE TO 1200 PSI AFTER PLUG BUMP -BLEED OFF PRESSURE,CHECK FLOATS- GOOD -PU TO EXPOSE DOG SUB AND SET DOWN ON LINER TOP 50K,25 RPM -REMOVE CEMENT HOSES FROM CEMENT HEAD -PU TO REMOVE RS PACK-OFF AND CIRCULATE EXCESS CEMENT OFF LINER TOP -PU RUNNING TOOL ABOVE LINER TOP AND MARK NO-GO.CIRCULATE 1X BU AT 10 BPM, 830 PSI --7 BBLS OF EXCESS CEMENT TO SURFACE ON BOTTOMS UP -LAY DOWN CEMENT HEAD AND 2 JOINTS OF DRILLPIPE TO PULL RUNNING TOOL OUT OF LINER HANGER AND CIRCULATE 1 BOTTOMS UP AT 10 BPM,830 PSI WHILE RECIPROCATING FULL STAND 06:00 - 13:00 7.00 CASING P INT2 PULL OUT OF THE HOLE FROM 9000'MD TO SURFACE -MONITOR WELL FOR 10 MIN PRIOR TO PULLING OUT OF THE HOLE(STATIC) -INSPECTAND LAY DOWN BUMPER SUB AND LINER HANGER RUNNING TOOL -DOG SUB SHEARED INDICATING LINER TOP PACKER SET Printed 6/24/2015 9:13:40AM North America-ALASKA-BP Page 36 of 63 Operation Summary Report Common Well Name:L3-03 ,AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 14:30 1.50 BOPSUR P INT2 CHANGE OUT TOP PIPE RAMS TO 2-7/8"X 5-1/2"VARIABLE BORE RAMS -BARRIERS WHILE CHANGING OUT RAMS: TESTED BLIND RAMS AND KWF MONITORED BY CIRCULATING ACROSS MUD CROSS UNDER BLIND RAMS. 14:30 - 16:00 1.50 BOPSUR P INT2 PULL WEAR BUSHING AND SET TEST PLUG RIG UP TO TEST BOPE 16:00 - 21:00 5.00 BOPSUR P INT2 TEST BOPE TO 250 PSI LOW,4000 PSI HIGH FOR 5 MINUTES EACH -TEST WITH 4"AND 5"TEST JOINTS -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS -TEST WITNESSED BY AOGCC REP JOHNNY HILL -NO FAILURES DURING TEST 21:00 - 22:30 1.50 BOPSUR P INT2 RIG DOWN TEST EQUIPMENT -PULL TEST PLUG AND INSTALL WEAR BUSHING(ID 8-3/4") 22:30 - 23:30 1.00 CASING P INT2 PRESSURE TEST 7"LINER TOP PACKER TO 250 PSI LOW FOR 5 MIN/4000 PSI HIGH FOR 30 MIN -CLOSE BLIND RAMS -PUMPED 10 BBL TO 4000 PSI,BLEED BACK 10 BBL -TEST APPROVED BY BP WTL -CEMENT REACHED 500 PSI COMPRESSIVE STRENGTH AT 14:42 04/03/2015 23:30 - 00:00 0.50 CASING P INT2 SERVICE TOPDRIVE AND FLOOR TOOLS 4/4/2015 00:00 - 03:00 3.00 TA C INT2 PICK UP 6-1/8"CLEANOUT BHA TO 959'MD -USED 6-1/8"MILLTOOTH TRICONE -BIT SUB WITH PORTED FLOAT -6"STABILIZER -6 JOINTS OF 4-3/4"DRILL COLLARS -24 JOINTS OF 4"DP 03:00 - 05:00 2.00 TA C INT2 SLIP AND CUT 96'OF DRILL LINE -HANG BLOCKS -SLIP AND CUT LINE -TORQUE DEADMAN AND DRAWWORKS DRUM CLAMPS TO SPEC -UNHANG BLOCKS -CALIBRATE BLOCK HEIGHT ON AMPHION SYSTEM 05:00 - 13:00 8.00 TA C INT2 RUN IN THE HOLE WITH CLEANOUT ASSEMBLY ON 5"DP FROM 959'MD TO TOP OF LANDING COLLAR AT 9729'MD -WASH DOWN LAST STAND AT 3 BPM,415 PSI -PU 280K,SO 175K -MUD WT:10.4 PPG IN/OUT 13:00 - 21:00 8.00 TA C INT2 DRILL OUT 7"SHOE TRACK FROM 9729'MD TO 9815'MD(5'FROM 7"SHOE AT 9820'MD) -3-8 BPM,360-915 PSI,60-130 RPM,15- 20K TORQUE,5-18K WOB -TAGGED LANDING COLLAR AND FLOAT COLLAR ON DEPTH -PU 280K,SO 175K,ROT 211K Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP Page 37 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor.PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code i NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 22:00 1.00 TA C INT2 CIRCULATE HOLE CLEAN -400 GPM,1280 PSI,130 RPM,15-20K TORQUE -PUMP 40 BBL HIGH VIS SWEEP,MODERATE INCREASE IN CUTTINGS BACK AT SHAKERS 22:00 - 00:00 2.00 TA C INT2 PULL OUT OF THE HOLE FROM 9815'MD TO 7876'MD -MONITOR WELL FOR 10 MIN PRIOR TO PULLING OUT OF THE HOLE(STATIC) 4/5/2015 00:00 - 07:00 7.00 TA C INT2 PULL OUT OF THE HOLE FROM 7876'MD TO SURFACE AND LAY DOWN BHA -MONITOR WELL FOR 10 MIN PRIOR TO PULLING BHA INTO BOP STACK(STATIC) -BIT GRADE:5-6-WT-A-E-IN-NO-TD -LAY DOWN BHA TOOLS FROM FLOOR -HOLD UNANNOUNCED D1 KICK WHILE TRIPPING DRILL 07:00 - 12:00 5.00 EVAL P INT2 RIG UP AND RUN USIT LOGS IN 9-5/8"CASING AND 7"LINER TO EVALUATE CEMENT -RIH WITH CCL/CTEM/CBL/UDUGPIT-F/USIT-E/USI SE TO 9800'MD -LOG FROM 9800'MD TO 200'ABOVE TOP OF CEMENT IN 7"LINER 12:00 - 16:00 4.00 EVAL N CEMT INT2 -PULL UP ABOVE LINER TOP AND LOG 9-5/8" CASING FROM 9120'MD TO 200'ABOVE TOP OF CEMENT -PERFORM REPEAT PASSES AS NEEDED 16:00 - 17:00 1.00 EVAL P INT2 RIG DOWN E-LINE TOOLS -BREAK DOWN LOGGING TOOL -RIG DOWN SHEAVES AND REMOVE FROM RIG FLOOR 17:00 - 17:30 0.50 EVAL P INT2 SERVICE TOP DRIVE -TOP OFF HYDRAULIC AND GEAR OIL 17:30 - 18:00 0.50 TA C INT2 CLEAN AND CLEAR RIG FLOOR -STAGE EZSV-B IN PIPE SHED -PREPPED PS-21'S TO TRIP IN THE HOLE 18:00 - 00:00 6.00 TA C INT2 INSTALL EZSV-B AND RUNNING TOOL ON 4"X 5"DP TAPERED STRING AND RUN IN THE HOLE ON ELEVATORS FROM SURFACE TO 7592'MD -RIH AT 100 FPM PER HALLIBURTON REP 4/6/2015 00:00 - 02:00 2.00 TA C INT2 RUN IN THE HOLE WITH EZSV-B FROM 7592' MD TO 5'ABOVE 7"LANIDING COLLAR AT 9724'MD -RIH AT 100 FPM PER HALLIBURTON REP -NO ISSUES RUNNING THROUGH LINER TOP WITH EZSV-B Printed 6/24/2015 9:13:40AM • • North America-ALASKA-BP Page 38 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth ' Phase Description of Operations (hr) j (usft) 02:00 - 02:30 0.50 TA C INT2 SET EZSV-B -STAGE PUMP UP TO 2 BPM,215 PSI AND RECIPROCATE PIPE 2 TIMES -ROTATE TO THE RIGHT 35 TIMES AT SET DEPTH OF 9724'MD TO SET EZSV-B -PULL UP 15K OVER AND SET FOR 1 MIN, PULL UP TO 30K OVER AND LET SET FOR 1 MIN,PULL UP AND SHEAR OFF AT 40K OVER STRING WEIGHT -SET DOWN 20K ON EZSV-B TO CONFIRM SET -PU 275K,SO 175K -TOP OF EZSV-B SET AT 9721'MD,BOTTOM SET AT 9724'MD 02:30 - 03:30 1.00 TA C INT2 RIG UP AND PRESSURE TEST EZSV-B TO 250 PSI LOW FOR 5 MIN AND 4000 PSI HIGH FOR 30 MIN -PUMP 10 BBLS TO 4000 PSI,BLEED BACK 10 BBLS -TEST APPROVED BY WTL 03:30 - 05:30 2.00 TA C INT2 DISPLACE WELL TO 8.6 PPG SEAWATER -500 GPM,1600-750 PSI -RECIPROCATE FULL STAND PUMP 80 BBL HIGH VIS SPACER 05:30 - 06:00 0.50 TA C INT2 PERFORM NEGATIVE TEST OF 7"LINER TOP PACKER AND EZSV-B -MONITOR WELL FOR 30 MIN(STATIC) -TEST APPROVED BY WTL 06:00 - 16:30 10.50 TA C INT2 PULL OUT OF THE HOLE ON ELEVATORS FROM 9724'MD TO SURFACE -STAND BACK 45 STANDS OF 5"DP TO LAY DOWN OFFLINE -LAY DOWN 50 STANDS OF 5"DP AND 8 STANDS OF 4"DP 16:30 - 17:00 0.50 TA C INT2 PULL WEAR BUSHING -CHANGE OUT PS-21'S WITH MASTER BUSHINGS 17:00 - 23:00 6.00 TA C INT2 RIG UP AND RUN 4-1/2",12.6#,L-80,TC11 KILL STRING WITH MULE SHOE TO 3181'MD -USE JET LUBE SEAL GUARD PIPE DOPE -TORQUE CONNECTIONS TO 4000 FT-LBS -PU 69K,SO 69K -MUD WEIGHT:8.6 PPG IN/OUT -WEIGHT ON HANGER:34K 123:00 - 00:00 1.00 TA C INT2 FREEZE PROTECT 4-1/2"TUBING X 9-5/8" CASING TO 2200'TVD,2245'MD -RIG UP AND PUMP 154 BBL 6.8 PPG DIESEL 4/7/2015 00:00 - 02:30 2.50 CASING C INT2 FINISH FREEZE PROTECTING 4-1/2"TUBING X 9-5/8"CASING TO 2200'TVD,2245'MD -ALLOW DIESEL TO U-TUBE FOR 1 HOUR SIMOPS: -LAY DOWN 5"DRILLPIPE OFFLINE 02:30 - 03:00 0.50 CASING P INT2 PERFORM NEGATIVE TEST OF 7"LINER TOP PACKER AND EZSV-B AFTER FREEZE PROTECTING -MONITOR WELL FOR 30 MIN(STATIC) -TEST APPROVED BY WTL SIMOPS: -LAY DOWN 5"DRILLPIPE OFFLINE Printed 6/24/2015 9:13:40AM • • North America-ALASKA-BP Page 39 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040.981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual(g69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 05:30 2.50 BOPSUR C INT2 INSTALL AND TEST TWC -PRESSURE TEST TWC FROM BELOWAND ABOVE TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 MINUTES EACH SIMOPS: -LAY DOWN 5"DRILLPIPE OFFLINE 05:30 - 08:00 2.50 BOPSUR C INT2 BLOW DOWN SURFACE LINES -BLOW OUT STACK -RIG DOWN FROM TESTING TWC -SUCK OUT AND LAY DOWN MOUSE HOLE -BLOW DOWN MUD MODULE AND CLEAN PITS SIMOPS: -LAY DOWN 5"DRILLPIPE OFFLINE 08:00 - 11:00 3.00 BOPSUR C INT2 NIPPLE DOWN 13-5/8",5K BOP STACK -CLEAN OUT FLOW BOX AND REMOVE FLOW NIPPLE -RIG DOWN TURN BUCKLES -NIPPLE DOWN STACK AND SET BACK ON TEST STUMP -NIPPLE DOWN HIGH PRESSURE RISERS AND LAY DOWN IN PIPE SHED SIMOPS: -LAY DOWN 5"DRILLPIPE OFFLINE -CLEAN PITS 11:00 - 14:00 3.00 WHSUR C INT2 NIPPLE UP DRY HOLE TREE -CLEAN UP WELLHEAD AND NIPPLE UP DRY HOLE TREE -INSTALL API RINGS -INSTALL TREE ADAPTER -RIG UP TO TEST HANGER VOID SIMOPS: -LAY DOWN 5"DRILLPIPE OFFLINE -CLEAN PITS 14:00 - 14:30 0.50 WHSUR C INT2 TEST HANGER VOID TO 250 PSI LOW FOR 5 MINUTES,5000 PSI HIGH FOR 30 MINUTES SIMOPS: -LAY DOWN 5"DRILLPIPE OFFLINE -CLEAN PITS 14:30 - 16:00 1.50 WHSUR C INT2 TEST TREE TO 250 PSI LOW FOR 5 MINUTES AND 5000 PSI HIGH FOR 5 MINUTES -NO LEAKS 16:00 - 16:30 0.50 WHSUR C INT2 -SUCK OUT TREE AND FILL WITH DIESEL -ADD BOTTLES OF HEET -SECURE THE WELL 16:30 - 20:00 3.50 DEMOB C INT2 -BLOW DOWN LINES ON RIG FLOOR -COMPLETE PRE-SKID CHECK LIST -DISCONNECT STEAM TABLE LINES -COMPLETE LAYING DOWN STANDS OFF-LINE 20:00 - 21:30 1.50 DEMOB C INT2 -HOLD PJSM FOR SKIDDING RIG FLOOR -SKID HAUNCH -SKID RIG FLOOR 40' Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP Page 40 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040;981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UVN:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:30 - 00:00 2.50 DEMOB C INT2 -PERFORM WELDING WORK ON FALSE FLOOR BELOW ROTARY TABLE *RIG RELEASED FROM L3-03 AT 04/07/2015 23:59 5/18/2015 00:00 - 02:00 2.00 MOB C INT2 RD FLOOR EQUIPMENT AND PREPARE TO BRIDLE UP -RIG DOWN DUMMY WELLHOUSE -PREP MUD MOD FOR RIG MOVE 02:00 - 04:00 2.00 MOB C INT2 BRIDLE UP -PJSM FOR BRIDLE UP -SKID HAUNCH TO DERRICK OVER POSITION -PREP FLOOR TO SKID -DERRICK INSPECTION -PARK IDLAND FORUM CRANE -SECURE LINES IN DERRICK 04:00 - 05:00 1.00 MOB C INT2 SKID RIG FLOOR -PJSM FOR SKID RIG FLOOR -SKID RIG FLOOR TO DERRICK LAYOVER POSITION 05:00 - 06:00 1.00 MOB C INT2 LAY OVER DERRICK -PJSM -MAX HOOKLOAD:367K LBS 06:00 - 08:30 2.50 MOB C INT2 PREPARE MODULES FOR MOVE OFF OF L3-10 -MOVE MUD MOD TO STAGING AREA -PREP UTILITY MOD FOR RIG MOVE -DISCONNECT INTERCONNECT BETWEEN UTILITY AND DRILL MODULES -MOVE UTILITY MODULE AWAY FROM DRILL MODULE 08:30 - 11:00 2.50 MOB C INT2 MOVE DRILL AND UTILITY MODULES INTO STAGING AREA 11:00 - 12:00 1.00 MOB C INT2 REMOVE RIG MATS FOR PAD PREP -REMOVE 5K DRYHOLE TREE FROM BOP DECK -CLEAN UP AROUND DUMMY WELLHOUSE 12:00 - 00:00 12.00 MOB C INT2 PERFORM RIG SERVICE AND MAINTENANCE PROJECTS WHILE PAD PREPARATION IS PERFORMED -INSTALLED SECONDARY IAAND OA VALVES ON L3-03 -LOWERED TREE ADAPTER FROM BOP DECK -PICKED UP NEW 10K PSI TREE AND TREE ADAPTER AND STAGED IN BOP DECK -WELDED IN TOOL TRAYS INSIDE DRILL MOD CARRIER BAY -WELDED IN BLEED PORTS FOR SUCTION LINES ON SLOP TANKS -INSTALL STEELANTI SKID STEPS ON UTIILITY MOD STAIRS AOGCC REP BOB NOBLE GIVEN UPDATE ON UPCOMING BOP TESTAT 18:00. Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP • Page 41 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/me:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor.PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations • (hr) (usft) 5/19/2015 00:00 - 07:00 7.00 MOB C INT2 PREPARE TO MOVE RIG OVER L3-03 WHILE PAD PREPARATION IS PERFORMED -WORK ON RIG MAINTENANCE ACTIVITIES AND GENERAL HOUSEKEEPING -PAINT BEHIND DRAWWORKS -CHECK MUD PUMP VALVES -CLEAN HYDRAULICS OIL FROM AROUND DRILLER SIDE TAGGER AND MAN RIDER -PLUM AIR LINES ON THE SHAKER DECK -CLEAN AND PREP BOP BOLTS -CLEAN OUT BOILER -ASSIST WELDER -INSTALL PORTS FOR SUCTION LINES OF UTILITY MODULE SLOP TANKS -CLEAN OUT BOILER SIMOPS:CREWASSISTING WITH CAMP ROOF REPAIR. 07:00 - 09:00 2.00 MOB C INT2 MOVE MUD MODULE -LAY MATS FOR WELL L3-03 -STAGE MUD MODULE ON OTHER SIDE OF WELL -WELDER INSTALLING PORTS FOR SUCTION LINES OF UTILITY MODULE SLOP TANKS. *HOLD RIG CAMP EVACUATION DRILL AT 08:00 HOURS. ALL PERSONNEL RESPONDED IN TIMELY MANNER AND WERE ACCOUNTED FOR.* 09:00 - 10:00 1.00 MOB C INT2 MOVE AND SET DUMMY WELL HOUSE OVER WELL L3-03 WITH CRANE -SET RIG MATS AROUND WELL 10:00 - 12:00 2.00 MOB C INT2 MOVE DRILL MODULE OVER L3-03 -REMOVE TIE RODS FROM MUD MODULE AND ORIENT DRIVE AXLES AND BOOSTERS 12:00 - 12:30 0.50 MOB C INT2 SPOT RIG -SPOT RIG AND SHIM DRILL MODULE -SET DOWN DRILL MODULE 12:30 - 14:00 1.50 MOB C INT2 SPOT MUD MODULE -CRAB MUD MODULE OVER TO DRILL MODULE -BUTTON UP UTILITY MODULE AND SHIM 14:00 - 17:00 3.00 MOB C INT2 BUTTON UP MUD MODULE AND SHIM -PLUG IN UTILITY ELECTRICAL INTER-CONNECT -FINISH SHIMMING MUD MODULE 17:00 - 17:30 0.50 MOB C INT2 DERRICK INSPECTION -PLUG IN MUD MODULE ELECTRICAL INTER CONNECT -PERFORM DERRICK INSPECTION -COMPLETE PRE DERRICK RAISING CHECK LIST 17:30 - 18:30 1.00 MOB C INT2 RIG UP -HOLD PJSM FOR RAISING DERRICK -RAISE DERRICK -DERRICK CAME OFF HEADACHE RACK AT 562K Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP • Page 42 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 20:30 2.00 MOB C INT2 RIG UP -SHIM MUD MODULE -SPOT THE CUTTINGS BOX -CHECK PRE-CHARGE ON ALL KOOMEY BOTTLES 20:30 - 22:00 1.50 MOB C INT2 RIG UP -RIG UP MUD MODULE AND UTILITY INTER CONNECTS -HOLD PJSM FOR SKIDDING THE RIG FLOOR -SKID RIG FLOOR TO WELL CENTER -MOVE HAUNCH INTO RIG OPERATION POSITION 22:00 - 00:00 2.00 MOB C INT2 BRIDAL DOWN -HOLD PRE JOB SAFETY MEETING FOR BRIDLING DOWN -INSTALL MANRIDERS -BRIDAL DOWN AND HOOK BLOCKS UP TO TOP DRIVE 5/20/2015 '00:00 - 02:30 2.50 MOB C PRE *ACCEPT PARKER RIG 272 AT 00:01 ON 5/20/2015* GENERAL RIG UP OPERATIONS -UN-PIN FORUM CRANE -RIG UP SURFACE LINES -HANG OFF TONGS -QUADCO REP ON LOCATION TO CALIBRATE BLOCKS AND PITS 02:30 - 03:00 0.50 MOB C PRE HOLD RIG EVACUATION AND H2S DRILL W1TH RIG AND SUPPORT CREWS -MUSTERED UP IN PRIMARY MUSTER AREA WITH ALL PERSONNEL ACCOUNTED FOR -AAR SHOWED ONE EMPLOYEE MUSTERED IN THE WRONG DIRECTION.WE RECORDED A LESSON LEARNED FOR THAT INDIVIDUAL AND SCHOOLED THE EMPLOYEE ON THE PROPER WAY TO RESPOND IN AN EVACUATION EVENT.EVERYTHING ELSE WENT WELL WITH NO OTHER FINDINGS. FIRST DRILL WITH NEW SITE CONTROL SPECIALIST(SCS). 03:00 - 04:00 1.00 RIGU C INT2 MONITOR INNER ANNULUS(IA)DURING GENERAL RIG UP OPERATIONS -BEGIN MONITORING IA FOR 1 HOUR -RIG UP SURFACE LINES -PRE-TEST SURFACE LINES AND VISUALLY INSPECT FOR LEAKS-NO LEAKS. -NO PRESSURE OR FLOW FROM IA 04:00 - 10:00 6.00 WHSUR C INT2 PRESSURE TEST TWC FROM ABOVE WITH TEST PUMP AND BELOW WITH RIG PUMP TO 250 PSI LOWAND 3500 PSI HIGH FOR 5 MIN EACH(PASSING TESTS,SEE ATTACHED CHART)TO ESTABLISH BARRIER FOR ND TREE OPS. -PERFORM PRESSURE CROSSCHECK -DIFFICULTY GETTING POPPET TO SEAT DURING TESTS FROM BELOW. EVENTUALLY SEAT POPPET WITH PRESSURE SURGING. Printed 6/24/2015 9:13:40AM North America-ALASKA-BP • Page 43 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040.981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task , Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 11:00 1.00 WHSUR N RREP 9,820.00 INT2 FIRE DRILL -FALSE FIRE ALARM IN COMPRESSOR ROOM DUE TO HEATER EFFECT ON FIRE EYE. -AAR WITH ALL INVOLVED PERSONNEL TO DISCUSS LEARNINGS. 11:00 - 13:00 2.00 WHSUR C INT2 NIPPLE DOWN 4"DRYHOLE TREE AND TUBING HEAD ADAPTER. -FMC REPRESENTATIVE ON LOCATION TO BLEED OFF HANGER VOID,INSPECT HANGER THREADS(6-112"TURNS TO MAKEUP CROSSOVER),AND FUNCTION ALL LOCKDOWN SCREWS. BARRIERS FOR NIPPLE DOWN: -TUBING: KILL WEIGHT 8.5 PPG SEAWATER AND TWC -IA: KWF,EZSV,ANNULAR VALVES,TUBING HANGER *PARKER MANAGEMENT ON LOCATION TO PERFORM SELF VERIFICATION OF SHIFT HANDOVER AND FLUID MANAGEMENT.* 13:00 - 17:30 4.50 BOPSUR P INT2 NIPPLE UP SHAFFER 13-5/8"5K BOP STACK AND HIGH PRESSURE RISERS WITH FOLLOWING COMPONENTS,TOP TO BOTTOM: -SPHERICAL ANNULAR PREVENTER -LXT ULTRALOCK 2-7/8"X 5-1/2"VBRS -POSLOCK W/BOOSTER BLIND-SHEAR RAMS -13-5/8"X 3-1/8"MUD CROSS -LXT ULTRALOCK 2-7/8"X 5-1/2"VBRS -SIMOPS:MADE UP 5"DRILLPIPE STANDS 17:30 - 18:00 0.50 BOPSUR P INT2 RIG SERVICE. -PERFORM SERVICE ON ST-80'ON RIG FLOOR. 18:00 - 19:00 1.00 BOPSUR P INT2 RIG UP TO TEST BOPE -PICK UP AND RIG UP 4"TEST JOINT -MAKE UP VALVE ASSEMBLIES -FILL LINES AND STACK -HOLD PRE-JOB SAFETY MEETING FOR TESTING BOPE 19:00 - 21:00 2.00 BOPSUR P INT2 TEST BOPE TO 250 PSI LOW,4000 PSI HIGH FOR 5 MINUTES EACH -TEST COMPLETED AT 03:00 ON 5/21/15. SEE FULL COMMENTS FOR TEST IN THAT TIME SUMMARY BOX. 21:00 - 23:00 2.00 WHSUR N HMAN INT2 FAILURE OF LOCKDOWN SCREWS TO HOLD PRESSURE -TWO LOCKDOWNS BEGAN TO LEAK ON 3RD TEST -CALLED OUT FMC REPRESENTATIVE -RIGGED DOWN TEST EQUIPMENT AND DRAINED STACK -FMC RE-TORQUE ALL LOCKDOWN SCREWS -RIGGED UP TEST EQUIPMENT AND FILLED LINES -PERFORMED A SHELL TEST TO VERIFY LOCKDOWNS HOLDING-NO LEAKS *SIMOPS:BUILD 5"DRILLPIPE STANDS.* Printed 6/24/2015 9:13:40AM • • North America-ALASKA-BP Page 44 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:00 - 00:00 1.00 BOPSUR P INT2 CONTINUE TO TEST BOPE TO 250 PSI LOW, 4000 PSI HIGH FOR 5 MINUTES EACH -SEE FULL COMMENTS FOR BOPE TEST IN 5/21/15 00:00-03:00 TIME SUMMARY SECTION 5/21/2015 00:00 - 03:00 3.00 BOPSUR C INT2 COMPLETE BOPE TEST -PERFORM SHELL TEST -TEST RAMS WITH 4"AND 5"TEST JOINTS -TEST ANNULAR WITH 4"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH FOR 5 MINUTES EACH -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS -NO TEST FAILURES 03:00 - 03:30 0.50 BOPSUR C INT2 RIG DOWN AFTER TESTING BOPE. 03:30 - 05:30 2.00 WHSUR C INT2 RIG UP DUTCH RISER. VALVE SHOP CREW ON LOCATION TO RIG UP LUBRICATOR. 05:30 - 20:30 15.00 WHSUR N RREP 9,820.00 INT2 UNSUCCESSFULLY ATTEMPT TO TEST LUBRICATOR(FAIL LOW&HIGH TESTS). DISCOVER LEAK FROM ANNULAR BONNET. TIGHTEN CAP BOLTS AND RETEST(FAIL). DECISION TO PULL CAP AND INSPECT CAP SEALS. BARRIERS FOR BREAKING CONTAINMENT: -TWC,8.5PPG SEAWATER KWF,DOWNHOLE PLUG,TBG HGR WITH ANNULAR CAP OFF,DISCOVER OUTER CAP SEAL(0-RING STYLE)VERY DAMAGED. CHANGEOUT SEAL AND ELECT TO REPLACE FULL ANNULAR ELEMENT BASED ON SEVERAL AREAS OF WEAR(LAST CHANGED OUT 2/6/15) 09:00-RECEIVE ORDERS FROM SUPERINTENDENT TO LEAVE WELL IN SECURE STATE BY NOT PULLING TWC DUE TO FIELD-WIDE CONCERNS ABOUT RIVER FLOODING DURING HEAVY RUN-OFF SEASON. CLEAR TO COMPLETE BOPE WORK. RELEASE NON-ESSENTIAL PERSONNEL FROM RIG. 20:30 - 22:00 1.50 BOPSUR N RREP 9,820.00 INT2 UNABLE TO GET TEST ON ANNULAR PREVENTER -DOOR SEAL ON DRILLERS SIDE BLIND SHEARS LEAKING -RIGGED DOWN TEST HOSE -DRAINED STACK -BLED OFF KOOMEY AND OPENED DOOR -CLEANED SEAL FACE AND INSTALL NEW SEAL -BARRIERS FOR BREAKING CONTAINMENT: TWC,KILL WEIGHT FLUID,DOWNHOLE PLUG, TUBING HANGER Printed 6/24/2015 9:13:40AM North America-ALASKA-BP Page 45 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(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 BOPSUR N RREP 9,820.00 INT2 TEST ANNULAR TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES EACH -TEST WITH 4"TEST JOINT -UNABLE TO ACHIEVE GOOD TEST -TROUBLE SHOOTAND FIND HCR KILL LEAKING WAIT ON RIVER FLOODING TO SUBSIDE. -DALTON HIGHWAY CLOSED. KUPARUK,PUT AND SAG RIVERS FLOWING OVER ROADS ON NORTH SLOPE. -WELL SECURE WITH TWC SET -NON-ESSENTIAL PERSONNEL FLOWN OFF SLOPE. 5/22/2015 00:00 - 01:30 1.50 BOPSUR N RREP INT2 TEST ANNULAR PREVENTER -CLOSE MANUAL BEHIND KILL HCR -TEST ANNULAR TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES EACH -GREASE KILL HCR -TEST KILL HCR AGAINST UPPER RAMS TO 250 PSI LOW,4000 PSI HIGH FOR 5 CHARTED MINUTES EACH 01:30 - 02:00 0.50 BOPSUR N RREP INT2 RIG DOWN TESTING EQUIPMENT AND LAY DOWN 4"TEST JOINT. 02:00 - 11:00 9.00 PULL N WAIT INT2 WAIT ON RIVER FLOODING TO SUBSIDE. -DALTON HIGHWAY CLOSED. KUPARUK,PUT AND SAG RIVERS FLOWING OVER ROADS ON NORTH SLOPE. -WELL SECURE WITH TWC SET -NON-ESSENTIAL PERSONNEL FLOWN OFF SLOPE. -DETERMINE EMERGENCY SERVICES AND SUPPORT AVAILABLE -RIG UP DUTCH RISER,ONE BAD SEAL, SUCK OUT STACK AND INSPECT LOCKDOWNS,REPLACE SEAL -SIMOPS:BUILD DRILL PIPE STANDS AND CLEAN RIG.PERFORM OTHER SHORT TERM MAINTENANCE TASKS AFTER CAREFUL REVIEW AND ASSESSMENT. 11:00 - 13:00 2.00 PULL N WAIT INT2 ALASKA GOVERNOR BILL WALKER AND BP ALASKA PRESIDENT JANET WEISS ON LOCATION FOR RIG TOUR. 13:00 - 15:00 2.00 PULL C INT2 MAKE UP AND TEST LUBRICATOR TO PULL TWC. -PICK UP LUBRICATOR AND MAKE UP POLISH ROD EXTENSIONS -OPEN BLIND/SHEAR RAMS AND FILL STACK WITH WATER -MAKE UP LUBRICATOR TO DUTCH RISER -FILL DUTCH RISER AND LUBRICATOR WITH WATER -ATTEMPT TO PRESSURE TEST DUTCH RISER AND LUBRICATOR 250 PSI LOW,3500 PSI HIGH. 15:00 - 17:00 2.00 BOPSUR N RREP INT2 DOOR SEAL ON BLIND/SHEAR RAMS LEAKING DURING PRESSURE TEST. -DRAIN STACK AND BLOW DOWN LINES. -OPEN RAM DOOR. -CLEAN AND INSPECT SEAL FACE ON DOOR AND RAM BODY -INSTALL NEW DOOR SEAL AND CLOSE RAM DOOR. Printed 6/24/2015 9:13:40AM North America-ALASKA-BP Page 46 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 !X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth 1 Phase Description of Operations (hr) (usft) 17:00 - 18:00 1.00 PULL N RREP INT2 ATTEMPT TO PRESSURE TEST LUBRICATOR 250 PSI LOW,3500 PSI HIGH -FILL STACK,DUTCH RISER AND LUBRICATOR -ANNULAR BONNET CAP LEAKING. 18:00 - 21:30 3.50 BOPSUR N RREP INT2 REPAIR LEAKING ANNULAR BONNET CAP -BLOW DOWN STACK AND LINES. -RIG DOWN LUBRICATOR AND DUTCH RISER -REMOVE FLOW RISER -PULL ANNULAR BONNET CAP -FOUND BONNET 0-RING SEAL PINCHED -REPLACE 0-RING SEAL AND INSPECT ANNULAR -REASSEMBLE ANNULAR. 21:30 - 22:00 0.50 BOPSUR N RREP INT2 PRESSURE TEST ANNULAR WITH 4"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MIN EACH. -GOOD TEST. 22:00 - 22:30 0.50 PULL N RREP INT2 PICKUP AND INSTALL DUTCH RISER. -DRAIN STACK TO BELOW DUTCH RISER LOCKDOWNS -INSTALL DUTCH RISER AND RUN IN LOCKDOWNS. 22:30 - 23:00 0.50 PULL N WAIT INT2 WAIT FOR DRILL SITE MAINTENANCE TO ARRIVE FROM ANOTHER JOB ON THE WEST SIDE OF THE FIELD. BUILD STANDS OF 4"DRILL PIPE OFF-LINE 23:00 - 00:00 1.00 PULL N RREP INT2 MAKE UP AND TEST LUBRICATOR TO PULL TWC. -PICK UP LUBRICATOR AND MAKE UP POLISH ROD EXTENSIONS -OPEN BLIND/SHEAR RAMS AND FILL STACK WITH WATER -MAKE UP LUBRICATOR TO DUTCH RISER -FILL DUTCH RISER AND LUBRICATOR WITH WATER 5/23/2015 00:00 - 01:00 1.00 PULL C INT2 PRESSURE TEST LUBRICATOR TO 250 PSI LOWAND 3500 PSI HIGH FOR 5 MIN EACH. -PJSM WITH RIG CREWAND DRILL SITE MAINTENANCE. -ATTEMPT TO PRESSURE TEST LUBRICATOR -WHITEY VALVE LEAKING. -REPLACE WHITEY VALVE AND RETEST LUBRICATOR. 01:00 - 01:30 0.50 PULL C INT2 PULL AND LAY DOWN TWC. 01:30 - 02:30 1.00 PULL C INT2 RIG DOWN AND LAY DOWN LUBRICATOR AND POLISH ROD. RIG DOWN DUTCH RISER AND LAY DOWN TO PIPE SHED. Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP • Page 47 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 1X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual©69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 05:00 2.50 PULL C INT2 RIG UP AND CIRCULATE OUT DIESEL FREEZE PROTECT -RIG UP SECONDARY KILL LINE TO IAAND PRESSURE TEST 250 LOW;3500 HIGH FOR 5 MIN EACH. -PJSM WMTH RIG CREWAND CH2MHILL VAC TRUCK DRIVERS -REVERSE CIRCULATE 50 BBLS OF HEATED SEAWATER TAKING DIESEL RETURNS FROM TUBING TO THE CUTTINGS BOX. -2 BPM;83 PSI -LINE UP AND CIRCULATE 261 BBLS OF HEATED SEAWATER DOWN THE TUBING TAKING RETURNS TO THE CUTTINGS BOX. -STUNG IN BARACLEAN TO THE FIRST 50 BBLS OF SEAWATER PUMPED. -7.5 BPM;700 PSI SIMOPS: -RIG UP TO PULL AND LAY DOWN 4 1/2"TC-II TUBING ON RIG FLOOR -RIG UP DOUBLE STACK TONGS -PREP PIPE SHED FOR LAYING DOWN TUBING. 05:00 - 06:00 1.00 PULL C INT2 MAKE UP LANDING JOINT,ENGAGE TUBING HANGER AND PULL TO FLOOR -PJSM WITH RIG CREW,DOYON CASING AND FMC -MAKE UP LANDING JOINT TO TUBING HANGER;8 TURNS -BACK OUT LOCK DOWNS -PULL TUBING HANGER OFF SEAT WITH 75K; BLOCK WT=36K 06:00 - 10:30 4.50 PULL C INT2 PULL AND LAY DOWN 74 JTS OF 4 1/2",12.6#, L-80,TC-II TUBING -CHANGE OUT ELEVATORS TO 4 1/2"YC -PU 70K;SO 70K AT 3000'MD -PULL AND LAY DOWN TUBING TO PIPE SHED -D1,KICK WHILE TRIPPING DRILL AND AAR HELD WITH CREW WHILE PULLING TUBING. -DISCUSSED NON-SHEARABLES,JACKING FORCES AND SAFETY JOINT SET UP. 10:30 - 12:00 1.50 PULL C INT2 RIG DOWN CASING EQUIPMENTAND CLEAR RIG FLOOR -CHANGE OUT ELEVATORS;BACK TO BX ELEVATORS -RIG UP AND INSTALL 8.625"ID WEAR RING; RUN IN LOCKDOWNS\ -RIG DOWN AND LAY DOWN ALL CASING RUNNING EQUIPMENT. 12:00 - 13:00 1.00 PULL C INT2 BLOW DOWN LINES AND RIG UP FLOOR TO PICK UP BHA -MAKE UP SAFETY JOINT WITH XO -DRESS PS-21S WITH 4"INSERTS -MOBILIZE BHA HANDLING EQUIPMENT TO RIG FLOOR Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP • Page 48 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 'X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud DateTme:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor.PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 16:00 3.00 CLEAN C INT2 PICK UP AND MAKE UP 6-1/8"CLEANOUT ASSEMBLY -MAKE UP 6-1/8"MILL TOOTH BIT,BIT SUB AND XO. -PICK UP SIX 4-3/4"SPIRAL DRILL COLLARS -PICK UP THREE 4-3/4"NON-MAG COMPRESSIVE COLLARS -PICK UP NINE JOINTS OF 4"HEAVY WEIGHT DRILL PIPE 16:00 - 18:30 2.50 CLEAN C INT2 RUN IN THE HOLE WITH THE 6-1/8" CLEANOUT ASSEMBLY TO 2176'MD;PICKING UP 4"DRILL PIPE FROM THE PIPE SHED. -PU 70K,SO 70K AT 2176'MD 18:30 - 19:00 0.50 CLEAN C INT2 SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT -GREASE TOP DRIVE AND BLOCKS -TOP OFF HYDRAULIC OIL ON TOP DRIVE _ 19:00 - 20:30 1.50 CLEAN C INT2 CONTINUE TO RUN IN THE HOLE VNTH 6 1/8" CLEANOUT ASSEMBLY TO 4539'MD ON STANDS OF 4"DRILL PIPE OUT OF THE DERRICK. -FILL PIPE EVERY 2000'MD. -PU 98K,SO 98KAT 4539'MD 20:30 - 00:00 3.50 CLEAN C INT2 CONTINUE TO RUN IN THE HOLE WITH 6 1/8" CLEANOUT ASSEMBLY TO 7386'MD;PICKING UP 5"DRILL PIPE FROM THE PIPE SHED. -FILL PIPE EVERY 2000'MD. -PU 183K,SO 137K AT 7386'MD 5/24/2015 00:00 - 00:30 0.50 CLEAN C INT2 CONTINUE TO RUN IN THE HOLE WITH 6-1/8" CLEANOUT ASSEMBLY TO 7520'MD;PICKING UP 5"DRILL PIPE FROM THE PIPE SHED. -PU 186K,SO 142K AT 7520'MD 00:30 - 02:30 2.00 CLEAN C INT2 CONTINUE TO RUN IN THE HOLE WITH 6-1/8" CLEANOUT ASSEMBLY TO 9705'MD ON STANDS OF 5"DRILL PIPE OUT OF THE DERRICK. -FILL PIPE EVERY 2000'MD. -PU 215K,SO 158KAT 9705'MD SITE CONTROL OBSERVED A SOW AND CUB GRIZZLY BEAR OF THE SOUTH END OF THE PAD AND NOTIFIED SECURITY AT PBOC. BEARS CONTINUED SOUTH TOWARDS FLOW 1. 02:30 - 04:30 2.00 CLEAN P INT2 DISPLACE WELL FROM 8.5 PPG SEAWATER TO 8.6 PPG QUICKDRIL-N MUD -PJSM WITH RIG CREWAND CH2MHILL TRUCK DRIVERS -500 GPM,1200-1300 PSI -PUMP 35 BBL HIGH VIS SPACER -PUMPED 644 BBLS TOTAL SIMOPS: -REPLACE LEAKING HYDRAULIC SENSOR ON TOP DRIVE Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP • Page 49 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UVN:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 09:00 4.50 CLEAN C INT2 DRILL 7"EZSV BRIDGE PLUG AT 9721'MD -TAKE SLOW PUMP RATES;9660'MD,8753' ND -MPI:30/40 SPM;290/350 PSI -MP2:30/40 SPM;285/350 PSI -ESTABLISH PARAMETERS: -PU 236K;SO 174K AT 9755'MD TAG 7"EZSV CAST IRON BRIDGE PLUG AT 9721'MD DRILL EZSV FROM 9721'MD TO 9724'MD -PU 236K;SO 174K;ROT 203K -VARY PARAMETERS WHILE DRILLING UP PLUG -70-120 RPM;12-14K TORQUE ON;12K TORQUE OFF -0.75-420 GPM;168-600 PSI ON -5-18K WOB 09:00 - 10:00 1.00 CLEAN P INT2 WASH DOWN FROM 9724'MD AND TAG CEMENT AT 9815'MD -PU 236K;SO 174K;ROT 203K -100 RPM;10-12K TORQUE -316 GPM;610 PSI 10:00 - 12:00 2.00 DRILL P INT2 DRILL CEMENT AND SHOE FROM 9815'MD TO 9820'MD -PU 224K;SO 185K;ROT 203K -100 RPM;12-14K TORQUE ON -316 GPM;670 PSI ON -7-16K WOB. 12:00 - 14:00 2.00 DRILL P INT2 DRILL 20'OF NEW HOLE FROM 9820'MD TO 9840'MD(8826'TVD) -PU 225K;SO 185K;ROT 203K -100 RPM;14K TORQUE ON;12K TORQUE OFF -423 GPM;970 PSI ON;965 PSI OFF -12-15K WOB. -1.6 HRS ACTUAL ROTATING TIME 14 00 - 15:00 1.00 DRILL P INT2 CIRCULATE A BOTTOMS UP -423 GPM;965 PSI -100 RPM;12K TORQUE -RECIPROCATING 60'OF STROKE INSIDE THE 7"SHOE SIMOPS: MAKE UP MWD COMPONENTS FOR NEXT DRILLING BHA OFF-LINE -MAKE UP T2 CONNECTIONS FOR 4 3/4" STOP SUB/STARTRAK/FLEX SUB/ NEUTRON DENSITY -MAKE UP T2 CONNECTION FOR 4 3/4" AUTOTRAK/FLEX SUB 15:00 - 16:00 1.00 DRILL P INT2 RIG UP AND PERFORM FIT TO 9.8 PPG EMW -8.5 PPG MW;8809'TVD;9820'MD. -PUMP 1.5 BBLS TO 630 PSI AND HELD FOR 10 MIN. -BLED BACK 1.5 BBLS -FIT EMW=9.8 PPG -NOTIFIED ODE OF FIT RESULTS SEE ATTACHED TEST CHART. Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP Page 50 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. U M:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 22:00 6.00 DRILL C PROD1 PULL OUT OF THE HOLE ON ELEVATORS WITH 6 1/8"CLEAN OUT ASSEMBLY FROM 9755'MD TO 568'MD -MONITOR WELL FOR 10 MIN;STATIC -PU 54K;SO 54K AT 568'MD SWOPS: MAKE UP AND STAND BACK JAR STAND FOR NEXT DRILLING BHA OFF-LINE 22:00 - 23:30 1.50 DRILL C PROD1 LAY DOWN 6 1/8"CLEAN OUT ASSEMBLY -PJSM WITH RIG CREWAND BAKER DD -STAND BACK 3 STANDS OF 4"HWDP FOR NEXT ASSEMBLY -STAND BACK 1 STAND OF NON-MAG COMPRESSIVE COLLARS -LAY DOWN 6 JTS OF 4 3/4"SPIRAL COLLARS TO PIPE SHED. DULL BIT GRADE:1-1-WT-A-E-I-NO-TD 23:30 - 00:00 0.50 DRILL P PROD1 SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT 5/25/2015 00:00 - 05:30 5.50 DRILL P PROD1 MAKE UP 6 1/8"RSS DRILLING BHA PER BAKER DD AND MWD TO 580'MD -PJSM WITH RIG CREW,BAKER DD AND MWD ON PICKING UP BHAAND HANDLING NUCLEAR SOURCES -6 1/8"HYCALOG SKH613M JETTED WITH 3X9,3X12 -AUTO TRACK RSS(NEAR BIT INC) -ONTRACK MWD(GAMMA/ECD/RES/DIR) -BCPM II(PULSER) -COPILOT(DOWNHOLE DRILLING DYNAMICS) -SDN(DENSITY/CALIPER/POROSITY) -STARTRAK(RESISTIVITY IMAGE) -PLUG IN AND SURFACE TEST DIRECTIONAL TOOLS PER BAKER(PASS) AT 02:00 SITE CONTROL RECEIVED NOTIFICATION THATASOWAND CUB GRIZZLY WERE ON LOCATION AND NOSING AROUND THE RIG.SITE CONTROL NOTIFIED SECURITY AT PBOCAND THE L3 PAD OPERATOR.NOTIFICATIONS WERE MADE ON THE RIG HARMONY HUB AND GAI-TRONICS. 05:30 - 06:30 1.00 DRILL P PROD1 SHALLOW HOLE TEST MWD TOOLS AT 580' MD-GOOD TEST -300 GPM;1176 PSI 06:30 - 09:00 2.50 DRILL P PROD1 RUN IN THE HOLE WITH 6 1/8"RSS DRILLING BHA ON 4"DRILL PIPE STANDS OUT OF THE DERRICK FROM 580'MD TO 4551'MD. -FILL PIPE EVERY 2000'MD;168 GPM;290 PSI -PU 98K,SO 98K AT 4551'MD 09:00 - 13:00 4.00 DRILL P PROD1 RUN IN THE HOLE WITH 6 1/8"RSS DRILLING BHA ON 5"DRILL PIPE STANDS OUT OF THE DERRICK FROM 4551'MD TO 9672'MD. -FILL PIPE EVERY 2000'MD;168 GPM;290 PSI -PU 252K,SO 164KAT 9672'MD Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP • Page 51 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 'X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/me:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 15:00 2.00 DRILL P PROD1 CUT AND SLIP DRILL LINE -HOLD PJSM ON SLIP AND CUT OPERATIONS -INSTALL FOSV IN STRING AND HANG OFF BLOCKS -CUT 60'OFF AND SLIP ON NEW LINE -CALIBRATE BLOCKS WITH AMPHION SYSTEM UNANNOUNCED KICK DRILL AND AAR WITH RIG CREW. -CALIBRATE BLOCK WITH BAKER MWD 15:00 - 15:30 0.50 DRILL P PROD1 SERVICE TOP DRIVE,BLOCKS AND RIG FLOOR EQUIPMENT 15:30 - 16:30 1.00 DRILL P PROD1 WASH DOWN LAST STAND AT 150 FT/MIN; FROM 9767'MD TO 9840'MD -300 GPM;1540 PSI -50 RPM;13K TORQUE 16:30 - 00:00 7.50 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE BUILD SECTION FROM 9840'MD TO 10,020'MD(8960'TVD);180'IN 7.5 HRS=24 FPH WITH CONNECTIONS -INSTANTANEOUS ROP=15-80 FPH -325 GPM;1746 PSI ON,1760 PSI OFF -120 RPM,14K FT-LBS OFF BOTTOM TORQUE,16K FT-LBS ON BOTTOM -10-12K LBS WOB -DH WOB=10-12K LBS(WITHIN 1-2K LBS OF SURFACE),DH TORQUE=0.8-1.4K FT-LBS -PU 228K,SO 183K,ROT 202K -MW IN/OUT=8.6 PPG -SURVEY EVERY 30' -NO LOSSES OBSERVED WHILE DRILLING AHEAD ACTIVATED STARTRAK(RES IMAGE)AT 9933' MD,INSTANTANEOUS ROP LIMITED TO 60 FT/HR DUE TO DATAACQUISITION RATE 7"LINER SHOE LOGGED AT 9823'MD.TOP OF LISBURNE LOGGED AT 9823'MD. NO ISSUES IN ACHIEVING 10°DOGLEGS WITH RSS ASSEMBLY. SPR'S©9830'MD,8.6 PPG MW MP1 30/40 SPM 443/627 PSI MP2 30/40 SPM 450/611 PSI SIMOPS: BUILT 33 STANDS OF 5"DRILL PIPE OFF-LINE Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP • Page 52 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 IX3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/me:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual©69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 5/26/2015 00:00 - 06:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 10,020'MD TO 10,150'MD(9033' ND);130'IN 6 HRS=21.6 FPH WITH CONNECTIONS -INSTANTANEOUS ROP=10-60 FPH -325 GPM;1780 PSI ON,1780 PSI OFF -120 RPM,15K FT-LBS OFF BOTTOM TORQUE,16K FT-LBS ON BOTTOM -10-12K LBS WOB -DH WOB=10-12K LBS(WITHIN 1-2K LBS OF SURFACE),DH TORQUE=0.8-1.4K FT-LBS -PU 228K,SO 185K,ROT 204K -MW IN/OUT=8.6 PPG -SURVEY EVERY 30' -NO LOSSES OBSERVED WHILE DRILLING AHEAD 06:00 - 12:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 10,150'MD TO 10,260'MD(9076' ND);110'IN 6 HRS=18.3 FPH WITH CONNECTIONS -INSTANTANEOUS ROP=10-60 FPH -325 GPM;1786 PSI ON,1780 PSI OFF -120 RPM,15K FT-LBS OFF BOTTOM TORQUE,16K-17K FT-LBS ON BOTTOM -10-12K LBS WOB -PU 231 K,SO 186K,ROT 206K -MW IN/OUT=8.6 PPG -SURVEY EVERY 30' -NO LOSSES OBSERVED WHILE DRILLING AHEAD 12:00 - 18:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 10,260'MD TO 10,409'MD(9094' ND);149'IN 6 HRS=24.8 FPH WITH CONNECTIONS -INSTANTANEOUS ROP=10-60 FPH -325 GPM;1802 PSI ON,1790 PSI OFF -120 RPM,16K FT-LBS OFF BOTTOM TORQUE,17K FT-LBS ON BOTTOM -10-12K LBS WOB -PU 232K,SO 182K,ROT 206K -MW IN/OUT=8.6 PPG -SURVEY EVERY 30' -NO LOSSES OBSERVED WHILE DRILLING AHEAD -FLOWCHECK DRILLING BREAK TO 80+FPM AT 10,360' 18:00 - 18:30 0.50 DRILL P PROD1 SERVICE TOP DRIVE AND BLOCKS Printed 6/24/2015 9:13:40AM • ® North America-ALASKA-BP Page 53 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date.6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual(g69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 00:00 5.50 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 10,409'MD TO 10,557'MD(9088' TVD);148'IN 6 HRS=24.7 FPH WITH CONNECTIONS -INSTANTANEOUS ROP=10-60 FPH -325 GPM;1820 PSI ON,1805 PSI OFF -120 RPM,16K FT-LBS OFF BOTTOM TORQUE,17K FT-LBS ON BOTTOM -10-12K LBS WOB -PU 236K,SO 180K,ROT 205K -MW IN/OUT=8.6 PPG -SURVEY EVERY 30' -NO LOSSES OBSERVED WHILE DRILLING AHEAD INVERT AT 10424'MD,9094'TVD,9025'TVDSS 5/27/2015 00:00 - 04:00 4.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 10,557'MD TO 10,618'MD(9088' TVD);148'IN 6 HRS=15 FPH WITH CONNECTIONS -INSTANTANEOUS ROP=20-80 FPH -325 GPM;1815 PSI ON,1805 PSI OFF -120 RPM,16K FT-LBS OFF BOTTOM TORQUE,17K FT-LBS ON BOTTOM -10-12K LBS WOB -PU 236K,SO 180K,ROT 205K -MW IN/OUT=8.6 PPG -SURVEY EVERY 30' -NO LOSSES OBSERVED WHILE DRILLING AHEAD 04:00 - 06:00 2.00 DRILL N DFAL 10,618.00 PROD1 TROUBLESHOOT MWD PULSER TOOL- CIRCULATE BOTTOMS UP. -325 GPM,1837 PSI -140 RPM,16K TORQUE 06:00 - 12:00 6.00 DRILL P PROD1 REGAIN COMMUNICATION WITH TOOLS DURING CIRCULATION OFF BOTTOM. ABLE TO RESUME DRILLING. DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 10,618'MD TO 10,746'MD(9064' TVD);128'IN 6 HRS=21 FPH WITH CONNECTIONS -325 GPM;1753 PSI ON,1813 PSI OFF -120 RPM,17K FT-LBS OFF BOTTOM TORQUE,17K FT-LBS ON BOTTOM -12-14K LBS WOB -PU 235K,SO 182K,ROT 204K -MW IN/OUT=8.6 PPG -SURVEY EVERY 30',EVERY 90'AFTER LANDING BUILD -NO LOSSES OBSERVED WHILE DRILLING AHEAD Printed 6/24/2015 9:13:40AM North America-ALASKA-BP Page 54 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/me:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 14:30 2.50 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 10,746'MD TO 10,800'MD(9057' TVD);53'IN 2.5 HRS=21 FPH WITH CONNECTIONS -325 GPM;1775 PSI ON,1745 PSI OFF -100-120 RPM,17K FT-LBS OFF BOTTOM TORQUE,18K FT-LBS ON BOTTOM 8K LBS WOB -PU 235K,SO 182K,ROT 207K -MW IN/OUT=8.6 PPG -SURVEY EVERY 90' -NO LOSSES OBSERVED WHILE DRILLING AHEAD 14:30 - 16:00 1.50 DRILL N DFAL 10,800.00 PROD1 CIRCULATE WHILE TROUBLSHOOTING MWD PULSER -325 GPM @ 1750 PSI -80-120 RPM,15K TORQUE 16:00 - 16:30 0.50 DRILL P PROD1 SERVICE TOP DRIVE AND BLOCKS 16:30 - 22:30 6.00 DRILL N DFAL 10,800.00 PROD1 POH FROM 10,800'MD TO 579'MD SWAP BHA FOR MWD PULSER FAILURE -FLOW CHECK WELL FOR 10 MINS ON BOTTOM AND AT 7"SHOE,WELL STATIC -POH ON ELEVATORS -INITIAL PUW=250K -NO ISSUES TRIPPING THROUGH OPENHOLE SIMOPS,MAKE UP BHA COMPONENTS FOR NEXT DRILLING ASSEMBLY USING OFFLINE STAND BUILDER DISCOVER CRACK IN 5"DRILLPIPE SLIP AREA (RENTAL STRING)AT BIT DEPTH 8425'MD- NO INDICATORS OF WASHOUT IN PARAMETERS DURING DRILLING. LAYDOWN JOINT AND RETURN TO API. SEE PICTURE. 22:30 - 00:00 1.50 DRILL N DFAL 10,800.00 PROD1 LAY DOWN/STAND BACK 6-1/8"DRILLING ASSEMBLY -FLOW CHECK 10 MIN @ BHA(STATIC) -HOLD PJSM FOR HANDLING BHA -LAY DOWN FLOAT,FILTER,AND COMPRESSIVE DC -REMOVE AND SECURE LOGGING SOURCES -DOWNLOAD STARTRACK DATA -STANDBACK REMAINING BHA 5/28/2015 00:00 - 01:00 1.00 DRILL N DFAL 10,800.00 PROD1 CONTINUE TO LAY DOWN/STAND BACK BHA. CLEAR AND CLEAN RIG FLOOR. BIT GRADE 0-1-CT-S-X-I-ER-DTF(SEE ATTACHED PHOTOS) 01:00 - 02:00 1.00 BOPSUR N RREP 10,800.00 PROD1 REPAIR LEAK ON ANNULAR CONTROL LINE WHILE GATHERING BHA. 02:00 - 02:30 0.50 BOPSUR P PROD1 FUNCTION TEST BOPE W/4"DRILL PIPE (WEEKLY) Printed 6/24/2015 9:13:40AM • • North America-ALASKA-BP Page 55 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/me:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 07:30 5.00 DRILL N DFAL 10,800.00 PROD1 MAKEUP AND RUN IN HOLE WITH SECOND 6-1/8"DRILLING ASSEMBLY FROM SURFACE TO OVERALL LENGTH AT 568' -6-1/8"SECURITY JETTED WITH 3X9,3X12 -AUTO TRACK RSS(NEAR BIT INC) -ONTRACK MWD(GAMMA/ECD/RES/DIR) -BCPM II(PULSER) -COPILOT(DOWNHOLE DRILLING DYNAMICS) -SDN(DENSITY/CALIPER/POROSITY) -STARTRAK(RESISTIVITY IMAGE) -PLUG IN AND SURFACE TEST DIRECTIONAL TOOLS PER BAKER(PASS) -FLOW CHECK WELL 10 MIN PRIOR TO RIH (STATIC) 07:30 - 16:00 8.50 DRILL N DFAL 10,800.00 PROD1 RUN IN HOLE WITH 6-1/8"DRILLING ASSEMBLY ON ELEVATORS WITH 4"/5" DRILLPIPE TAPERED STRING OUT OF DERRICK FROM BHAAT 568'MD TO PREVIOUSLY DRILLED DEPTH OF 10800'MD. -SHALLOW HOLE TEST TOOLS AT 1500'MD (PASS) -FILL 4"PIPE EVERY 30 STANDS,FILL 5" EVERY 20 STANDS 200 FPM IN 9-5/8"CASING,100 FPM IN 7" LINER AND OPENHOLE. -NO ISSUES TRIPPING THROUGH OPENHOLE -WASH FINAL STAND TO BOTTOM;325 GPM, 1750 PSI 16:00 - 00:00 8.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 10,800'MD TO 10,976'MD(9036' TVD);176'IN 8 HRS=22 FPH WITH CONNECTIONS -325 GPM;1680 PSI,130 RPM,16K/15K FT-LBS ON/OFF BOTTOM TORQUE,13K LBS WOB -PU 232K,SO 175K,ROT 205K -MW IN/OUT=8.6 PPG -SURVEY EVERY STAND,NO BACKREAMING -NO LOSSES OBSERVED WHILE DRILLING AHEAD 5/29/2015 00:00 - 06:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 10,976'MD TO 11,110'MD(9011' ND);134'IN 6 HRS=22 FPH WITH CONNECTIONS -325 GPM;1703 PSI,130 RPM,16K/15K FT-LBS ON/OFF BOTTOM TORQUE -13K LBS WOB -PU 230K,SO 175K,ROT 205K -MW IN/OUT=8.6 PPG -SURVEY EVERY STAND,NO BACKREAMING -NO LOSSES OBSERVED WHILE DRILLING AHEAD Printed 6/24/2015 9:13:40AM North America-ALASKA-BP Page 56 of 63 Operation Summary Report Common Well Name:L3-03 1AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To ' Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 12:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 11,110'MD TO 11,220'MD(8984' ND);110'IN 6 HRS=18 FPH WITH CONNECTIONS -325 GPM;1700 PSI,120 RPM,17K/16K FT-LBS ON/OFF BOTTOM TORQUE -11-15K LBS WOB PU 232K,SO 180K,ROT 204K -MW IN/OUT=8.6 PPG -SURVEY EVERY STAND,NO BACKREAMING -NO LOSSES OBSERVED WHILE DRILLING AHEAD 12:00 - 18:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 11,220'MD TO 11384'MD(8985' ND);164'IN 6 HRS=27 FPH WITH CONNECTIONS -325 GPM;1768 PSI,120-130 RPM,18K/16K FT-LBS ON/OFF BOTTOM TORQUE -13K LBS WOB -PU 231K,SO 184K,ROT 203K -MW IN/OUT=8.6 PPG -SURVEY EVERY STAND,NO BACKREAMING -NO LOSSES OBSERVED WHILE DRILLING AHEAD PUMPED A 25 BBL HIGH VIS SWEEP AT 11,380' MD WITH SLIGHT INCREASE IN CUTTINGS 18:00 - 21:30 3.50 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 11,384'MD TO 11,462'MD(8964' ND);78'IN 3.5 HRS=22 FPH WITH CONNECTIONS -325 GPM;1750 PSI,130 RPM,19K/16K FT-LBS ON/OFF BOTTOM TORQUE -13K LBS WOB -PU 230K,SO 182K,ROT 203K -MW IN/OUT=8.6 PPG -SURVEY EVERY STAND,NO BACKREAMING -NO LOSSES OBSERVED WHILE DRILLING AHEAD 21:30 - 22:00 0.50 DRILL P PROD1 SERVICE TOP DRIVE AND BLOCKS 22:00 - 00:00 2.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 11,462'MD TO 11,507'MD(8959' ND);45'IN 2 HRS=22 FPH WITH CONNECTIONS -325 GPM;1711 PSI,130 RPM,17K/15K FT-LBS ON/OFF BOTTOM TORQUE -13K LBS WOB -PU 230K,SO 182K,ROT 204K -MW IN/OUT=8.6 PPG -SURVEY EVERY STAND,NO BACKREAMING -NO LOSSES OBSERVED WHILE DRILLING AHEAD Printed 6/24/2015 9:13:40AM North America-ALASKA-BP Page 57 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor.PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 5/30/2015 00:00 - 06:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 11,507'MD TO 11,564'MD(8,952' TVD);57'IN 6 HRS=9 FPH WITH CONNECTIONS -325 GPM;1715 PSI,140 RPM,16K/15K FT-LBS ON/OFF BOTTOM TORQUE -16K LBS WOB -PU 230K,SO 175K,ROT 205K -MW IN/OUT=8.6 PPG -SURVEY EVERY STAND,NO BACKREAMING -NO LOSSES OBSERVED WHILE DRILLING AHEAD 06:00 - 12:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 11,564'MD TO 11,616'MD(8945' TVD);52'IN 6 HRS= 9 FPH WITH CONNECTIONS -325 GPM;1712 PSI,140 RPM,16-17K/15K FT-LBS ON/OFF BOTTOM TORQUE -15K LBS WOB -PU 230K,SO 182K,ROT 205K -MW IN/OUT=8.6 PPG -SURVEY EVERY STAND,NO BACKREAMING -NO LOSSES OBSERVED WHILE DRILLING AHEAD *DUMP 290 BBL MUD AND REPLACE WITH WATER AT 25 BPH 12:00 - 18:30 6.50 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 11,616'MD TO 11,745'MD(8926' TVD);129'IN 6.5 HRS= 20 FPH WITH CONNECTIONS -325 GPM;1705 PSI,120 RPM,18K/14K FT-LBS ON/OFF BOTTOM TORQUE -13-15K LBS WOB -PU 236K,SO 180K,ROT 204K -MW IN/OUT=8.7 PPG -SURVEY EVERY STAND,NO BACKREAMING -NO LOSSES OBSERVED WHILE DRILLING AHEAD 18:30 - 19:00 0.50 DRILL P PROD1 SERVICE TOP DRIVE AND BLOCKS 19:00 - 00:00 5.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 11,745'MD TO 11,834'MD(8911' TVD);89'IN 5 HRS=18 FPH WITH CONNECTIONS -325 GPM;1710 PSI,140 RPM,18K/16K FT-LBS ON/OFF BOTTOM TORQUE -10-15K LBS WOB -PU 236K,SO 180K,ROT 205K -MW IN/OUT=8.7 PPG -SURVEY EVERY STAND,NO BACKREAMING -NO LOSSES OBSERVED WHILE DRILLING AHEAD *DUMP 175 BBL MUD AND REPLACE WITH WATER AT 25 BPH Printed 6/24/2015 9:13:40AM North America-ALASKA-BP Page 58 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 5/31/2015 00:00 - 06:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 11,834'MD TO 11,914'MD(8896' TVD);80'IN 6 HRS=13 FPH WITH CONNECTIONS -325 GPM;1712 PSI,140 RPM,18K/16K FT-LBS ON/OFF BOTTOM TORQUE -12K LBS WOB PU 235K,SO 182K,ROT 205K -MW IN/OUT=8.7 PPG -SURVEY EVERY STAND,NO BACKREAMING -NO LOSSES OBSERVED WHILE DRILLING AHEAD *FLOW CHECK FOR DRILLING BREAK AT 11,914'(STATIC) 06:00 - 12:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 11,914'MD TO 11,971'MD(8,888' ND);57'IN 6 HRS=9 FPH WITH CONNECTIONS -325 GPM;1708 PSI,140 RPM,18K/17K FT-LBS ON/OFF BOTTOM TORQUE -15K LBS WOB -PU 240K,SO 180K,ROT 206K -MW IN/OUT=8.7 PPG -SURVEY EVERY STAND,NO BACKREAMING -NO LOSSES OBSERVED WHILE DRILLING AHEAD 12:00 - 16:00 4.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 11,971'MD TO 12,026'MD(8,829' ND);55'IN 4 HRS=14 FPH WITH CONNECTIONS -325 GPM;1726 PSI,140 RPM,20K/18K FT-LBS ON/OFF BOTTOM TORQUE -15KLBS WOB -PU 242K,SO 180K,ROT 205K -MW IN/OUT=8.7 PPG -SURVEY EVERY STAND,NO BACKREAMING -LOSSES OCCORRED AT 12,018'-INITIAL DYNAMIC LOSSES=60 BPH,STATIC LOSSES =0 BPH. DYNAMIC LOSSES DECREASED TO 5 BPH 16:00 - 16:30 0.50 DRILL P PROD1 SERVICE TOP DRIVE AND BLOCKS 16:30 - 00:00 7.50 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 12,026'MD TO 12,160'MD(8,862' ND);134'IN 7.5 HRS=18 FPH WITH CONNECTIONS -325 GPM;1735 PSI,140 RPM,18K/16K FT-LBS ON/OFF BOTTOM TORQUE -13KLBSWOB -PU 235K,SO 182K,ROT 205K -MW IN/OUT=8.7 PPG -SURVEY EVERY STAND,NO BACKREAMING -5 BPH DYNAMIC LOSSES Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP Page 59 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual©69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/1/2015 00:00 - 06:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 12,160'MD TO 12,250'MD(8,852' TVD);90'IN6HRS=15FPH WITH CONNECTIONS -325 GPM;1740 PSI,140 RPM,18K/16K FT-LBS ON/OFF BOTTOM TORQUE -13K LBS WOB -PU 235K,SO 182K,ROT 205K -MW IN/OUT=8.7 PPG -SURVEY EVERY STAND,NO BACKREAMING -5 BPH DYNAMIC LOSS RATE 06:00 - 12:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 12,250'MD TO 12,420'MD(8,832' TVD);170'IN 6 HRS=28 FPH WITH CONNECTIONS -325 GPM;1770 PSI,140 RPM,20K/18K FT-LBS ON/OFF BOTTOM TORQUE -15K LBS WOB -PU 240K,SO 184K,ROT 208K -MW IN/OUT=8.7 PPG -SURVEY EVERY STAND,NO BACKREAMING LOSES INCREASED AT 0600,INITIAL DYANAMIC LOSSES WERE 350 BPH, TAPERING OFF TO 180 BPH,INITIAL STATIC LOSSES WERE 6 BPH PUMPED A40 BBL,40 PPB,CALCIUM CARBONATE LCM PILL AT 12,355'MD WHILE LOSSES WERE 180 BPI-I,NO CHANGE IN LOSS RATE 12:00 - 18:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 12,420'MD TO 12,609'MD(8,813' ND);189'IN 6 HRS=31 FPH WITH CONNECTIONS -250 GPM;1240 PSI,140 RPM,20K/19K FT-LBS ON/OFF BOTTOM TORQUE -11-15K LBS WOB -PU 252K,SO 180K,ROT 210K -MW IN/OUT=8.6 PPG -SURVEY EVERY STAND,NO BACKREAMING -DYANMIC LOSSES 130-200 BHP,NO STATIC LOSSES PUMPED A80 BBL,40 PPB,CALCIUM CARBONATE LCM PILL AT 12,540'MD WHILE LOSSES WERE 130 BPH,NO CHANGE IN LOSS RATE REDUCED PUMP RATE FROM 325 GPM TO 250 GPM AT 12,580'MD IN AN ATTEMPT TO REDUCE LOSSES PUMPED A 80 BBL,40 PPB,CALCIUM CARBONATE LCM PILL AT 12,590'MD WHILE LOSSES WERE 200 BPH,NO CHANGE IN LOSS RATE 18:00 - 18:30 0.50 DRILL P PROD1 SERVICE TOP DRIVE AND BLOCKS Printed 6/24/2015 9:13 40AM North America-ALASKA-BP Page 60 of 63 Operation Summary Report Common Well Name:L3-03 1AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 00:00 5.50 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 12,609'MD TO 12,758'MD(8,793' TVD);149'IN 6 HRS=25 FPH WITH CONNECTIONS -260 GPM;1245 PSI,150 RPM,20K/17K FT-LBS ON/OFF BOTTOM TORQUE -11-15K LBS WOB -PU 252K,SO 178K,ROT 211K -MW IN/OUT=8.6 PPG -SURVEY EVERY STAND,NO BACKREAMING -DYNAMIC LOSSES 50-130 BPH,NO STATIC LOSSES PUMPED A 80 BBL,40 PPB,CALCIUM CARBONATE LCM PILL AT 12,695'MD WHILE LOSSES WERE 150 BPH,LOSS RATE DROPPED TO 100 BPH PUMPED A80 BBL,40 PPB,CALCIUM CARBONATE LCM PILL AT 12,750'MD WHILE LOSSES WERE 100 BPH,LOSS RATE DROPPED TO 50 BPH 6/2/2015 00:00 - 06:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 12,758'MD TO 12,855'MD(8,780' ND);97'IN 6 HRS=16 FPH WITH CONNECTIONS -260 GPM;1211 PSI,150 RPM,20K/17K FT-LBS ON/OFF BOTTOM TORQUE -13K LBS WOB -PU 252K,SO 178K,ROT 211K -MW IN/OUT=8.6 PPG -SURVEY EVERY STAND,NO BACKREAMING -DYNAMIC LOSSES 90-130 BPH 06:00 - 09:30 3.50 DRILL P PROD1 DIRECTIONAL DRILL 6-1/8"PRODUCTION HOLE FROM 12,855'MD TO TD AT 12,875'MD• (8,777'ND);20'IN 3.5 HRS=6 FPH WITH CONNECTIONS -260 GPM;1210 PSI,150 RPM,19K/18K FT-LBS ON/OFF BOTTOM TORQUE -14K LBS WOB -PU 243K,SO 185K,ROT 211K -MW IN/OUT=8.7 PPG -SURVEY EVERY STAND,NO BACKREAMING -DYNAMIC LOSSES 80-90 BPH 09:30 - 13:00 3.50 CONDHL P PROD1 CIRCULATE HOLE CLEAN(2 BOTTOMS UP) -300 GPM,1450 PSI -80-140 RPM,10-15K TORQUE -RECIPROCATE 1 STAND WHILE CIRCULATING -DYNAMIC LOSSES 60-100 BPH -STATIC LOSSES 6 BPH 13:00 - 14:30 1.50 EVAL P PROD1 POH ON ELEVATORS FROM 12,784'MD TO 11,993'MD -10 MIN FLOW CHECK(6 BPH STATIC LOSSES) -10-20K OVERPULLS SEEN POOH FROM —12500'TO 12000'MD CORRESPONDING TO FAULTED AND FRACTURED ZONE -PU 245K,SO 182K Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP Page 61 of 63 Operation Summary Report Common Well Name:L3-03 ,AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 16:30 2.00 EVAL P PROD1 MADD PASS FOR CALIPER FROM 11,993'MD TO 11,723"MD AT 300 FPH -290 GPM,1320 PSI -30 RPM,9K TORQUE 16:30 - 17:30 1.00 EVAL P PROD1 POH ON ELEVATORS FROM 11,723'MD TO 10,810'MD -10 MIN FLOW CHECK(6 BPH STATIC LOSSES) -PU 238K,SO 160K 17:30 - 23:00 5.50 EVAL P PROD1 MADD PASS FOR SPECTRAL GAMMA RAY FROM 10,810'MD TO 9,957"MD AT 180 FPH -NO PUMPS OR ROTATION -PU 230K,SO 185K -POH FROM 9,957'TO 7"CASING SHOE AT 9,752' -10 MIN FLOW CHECK AT 7"CASING SHOE(6 BPH STATIC LOSSES) -NO HOLE PROBLEMS ENCOUNTERED 23:00 - 23:30 0.50 EVAL P PROD1 SERVICE TOP DRIVE AND BLOCKS,MONITOR WELL 23:30 - 00:00 0.50 EVAL P PROD1 PERFORM DERRICK,CROWN AND TOP DRIVE INSPECTION PER REQUEST FROM BP MANAGEMENT,MONITOR WELL 6/3/2015 00:00 - 01:00 1.00 CONDHL P PROD1 POH ON ELEVATORS FROM 9,752'MD TO 9,090'MD -MONITOR WELL FOR 10 MINUTES- OBSERVED STATIC LOSSES OF 6 BPH -PU 230K,SO 185K AT 9,752' -NO TIGHT SPOTS WHILE PULLING OUT OF HOLE -LOSS RATE OF 30 BBLS/HR WHILE PULLING OUT OF THE HOLE 01:00 - 02:30 1.50 CONDHL P PROD1 CIRCULATE HOLE CLEAN(1.5X BOTTOMS UP) FROM TOP OF 7"LINER -325 GPM,1450 PSI -80 RPM,5K TORQUE -RECIPROCATE 1 STAND WHILE CIRCULATING -DYNAMIC LOSSES 60-100 BPH -STATIC LOSSES 6 BPH -MINIMAL CUTTINGS RETURNS AT SHAKERS 02:30 - 05:30 3.00 CONDHL P PROD1 RUN IN HOLE ON ELEVATORS FROM 9,090' MD TO 12,858'MD -FILL PIPE EVERY 2000'MD -TOOK 10-20K WEIGHT CORRESPONDING TO FAULTED AND FRACTURED ZONE FROM —12000'MD TO 12500'MD -LOSS RATE OF 30 BBLS/HR WHILE RUNNING IN HOLE Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP • Page 62 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040,981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code ,, NPT NPT Depth Phase Description of Operations (hr) (usft) 05:30 - 09:30 4.00 CONDHL P PROD1 CIRCULATE HOLE CLEAN(3X BOTTOMS UP) -315 GPM,1554 PSI -80 RPM,9.5K TORQUE -RECIPROCATE 1 STAND WHILE CIRCULATING -DYNAMIC LOSSES INITIALLY AT 140 BPH AT BEGINNING OF CIRCULATION,TAPERED OFF TO 80 BPH -MINIMAL CUTTINGS RETURNS AT SHAKERS -UPDATE AOGCC REPRESENTATIVE MATT HERRERAAT 06:30 FOR UPCOMING BOPE TEST. -HELD PLANNING MEETING WITH SLB REPRESENTATIVE TO CHECK EQUIPMENT FOR LINER RUN AND TO DRIFT FRAC SLEEVES 09:30 - 12:00 2.50 CONDHL P PROD1 PULL OUT OF HOLE ON ELEVATORS FROM 12,858'MD TO 9,092'MD -MONITOR WELL FOR 10 MINUTES PRIOR TO PULLING OFF BOTTOM-OBSERVED STATIC LOSSES OF 30 BPH -PU 245K,SO 180KAT 12,858'MD -NO HOLE PROBLEMS OBSERVED ON FINAL TRIP OUT OF HOLE -LOSS RATE OF—30 BBLS/HR WHILE PULLING OUT OF HOLE -HELD PLANNING MEETING WITH HES REPRESENTATIVE AT 11:00 TO CHECK SWELLPACKER EQUIPMENT FOR LINER RUN 12:00 - 14:00 2.00 CONDHL P PROD1 CIRCULATE HOLE CLEAN AT 7"LINER TOP (1.5X BOTTOMS UP) -300 GPM,1280 PSI -80 RPMS,6K TORQUE -RECIPROCATE 1 STAND 90' -NO INCREASE IN CUTTINGS OBSERVED AT SHAKERS 14:00 - 14:30 0.50 CONDHL P PROD1 SERVICE TOP DRIVE -GREASED WASH PIPE -CHECK FLUID LEVELS -GREASE MOTORS ON TOP DRIVE Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP • Page 63 of 63 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:DRL-ONSHORE(DON) Start Date:3/11/2015 End Date:6/3/2015 X3-016C7-C:(14,040.981.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 19:00 4.50 CONDHL P PROD1 PULL OUT OF HOLE ON ELEVATORS FROM 9,092'MD TO 567'MD -MONITOR WELL FOR 10 MINUTES PRIOR TO PULLING OUT OF HOLE-OBSERVED STATIC LOSSES OF 30 BPH -PU 200K,SO 178KAT 9091'MD -LOSS RATE OF 30 BBLS/HR WHILE PULLING OUT OF HOLE -HELD PLANNING MEETING WITH BAKER REPRESENTATIVES TO CHECK EQUIPMENT FOR LINER RUN:SENT SHOE TRACK BACK TO BAKER MACHINE TO HAVE OVERSIZED CENTRALIZER MODIFIED -HELD PLANNING MEETING WITH DOYON CASING TO PREPARE FOR UPCOMING LINER RUN -CONTACTED BY AOGCC REPRESENTATIVE JOHN CRISP AT 16:30 TO DISCUSS WITNESS OF UPCOMING BOPE TEST 19:00 - 00:00 5.00 CONDHL P PROD1 LAY DOWN BHA -HOLD PJSM ON LAYING DOWN BHAAND HANDLING NUCLEAR SOURCES -RACK BACK HEAVY WALL STANDS -LAY DOWN JARS -LAY DOWN FLOAT AND FILTER SUB, COMPRESSIVE DRILL COLLARS,AND SLB SPECTRAL GAMMA RAY TOOL -REMOVE NUCLEAR SOURCES -PLUG INTO BAKER TOOLS AND DOWNLOAD DATA -LAY DOWN STARKTRAK TOOL,MWD, COPILOT,AND AUTOTRAK -END OF DON EVENT,SEE CON REPORT#1 Printed 6/24/2015 9:13:40AM • North America-ALASKA-BP Page 1 of 6 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:COM-ONSHORE(CON) Start Date:6/4/2015 End Date:6/8/2015 4X3-016C7-C:(5,043,178.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/4/2015 00:00 - 03:00 3.00 BOPSUR P RUNPRD RIG UP FOR BOP TEST -CLEAN AND CLEAR RIG FLOOR -PULL WEAR RING AND SET TEST PLUG -MAKE UP TEST JOINTS -PJSM FOR TESTING BOPS -MONITOR WELL,WELL TAKING 25-30 BPH LOSSES 03:00 - 09:00 6.00 BOPSUR P RUNPRD TEST BOPE TO 250 PSI LOW,4000 PSI HIGH FOR 5 MINUTES EACH -TEST WITH 4"AND 5"TEST JOINTS -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS -GREASE FITTING FAILURE ON VALVE 6, REPLACED AND SUBESEQUENT GOOD TEST -TEST WITNESSED BY AOGCC REP JOHN CRISP -MONITOR WELL VIA TRIP TANK WHILE FILLING UP VIA SECONDARY KILL LINE,WELL TAKING 25-30 BPH LOSSES 09:00 - 10:00 1.00 BOPSUR P RUNPRD RIG DOWN BOP TESTING EQUIPMENT -PULL TEST PLUG AND SET WEAR RING -LD TEST JOINTS -CLEAN AND CLEAR RIG FLOOR MONITOR WELL,WELL TAKING 25-30 BPH LOSSES 10:00 - 15:00 5.00 CASING P RUNPRD MAKE UP 4.5"SWELL PACKER/SLIDING SLEEVE LINER TALLY -WAIT ON SWELL PACKER/SLIDING SLEEVE PLACEMENT DATA FROM TOWN -MAKE UP LINER TALLY AFTER RECEIVING PLACEMENT DATA FROM TOWN -SIMOPS:LAY DOWN 4"HWDP AND DP OFF LINE -BEGIN RIGGING UP TO RUN LINER -MAKE UP 4"SAFETY JOINT -SWAP TO 4.5"ELEVATORS -STAGE POWER TONGS ON RIG FLOOR -RIG UP FILL UP HOSE ON RIG FLOOR -PULL MASTER BUSHINGS AND RIG UP PS-21'S WITH FALSE BOWL -WELL CONTINUING TO TAKE 25-30 BPH LOSSES 15:00 - 15:30 0.50 CASING P RUNPRD RIG SERVICE -GREASE TOP DRIVE -SERVICE PS-21'S Printed 6/24/2015 9:14:50AM • North America-ALASKA-BP • Page 2 of 6 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:COM-ONSHORE(CON) Start Date:6/4/2015 End Date:6/8/2015 X3-016C7-C:(5,043,178.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor.PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual(8269.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 20:00 4.50 CASING P RUNPRD FINALIZE 4.5"LINER TALLY -SIMOPS:COMPLETE RIGGING UP CASING POWER TONGS AND TEST -INSPECT TOP DRIVE -CLEAN AND PAINT AROUND RIG -WELL CONTINUING TO TAKE 25-30 BPH LOSSES *LINA SERPA,JEFF KILFOYLE,AND HERB WILLIAMS ON LOCATION FOR DROPPED OBJECTS AUDIT DUE TO RECENT GLOBAL INCIDENTS *HELD SAFETY DISCUSSION ON NEAR MISS DROPPED OBJECT WITH MUD MOD SIDE TUBULAR LIFTING SYSTEM WITH BP DRILLING SUPERINTENDENT,HSE,AND WSL'S,PARKER DRILLING SUPERINTENDENT,HSE,AND RIG MANAGERS;SEE TRACTION REPORT #5015201 20:00 - 00:00 4.00 CASING P RUNPRD ORGANIZE PIPE SHED TO TALLY RUNNING ORDER -ARRANGE ALL LINER AND JEWELRY IN PIPE SHED ACCORDING TO RUNNING ORDER INSPECT AND VERIFY TALLY IN SHED -WELL CONTINUING TO TAKE 25-30 BPH LOSSES 6/5/2015 00:00 - 01:00 1.00 CASING P RUNPRD COMPLETE RIGGING UP FOR RUNNING 4-1/2" LINER -PJSM FOR RUNNING 4-1/2"LINER 01:00 - 12:00 11.00 CASING P RUNPRD RUN 4.5",13.5#,13CR-80 HYDRIL 521 PRODUCTION LINER TO 3170'MD -CHECK FLOATS -BAKERLOK SHOETRACK -USE JET LUBE SEAL GUARD ON ALL CONNECTIONS -TORQUE CONNECTIONS TO 5000 FT-LBS -RUN 1 FREE FLOATING CENTRALIZER ON JOINTS 1-54 -FILL CASING ON THE FLY AND TOP OFF EVERY 10 JOINTS 12:00 - 20:00 8.00 CASING P RUNPRD MAKE UP LINER HANGER/PACKER ASSEMBLY -ADD PAL MIX -CIRCULATE 1.5X LINER VOLUMES AT 4 BPM, 160 PSI -PU 73K,SO 73KAT 3331'MD -CONTINUE IN HOLE TO 9820'MD(7"SHOE) ON 4"AND 5"DRILL PIPE -RIH AT 90 FT/MIN FROM 3331'MD TO 9820' MD -CIRCULATE 1.5X BOTTOMS UP AT 4 BPM, 350 PSI -PU 190K,SO 165K AT 9773'MD -OBTAIN SURFACE TORQUE:10 RPMS:4.2K FT-LBS,20 RPMS:4.5K FT-LBS Printed 6/24/2015 9:14:50AM • North America-ALASKA-BP • Page 3 of 6 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:COM-ONSHORE(CON) Start Date:6/4/2015 End Date:6/8/2015 X3-016C7-C:(5,043,178.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 23:30 3.50 CASING P RUNPRD RUN IN OPEN HOLE WITH LINER TO TD AT 12858'MD -OBTAIN SO WEIGHTS EVERY 1000 FT -PU 240K,SO 150K AT TD -MUD WEIGHT:8.5 PPG IN,8.5 PPG OUT -MUD LOSSES WHILE RIH:352 BBLS -TOP OF LINER AT 9650'MD NO MAJOR HOLE PROBLEMS SEEN WHILE RIH -PUMP 15 BBLS HIGH VIS QUIKDRIL SWEEP AT 3 BPM,420 PSI -DROP 1.275"SLB CIRC VALVE BALL,CHASE WITH 20 BBL HIGH VIS QUIKDRIL SWEEP 23:30 - 00:00 0.50 CASING P RUNPRD RIG SERVICE -SERVICE WELL CENTER ST-80 -GREASE PS-21'S 6/6/2015 00:00 - 01:30 1.50 CASING P RUNPRD SET LINER HANGER AND LTP -LAND 1.275"SLB CIRC VALVE BALL ON SEAT AND PRESSURE UP TO 1900 PSI TO CLOSE -PRESSURE UP TO 3000 PSI TO SET HANGER -SLACK OFF TO CONFIRM HANGER SET AND OBSERVE HANGER DID NOT SET -PRESSURE UP TO 3000 PSI AGAIN TO SET HANGER -SLACK OFF 100K TO CONFIRM HANGER SET -PRESSURE UP TO 4000 PSI TO RELEASE RUNNING TOOL,GOOD INDICATION OF RELEASE -PICK UP 5'TO RELEASE DOGS,SLACK OFF 50K TO SET LTP,GOOD INDICATION OF SET 01:30 - 02:30 1.00 CASING P RUNPRD PRESSURE TEST LTP TO 250 PSI LOW FOR 5 MIN/4000 PSI HIGH FOR 30 MIN -TEST APPROVED BY BP ACTING WTL KEN S CH N EIDER 02:30 - 04:30 2.00 CASING P RUNPRD DISPLACE 8.5 PPG QUIKDRIL WITH 8.5 PPG SEAWATER -650 GPM,1090 PSI -PUMP HIGH VIS SWEEP AS SPACER -SIMOPS:BEGIN LAYING DOWN DRILLPIPE OUT OF DERRICK OFFLINE 04:30 - 12:00 7.50 CASING P RUNPRD PULL OUT OF HOLE ON ELEVATORS FROM 9731'MD TO SURFACE -MONITOR WELL FOR 10 MINUTES:STATIC -PU 225K,SO 178KAT 9731'MD -STAND BACK 60 STANDS TO BE LAVED DOWN OFFLINE -LAY DOWN REMAINING PIPE TO PIPE SHED -LAY DOWN LINER SETTING TOOL -INSPECT ROTATING DOG SUB:PINS SHEARED,GOOD INDICATION LTP IS SET 12:00 - 13:00 1.00 CASING P RUNPRD PULL WEAR RING AND SWAP OUT PS-215 FOR MASTER BUSHINGS Printed 6/24/2015 9:14:50AM • North America-ALASKA-BP • Page 4 of 5 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:COM-ONSHORE(CON) Start Date:6/4/2015 End Date:6/8/2015 X3-016C7-C:(5,043,178.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud DateTme:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UWI:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To ®®® NPT NPT Depth Phase Description of Operations (usft) 13:00 - 15:00 2.00 RUNCOM P RUNCMP RIG UP CASING EQUIPMENT AND I-WIRE SPOOL -HOLD PJSM ON RIGGING UP -RIG UP POWER TONGS -RIG DOWN BX ELEVATORS AND RIG UP MANUAL ELEVATORS -BRING I-WIRE SPOOLAND CLAMPS TO RIG FLOOR -RIG UP I-WIRE SPOOL AND SHEAVE 15:00 - 15:30 0.50 RUNCOM P RUNCMP SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT 15:30 - 00:00 8.50 RUNCOM P RUNCMP RUN 4-1/2",12.6#,13CR-85,VAMTOP TUBING TO 3006'MD -HOLD PJSM ON RUNNING COMPLETION: DISCUSSED RUNNING I-WIRE AND INSTALLING CLAMPS,WELL CONTROL WITH I-WIRE AND POWER TONG SAFETY -BAKERLOK CONNECTIONS TO THE PACKER -INSTALL SAPPHIRE DOWNHOLE PRESSURE AND TEMPERATURE GAUGE AND PRESSURE TEST CONNECTION PER SLB PROCEDURE -USE JET LUBE SEAL GUARD PIPE DOPE TORQUE CONNECTIONS TO4,400 FT-LBS -RUN IN HOLE AT 90 FT/MIN -INSTALL CANNON CLAMP FOR I-WIRE ON EVERY COLLAR -VERIFY COMMUNICATION WITH DOWNHOLE GAUGE EVERY 1000'MD -PU 63K,SO 63K AT 2760'MD -MUD WEIGHT:8.5 PPG IN,8.5 PPG OUT 6/7/2015 00:00 - 10:30 10.50 RUNCOM P RUNCMP RUN 4-1/2",12.6#,13CR-85,VAMTOP TUBING FROM 3006'MD TO 9660'MD -USE JET LUBE SEAL GUARD PIPE DOPE -TORQUE CONNECTIONS TO 4,400 FT-LBS -RUN IN HOLE AT 90 FT/MIN -PU 151 K,SO 117K -INSTALL CANNON CLAMP FOR I-WIRE ON EVERY COLLAR -VERIFY COMMUNICATION WITH DOWNHOLE GAUGE EVERY 1200'MD -TAG BOTTOM OF TIE-BACK RECEPTACLE AT 9660'MD,REPEAT TO VERIFY -MUD WEIGHT:8.5 PPG IN,8.5 PPG OUT 10:30 - 12:30 2.00 RUNCOM P RUNCMP PERFORM SPACE OUT AND MAKE UP TUBING HANGER -LAY DOWN JOINT 225 AND 224 -MAKE UP TUBING HANGER PER FMC -CONNECT I-WIRE TO TUBING HANGER AND PERFORM PRESSURE TEST PER SLB PROCEDURE -LAND TUBING HANGER AND RUN IN LOCK DOWN SCREWS -WLEG SET AT 9656'MD Printed 6/24/2015 914:50AM North America-ALASKA-BP Page 5 of 6 Operation Summary Report Common Well Name:L3-03 AFE No Event Type:COM-ONSHORE(CON) Start Date:6/4/2015 End Date:6/8/2015 X3-016C7-C:(5,043,178.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud Date/Time:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UVN:500292353500 Active datum:L3-03 Actual @69.55usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 17:30 5.00 RUNCOM P RUNCMP RIG UP AND REVERSE CIRCULATE COMPLETION FLUID -HOLD PJSM ON CIRCULATING COMPLETION FLUID,DISCUSS FLUID MANAGEMENT,VALVE ALIGNMENT,AND THE IMPORTANCE OF TRACKING BBLS IN AND BBLS OUT DURING THE DISPLACEMENT -4 BBLS/MIN,400 PSI -PUMP 150 BELS CLEAN 8.5 PPG SEAWATER -PUMP 263 BBLS CORROSION INHIBITED SEAWATER -PUMP 233 BBLS CLEAN SEWATER -PUMP 5 BBLS EACH WAY TO CLEAN OFF RHC SEAT 17:30 - 20:30 3.00 RUNCOM P RUNCMP SET PACKER AND PRESSURE TEST TUBING AND IA -DROP BALL AND ROD -PJSM FOR SETTING PACKER AND TESTING, COVER BP PRESSURE CROSSCHECK CHECKLIST -TEST TUBING TO 250 PSI LOW FOR 5 MINUTES,4000 PSI HIGH FOR 30 MINUTES: PASS -BLEED OFF TUBING PRESSURE TO 2300 PSI -TEST IA TO 250 PSI LOW FOR 5 MINUTES, 4000 PSI HIGH FOR 30 MINUTES:PASS -TEST APPROVED BY ACTING BP WTL KEN SCHNEIDER,SEE ATTACHED TEST CHARTS -BLEED OFF TUBING PRESSURE TO SHEAR DCR VALVE -OBSERVE SHEAR AT-1000 PSI TUBING PRESSURE(3100 PSI DIFFERENTIAL) -PUMP 2 BBLS EACH WAY AT 2.5 BBUMIN, 250 PSI 20:30 - 00:00 3.50 RUNCOM P RUNCMP FREEZE PROTECT TUBING X IA -PJSM FOR PUMPING FREEZE PROTECT -REVERSE CIRULATE 155 BBLS OF DIESEL AT 2.5 BPM DOWN IA -U-TUBE DIESEL TO EQUALIZE TUBING X IA -FREEZE PROTECT DEPTH TO 2200'MD -SIMOPS:LAY DOWN 5"DRILL PIPE OFF LINE 6/8/2015 00:00 - 00:30 0.50 RUNCOM P RUNCMP U-TUBE FREEZE PROTECT -CONTINUE TO ALLOW DIESEL TO U-TUBE -SIMOPS:LAY DOWN 5"DRILL PIPE OFF LINE 00:30 - 01:00 0.50 WHSUR P RUNCMP SETTWC -DRY ROD IN AND SET TYPE H PROFILE TWC 01:00 - 03:00 2.00 WHSUR P RUNCMP PRESSURE TEST TVVC TO 250 PSI LOW FOR 5 MIN/3500 PSI HIGH FOR 5 MIN EACH FROM ABOVE AND BELOW -PJSM FOR TESTING TWC,REVIEW PRESSURE CROSSCHECK CHECKLIST -GOOD TEST Printed 6/24/2015 9:14:50AM • North America-ALASKA-BP Page 6 of 6 Operation Summary Report -- - - ---- ------ Common Well Name:L3-03 AFE No Event Type:COM-ONSHORE(CON) Start Date:6/4/2015 End Date:6/8/2015 X3-016C7-C:(5,043,178.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:PARKER 272 Spud DateTme:3/14/2015 9:00:00AM Rig Release:6/8/2015 Rig Contractor:PARKER DRILLING CO. UW:500292353500 Active datum:L3-03 Actual t69.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 06:30 3.50 WHSUR P RUNCMP NIPPLE DOWN RISER AND BOP -BLOW DOWN SURFACE LINES AND EQUIPMENT -RIG DOWN LINES -NIPPLE DOWN STACK -REMOVE HIGH PRESSURE RISER AND PLACE IN SHED -SIMOPS:CONTINUE LAYING DOWN 5"DRILL PIPE 06:30 - 09:30 3.00 WHSUR P RUNCMP -CLEAN WELLHEAD -SLB TEST DOWN HOLE GAUGE AND I-WIRE -FINAL DOWNHOLE PRESSURE AND TEMPERATURE:3570 PSI,153 DEGREES F -SIMOPS:CONTINUE LAYING DOWN 5 DRILL PIPE 09:30 - 10:30 1.00 WHSUR P RUNCMP NIPPLE UP DRYHOLE 10K FRAC TREE AND ADAPTER FLANGE 10:30 - 12:00 1.50 WHSUR P RUNCMP FMC TEST ADAPTER FLANGE -TEST VOID TO 250 PSI LOW FOR 5 MIN,5000 PSI HIGH FOR 30 MIN-PASS -LAY DOWN STANDS OF DRILLPIPE OFFLINE 12:00 - 13:00 1.00 WHSUR P RUNCMP PERFORM VISUAL LEAK TIGHT TEST OF TREE TO 5000 PSI -FILL TREE WITH DIESEL -PRESSURE TEST TO 250 PSI LOW FOR 5 MIN,5000 PSI HIGH FOR 5 MIN:PASS 13:00 - 15:00 2.00 RIGD P RUNCMP PREPARE TO MOVE RIG -HOLD PJSM ON RIGGING DOWN -SECURE PIPE SHED -RIG DOWN RIG FLOOR -SECURE IRON DERRICKMAN -BEGIN TO MOVE MUD MODULE RIG RELEASED FROM L3-03 06/0812015 15:00 FINAL T/I/O=0/0/0 PSI CLOSE OUT UWVTP WITH PAD OPERATOR COMPLETE HANDOVER WITH WELLS GROUP _ Printed 6/24/2015 9:14:50AM • • Urn 0111 `Wto ii wog z 0 m I co Q -t J Q Q I CD v IX • iCD W E Q eq in M M CO r Mo M -Jcov t i N N C a O7 0 M M C7 C C N N p p Np •y 3 -CDZ J J J J in 0 LL 2 0 • s Ill a Z m co 1 CO IN i N R q61� p d. 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G,w\-\;I��:4N THE STATE Alaska Oil and Gas �w "?���'�9� O f A A Conservation Commission " s `. .itv-= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ° 'AL ASS‘P' Fax: 907.276.7542 www.aogcc.alaska.gov Ken Allen Engineering Team Leader BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L3-03 Sundry Number: 315-198 Dear Mr. Allen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P-73,C,v)`4"-- Cathy . Foerster . - Chair DATED this / day of April, 2015 Encl. STATE OF ALASKA • RECEIVED ' ALAS OIL AND GAS CONSERVATION COMMISSION APR R 0 2 2015 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 AOGC,C 1. Type of Request: ❑Abandon 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations ❑Perforate 0 Pull Tubing 0 Time Extension . ®Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. 0 Exploratory 0 Stratigraphic 215-018 3. Address: 6. API Number: e,Alaska 99519-6612 ®Development ❑Service P.O. Box 196612,Anchorage, 50.029-23535-00-00 . 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? o PBU L3-03 • Will planned perforations require a Spacing Exception? 0Yes N 9. Property Designation 10.Field/Pool(s): ADL 028322&034631 ' Prudhoe Bay/Lisburne. 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9220' 8808' 9220' 8808' 9135' None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1490 470 Surface 4143' 13-3/8" 4143' 3832' 4930 2270 Intermediate 9252' 9-5/8" 9252' 8325 6870 4760 Production Liner 732' 7" 9088'-9820' 8186'-8808' 7240 5410 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): None None Packers and SSSV Type: None Packers and SSSV None MD(ft)and ND(ft): 12. Attachments: 13.Well Class after proposed work: . _: Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program ElExploratory 0 Stratigraphic ®Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation April 5,2015 0 Oil 0 WINJ ❑WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG ®Suspended• 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ryan Ciolkosz,564-5977 Printed Name: Ken Allen Title: Engineering Team Leader Email: Ryan.Ciolkosz@bp.com Signature: _ tom' Phone: 564-4366 Date: Ly2/,s-, �� Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 2' � /,y Sundry Number: J r "( ❑ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: S"!1 b,tS L�rvi iv i v Li o f' Cued r2,p C,k--qt 7Vo yr 5 e-c I.-1 d hi 5 • .0 c/4¢'C l ' !-1 1.-5-5- op e k e /1v vz.5 Gi 1i t /-C 5 r d>' kc i t h i 4t, al q dy 1 Re5uvt,z -e oID ri,-•,t 1-1ovi5 tAxi f-1- IO - 4o 3 0 ,- ni-t,p,Tj),(2c .4-19-C2 o7_Z(b)). Spacing Exception Required? ❑Yes Lit No Subsequent Form Required: if.b _ 104_ APPROVED BY ((//--/7 Approved By: COMMISSIONER THE COMMISSION Date: T X1 Form 10-403 Revised 1 /2012 Approved application is ado h f th date of approval/04 /7`/ Submit In Duplicate RBDMS-•�k APR 1 8 � ¢eg1J� RI IN M L ,,�� y/-� z4 ,S-. • s 0 bp GPfffjpjyg jjz6p L3-03 Sundry Application Well Type: Lisburne Producer Current Status: Cemented 7" Liner set at Top of Reservoir. Bridge plug set and kill string installed Request: Approval is requested to shutdown drilling operation on the L3-03 well until after drilling and competing L3-10. After setting and cementing the 7" liner, Parker 272 will secure L3-03 with a bridge plug, kill string and two master valves and move over to L3-10. Once L3-10 is completed, Parker 272 will move back to L3-03 and complete the well as per the L3-03 Permit to Drill 215-018. . Variance Request Because operations on L3-03 are planned to be resumed within 60 days after operation shutdown, it is requested that the requirements of 20 AAC 25.072 (b) and not file a complete well record on a Form 10- 404 until L3-03 is completed as per the original permit to drill. Approximate Date to Resume Operation on L3-03 May 16th, 2015 After completion of L3-10 Reason for Suspension Waiting on Delivery of completion equipment for 4-1/2" liner. Due to increase in manufacturing time, all the required completion equipment for L3-03 will not be delivered to the North Slope before the rig is ready to run the 4-1/2" liner. Proposed Procedure: 1. Run 7", 26ppf, L-80, Vamtop HC liner with 150ft lap in the 9-%" casing shoe 2. Cement to the TOL with 15.8 ppg Class G cement 3. Set the liner hanger and packer. 4. Circulate cement off the top of the liner. 5. Test BOPE 6. PU Cleanout BHA and drill out 7' shoe track 7. Run cement bond log from TD to surface 8. Pick up bridge plug and set in the 7" liner between the bottom of the Ivishak and top of the Lisburne. Pressure test 7" liner and CIBP to 4000 psi 9. Swap well to 8.5 ppg seawater 10. Run 4-1/2" 12.6#TCII tubing to 3000' MD. Freeze protect well to 2000' TVD 11. ND BOPE. NU and test the Double master valves to 5,000 psi 12. RDMO. Drilling Engineer: Ryan Ciolkosz (907) 564-5977 • 0 L3-03 Shutdown Proposal Lisburne ':F 128' 20'Conductor ke i* '+i 4-1/2"Tubing,12.6#,TCII,ID=3.958" 3000' ,: 041 tt:„" . 13-3/8"CSG,68#,L-80 BTC,ID=12.415 4143'MD 3840'ND P I 4650'MDI Targeted TOC^'500'MD above UG4 "4283'TVD 1. DPZ1 ` ' DPZ1 TSV1 4866'M D/4476'TVD ` TSV1 4866'MD/4476'ND BWS 7504'MD/6802'TVD . BWS 7504'MD/6802'ND r . '"9088'MD 9-%"x7"BKR ZXP PKR&HMC 9-'/"CSG,47#,L-80 TCII,ID=8.681" 9252'MD , —8186'TVD HGR ID=4.4" 8330'TVD 0 DPZ 3-Ivishak DPZ 3-Ivishak TOP 9286'MD/8354'ND TOP 9286'MD/8354'TVD BOTTOM 9632'MD/8649'ND BOTTOM 9632'MD/8649'TVD x 7"LNR 26#,L-80 VTHC,ID=6.276" 9820'MD ,' J 9735'MDI 7"CIBP 8808'ND � �e s y "'8736'ND DPZ 4-Lisburne 9819'MD/8808'TVD •�Pv oF�Ty� THESTATE �w��\\�I//i�,, Alaska Oil and. Gas � O Conservation G®rn�nissi®211. _�� Of LASS<:A - 'r- - 333 West Seventh Avenue .V-�"‘- �� Anchorage, Alaska 99501-3572 ;Th,> I GOVERNOR BILL WALKER g to- Main: 907.279.1433 oF -ALAS'" Fax: 907.276.7542 www.aogcc.alaska.gov Ken Allen Engineering Team Leader BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L3-03 BP Exploration(Alaska), Inc. Permit No: 215-018 Surface Location: 346' FNL, 561' FWL, Sec. 22, T11N, R15E, UM Bottomhole Location: 1247' FSL, 747' FEL, Sec. 09, T11N, R15E, UM Dear Mr. Allen: Enclosed is the approved application for permit to 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, Cathy . Foerster Chair DATED this i-71.--- DATED of February, 2015. Pi'ECEIVED STATE OF ALASKA ifr ALA OIL AND GAS CONSERVATION COM11f ON JAN 2 2 2015 PERMIT TO DRILL 20 AAC 25.005 AOGCC 1 a.Type of work: 1 b.Proposed Well Class: ®Development Oil 0 Service-Winj ®Single Zone • 1 c.Specify if well is proposed for: 0 Drill . 0 Lateral 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates 0 Redrill 0 Reentry 0 Exploratory 0 Service-WAG 0 Service-Disp ❑Geothermal 0 Shale Gas 2.Operator Name: 5. Bond • 0 Blanket 0 Single Well 11.Well Name and Number: BP Exploration (Alaska) Inc. Bond No 6194193 • PBU L3-03 • V 3. Address 6.Proposed Depth: 12.Field/Pool(s) P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 12982' • ND 8809'• Prudhoe Bay/Lisburne 4a.Location of Well(Governmental Section): 7.Property Designation(Lease Number): .✓" Surface: ADL 028322&034631 346'FNL, 561'FWL, Sec.22,T11N, R15E, UM / Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3611'FSL, 5072' FEL, Sec.09,T11N, R15E, UM March 1,2015 Total Depth Z'" 9.Acres in Property: 14.Distance to Nearest Property: 1247'FSL, 747' FEL, Sec.09,T11N, R15E, UM 2560 30000' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 68.6' • feet 15.Distance to Nearest Well Open Surface: x 707811 • y-5961949 • Zone- ASP4 GL Elevation above MSL: 21.5' • feet to Same Pool: 2200' 16.Deviated Wells: Kickoff Depth: 700' feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 97 degrees Downhole: 4420 • Surface: 3561 • 18. Casing Program Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 30" 20" 91.5# H-40 80' Surface Surface 80' 80' 1800#Poleset(Approx.) 16" 13-3/8" 68# L-80 BTC 4262' Surface Surface 4262' 3969' ,2649 sx DeepCrete,312 sx Class'G' 12-1/4" 9-5/8" 47# L-80 TCII 9203' Surface Surface 9203' 8299' 797 sx LiteCrete,408 sx Class'G' 8-1/2" 7" 26# L-80 VamTop HC 759' 9053' 8170' 9812' 8819' 145 sx Class'G' 6-1/8" 4-1/2" 13.5# 13Cr85 Hydril 521 3319' 9663' 8692' 12982' 8809' Uncemented Sliding Sleeves w/Swell Packers 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20.Attachments: 0 Property Plat 0 BOP Sketch 0 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct: Contact Troy Jakabosky,564-4868 Printed Name Ken Allen Title Engineering Team Leader Email TroyJakabosky@bp.com Signature ;,,,,1.:. •�^�._ _ _ Phone 564-4366 Dateil ..."2,.//' ' /cc' Commission Use Only Permit To Drill „ ,` - API Number: i — — ....Permit Apprr I pa te: , 5 See cover letter for Number: .0 V I 50-02/'Z 35 5 ' � ! other 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 lir Other:06,p-tC5t to 4600 5 contained shales: Samples Req'd: 0 Yes 12/No Mud Log Req'd: ❑yes L+1 E-No 4✓1"t.,/aG,---p r-t!/«f"rf f e',5/- h) 25;00/95142S Measures: [>'Yes ❑l No Directional Survey Req'd: I2 Yes 0 No Flow p a el d J c wct s'✓ed fo r Spacing exception req'd: 0 Yes L•g No inclination-only svy Req'd: ❑Yes IZNo ±/UD0 /id Cr ),o AA-c. Z5-,D1'3 0) OAPPROVED BY i APPROVED BY /2 • COMMISSIONER THE COMMISSION Date 2 -/7 —/.s Form 10-401 Revised 10/20 2 T ®• ~ i i#�rpIN2Aths from the date of approval(20 25.005 g)) Submit Form and Attachments In Duplicate VIZ_ z//v//5- �J � ,0 „seb /,z-7, ( bp • • To: Alaska Oil &Gas Conservation Commission From: Troy Jakabosky, ODE Date: January 22, 2015 Re: L3-03 Permit to Drill The planned L3-03 well is currently scheduled to be drilled by Parker 272 in March 1, 2015. The rotary well is a grassroots Lisburne producer. The intermediate hole is planned as a casing with the shoe set in the top of the Sag River Formation. An 8.75" hole will be drilled to top Lisburne and a 7" Liner will be ran to top Lisburne. The production interval will be completed with a cementless liner. The well will be fracture stimulated post rig. The maximum anticipated surface pressure from the Ivishak with a full column of gas from TD to ' (Lc surface is-3,561 psi (assumes 9.9 ppg as max pore pressure and 0.1 psi/ft gas gradient). The maximum anticipated surface pressure from the Lisburne with a full column of gas from TD n'411*(- • to surface is-2,174 psi (assumes 6.72 ppg as max pore pressure and 0.1 psi/ft gas gradient). ) This well will be drilled by Parker 272 using their 5,000 psi four preventer BOP stack(3 rams and / an annular). The BOP rams will be tested to 4,000 psi and the annular will be tested to 3,500 psi. A detailed operations summary is included with the permit application. Below is a brief summary of planned drilling operations: 1. Move in Parker 272 and function test diverter. 2. Drill 16" surface hole to -4262 ft MD. 3. Run 13-3/8" surface casing and cement to surface. 4. Nipple up BOPE and test to 4000 psi. 5. Pressure test surface casing to 3500 psi. Drill out the shoe and perform Lar 6. Drill 12-1/4" intermediate hole to top of the Ivishak at 9,203 ft MD. 7. Run 9-5/8" casing and cement to-9,203 ft MD. 8. Pressure test casing to 4000 psi. Drill out of intermediate shoe and perform' J 9. Drill 8.5" hole to top of the Lisburne to TD at-9,812 ft MD. i�31 i 10. Run 7"casing and cement to 200 ft above TOL(TOC at-8,853 ft MD). 11. Pressure test casing to 4000 psi. Drill out of intermediate shoe and perform FIT. 12. Drill 6-1/8" horizontal production hole through Lisburne to TD at-12,982 ft MD. 13. Run a 4-1/2", solid cementless swell packer liner. 14. Pressure test liner top packer to 4000 psi. 15. Run 4-1/2" chrome completion tubing. Sting into liner tieback sleeve and set production packer. 16. Pressure test the tubing and the inner annulus to 4000 psi each. 17. Rig down and move off the well. In addition to a planned well summary, a directional plan and proposed completion diagram is attached to the permit application. If there are any questions concerning information on L3-03, please do not hesitate to use the contact information below. Troy Jakabosky. Office: 907 564-4868 Cell: 907 632-2609 Email: troy.jakaboskyabp.com Attachments: L3-03 Wellbore Schematic Directional Plan As-Built Survey BOPE Equipment/Diverter Schematics Well Head Schematic Tree Schematic L3-03 PTD Page 1 1/22/2015 • S Planned Well Summary Well L3-03 • Well Producer Target Lisburne. Type Objective Current Status L3-03 . , Estimated Start Date: 3/1/2015 Time to Complete: 47.1 Days Surface Northing Easting Offsets TRS Location 5961949.12• 707810.65 346.3' FWL 561.4' 11N 15E sec 22 . Northing Easting TVDss Offsets TRS Tgt 1 5965491.00 707436.00 -8,062' 292.08 FNL /2075.0 10N 15E Sec THRZ FWL 15 Tgt 2 1668.5' FNL /208.1' 11N 15E Sec 5965895.00 707340.00 -8,750' TLSB FWL 15 Tgt 3 5966466.00 707207.00 -9,030' 1094.0 FNL / 92.1' 11N 15E Sec FWL 15 BHL 5968783.50 706298.19 -8,740' 4032.3' FWD 4532.2 11N 15E Sec 9 • Planned KOP: 700 . Planned TD: 12,982' MD / 8,740' TVDss • Rig: Parker 272 GL-RT: 46.95 RTE (ref MSL): 68.6 Directional - Baker P9 KOP: 700 Maximum Hole Angle: -31.2° in the intermediate section 96.7 in the 6-1/8" production section Close Approach Wells: None Survey Program: Surface to 500' MD = GYRO 500 MD to TD = MWD+IFR+MS • Nearest Property Line: 30,000' Nearest Well within 2200' Pool: L3-03 PTD Page 2 1/22/2015 0 0 , Formation Tops & Pore Pressure Estimate (SOR) 7/,0's n Estimated Minimum Most Likely fe.4 &.i„ Formation Formation Top Pore Pressure Pore Pressure (TVDss) (EMW ppg) (EMW ppg) Carte G1 520 8.35 8.40 $'S SV6 2,460 8.35 8.40 SV5 3,243 8.35 8.40 EOCU 3,231 8.35 8.40 SV4 3,394 8.35 8.40 qW SV3 3,811 8.35 8.40 /0'y SV2 4,015 8.35 8.40 9 3 SV1 4,407 8.35 8.40 ,lj UG4 4,940 8.35 9.50 p `27, S UG4A 4,930 8.35 9.50 UG3 5,160 8.35 9.50 UG1 5,800 8.35 9.50 UG_MA 6,120 8.35 9.50 , UG MB1 6,170 8.35 9.50 UG_MB2 6,225 8.35 9.50 /1,0--C) UG_MC 6,310 8.35 9.50 "k WS2 6,370 8.48 • 9.30 • WS1 6,530 8.48 9.30 /C,?,3 r CM3 6,760 9.70 , 10.00 /4'=.3 CM2 7,230 9.70 10.00 CM1 7,675 9.70 10.00 Y THRZ 8,060 9.60 10.20 • /0 LCU 8,230 7.14 7.72 ,1 TSAD 8,230 ✓ 7.14 7.72 40 BCGL 8,300 7.19 7.72 /0, Z. 14N 8,440 - 7.19 8.01 ,/ /C's.,Z. TDF 8,520 7.19 7.96 • it TKVK/BSAD 8,585 9.80 • 9.90 /2",r.. - TLSB 8,751 5.77 • 6.69 ',S---->t?.d • / r d, . Casing/Tubing Program Hole Liner/ Wt/Ft Grade Conn Length Top Bottom Size Tbg O.D. MD/TVDss MD/TVDss 16" 13-3/8" 68# L-80 BTC 4262' Surface 4262/3899 12-1/4" 9-5/8" 47# L-80 TCII 9203' Surface 9203/8229 8-1/2" 7" 26# L-80 VamTop HC 759' 9053/8101 9,812'/8,750' 6-1/8" 4 'h" 13.5# 13Cr-80 Hydril 521 3,319' 9 663/8,623' 12,982/8,740' (-150' lap) Tubing 4 '/2" 12.6# 13Cr-85 VT 9,658' Surface 9,658/8,619 (-5' into liner TBS) L3-03 PTD Page 3 1/22/2015 • Mud Program Surface Mud Properties: Spud Mud 16" hole section Depth Interval Density PV YP API FL LSR-YP pH (ppg) (cp) (Ib/100ft2) (2x3-6)rpm Surface -4262 8.5—9.4 6-20 10 -20 <10 25-60 8 - 10 Intermediate 1 Mud Properties: LSND 12-1/4" hole section Depth Interval Density PV YP API FL HTHP FL MBT pH (PP9) 4262 MD—6,871 MD 9.3 -9.8 - <17 18 -25 <8 NA <18 9 - 10 6,871 MD-7,314 MD 10.0- 10.3- <17 18 -24 <8 NA <20 9 - 10 7,314 MD-9,203 MD 10.3 - 10.4. <20 18 -24 <4 <10 <20 9 - 10 Intermediate 2 Mud Properties: LSND 8-1/2" hole section Depth Interval Density Pp) YP API FL HTHP FL MBT pH (cp) (Ib/100ft2) 9,203 MD-9,418 MD 8.9- 10.2 <22 18 -24 <10 <10 <4 8 - 10 9,418 MD-9,812 MD 10.2- 10.3 <22 18 -24 <10 <10 <4 8 - 10 Production Mud Properties: Water Based Polymer Fluid (FloPro) 6-1/8" hole section Depth Interval Density Pp) ( YP API FL HTHP FL MBT pH (cp) Ib/100ft2) 9,812' MD -TD 8.5-9.0 - <12 10 -20 <10 NA <4 9-9.5 Logging Program 16" Surface: Drilling: Dir/GR Open Hole: None Cased Hole: None 12-1/4" Intermediate 1: Sample Catchers—as required by Geology Drilling: Dir/GR/GR at bit/Res - Open Hole: None Cased Hole: None 8-1/2" Intermediate 2: Sample Catchers—as required by Geology Drilling: DIR/GR/GR at bit/Res - Open Hole: None Cased Hole: None 6-'/8" Production: Sample Catchers—as required by Geology Drilling: GR/Res/Neu/Den/Pef/Image/Spectral GR Open Hole: None Cased Hole: None L3-03 PTD Page 4 1/22/2015 0 0 Cement Program Casing Size 13-3/8" 68#, L-80 BTC, Surface Casing Lead: Open hole volume + >350%excess in permafrost and 40% excess Basis: Lead TOC: Target Surface Tail: Open hole volume+ 40% excess + 80 ft shoe track Tail TOC: 500 ft MD above casing shoe Total Cement Spacer -100 bbls of Viscosified Spacer weighted to -10.5 ppg (Mud Push II) Volume: Lead 905.7 bbls, 5085 cuft, 2649 sks of 11.0 ppg DeepCRETE, Yield: 1.92cuft/sk Tail 64.4 bbls, 362 cuft, 312 sks 15.8 lb/gal Class G- 1.16 cuft/sk Temp BHST 74° F Casing Size 9-5/8"47#, L-80 TCII, Intermediate Casing Lead: Open hole volume +40% excess Basis: Lead TOC: Target 500 MD above UG Tail: Open hole volume + 40% excess + 80 ft shoe track Tail TOC: 1000 ft MD above casing shoe Total Cement Spacer -100 bbls of Viscosified Spacer weighted to -11.0 ppg (Mud Push II) Volume: Lead 248.3 bbls, 1394 cuft, 797 sks of 11.5 ppg LiteCRETE, Yield: 1.75 cuft/sk Tail 84.2 bbls, 473 cuft, 408 sks 15.8 lb/gal Class G- 1.16 cuft/sk Temp BHST 140° F Casing Size 7" 26#, L-80 VAM TOP HC, Intermediate Liner Basis: Tail: Open hole volume +40% excess + 80 ft shoe track+150ft liner lap +200ft DP x Csg Total Cement Spacer -50 bbls of Viscosified Spacer weighted to -12.0 ppg (Mud Push II) Volume: Lead N/A Tail 30.2 bbls, 170 cuft, 145 sks 15.8 lb/gal Class G- 1.17 cuft/sk Temp BHST 151° F Casing Size 4-1/2" 13.5#, L-80 HYD 521 Production liner Basis: Sliding Sleeve/Swell Packer Cementless Completion Total Cement N/A N/A Volume: Lead N/A Tail N/A Temp N/A L3-03 PTD Page 5 1/22/2015 • • Surface and Anti-Collision Issues Surface Close Proximity: No wells will be affected by the Parker 272 rig shadow. Sub-Surface Pressure Management: Jurassic/Cretaceous: Check that injection rates have not changed prior to spud in the closest injection wells. The closest injection wells to LPC-01, LPC-02, GNI-02A, GNI-03, GNI-04 and the PWDW 1-2A wells. If injection rates in GNI wells increase significantly prior to spud, obtain a SBHP preferably in GNI- 02A, which is closest to the target area. Ivishak Interval: Get pressure estimate of area from FFM, in order to confirm/constrain PPFG prediction. Lisburne Interval: Get updated 2014 Lisburne pressure to confirm pressure estimate in area. (L3-05). Anti-Collision: None. Wp09 passes major risk criteria. Hydrogen Sulfide L3-Pad is considered an H2S site. Recent H2S data from the Pad is as follows: Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level L3-08 50 2/7/1994 #2 Closest SHL Well H2S Level L3-01 40 8/30/2009 #1 Closest BHL Well H2S Level 18-12C 0 1/5/2014 (Ivishak) #2 Closest BHL Well H2S Level L3-02(Lisburne) 35 7/3/2014 #3 Closest BHL Well H2S Level L3-05(Lisburne) 36 1/31/2009 #4 Closest BHL Well H2S Level L3-01 (Lisburne) 40 8/30/2009 Max Recorded H2S on Pad/Facility L3-28 120 4/16/1993 Faults Formation Where MD TVDss Throw Direction Uncertainty Lost Circ Encounter Fault Intersect Intersect and MagnitudePotential Fault#1 -HRZ 9,185.0 -8,085.0 down to the NNE(20 ft) 150 ft lateral low/medium (500 ft MD) Fault#2-Lisburne Wahoo 150 ft lateral top Z5 near Zone 6/Zone 5 10,312.0 -8,977.0 down to the NNE(20 ft) (500 ft MD) medium boundary Fault#3-Lisburne Wahoo down to the S or SSW 150 ft lateral Mid Zone 5 11,073.0 8,981.0 (20 ft) (400 ft MD) medium Fault#4-Lisburne Wahoo 11,726.0 -8,907.0 down to the NNW(10 ft) 150 ft lateral small/medium Zone 6 (400 ft MD) Fault#5-Lisburne Wahoo 12,518.0 -8,815.0 down to the SSE(10 ft) 150 ft lateral small/medium upper Zone 6 (400 ft MD) Drilling Waste Disposal • There is no annular injection in this well. • • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for . injection. Haul Class I waste to DS-04 and/or Pad 3 for disposal/Contact the GPB Environmental Advisors (659-5893) f/guidance. L3-03 PTD Page 6 1/22/2015 • s Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi, except annular at 3500 psi. BOP tcst-frequency for L3-03 will be 7 days during the de-complete phase. Once the window milling- -begins, a full BOP test will occur every 14 days with a function test occurring every 7 days. Except in the event of a significant operational issues that may affect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Intermediate 1 Interval Maximum anticipated BHP 3,304psi at the TSAD at 8,230' TVDss (7.72ppg EMW) • Maximum surface pressure 2,481 psi (.10 psi/ft gas gradient to surface) 25 bbls with 11.4 ppg frac gradient Kick tolerance Assumes 7.72 ppg pore pressure in the TSAD + 0.5 ppg kick intensity and 10.3 ppg MW. Planned BOP test pressure Rams test to 4,000 psi/250 psi. Annular test to 3,500 psi/250 psi Integrity Test—12-1/4" hole LOT after drilling 20'-50' from middle of window 9-5/8" Casing Test 4000 psi surface pressure Intermediate 2 Interval Maximum anticipated BHP 3,049 psi at the TLSB at 8,751' TVDss (6.7ppg EMW) Maximum surface pressure 2,174 psi (.10 psi/ft gas gradient to surface) Infinite with >11.1 ppg frac gradient Kick tolerance Assumes 6.7 ppg pore pressure in the TLSB + 0.5 ppg kick intensity and 10.3 ppg MW. Planned BOP test pressure Rams test to 4,000 psi/250 psi. Annular test to 3,500 psi/250 psi 7" Liner Top Packer 4,000 psi surface pressure Integrity Test—8-1/2" hole > after drilling 20'-50' from middle of window 7" Casing Test / 4000 psi surface pressure Production Interval .a *' � c, 4k` - ( ' itojcit74014 41/141W Maximum anticipated BHP 3,049 psi at TLSB at 8,751' TVDss (6.7 ppg EMW) Maximum surface pressure 2,174 psi (.10 psi/ft gas gradient to surface) Infinite with >8.8 ppg frac gradient /.2.7-0 . Kick tolerance Assumes an 6.7 ppg max pore pressure in the TLSB + 0.5 ppg kick intensity and 8.5 ppg MW. Planned BOP test pressure Rams test to 4,000 psi/250 psi. Annular test to 3,500 psi/250 psi Integrity Test—6-1/8" hole FIT after drilling 20'-50' of new hole 4-1/2" Liner Top Packer 4,000 psi surface pressure Planned completion fluids 8.6 ppg Sea Water/2200 ft diesel to 2,200 ft TVD L3-03 PTD Page 7 1/22/2015 • L3-03 — Drill and Complete Operations Summary Current Condition & Well History: 1. This is a grassroots well. 2. 20" Conductor Currently installed with Landing Ring welded on Preliminary (Pre-Rig) Operations: 1. If necessary, level the pad and prepare location for rig move. 2. Shut-in nearby wells, bleed-off process lines, and remove well houses as necessary. 3. Confirm Cretaceous injection Pressures. If injection rates in GNI wells increase significantly prior to spud, obtain a SBHP preferably in GNI-02A, which is closest to the target area. 4. Get updated pressure estimate of Ivishak area from FFM. Get updated 2014 Lisburne pressure to confirm pressure estimate in area. (L3-05). Rig Operations: 1. MIRU Parker 272: a. Survey conductor with rig over it to ensure rig is centered over the hole. b. R/U diverter system and test. Notify AOGCC 24 hours in advance of test. 2. Drill 16" Surface Hole Section: a. Prepare enough 5" drill pipe to drill the surface hole. b. Make-up 16" directional drilling assembly with MWD/GR/UBHO tool string. c. Cleanout 20" conductor, spud well & directionally drill surface hole to the base of the permafrost. (Gyro until clean MWD surveys) d. At base permafrost circulate hole clean and condition mud as required prior to making wiper trip to the top of the HWDP. e. RIH &drill remainder of surface hole to planned casing point in the shale above the SV3. f. Circulate hole clean &condition mud as required prior to making wiper trip to base of permafrost. g. Trip back to TD, circulate hole clean and condition mud for running 13-3/8" casing. h. POOH and L/D BHA. 3. Run & Cement 13-3/8" Surface Casing: a. Run 13-3/8", 68 ppf, L-80, BTC surface casing with Volant tool. b. Cement with 15.8 ppg Class G tail cement& Non-freezing LiteCRETE cement to surface. c. R/D cementing equipment and flush and RD diverter system. . d. N/U FMC 13-5/8" 5M New Standard Big Bore wellhead system and test as required. e. N/U & pressure test 13-5/8" 5M BOPE (Configured from top to bottom: 13-3/8" Annular Preventer, 2-7/8" x 5-1/2" VBR rams in the upper cavity, Blind/Shear Rams, mud cross and 2-7/8" x 5-1/2" VBR in the lower cavity) ➢ Test rams to 250 psi/4,000 psi with 4" and 5" test joints ➢ Test annular to 250 psi /3,500 psi L3-03 PTD Page 8 1/22/2015 • 4. Drill 12-1/4" Intermediate#1 Hole Section: a. Prepare enough 5" drill pipe to drill the 12-1/4" 1st intermediate hole. b. Test 13-3/8" casing to 250 psi for 5 minutes / 3,500 psi for 30 minutes after cement reaches a minimum of 500 psi compressive strength. c. Make-up 12-1/4" drilling assembly with MWD/GR/RES/GAB tool string. d. RIH &tag float collar or TOC. Displace to 9.3 ppg LSND mud while drilling the shoe track. e. Drill at least 20 ft but no more than 50 ft of new formation for the LOT and CBU. f. Pull inside casing and perform the LOT. Minimum LOT required is 11.4 g. Drill ahead following the directional plan. Ensure mud weight is increased to 10.3 ppg at least 200 ft above the CM3, h. Continue drilling to the 9-%" intermediate casing point which is the HRZ/Ivishak interface. CBU as needed for cutting samples to properly identify Ivishak boundary. i. At casing point, circulate hole clean &condition the mud as needed prior to performing wiper trip. j. Run back to bottom, circulate hole clean and condition mud for running 9-5/8" casing. k. POOH and lay down the BHA. 5. Run &Cement 9-5/8" Intermediate Casing: a. Change upper VBR's to 9-5/8" casing rams and test to 250 psi/4,000 psi. b. Run 9-5/8", 47 ppf, L-80, TCII intermediate/production casing. c. Cement with 15.8 ppg Class G Tail and 11.5 Lite Crete cement to 500 ft above UG4 d. Pressure test casing to 4,000 psi for 30 minutes on plug bump. e. Install casing pack-off and test per FMC representative procedures/instructions. f. Confirm that OA is open by pumping small volumes of mud down annulus as soon as possible. g. R/D cementing equipment and flush stack. h. Freeze-protect the 13-3/8" x 9-5/8" annulus, once the cement has reached 500 psi compressive strength. . 6. Drill 8-1/2" Intermediate#2 Hole Section: a. Change upper 9-5/8" casing rams to VBR's to and test to 250 psi/4,000 psi. b. Pick-up additional 5" drill pipe as required to drill the 8-1/2" 2nd intermediate hole. c. Make-up 8-1/2" drilling assembly with MWD/GR/RES/GAB tool string. d. RIH &tag float collar or TOC. Displace to 9.0 ppg LSND mud while drilling the shoe track. e. Drill out shoe track &at least 20 ft but no more than 50 ft of new formation for the LOT and CBU. f. Pull inside casing and perform the LOT. Minimum LOT required is 11.1 g. Drill ahead according to the directional plan and gradually weight up to a minimum of 10.2 ppg before entering the Kavik. h. Continue drilling to the intermediate #2 casing point which is the Kavik/Lisburne interface. CBU as needed for cutting samples to properly identify Lisburne boundary. i. At casing point, circulate hole clean and condition the mud as needed prior to performing wiper trip to the shoe. j. Run back to bottom, circulate hole clean and condition mud for running the 7" liner. k. POOH and lay down the BHA. 7. Run & Cement 7" Intermediate Liner: a. Change upper VBR's to 7" casing rams and test to 250 psi/4,000 psi. L3-03 PTD Page 9 1/22/2015 • • b. Run 7", 26 ppf, L-80, VAM Top HC intermediate/production liner with 150 ft lap into the 9-5/8" casing shoe. c. Cement to the TOL with 15.8 ppg Class G cement. d. Set the liner hanger& liner top packer. LD Liner running tool. 8. Drill 6-1/8" Production Hole Section: a. Change 7" casing rams to 2-7/8"x5-1/2"VBR's and test to 250 psi/4,000 psi. b. Pick-up enough 4" drill pipe to drill the 6-1/8" production hole. c. Test 7" liner to 250 psi for 5 minutes /4,000 psi for 30 minutes after cement reaches a minimum of 500 psi compressive strength.. d. Perform a negative pressure test 7" liner(no flow test). e. Make-up 6-1/8" drilling assembly with MWD/GR/Res/Spectral GR/Density/Pef/Image/Neutron tool string. f. RIH &tag landing collar or TOC. Displace to 8.5 ppg Flo-Pro SF. g. Confirm no flow 7" liner lap. h. Drill shoe track and at least 20 ft but no more than 50 ft of new formation for the FIT and CBU. i. Pull inside casing and perform the FIT. Minimum FIT required is 8.8 j. Drill ahead, as bit performance allows, according to directional plan and rig site geologist to well TD. POOH to replace bit if required. k. At casing point, circulate hole clean and condition the mud as needed prior to performing wiper trip to the casing shoe. I. Run back to bottom, circulate hole clean and condition mud for running casing. m. POOH, L/D excess 4" drill pipe and the BHA. 9. Run & Cement 4-1/2" Production Liner: a. Run 4-1/2", 13.5 ppf, 13Cr80, Hydril 521 production liner with 150 ft lap into the 7" liner shoe. b. Drop WIV ball Set the liner hanger & liner top packer. Displace well to clean seawater above the liner top. c. Pressure test 9-5/8" casing x 7" liner x 4-1/2" liner to 4,000 psi for 30 minutes. d. POOH, L/D liner running tool (LRT). 10. Run 4-1/2" Completion: a. R/U and run a 4-1/2", 12.6 ppf, 13Cr80, VT completion with SLB sapphire gauge mandrel above the production packer and iWire to surface. Space out and land the tubing with the tubing tail inserted into the liner tie back sleeve. Run in lock down screws (RILDS). b. Displace well to seawater completion fluid through the IA, topping off the IA with corrosion inhibited seawater. c. Drop ball & rod assembly to RHC plug. d. Test tubing to 250 psi for 5 minutes and then set production packer with 4,000 psi. e. Hold 4,000 psi for 30 minutes for tubing pressure test. f. Bleed tubing pressure down to 2,500 psi. g. Pressure test IA to 250 psi for 5 minutes / 4,000 psi for 30 minutes. Bleed down Tubing to 0 psi and shear DCR. Pump both ways to confirm shear. h. Pump enough diesel freeze protect fluid into the IA to protect to 2,200 ft TVD on both tubing & IA. i. R/U jumper line between tubing & IA to allow diesel to U-tube into tubing. L3-03 PTD Page 10 1/22/2015 • i► 11. Nipple Down BOPE/Nipple Up Production Tree & Freeze Protect: a. Install TWC and test. Nipple down BOPE. b. N/U the tubing head adapter flange and production tree. c. Test tubing head adapter flange &tree to 250 psi for 5 minutes/5,000 psi d. Install VR plugs in the annulus valves as needed and secure the well. Ensure that both IA & OA are protected by two barriers. 12. Release Rig: a. Rig down and move off location. Post-Rig Operations: 1. MIRU slick line. Pull TWC. 2. Pull ball & rod/ RHC plug from landing nipple below production packer. 3. Negative pressure test 7" Liner Top 4. Acid Fracture Stimulation 5. Coil Cleanout 6. Set GLV 7. Flowback 8. Install the well house, instrumentation, and injection line. L3-03 PTD Page 11 1/22/2015 • L3-03 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures: / 614 I,&+iz,I-bin 3et.td,. /5-k, 6 A. Intermediate Hole: The UG4 is expected to be a 9.5 ppg EMW. The.CM2>i ; xpected to be a?:10.0 ppg EMW. Formation pressures will be controlled by weighting up to a 9.8 ppg MW before entering the UG4 (4,940 TVDss). Another weight up will occur prior to entering the CM3 (6,760 TVDss) by weighting up to a 10.3 ppg EMW. B. Production Hole: The Ivishak is expected to be at a 8.01 ppg EMW. Reservoir pressures will be controlled by using 8.9 — 9.2 ppg water based mud though the Ivishak. Another weight up will occur prior to entering the TKVK(8,585 TVDss) by weighting up to a 10.2 ppg EMW. II. Lost Circulation/Breathing A. Intermediate Hole: There is one expected fault crossings in the intermediate hole section. Be aware of drilling ECDs. B. Production Hole: There are 4 expected fault crossings in the production hole. Ill. Fault Locations Formation Where MD TVDss Throw Direction Uncertainty Lost Circ Encounter Fault Intersect Intersect and Magnitude Potential Fault#1 -HRZ 9,185.0 -8,085.0 down to the NNE(20 ft) 150 ft lateral low/medium (500 ft MD) Fault#2-Lisburne Wahoo 150 ft lateral top Z5 near Zone 6/Zone 5 10,312.0 -8,977.0 down to the NNE(20 ft) (500 ft MD) • medium boundary Fault#3-Lisburne Wahoo down to the S or SSW 150 ft lateral Mid Zone 5 11,073.0 -8,981.0 (20 ft) (400 ft MD) medium Fault#4-Lisburne Wahoo 11,726.0 -8,907.0 down to the NNW(10 ft) 150 ft lateral small/medium Zone 6 (400 ft MD) Fault#5 Lisburne Wahoo 12 518.0 -8,815.0 down to the SSE(10 ft) 150 ft lateral small/medium upper Zone 6 (400 ft MD) IV. Integrity Testing Test Point Test Depth Test type EMW(Ib/gal) 13-3/8" Shoe 20'-50' from the 13-3/8" shoe LOT 11.4 ppg 9-5/8" Shoe 20'-50' from the 9-5/8" shoe LOT 11.1 ppg 7" shoe 20'-50' from the 7" shoe FIT 8.8 ppg V. Hydrogen Sulfide A. L3-Pad is considered an H2S site. Recent H2S data from the Pad is as follows: Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level L3-08 50 2/7/1994 #2 Closest SHL Well H2S Level L3-01 40 8/30/2009 #1 Closest BHL Well H2S Level 18-12C 0 1/5/2014 (Ivishak) #2 Closest BHL Well H2S Level L3-02(Lisburne) 35 7/3/2014 #3 Closest BHL Well H2S Level L3-05(Lisburne) 36 1/31/2009 #4 Closest BHL Well H2S Level L3-01 (Lisburne) 40 8/30/2009 Max Recorded H2S on Pad/Facility L3-28 120 „. 4/16/1993 VI. Anti-Collision Issues ➢ None - CONSULT THE L3-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. L3-03 PTD Page 12 1/22/2015 i i PARKER 272 1 1 1 BOP STACK 1 RAM TYPE BOP: DUTCH LOCK DOWN FLANGE SHAFFER LXT DOUBLE BOP 13 5/8"-5M 13 5/8"-5M STUDDED TOP Qn In.. 13 5/8"-5M FLANGED BOTTOM =0 II= ANNULAR BOP: W/(2) 14" UL2 OPERATOR, UPPER CAVITY rr�� ���RRR AND (2) 14" PSLK W/BSTR OPERATOR, ��� SHAFFER LXT 13 5/8"-5M 13-5/ LOWER CAVITY 13-5/8" 5M STUDDED TOP 0 13-5/8" 5M FLANGED BOTTOM 0 ' I I DRILLING CROSS: l I 13 5/8"-5M FLANGED TOP F-1---.1], ,p I i4 13 5/8"-5M FLANGED BOTTOM » ,Q Q«•r W (2) 3 1/8"-5M SIDE OUTLETS IIII o �e f`�ep II 3U � U••" I II I I _ KILL LINE: —wow, .ritti����� r� ,� 2-1 16" 5M FLEX HOSE �v`���l .�1�• ' r �r l�`-1.I 1. .ice t � � 2-1/16" 5M X 3-1/8" 5M D.S.A. �� �1111111111M1 WI 1111 3-1/8" 5M FLANGED MANUAL GATE VALVE O 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE • • E .. . o �s ..= 3 — ■��` o o ■ I I CHOKE LINE: RAM TYPE BOP: 3-1/8" 5M FLANGED MANUAL GATE VALVE SHAFFER LXT SINGLE 13 5/8" 5M 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE 13 5/8" SM STUDDED TOP 3-1/8" 5M FLEX HOSE 13 5/8"- 5M FLANGED BOTTOM / w/(2) 14" UL2 OPERATOR L3-03 PTD Page 13 1/22/2015 TREE= WELLFE�AcTUATOR= I-03 Proposed I !II BF.ELEV= KaP= /I Max Angle= Datum MD= 20"Conductor--80' E tum1VD= ,. 2200'-4-1/2"HES X NIP, ID=3.813" GAS UFT MAr ELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 5 4300 4001 4 6900 6199 2.162"ball seat on 3 8300 7383 Minimum ID = 2 9129 8080 bottom frac sleeve 1 -12,800 3900 SSTVD(SV3) 13-3/8"CSG, 68#, L-80 BTC, ID= 12.415"-4262' -TOC 4,945 MD 9,053"-TOL -----: 9-5/8"CSG,47#, L-80 TCII, ID=8.835"-9203' CTop TSAD f ' H4-1/2"NDPG-C SAPPHRE GAUGE,D=3.813" I 9,508'-7"X 4-1/2"4-1/2" HES X NIP, ID=3.813" M 0 9,540'-7"X 4-1/2"TNT PKR 4-1/2"HES X NIP, ID=3.813"-9,571' I 9,643'-4-1/2" HES X NIP, ID=3.813" 4-1/2"TBG, 12.6#,13Cr-85 VAM Top, ID=3.958"-9,658' _� 9,663' 4-1/2"WLEG, ID=4" El 0 9,662'-7"X 5" LNR 7" Liner, 26#, L-80 Vam Top HC, ID=6.276"-9,812' ._,411 31° Inc-7" @ Top Wahoo ® I \ ►l 4 ►4 ►1 V4NQ ►1 d( ►1 IX thl 4-1/2" LNR, 13.5#,13Cr-80,HYD 521, ID=3.958"- 12,982' 1� 96° DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY MT 01/12/15 TDJ Update WBS 1NE-L: PERMIT No: API No: SEC NE'FNL'FWL '' BP Exploration(Alaska) g • 1 1 U ao illogi ki , , rn $ ClJJLJ 1§§• SCO O .. 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CO (1) U) U) U) U) U) (n U) U) U) I- 0 M OO r V 0) u) fD 0 CO N 1. 0 0) O u) 0 OD N- N- N- N O O I� OD N4 V O M 0- M 1 V CO u] CO N- N- 0 N N N M (h ('? vf u] M W w y) + � d C I t".5 0 0 0 O (D (D CO CO (D (D 0) I- 0 0) 75 O CO CO CO N ,- CO CO V 1 u O ui 0) co N (+i O M I- N V V OM (O OO CO N N CO (O (D N J U) e V NV N- CO 0) V u) CO Z w M M M M M V V O + 7 a m 11 0 N CO CO N 0 V M O 0 0 0 0) (0 V N V N. M CO (D (D (O O 0) m V O) u) 0) OD Cl) Cl L c O 0) T N N N. CO I. u) N O 0) O •tE 0)w D-- ,- OO V (O CO CO N CO 0 OO CD d 7 N I- I� CO CO CO CO 0) OD CO U 0) O 0 0 O 0 0 0 O 0 0 u) V E N MO o o >a> 1; •a 0 O 0 0 0 O 0 0 0 N CO u] Q ` M M > ` p O O O N C) u) 0) N N M N L 7 J 'J M 3 r C O O O O N CO CO 0) N CO r L C CO w o w f� 0) N u) V N- N V OD 'Cr u) CO O w w l6 (6 M R 0 3, n- N CO CO- CO- 01 O) O O N Z Z J J a a J I d w 2 co N C Oui a N -CDC O T iiCC .. 0 co o ol m _ w o c m v U a cn D a 1 e- N J • 0 by North America - ALASKA - BP Lisburne Lis DS 03 Plan L3-03 Plan L3-03 L3-03 WP09 Anticollision Summary Report 04 December, 2014 BAKER HUGHES • 0 10 BP 0 ()bp Anticollision Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan L3-03 Project Lisburne TVD Reference: L3-03 @ 68.60usft(Parker 272) Reference Site: Lis DS 03 MD Reference: L3-03 @ 68.60usft(Parker 272) Site Error: 0.00usft North Reference: True Reference Well: Plan L3-03 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan L3-03 Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: L3-03 WP09 Offset TVD Reference: Offset Datum Reference L3-03 WP09 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.O0usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,493.54usft Error Surface: Elliptical Conic Survey Tool Program Date 12/4/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 47.10 500.00 L3-03 WP09(Plan L3-03) GYD-GC-SS Gyrodata gyro single shots 500.00 2,000.00 L3-03 WP09(Plan L3-03) MWD MWD-Standard 500.00 4,263.00 L3-03 WP09(Plan L3-03) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 4,263.00 5,784.00 L3-03 WP09(Plan L3-03) MWD MWD-Standard 4,263.00 9,204.00 L3-03 WP09(Plan L3-03) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 9,204.00 9,800.00 L3-03 WP09(Plan L3-03) MWD MWD-Standard 9,204.00 9,800.00 L3-03 WP09(Plan L3-03) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal 9,800.00 11,300.00 L3-03 WP09(Plan L3-03) MWD MWD-Standard 9,800.00 12,982.54 L3-03 WP09(Plan L3-03) MWD+IFR+MS-WOCA MWD+IFR+Multi Station W/O Crustal I 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) East Dock(PSI) PSI-01-PSI-01-PSI 1 wp06 Out of range PSI-01-PSI-01-PSI-01 Out of range PSI-05-PSI-05-Plan#8 Out of range PSI-05-PSI-05-PSI-05 Out of range PSI-06-PSI-06-PSI 6 wp07 Out of range PSI-06-PSI-06-PSI-06 Out of range PSI-07-PSI-07-Plan#9 Out of range PSI-07-PSI-07-PSI-07 Out of range PSI-08-PSI-08-PSI-08 Out of range PSI-08-PSI-08-PSI-08 wp05 Out of range PSI-09-PSI-09-PSI-09 Out of range PSI-10-PSI-10-PSI-10 Out of range EX EBAYST-01 EBAYST-01-EBAYST-01-EBAYST-01 12,978.53 8,925.00 1,467.93 556.32 1,021.12 Pass-Major Risk Lis DS 03 L3-01-L3-01-L3-01 533.59 525.00 59.89 10.09 49.81 Pass-Major Risk L3 02 L3 02 L3 02 1,515.01 1,500.00 171.68 26.24 145.52 Pass-Major Risk L3-05-L3-05-L3-05 1,182.22 1,175.00 56.51 23.63 33.26 Pass-Major Risk L3-08-L3-08-L3-08 805.37 800.00 199.68 13.32 186.36 Pass-Major Risk L3-11-L3-11-L3-11 763.15 750.00 243.83 12.87 230.96 Pass-Major Risk L3-12-L3-12-L3-12 755.52 750.00 276.46 12.86 263.59 Pass-Major Risk Plan L3-10-Plan L3-10-L3-10 Plan 12 772.24 775.00 231.02 12.89 218.13 Pass-Major Risk 12/4/2014 10:35:26AM Page 2 of 3 COMPASS 5000.1 Build 61 81, • BP • Øbp Anticollision Report BAKER HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan L3-03 Project: Lisburne TVD Reference: L3-03 @ 68.60usft(Parker 272) Reference Site: Lis DS 03 MD Reference: L3-03 @ 68.60usft(Parker 272) Site Error: 0.00usft North Reference: True Reference Well: Plan L3-03 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore Plan L3-03 Database: EDM R5K-Alaska PROD-ANCP1 Reference Design: L3-03 WP09 Offset ND Reference: Offset Datum Reference Depths are relative to L3-03 @ 68.60usft(Parker 272) Coordinates are relative to:Plan L3-03 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04 Central Meridian is 150°0'0.00 W° Grid Convergence at Surface is:1.58° Ladder Plot 1600- -:_ , 'p - ,, 1 I I __Ii J J J J C I ! I I 1200- r e • t , I 1 9i`%4I II 1 I I 0 i 1 I i O NI. r0 1 1 �� • I I I 1 O - J �if J J I - (6 1 I (6 I I 0 I I I d I I01) I 1 800- /- 1--_- 1 4A. , r� I I Ni Apt f i 1 1 I 1 1 U , I 1 I I 1 1 0 I A i1 I I I I /;; • Loepp, Victoria T (DOA) From: Jakabosky, Troy <Troy.Jakabosky@bp.com> Sent: Thursday, February 12, 2015 4:00 PM To: Loepp, Victoria T (DOA) Subject: FW: Parker 272 Diverter Drawing Lisburne L3-03 Attachments: L3-03 Proposed Diverter.pptx Victoria—here is a different route for the diverter. If this is not acceptable,or you need some additions, please let me know? Additionally, can we get a variance request for the flow paddle. I will add this to the well program, if you approve? Variance Request To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line (<1000 ft). Procedures/Safeguards with paddle removed: • Fluid levels will be monitored in the pits for both gains and losses while drilling. Alarms will be set to indicate if gain or loss of more than 5 bbls has occurred. • The well will be monitored for flow when the pumps are off at each connection. • The planned 8.6 -9.1 ppg fluid will provide over balance to formation fluid. Thanks,Troy Troy Jakabosky Drilling Engineer bp 900E. Benson Blvd.Cube 748C Anchorage,AK 99508 Office 907.564.4868 Cell 907.632.2609 From: AK, D&C Rig 272 Well Site Leader Sent: Thursday, February 12, 2015 12:56 PM To: Sarber, Greg J; Jakabosky, Troy Subject: Parker 272 Diverter Drawing Greg,Troy, Take a look at this drawing and let me know what you think. 272 Rig Team Chris Weaver Parker 272 WSL 659-8379 1 • Enter/ Exit A EriterrE,c: • r„, CU 0 5 eNi • II C2I 'Pt?) ILI CN c .a N , 0 .5 CN1 : m u Ln " II r'42 cr's, • , c < 0 4., g .5 a), • -NJ 6 71 a • o a O I-4 147, NI 0J @.) • :OE. • 2:21 24 4',3 ft • • 446, - I WELL PRODUCER 111 or 0 DATE 7/26/2013 WELL INJECTOR A BLAST ZONE • SCALE: 1-= 225' .7'E_I - -7=- WELL SLOT WIC ONDUCTOR MAP DATE:2012 . ‘ 0 • e )e . Enter/ \--, ( L-13 / \ N, . Exit • r/ \ <\ ,....Q.,,,„ , ,... %. .., 1 & Alk\ tklkk r! -, % I ...\ N. e ‘ \ i Y"`Dc17' '., \ ., N X • _ CP'' ...''''.. \ _,..--- . , _ A , '- .. --._ Enter/Exit --__-- 1 --,' I .,....;,\ 2 section o -; 272 Dive :rtef ',,./ ..,,- , , — -,---..-7,-- 2 • (— _.------ ''..\\ : _} ----,..._ Diverter outlet ''' •5 line will point out 8 • below elevation of flow lines. =i joint I , 1 .—___----/ „ , . i2 • \ , : I . . \ , it , r r 4 y8 .• 79 ,.„ , 7t-' ,. . , _ . r.._,- i • r. Gra, vel 24 Removed ' 0 . Tundra .,......-.., ' .' C> ‘..0 -1-30 • ,i''. ..., 0 Gravel Removed from ... Tundra -'11-150' 446 1 --4--- ' pp, . _ _ _ .. __ 1 __ i I ) WELL PRODUCER •cr 0 WELL INJECTOR A DATE: 1 C.,Da2G 1 3 S.C.4"_E : -` = MO• MAP DATE :23 2 PBU -DSL3 WELL SLOT WC OND UC TOR El 0:04405.w:1 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: (514' L -0--3 PTD: —2_,I '' )/R i/ Development Service _Exploratory _Stratigraphic Test _Non Conventional ., FIELD: 21_1_4,6 �'.n-t-r POOL: ' /LC✓"G' = / Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( 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 Spacing Exception conservation 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 Well Lo ,n also required for this well: gg g 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 4/2014 • • CI rao N o a ,• „ a to El? E co, M Q @ m ▪ ¢ U. y, m v, L' N, 0 N C 3, C, 4 4 n O CO �„ C, a . 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