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201-187
PTV aO) -187- • • Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Tuesday, March 20, 2018 8:46 AM To: Regg,James B (DOA) Cc: Brooks, Phoebe L(DOA) Subject: RE: Nabors CDR2 3/17/18 BOPE Test Jim, The incorrect sundry is referenced on this BOP test report. Sundry 317-428(PTD 201-187)was for a packer squeeze prior to CTD and did not involve rig work/BOP so a test BOP pressure was not included on the Sundry. The correct PTD for this BOP test is for PBU L-118L1(PTD 217-006)which is a lateral currently being drilled. The BOP test pressure listed on this PTD is 3500 psig. Note this was not a plug for redrill. Let me know if there are any more questions. Thanx, Victoria From: Regg,James B(DOA) SCANNED Sent: Monday, March 19,2018 2:42 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Brooks, Phoebe L(DOA)<phoebe.brooks@alaska.gov> Subject: FW: Nabors CDR2 3/17/18 BOPE Test Received the attached BOPE test PBU L-118 using Nabors CDR2AC. Referenced Sundry 317-428 is for packer squeeze prior to CTD redrill—the MSPS is not reported in the Sundry. Can you confirm the MSPS shown on their test report? Jim Regg Supervisor, Inspections AOGCC 333 W.7t"Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Barr, Kevin<Kevin.Barr@nabors.com> Sent:Saturday, March 17,2018 3:17 PM To: DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov>; Regg,James B(DOA)<iim.regg@alaska.gov>; Brooks, Phoebe L(DOA)<phoebe.brooks@alaska.gov> Cc: Henson,James<Jim.Henson@nabors.com>;darci.horner@bp.com;AKGWORigNaborsCDR201(a)bp.com;Corder, Gary<Gary.Corder@nabors.com>;Stout,Wayne<Wayne.Stout@nabors.com>; Barr, Kevin<Kevin.Barr@nabors.com>; Bordelon,Toby<Toby.Bordelon@nabors.com> Subject: Nabors CDR2 3/17/18 BOPE Test 1 • • Kevin Barr Tool Pusher Nabors Alaska Drilling Rig CDR-2 Direct(907)685-4884 Cell(907)602-0767 kevin.barr@nabors.com NABORS EMAIL NOTICE-This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender(only)and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. 2 STATE OF ALASKA "'REPORT OIL AND GAS CONSERVATION COMMIS, REPORT OF SUNDRY WELL OPERATIONS JAN 18 2018 1. Operations Performed Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 OperationA ar GG 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved •rogram 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other Packer Cement Squeeze I21 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 201-187 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23043-00-00 7. Property Designation(Lease Number): ADL 028239 8. Well Name and Number PBU L-118 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,BOREALIS OIL 11.Present Well Condition Summary: Total Depth: measured 8980 feet Plugs measured None feet true vertical 6753 feet Junk measured 8836,8851 feet Effective Depth: measured 8904 feet Packer measured feet true vertical 6678 feet Packer true vertical feet Casing: Length: Size: MD: ND: Burst Collapse: Structural Conductor 78 20" 31-109 31-109 1490 470 Surface 3265 7-5/8" 30-3295 30-2622 6890/8180 4790/5120 Intermediate Production 8942 5-1/2"x 3-1/2" 27-8969 27-6743 7000/10160 4990/10530 Liner Perforation Depth: Measured depth: 8726-8776 feet feet True vertical depth: 6502-6552 feet feet scANNED JAN 3 1 '' 8 Tubing(size,grade,measured and true vertical depth) 3-1/2"9.2#L-80 25-8481 25-6262 Packers and SSSV(type,measured and true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 800 0 Subsequent to operation: 0 0 0 0 1750 14.Attachments:(required per 20 AAC 25.070.25.071,&25283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory 0 Development a Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil (! Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 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: 317-428 Authorized Name: Lastufka,Joseph N Contact Name: Tempel,Joshua Authorized Title: ,rmation n, Da- ontroller Contact Email: Joshua.Tempelabp.com Authorized Signature: Date: 1/I U/J Q Contact Phone: Form 10-404 Revised 04/2017 VT L. // 6,/jp t I, /gl, RPDNIS 7 J,_..1 2 2 7:18 Submit Original Only • • Daily Report of Well Operations ® L-118 ACTIVITYDATE SUMMARY CTU #8 - 1.75" Coil Objective: Ice Plug, log, tubing punch, packer squeeze, mill, drift MIRU CTU. MU Baker MHA with 2.25". Encountered obstruction at 3403'..Jetted with 70 bbls of 60/40 meoh while maintaining 1500 psi back pressure. Broke thru at 4200' md. Pooh. 12/29/2017 **Continued on 12/30/17** CTU #8 - 1.75" Coil Objective: Ice Plug, log, tubing punch, packer squeeze, mill, drift. MU HES GR/CCL logging tools w/2.70" JSN drift. Tagged TD at 8850' and logged up at 50 fpm to 8200'. Flag pipe at 8450'. Pooh. Tie in to SLB Perf Record dated 17-April-2003, (+ 0.5' correction) Set Baker 2.53" CBP 8529' ELM. Performed a passing CMIT Tx IA to 2500 psi. Circulated 150 bbls diesel and 65 bbls of KCL down the tubing thru the leak point at GLV mandrel#1 at 8361' up the Inner Annulus at 2 bpm at 2200 psi. MU cementing BHA w/2.0" BDJSN and RIH. 12/30/2017 **Continued on 12/31/17** CTU #8 - 1.75" Coil Objective: Ice Plug, log, tubing punch, packer squeeze, mill, drift. Tag CBP. Pick and park nozzle at 8527' (2' above plug). Let 1 bbl above nozzle & lay in bbls 15.8 Glass G cement up to 7284'. Puh to safety at 6788' and park. Circulate 6 bbls of cement into Inner Annulus. Drop 9/16" ball and pump powervis. Contaminate cement down to plug. Lay in clean gel from plug up to 7700'. Chase ooh at 80%w/ 1% Slick KCL. Jet jewelry on way ooh. Jet BOP's. Lay in 60/40 Freeze Protect from 500'. Stay on well and wait for cement to build 500 psi compressive strength. Performed a passing pressure test on IA. MU Baker milling bha w/2.80" 5-blade junk mill. Mill plug at 8529' and pushed to 8836', (50' below btm perf). Pooh. MU Baker 3-1/2"Whipstock Drift, (OD =2.63" OAL= 27.36') and Rih. Due to fish in hole drifted to 8831' (-19' short of TD)with no issues. Pooh. Freeze protect well with 60/40 down to 4500'. Start rigging down. 12/31/2017 **Continued on 01/01/18** CTU #8 - 1.75" Coil Objective: Ice Plug, log, tubing punch, packer squeeze, mill, drift. Rig down CTU and travel to slb yard for Planned Maintenance. 1/1/2018 **Job complete** T/I/O = 700/Vac/340. Temp = SI. MIT-IA PASSED to 2653 psi, Max applied = 2750 psi, Target pressure = 2500 psi. (post packer squeeze). IA FL near surface. Pumped 2.3 bbls of diesel to pressure IA from 0 psi to 2730 psi. IAP decreased 62 psi in 1st 15 min and 15 psi in 2nd 15 min for a total loss of 77 psi in 30 min. Bled IAP from 2653 psi to 0 psi in 15 min (2 bbls). Tags &AFE sign hung. Final WHPs = 700/0/340. 1/5/2018 SV, WV, SSV= C. MV= O. IA, OA= OTG. 12:00. Fluids Summary Bbls Type 221 Bbls 60/40 meoh 182 Bbls Diesel 11 Bbls Cement 352 Bbls 1% KCL 55 Bbls Fresh Water 55 Bbls PowerVis TREE= 3-1/8"511 CNV WELLHEAD= FMC • L-1 1 8 ikAFETY NOTES: ACTUATOR= BAKER C KB.ELEV= 76.9` BF.ELEV= 52.03' KOP= 300' Max Angle= Mr @ 3414' Datum MD= 8903' , 2574' —13-1/2"HES X NP,El=2.813" Datum TVD= 6600'SS 7-518"CSG,29.7#,L-80/S-95,D=6.875" 1 3295' -, GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATC1-! FORT DATE 4 4788 3502 51 KBG-2 DMY NT 0 09/13/16 3 6385 4496 51 KBG-2 DMY NT 0 09/13/16 2 7671 5486 23 KBG-2 0M' NT 0 09/13/16 Minimum ID =2.813" 2574' '1 8381 6166 14 KBG-2 'DMY NT 0 11/29/11 3-1/2" HES X NIPPLE `STA#1 =COVERED BY CEMENT EST TOC N IA(12/31/17) 1 7950' 8438' H 3-1/2"BKR CND SLD SLV,D=2.813" 3-1/2"TBG,9.2#,L-80,.0087 bpf,D=2.992" H 8462' 8462' BKR LOC SEAL ASSY,D=3.00" 5-1/2"CSG, 15.5#,L-80,D=4.950" — 8469' i 8469' --TOP OF BKR FBR,13=4.00" 5-1/2"X 3-1/2"CSG XO,D=3.000" —{ 8489' 8481' BTMOF 3-1/2"BKR SEAL ASSY,ID=3.00" 8508' H3-1/2"HES X NP,D=2.813" PERFORATION SUIMARY • REF LOG: SWS VISION D-N ON 03/29/03 J ANGLE AT TOP PERF: 100 @ 8726` 8559'-' —13-1/2"HES X NP,D=2.813" Note:Refer to Production DB for historical perf data 8554' —X NP B_ND LOGGED ON 11/17/03 SIZE SPF NTB2VAL Opn/Sqz DATE 2-1/2" 6 8726-8776 0 04/17/03 8694' —20`PUP JT W/RA TAG I8836'CTM .JFLSH:3-1/2"BKR CBP(12/31/17) 8851'CTMJ—FISH-3"X 3-1/2"BKR KB PKR RUBBER J ELEMENTS(09/20/16) PBTD —I 8871' I • ►44444..441 414.4 3-1/2"CSG,9.2#,L-80,D=2.992" —{ 8969' 04.446.4. DATE REV BY C OMMBJTS DATE REV BY COMETS BOREAUS UJT 04/01103 DAC/KK ORIGINAL COMPLETION 07/16112 PJC TREE C/0(07/09/12) WELL: L-118 12/16/11 WEC/PJC SET XX PLUG(09/16/11) 09/20/16 GJB/JM) GLV C/O(09/13/16) FERMI No:"2011870 05/16/12 LEC/J6,13 XX PLUG PULLS)(05/03/12) 09/20/16 JC F/JM3 PULL TBG PATCH/SET FISH(09/20/16) AR No: 50-029-23043-00 06/05/12 TTR/JMD SET 3-1/2"TBG PATCH(06/02/12 01/03/18 JTMIJMD PKR SOZ&SET FISH(12/31/17) SEC 34,T12N,R11E,2551'FSL&3773'FEL 06/17/12 PJC DRAWING CORRECTIONS 06/18/12 TJWJMD GLV C/O&SET FISH(06/13-14/12) BP Exploration(Alaska) y OF 7,4, • • THE STATE Alaska Oil and Gas of® LAsKA Conservation Commission 333 West Seventh Avenue { GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS ` Fax: 907.276.7542 www.aogcc.alaska.gov Joshua Tempel Integrity Engineer SSE® SEP 2 52017, BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, PBU L-118 Permit to Drill Number: 201-187 Sundry Number: 317-428 Dear Mr. Tempel: 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, Hollis S. French Chair 41 DATED this I day of September, 2017. RSDEVBS v Sur 1 9 2017 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMM N APPLICATION FOR SUNDRY APPROV S 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well 0• Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change A proved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Packerqueeze I I • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number:: 201-187 Ed 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 6. API Number: 50-029-23043-00-00 - 99519-6612 Stratigraphic 0 Service 0 A 7. If perforating: 8. Well Name and Numb E j V-E I V E D What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ® PBU L-118 • 9. Property Designation(Lease Number): 10. Field/Pools: SP Q 8 2017 ADL 028239 ' PRUDHOE BAY,BOREALIS OIL „�,, g A �� �/ 11. PRESENT WELL CONDITION SUMMARY (�](�,w' Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 8980 ' 6753 • 8904 6678 None 8851 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 31-109 31-109 1490 470 Surface 3265 7-5/8" 30-3295 30-2622 6890/8180 4790/5120 Intermediate Production 8942 5-1/2"x 3-1/2" 27-8969 27-6743 7000/10160 4990/10530 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8726-8776 6502-6552 3-1/2"9.2# L-80 25-8481 Packers and SSSV Type: No Packer Packers and SSSV MD(ft)and ND(ft): No Packer No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary I21 Wellbore Schematic [JJ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development ® . Service 0 14.Estimated Date for Commencing Operations: September 25,2017 15. Well Status after proposed work: Oil lI • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Tempel,Joshua be deviated from without prior written approval. - Contact Email: Joshua.Tempel@bp.com Authorized Name: Tempel,Joshua Contact Phone: Authorized Title: Integrity Enginee Authorized Signature: Date: el/go COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 3 I7- it2s' Other: Post Initial Injection MIT Req'd? Yes❑ No / Spacing Exception Required? Yes❑ No 12 Subsequent Form Required: ID- 401- da2q---\______ APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Dater I Iy 1-1 vrt-- 1//2/1 y- ORIGINAL RBDMS t/CiSrsi 192017 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in 9 pl cite • • fes. L-118 Packer Squeeze Well Interventions Engineer: Josh Tempel (907) 891-5930 Pad Engineer: Eric Zoesch (907) 564-4695 Expected Start Date: 09/25/2017 History L-118 was drilled and completed in 2003. The completion is a cemented and perforated 3-1/2" liner targeting the Kuparuk C sands of the Borealis structure. The well was produced until 2011 when a leak was found in the tubing near the tubing packer. A patch was installed over the leak in 2012 and the well continued to produce until 2016 when it was shut in due to an uncompetitive GoR. The patch was removed in 2016 in preparation for a CTD sidetrack. Current Status The well is currently shut in classified as "Not Operable" by BP due to the packer leak. Objective The objective of this job is to perform a packer squeeze to repair the leak. Procedural steps Eline 1. Set CBP near the production packer. Tubing punch just above production packer. Coiled Tubing 2. Pump packer squeeze with -6 bbls Class G cement. Mill out Cement/CBP after cement reaches -500 psi compressive strength. TOC in IA after packer squeeze expected to be -7,950' MD. Cement Type/weight: Class G 15.8 ppg batch mixed. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 6 hours Activity Time(hours) • • Shearing time, quality control, PJSM 1 Cement displacement 2 Cement contamination 2 Safety Minimum required thickening time: 6 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 120 3000 2:00 130 3000 3:00 140 3000 4:00 150 3000 7:00 150 3000 15:00 150 3000 DHD 3. MITIA to 2500 psi. 2 • • - 5 L-118 Current V- zia.W, ; 5z.DT s.« = 3C33, 344433. 5e.q 34141 0 WO ', :I- 0 Je itilP V=2913" 7-3 ,29,It L- !'a- r, t=6 316 ., , � s ST 10 1 TYRE YiN I IAJ 1 '/ DXTE - t Minknum 83 =2.813"itt257 ' 4 47 rr Fe 9 3-112"' HES X NIPPLE 3 51 f. r Es& 141 0 i 3116 �, .,... ,_.. _ ,.... 2 2 1 1, L4;' 11611 141 0 I 3 1 I14 . law I a 1 1;;x°';1 13.431'" 3- 6 ,10- 3' VT TM.9.1,L- ,.7#moi`,U-2. ' I 5-1J7 X 3,51/2"CSG X0,D-1.00211111=11 " a -OF 3-9? t o, -1.AW PDIFUI 4TIQl15'tlt4 4.187 REF LOG. $WS VISION OM ON iw AM-4.FAT 10 @: j3- 3 , ' •Rofor to Rx$41KtiOrt OR for heric44 .Sqz (*TE 2 4 8126-ert6 3 a 14411txrsy I IMII r x 3-vr M �... .,, H #lIM#1 3-10 rte.921,L-80,ID..z +!6*4 CATE FEY BY CO1A4134155 DATE 551 1401143 . !.ecomPtEnot4 Ok'fl '12 4 WELL L-148 42/16111 ,JG-SET XX FLU ( . .. 11 aer2sIts GE/11112 GLV OD • FERMI bit 121411679 6112 )(X PUJGRAIED I�.. 12).. .. 16 PILLE 2 '-;; "�. :. 2 TLTh W4)'SET 3.117 IBC Ft%TO1$r:c 12 34. R116„2 T F .4..3723 FEL .« .7112` RE OFIAVANG 034941C11(36 0616121T GLV & 131�tr1 ' • • 3.1/6'SA OW L-118 Proposed ssfEry R C 4.� .. 76;6 , t ELEV a S2 GT i ,t z' ..__._.. } " z =11117 f 29.7*.L- r ,0=61W i 6-y „„a —, --,_ , , Mini um ID =2.813”@ 2574 4 6 1 44 6 3-1r2" HES X NIPPLEt6 1 t PST 6 1 _,: SIMI 14 liar I 1NT #a 11 1 Packer squeeze cement; TOC —7,950'MD 1121 ,.920,L-66, 6067 bpf.C 2. ear .. 1 1-5.667L:716:64 . `:... sew to 4 54.1"2'X 3-112" XO,D-3. OF 3-107.,.. �'�t,.41=3. "f PINFORATIC*4 SJAMAR, KF LOG S164 V .... ; ANSLE AT_y ' 101@ =' X. , 6.2: *Tf . ��yr to� IX.Erg NokmoN 3 DA It 3 .... .. f nfA�'. a GO tv1 INTERVAL ear P3 PIP it IN i1`01 I II ,..,, y .._...-. ..�.... s. Li 4441 S.4 • 13-112' ;9.. ,L-86,11 . H•2 ®.440 4-I Goat A 1 F 1'BY C t rs r DATE ESC b4 1>,. ,. • .> 1L 049143 DIMPIX} L PLL 0 PNLI 2 (O7 t . LA V 12,1EVI 1 XX PLUS X111) 16 _ O€V.IF t /16112$r. LBo RiC XX 1F .L®?(asio t12`�... X•` r.16 .6 d µFU L ,. PA. 4 ' d L ,A „ r M 06006112'FIt4,L 1SET 3 VT TEM PATCH( 12) 34,1% R1I :+ T &377S M. • +117112 g RE lC9F AVNI!G 1 a Cot 51 Image ¡:. .1ject Well History File Ct;.kr 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. a Q L - j ~ r: Well History File Identifier Organizing (done) o Two-sided 11I111111I111111111 o Rescan Needed I RESCAN D,TAL DATA ~ Diskettes, No. J o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: I BY: Helen ~ Date: IE; d..,~ ()¡ S-/sl I I ~ Project Proofing I Scanning Preparation BY: Helen (Ma,:!-a ") a x 30 = (PO Ill!],,£) Date: 61~4 ð_Ç7sl Y f I . . + 0' = TÇ)TAL PAGES /c;q . (count, doe~ ,not i~ude ..£2ver sheett/'lA .p' Date: Ö ~ Ó'-\ 151 r , . . II I BY: Hele~ ) Production Scanning Stage 1 Page Count from Scanned File: 7 D (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: t/ YE~ 1 NO Helen A Date: ~ ';;"'4: óS- Is! rvI P If NO in stage 1, page(s) discrepancies were found: YES NO BY: Stage 1 BY: Helen Maria Date: 151 II! 111111111111111I 11I1111111111111111 I Date: 151 Quality Checked III II 1111111 II 11111 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: STATE OF ALASKA RECEIVED A OIL AND GAS CONSERVATION COM ION JUL 31 2012 $i „�' v r RE OF SUNDRY WELL OPERA IONS V ` �1 0 9 1. Operations Abandon Li Repair Well [� ( Plug Perforations Li Perforate Li Othe X99 t � Cq Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extensior ❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Wel' ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc 201 -187 -0 Development IS Exploratory ❑ 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23043 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028239 L -118 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): — To Be Submitted PRUDHOE BAY, BOREALIS OIL 11. Present Well Condition Summary: Total Depth measured 8980 feet Plugs measured None feet true vertical 6753.39 feet Junk measured 8870 feet Effective Depth measured 8871 feet Packer measured See Attachment feet true vertical 6645.52 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H-40 25 - 105 25 - 101.9 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None None None Perforation depth Measured depth 8726 - 8776 feet True Vertical depth 6502.44 - 6551.75 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): StAttitift AUG 2 0 n' 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: 1053 2617 2615.7 1653.9 0 Subsequent to operation: 1047 1857 3004 1597.3 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development © •• Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ,. IS Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSPE 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: Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature Phone 564 -4424 Date 7/27/2012 DMS AUG 012012 X Vri / L 1 ( - -- Form 10 -404 Revised 10/2010 ` Submit Original Only / \, b ' , ^7 2, Casing / Tubing Attachment ADL0028239 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H -40 25 - 105 25 - 101.9 1490 470 PATCH 30 3 -1/2" KB Patch 8374 - 8404 6158.84 - 6235.74 PRODUCTION 8464 5 -1/2" 15.5# L -80 25 - 8489 25 - 101.9 7000 4990 PRODUCTION 480 3 -1/2" 9.2# L -80 8489 - 8969 6270.41 - 6347.31 10160 10530 SURFACE 86 7 -5/8" 29.7# L -80 28 - 114 28 - 104.9 6890 4790 SURFACE 2218 7 -5/8" 29.7# S -95 114 - 2332 114 - 190.9 8180 5120 SURFACE 836 7 -5/8" 29.7# L -80 2332 - 3168 2049.4 - 2126.3 6890 4790 411 SURFACE 127 7 -5/8" 29.7# S -95 3168 - 3295 2549.31 - 2626.21 8180 5120 TUBING 8440 3 -1/2" 9.2# L -80 23 - 8463 23 - 99.9 10160 10530 TUBING 18 4" Baker Seal Assembly 8463 - 8481 6245.17 - 6322.07 • • • Packers and SSV's Attachment ADL0028239 SW Name Type MD TVD Depscription L -118 PACKER 8374 6081.94 3 -1/2" KB Straddle Packer L -118 PACKER 8404 6111.06 3 -1/2" KB Straddle Packer • • • Daily Report of Well Operations ADL0028239 ACTIVITYD ** *WELL SHUT -IN ON ARRIVAL * ** (E -LINE SETTING PATCH ) INITIAL T / IA/OA= 400/359/380 SWAB /SSV= CLOSED, IA/OA =OTG RIH WITH MH -32 /ERS /PCCL /BAKER SETTING TOOL /BAKER PATCH OVERALL TOOL LENGTH =50', TOOL WEIGHT =350 #, MAX OD= 2.75" 35KB BAKER PATCH MAX OD= 2.78 ". MIN ID= 1.83 ", LENGTH = 35.6', UPPER TO LOWER ELEMENT = 30.46' SET BAKER PATCH FROM 8374'- 8404', TOP OF PATCH AT 8372.7, TOP ME AT 8374', CCL TO TOP ME = 8.05 ", CCL STOP DEPTH AT 8365.9', BOTTOM ME = 8404' SWAB /SSV= CLOSED, IA/OA =OTG DSO NOTIFIED OF DEPARTURE FINAL T / IA/OA= 455/350/360 5/31/2012 ** *JOB COMPLETE WELL SHUT -IN ON DEPARTURE * ** ** *WELL SHUT -IN ON ARRIVAL * ** (E -LINE SET FING PATCH) INITIAL T /I /0= 400/359/380 SWAB /SSV= CLOSED, IA/OA=OTG RIH WITH MH -32 /ERS /P CCL /BAKER SETTING TOOL /BAKER PATCH TOOL LENGTH =50', TOOL WEIGHT =350 #, MAX OD= 2.78" CCL TO MIDDLE OF TOP ELEMENT = 8.05" CCL STOP DEPTH AT 8365.9' BAKER PATCH SET FROM 8374' -8404' MD OVER GLM #1 AT 8381' MD. SWAB /SSV= CLOSED, IA/OA=OTG DSO NOTIFIED OF DEPARTURE FINAL T /IA/OA= 455/350/360 5/31/2012 ** *JOB COMPLETE WELL SHUT -IN ON DEPARTURE * ** T/I/0= 477/340/370 MIT -IA * *PASSED** to 2500 psi (Post Patch) Pumped 1.6 bbls of neat methanol into IA to reach test pressure. 15 min IA lost 43 psi. 30 min IA lost 14 psi. Total loss of 57 psi in 30 mins. Bled IA back to 400 psi. Bled back 1.2 bbls. Pad op notified of well status and tree valve positions as follows:SV,WV,SSV = closed. MV =open. 6/2/2012 IA and OA open to gauges. FWHP= 477/400/370 ** *WELL SHUT -IN ON ARRIVAL * ** (patch tbg /Liner) SET 4 -1/2" WHIDDON CATCHER SUB AT 8,352' SLM 6/7/2012 ** *CONT. WSR ON 6- 8 -12 * ** 171/0 = SSV /440/360. Temp = SI. WFIPs (Eval High IAP). AL SI @ casing valve, ALP = 1600 psi. * ** Note SLB nite unit on location. 6/8/2012 SV,WV,SSV = C. MV = 0. IA, OA = OTG. NOVP. 1500 ** *CONT. WSR FROM 6- 7 -12 * ** (patch tbg /Liner) PULLED STA. #2 INT -DGLV FROM 7,660' SLM (7,671' MD) * * *GO TO WEATHER TICKET * ** * *NOTE: WHIDDON CATCHER IN THE HOLE, STA. #2 HAS AN OPEN POCKET * ** 6/8/2012 ** *CONT. WSR FROM 6- 8 -12 * ** (patch tbg /Liner) PULLED STA. #3 INT -DGLV FROM 6,375' SLM (6,385' MD) 6/12/2012 ** *CONT. WSR ON 6- 13 -12 * ** • • PULLED STA. #4 INT -DGLV FROM 4,775' SLM (4,788' MD) SET STA. #4 INT -LGLV (16/64" PORTS, 1717# TRO) AT 4,775' SLM (4,788' MD) SET STA. #3 INT -LGLV (16/64" PORTS,1677# TRO) AT 6,375' SLM (6,385' MD) SET STA. #2 INT -OGLV (20/64" PORTS) AT 7,660' SLM (7,671' MD) (lost 2 kick springs and screw off kickover tool) DRIFT TBG W/ KJ, XO, 3 -1/2" BLB, 2.73" G. RING TO WHIDDON C -SUB AT 8,352' SLM 6/13/2012 ** *CONT. WSR ON 06- 14 -12 * ** * * *CONT WSR FROM 6- 13- 12 **** PULL 3 -1/2 WHIDDON CATCHER SUB FROM 8352' SLM, UNABLE TO RETRIEVE 2 KICK SPRINGS 6/14/2012 ** *WELL LEFT S /I, PAD OP NOTIFIED * ** • TREE ' 3-1/8" 5M CIW 'WELLHEAD = FMC • 11/SAFETY NOTES: ACTUATOR = BAKER C L-'118 KB. ELEV = 76.g BF. ELEV = 52.03' KOP = 300' Max Angie = 56° @ 3414' Datum MD = 8903' Datum TVD = 6600' SS r — 2574' N 3.1/2" I-ES X PP, D= 2.813" I 17 -518" CSG, 29.7#, L-80/S-95,13= 6.875' I—I 3295' HA GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 1.83" @ 8374' 4 4788 3502 51 KBG-2 DONE INT 16 06/13/12 3 -1/2" BKR TBG PATCH 3 6385 4496 51 KBG-2 DONE NT 16 06/13/12 2 7671 5486 23 KBG-2 SO NT 20 06/13/12 1 8381 6166 14 KBG-2 'OMY INT 0 1129/11 STA # 1 = IMY HAS SWELL PiACKPIG & IS COVERED BY TBG PATCH 8374' - 8404'F BKR TBG PATCH, D = 1.83" (06/02/12) I 1 8438' 1--13-1/2" BKR CMD SID SLV, D= 2.813' 1 13 - 1/2" TBG, 9.2#, 1 .0087 bpf, D = 2.992" H 8462' 8462' L.--1 BKR LOC SEAL ASSY, 13= 3.00" 1 5-1/2" CSG, 15.5#, L-80, D = 4.950" H 8469' I 1 8469' 1—L. TOP OF BKR PER, D = 4.00" 1 15-12" X 3 -1/2' CSG X0,13 = 3.000" 848W ( 8481' 1_1 BIM OF 3-1/2' BKR SEAL ASSY, D= 3.00" I ' { 8508' H3-12" I4S X NP, D= 2.813' PBRFORATDN SU MAR ' REF LOG: SWS VISION D-N ON 03/29/03 ANGLEAT TOP PERE: 10° @ 8726' , 1 8559' H3-1/2" HES X NP, D= 2.813' Note: Refer to Reduction DB for historical pert data I 8554` HX NP ELND LOGGED ON 11/17/03 SIZE SIT INTERVAL Opn/Sqz DATE 2 -1/2" 6 8726 - 8776 0 04/17/03 8694' H20' R PJT W / RA TAG I L ? I- FISH - 2 SPRINGS FROM SL KICKOVER TOOL - APPROX 4-3/4" X 3/4' X1/16* (06/14/12) I FBTD H 8871' 'R444'1 13-12' CSG, 9.2#, L -80, D = 2.992" H 8969' I • * 1 1 / 1 1 1 /1 1 4 ■■4N♦ DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 04101/03 DAC/KK ORIGINAL. COMPLETION 07/16/12 PJC TREE C/0 (07/09/12) WELL: 1-118 12/16/11 WECJPJC SET XXPLUG (09/16/11) PERMIT No: "2011870 05/16/12 LEC/JMD )0( PLUG PULLED (05/03/12) API No: 50-029-23043-00 06/05/12 TTR/JMD SET 3-1/2' TBG PATCH (06/02/12) SEC 34, T12N, R11E, 2551' FSL & 3773' FEL 06/17/12 PJC DRAWING CORRECTIONS I 06/18/12 TJH/JMD GLV C/O & SET FISH (06/13- 14/12) BP Exploration (Alaska) • 0 .1.-c/-14=5,0 WELL LOG TRANSMITTAL 2_0(457 I,. Z l zG5 PROAc1ivE DiAgNosTic SERVicES, INc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Nita Summerhays LR2 - 1 900 Benson Blvd. 7,' Z Anchorage, AK 99508 AUG and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - WLD 28 -Oct-11 L -118 BL / CD 50-029 - 23043 -00 2) Leak Detection - WLD 09- Sep-11 02 -24A BL 50 -029- 20744-01 -11 Signed : ) .G+:d"_ Date : 3 `') ll- Print Name: Ml PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -8952 E -MAIL : PDSANCHORAGEC[DA7EMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution \TransmittalSheets\BP Transmitdocx ~ ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Au ust 14 2009 , ~` fi` ` R~ `" ~'a`'`' 9 ~ ~ ~ ~~ ~~~ ~ ~:~~_' ~' ~`~~ `` ~~r~.~,:~.. Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, bp ~~~~~~~L~ ocT a ~ 200~ ~fasVc~ ~ii ~ Gas Cans. Conxnis~ion Anchorag~ ~~- GS ~" ~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) Inc. Surtace Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operetions (10-404) ~~ nwre L pad an snnns Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbis ft na al L-01 2010720 50029230110000 NA 6 NA 612 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.6 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 62 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 102 6/26/2009 1.-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 1.-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 l•118 2071870 50028230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 225 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 203~390 50029231380100 NA 22 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 1-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L405 2080530 50029233880000 NA t NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 025 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late bbckin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Matker.doc i 7 1V1~ J.ù,~ \" DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2011870 Well Name/No. PRUDHOE BAY UN BORE L-118 Operator BP EXPLORATION (ALASKA) INC Jf~J ~ À.~J.-ô-IJ) API No. 50-029-23043-00-00 MD 8980 '-'" TVD 6753./ Completion Status 1-01L Completion Date 4/17/2003.-/ REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, PWD, DEN, NEU, RES Well Log Information: Log/ Data Digital Type MegtFrmt -~% I _ }RT5f í í i I I I Electr Dataset Number Name Directional Survey Directional Survey Log Log Scale Media Run No 1 .--/-- ~ C ~.:H't...i~ Y''''-C Pds 12125 L1S-VArifiC'.;:¡tinn h I}.ur \) t \'~ l j- i ~ KJ A.~ fJ I ~ 12125 Induction/Resistivity 25 ~/ 4'ó- C Induction/Resistivity 25 Blu 25 25 Blu 25 25 Blu Pds 12125 Density ! ~ .~/C î Density '"---. Pds 12125 Neutron ~ Neutron Well Cores/Samples Information: Name Interval Start Stop Received Sent Current Status 1-01L UIC N Directional su~~~._~~ (data taken from Logs Portion of Master Well Data Maint) ~ Interval OHI Start Stop CH Received Comments 0 8980 Open 4/21/2003 0 8980 Open 4/21/2003 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 2/18/2003. 108 8980 Open 7/23/2003 108 8043 Open 7/23/2003 See Vision Service Log (Composite Log) Individual Log Culled 108 8043 Open 7/23/2003 See Vision Service Log (Composite Log) Individual Log Culled 108 8043 Open 7/23/2003 See Vision Service Log (Composite Log) Individual Log Culled 108 8043 Open 7/23/2003 See Vision Service Log (Composite Log) Individual Log Culled 108 8043 Open 7/23/2003 See Vision Service Log (Composite Log) Individual Log Culled 108 8043 Open 7/23/2003 See Vision Service Log (Composite Log) Individual Log Culled Sample Set Number Comments Permit to Drill 2011870 MD 8980 ìVD 6753 ADDITIONAL INFORMATION Well Cored? ~ Chips Received? --ViN Analysis Received? ~ Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Well Name/No. PRUDHOE BAY UN BORE L-118 Operator BP EXPLORATION (ALASKA) INC Completion Date 4/17/2003 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? QN <@/N Formation Tops ~ Date: API No. 50-029-23043-00-00 c2 7~ 1'1t~J..J ! 1 H¡ 'U-ù '~ r- ~Ot-\~T- 7/3/2003 Scblullbepgep NO. 2896 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th A ve, Suite 100 Anchorage, AK 99501 Well Job# Log Description L-118 23379 OH EDIT LWD M10,ADN,IMP L-118 23379 MD VISION RESISTIVITY L-118 23379 TVD VISION RESISTIVITY L-118 23379 MD VISION DEN/NEUTRON L-118 23379 TVD VISION DEN/NEUTRON L-118 23379 MD VISION SERVICE L-118 23379 TVD VISION SERVICE Field: Borealis Date Color BL CD --/ 03/29103 1 J81ð-~ 03/29/03 1 03/29/03 1 03/29/03 1 03/29/03 1 03/29/03 1 03/29/03 1 -'- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 R IVED Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth Date Delivered: JUL 23 2003 Received-~Ö\~~~~"~~ ~~~\\.\ '" ~ Alaska 0;'1 & Gas Cons. Ccmmi88kJn Anchora:Qe STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2551' NSL, 3773'WEL, SEC. 34, T12N, R11E, UM At top of productive interval 1744' NSL, 1458' WEL, SEC. 27, T12N, R11 E, UM X = 585397, Y = 5982770 10. Well Number At total depth 1777' NSL, 1436' WEL, SEC. 27, T12N, R11 E, UM X = 585419, Y = 5982803 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Borealis Pool RKB = 76.9' ADL 028239 (Undefined) 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 3/22/2003 3/28/2003 4/17/2003 NIA MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8980 6753 FT 8904 6678 FT 181 Yes 0 No (Nipple) 2574' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, PWD, DEN, NEU, RES Classification of Service Well 9. X = 583142, Y = 5978272 7. Permit Number 201-187 8. API Number 50- 029-23043-00 Unit or Lease Name Prudhoe Bay Unit L-118 ,23. CASING SIZE 34" X 20" 7-5/8" 5-1/2" x 3-1/2" WT. PER FT. 91.5# 29.7# 15.5# I 9.2# GRADE H-40 L -80 I S-95 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 110' 42" 28' 3295' 9-7/8" 25' 8969' 6-3/4" CEMENTING RECORD 260 sx Arctic Set (Approx.) 400 sx PF 'L', 200 sx Class 'G' 149 sx Class 'G', 116 sx Class 'G' AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 6 spf MD TVD MD TVD 8726' - 8776' 6502' - 6552' 25. SIZE 3-1/2", 9.2#, L-80 TUBING RECORD DEPTH SET (MD) 8481' PACKER SET (MD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected wI 145 Bbls of Diesel 8726' - 8776' Frac'd: Placed 180,500 # 16/20 Carbolite behind pipe 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 10, 2003 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-MCF WATER-BBL 5/10/2003 4 TEST PERIOD 726 379 37 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-MCF WATER-BBL Press. 540 24-HoUR RATE ?8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SUbnfL(~eE I VE D CHOKE SIZE GAS-OIL RATIO 176 522 OIL GRAVITY-API (CORR) No core samples were taken. ;¡:¿..'i;./. " . .:L"'4:.~" '.lr;:'¡;!~:tn -,_.6J!~ ',.. -.r h', ,~,~. , RBDMS BfL ~¡: MAY 1 ~ ~~ 1 6 2003 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate ) 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Ugnu 3672' 2833' Ugnu M 5561' 3983' Schrader Bluff N 5924' 4210' Schrader Bluff 0 6172' 4365' Base Schrader I Top Colville 6750' 4736' HRZ 8373' 6158' Kalubik 8578' 6357' Kuparuk D 8725' 6501' Kuparuk C 8726' 6502' Kuparuk B 8862' 6637' 31. List of Attachments: ) 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. RECEIVED MAY 1 6 Z003 Alaska Oil & Gas Cons. Commission Anchorage Summary of Daily Drilling Reports and Post Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble -'1QJJJ..e -' ~ Title Technical Assistant Date 05'·' 6 ·03 L-118 201-187 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Drilling Engineer: Neil Magee, 564-5119 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. I;EM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 28: If no cores taken, indicate 'none'. , hEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ORIG\NAL Form 10-407 Rev. 07-01-80 Legal Name: Common Name: Test Date 3/25/2003 LOT L-118 L-118 Test Type BP Leak-OffIestSutrlrnary Test Depth (TMD) 3,295.0 (ft) . T~stDepthlTVD) 2,622.0 (ft) AMW 9.70 (ppg) SUrfäcef'ressure LeaKOff ¡>rE!ssurê (BAP) 675 (psi) 1,996 (psi) EMW 14.66 (ppg) J ~ ~ Printed: 4/8/2003 9:04:31 AM ) ) BP OperationsSuml1'l'ary Report . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-118 L-118 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES . . Date From ~To Hours Task Code NPT Phase 3/21/2003 12:00 - 15:00 15:00 - 16:00 16:00 - 20:00 3.00 MOB P 1.00 MOB P 4.00 RIGU P PRE PRE PRE Page 10f 7 Start: 3/21/2003 Rig Release: 4/1/2003 Rig Number: Spud Date: 3/22/2003 End: 4/1/2003 Description of Operations Move rig over L-118 Spot pits and camp RU all lines. NU riser. Change over top drive to 4", HT-40. 20:00 - 22:00 2.00 RIGU P 22:00 - 23:00 1.00 BOPSUR P 23:00 - 00:00 1.00 RIGU P 3/22/2003 00:00 - 04:30 4.50 RIGU P 04:30 - 05:30 1.00 RIGU P 05:30 - 06:00 0.50 RIGU P 06:00 - 06:30 0.50 RIGU P 06:30 - 07:30 1.00 RIGU P 07:30 - 08:00 0.50 RIGU P 08:00 - 10:00 2.00 DRILL P Rig accepted @ 17:00 hrs PRE Take on water, mix spud mud. Load DP in pipe shed, strap. PRE Function test diverter and PVT's. Witness of diverter function test waived by John Crisp, AOGCC. PRE PU 12.25 bit and DP, drill ice plug out of conductor to 110', flush conductor with water PRE PU DP PRE Build jar and collar stands, stand back PRE Rig service, service top drive, blocks and crown PRE Prespud meeting with Co. Rep., TP, Baroid, Gyro Data, Anadrill and all rig personnel. PRE PU motor, MU bit and BHA #1 PRE Rig up SWS wireline unit for Gryo Data surveys on e-line SURF Drill from 108' to 300'.650 gpm @ 1320 psi. Circulate hole clean @ 300' 10:00 - 11 :00 1.00 DRILL P SURF 11 :00 - 12:00 1.00 DRILL P SURF 12:00 - 15:00 3.00 DRILL P SURF 15:00 - 15:30 0.50 DRILL P SURF 15:30 - 22:30 7.00 DRILL P SURF 22:30 - 23:00 0.50 DRILL P SURF 23:00 - 00:00 1.00 DRILL P SURF 3/23/2003 00:00 - 01 :00 1.00 DRILL P SURF 01 :00 - 01 :30 0.50 DRILL P SURF 01 :30 - 02:30 1.00 DRILL P SURF 02:30 - 11 :00 8.50 DRILL P SURF 11 :00 - 12:00 1.00 DRILL P SURF 12:00 - 14:30 2.50 DRILL P SURF Spud well @ 08:00 POH 2 stands. MU jar stand. RIH, wash last stand to bottom PU Gyro Data tools, RIH. Survey @ 290', POH Directional drill from 300' to 816'. Build angle to -6.8 degrees, hold azimuth at -21 degrees as per directional plan. 63 klbs up, 63 klbs down, 63 klbs rotate. 650 gpm @ 1900 psi. PU Gyro Data tools, RIH. Survey @ 816', POH. RD Gyro Data and SWS wireline unit. Directional drill from 816' to 1560'. Build angle to -33.5 degrees, hold azimuth to -21 degrees as per directional plan. 71 klbs up, 71 klbs down, 71 klbs rotate. 650 gpm @ 2480 psi. AST last 24 hrs. = 5.38 hrs ART last 24 hrs. = 3.97 ADT = 9.35 hrs Circulate and condition hole. CBU X 2 Monitor well. POH for bit #1. 80 klbs up, 65 klbs down. Cont. POH - Stand back HWDP, jars and collars. Break out bit #1 and MU bit #2 Rig service - Top drive and blocks RIH, wash last stand to bottom at 1560' Directional drill from 1560' to 3310'. Build angle to 55 degrees, azimuth worked left 2 degrees from directional plan will correct in the 6.75" hole section. 94 klbs up, 68 klbs down, 81 klbs rotate. 650 gpm @ 3225 psi. AST last 24 hrs. = 2.57 ART last 24 hrs. = 3.23 ADT = 15.15 hrs. Circulate and condition hole for wiper trip, reciprocate DP throughout. POH on short trip to 700'. Pulled tight @ 1550', pumped 1 stand out from 1558' to 1465'. No problems the rest of the way Printed: 4/8/2003 9:04:38 AM ) ) BP Operations Sumrnary Report Page2 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-118 L-118 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 3/21/2003 Rig Release: 4/1/2003 Rig Number: Spud Date: 3/22/2003 End: 4/1/2003 Date From -To· Hours Task Code NPT Phase Description of Operations 3/23/2003 12:00 - 14:30 2.50 DRILL P SURF out to 700'. 100 klbs up, 70 klbs down. 14:30 - 16:30 2.00 DRILL P SURF TIH to 1280'. Obstruction at 1280', work pipe down to 2186'. Pump down to 2210'. Able to work pipe down again to 2583'. Obstruction at 2583', pump 1 stand down from 2583' to 2677'. Worked pipe down to TO @ 3310' 16:30 - 17:30 1.00 DRILL P SURF Circulate and condition hole clean to POH for casing. CBU X 2 17:30 - 19:30 2.00 DRILL P SURF POH to run 7-5/8" 29.7# casing. Pulled 25 klbs over @ 1700', work through. Work through tight spot again @ 1280'. 19:30 - 21 :00 1.50 DRILL P SURF LD BHA #2 21 :00 - 21 :30 0.50 DRILL P SURF Clean and clear rig floor 21 :30 - 23:00 1.50 CASE P SURF RU csg equipment. Make dummy run with hanger. 23:00 - 00:00 1.00 CASE P SURF MU shoe track. Test float equipment 3/24/2003 00:00 - 04:00 4.00 CASE P SURF Run 7-5/8" 29.7# S-95/L-80 casing to TO. Shoe @ 3295'. Taking on weight intermintently from 2850' to TO. Land casing on hanger- OK 04:00 - 04:30 0.50 CEMT P SURF Blow down topdrive. MU cement head 04:30 - 06:00 1.50 CEMT P SURF Circulate and condition hole prior to cement csg @ 8 bpm , 350 psi. Reciprocate pipe no problems - 128 klbs up, 80 klbs down 06:00 - 06: 15 0.25 CEMT P SURF PJSM with crew & service companies prior to cement job. 06:15 - 06:30 0.25 CEMT P SURF Continue circ at 8 bpm while Howco airs up & primes up. 06:30 - 07:00 0.50 CEMT P SURF Switch to cementers. Pump 10 bbl water. Test lines to 3500 psi. Pump 10 bbl water followed by 75 bbl Alpha spacer at 10.2 ppg - 6.5 bpm @ 350 psi. 07:00 - 08:00 1.00 CEMT P SURF Release bottom plug. Mix & pump 293 bbl (400 sx) Permafrost L lead cement at 10.7 ppg. 8 bpm @ 300 psi. Reciprocate pipe until -80 bbllead slurry in annulus. Started pulling heavy so landed casing on hanger for remainder of job. Switch to tail slurry. Mix & pump 41 bbl (200 sx) 15.8 ppg Premium Class G tail slurry - 5 bpm @ 850 psi final pressure. 08:00 - 08:30 0.50 CEMT P SURF Kick out top plug with 10 bbl water from Howco. Switch to rig pump and displace with mud at 8 bpm @ 900-1100 psi. Started getting good cement returns 1250 stks into displacement. Bump plug with 137.7 bbl mud as calculated with 1500 psi. Got back -50 bbls good lead cement. CIP @ 0815 hrs. Bleed off pressure & break cement line - floats holding OK. RD cement head. 08:30 - 09:30 1.00 CEMT P SURF Rig down cement equipment. Back out landing joint. Flush knife valve, diverter and flowline 09:30 - 10:30 1.00 CASE P SURF Rig down casing equipment and clear floor. CO bails and install elevators 10:30 - 14:00 3.50 DIVRTR P SURF NO diverter, riser and surface Hydril and remove from cellar 14:00 - 15:30 1.50 WHSUR P SURF NU speed head and tubing spool 15:30 - 17:30 2.00 BOPSUR P PROD1 NU BOPE 17:30 - 18:00 0.50 BOPSURP PROD1 PU and MU test joint and test plug. Fill stack 18:00 - 20:30 2.50 BOPSUR P PROD1 Test BOPE 250/4000 psi. Test annular preventer to 250/3500 psi. Witness of BOP test waived by John Crisp, AOGCC 20:30 - 23:30 3.00 DRILL P PROD1 PU single jts of DP and stand back 31 stands 23:30 - 00:00 0.50 DRILL P PROD1 PU and MU BHA #3 3/25/2003 00:00 - 02:00 2.00 DRILL P PROD1 PU / MU BHA #3 02:00 - 02:15 0.25 DRILL P PROD1 PJSM with rig personnel and service company personnel regarding loading of MWD source 02:15 - 02:30 0.25 DRILL P PROD1 Load MWD source. PU and RIH jar stand. Shallow test MWD tools, 300 gpm, 1340 psi - OK Printed: 4/8/2003 9:04:38 AM ) ') BP Operatio n55 u mma ryRep.ort Page 3 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-118 L-118 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 3/21/2003 Rig Release: 4/1/2003 Rig Number: Spud Date: 3/22/2003 End: 4/1/2003 Date From - To Hours ·Task Code NPT Phase Description· of· Operations 3/25/2003 02:30 - 04:30 2.00 DRILL P PROD1 PU singles of DP from pipe shed and RIH to 1975' 04:30 - 05:00 0.50 DRILL P PROD1 Rig Service - Service top drive, blocks and crown 05:00 - 06:00 1.00 DRILL P PROD1 Cut & slip 45' of drilling line 06:00 - 07:00 1.00 DRILL P PROD1 Continue PU DP from pipe shed, 51 jts total, and RIH. Continue RIH with DP from derrick to 3096' 07:00 - 08:00 1.00 CASE P PROD1 Fill lines and test 7-5/8" casing to 3500 psi for 30 min. - OK 08:00 - 09:00 1.00 DRILL P PROD1 Wash down and tag float collar @ 3209'. Drill shoe track, 300 gpm @ 2112 psi. Drill 20' of new hole from 3310' to 3330'. 09:00 - 09:30 0.50 DRILL P PROD1 Circulate new 9.7 ppg LSND mud around, 330 gpm @ 1914 psi 09:30 - 10:30 1.00 DRILL P PROD1 Perform LOT. Leak off pressure 675 psi. MW 9.7. EMW 14.6. Establish baseline ECD readings 10:30 - 12:00 1.50 DRILL P PROD1 Directional drill from 3330' to 3656'. 92 klbs up, 61 klbs down, 78 klbs rotate. 330 gpm @ 2650 psi 12:00 -13:00 1.00 DRILL P PROD1 Circulate sweep. When sweep rounded the bit ECD increased to 12.8 ppg. Reduced pump rate continued backream. ECD spiked to 13.6 ppg and the well started taking fluid. Backreamed to casing shoe at 3298' and pumped sweep at the shoe. Circulated sweep around, ECD came down to 11.25. Wash and ream to bottom. 13:00 -18:30 5.50 DRILL P PROD1 Directional drill from 3656' to 4554'. 106 klbs up, 73 klbs down, 86 klbs rotate. 330 gpm @ 2450 psi. Backream every stand with reduced pump rate on the down stroke. Circulate Hi-vis sweep every 200' drilled. Observed flow rate decrease and loss of returns. 18:30 - 22:00 3.50 DRILL N DPRB PROD1 Circulate at reduced pump rate of 150 gpm, to control losses. Spot LCM pill. Reduce mud weight from 9.7 ppg to 9.2 ppg. String in 10 sxs/hr. Barofibre throughout circulation. 110 klbs up, 75 klbs down. Losses stabilized at -30 bbl/hr 22:00 - 00:00 2.00 DRILL P PROD1 Directional drill from 4554' to 4683' with reduced pump rate of 300 gpm. Continue losing fluid, work pipe at 150 gpm. Spot LCM pill. Limit ROP to maintain ECD less than 0.8 ppg over calculated. AST last 24 hrs. = 0.80 hrs. ART last 24 hrs. = 2.41 hrs. ADT = 3.21 hrs. Total losses = 497 bbls 3/26/2003 00:00 - 12:00 12.00 DRILL P PROD1 Directional drill from 4683' to 5553'. The hole has shown a natural tendancy to drop angle, sliding to turn right as per directional plan and maintain angle, will try to build angle to plan after curve section. 121 klbs up, 81 klbs down, 96 klbs rotate. 300 gpm @ 1756 psi. Backream every stand with reduced pump rate on the down stroke. Circulate Hi-vis sweep every 200' drilled. String in 10 sxs/hr. Barofibre. Losses stabilized at 20-30 bph. Monitor ECD's and circulate as necessary to keep within 1.0 ppg of calculated. 12:00 - 00:00 12.00 DRILL P PROD1 Directional drill from 5553' to 6151'. Still sliding to turn right as per directional plan and maintain angle, projected to hit driller's target through the Shrader. 141 klbs up, 81 klbs down, 103 klbs rotate. 300 gpm @ 1960 psi. Backream every stand with reduced pump rate on the down stroke. Circulate Hi-vis sweep every 200' drilled. String in 6 sxs/hr. Barofibre. Losses stabilized at 20-30 bph. Monitor ECD's and circulate as Printed: 4/8/2003 9:04:38 AM ) ') BP Op~rationsSummaryReport Page 4 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-118 L-118 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 3/21/2003 Rig Release: 4/1/2003 Rig Number: Spud Date: 3/22/2003 End: 4/1/2003 . Date From - To Hours . Task Code NPT Phase Description of Operations 3/26/2003 12:00 - 00:00 12.00 DRILL P PROD1 necessary to keep within 1.0 ppg of calculated. AST last 24 hrs. = 7.57 hrs. ART last 24 hrs. = 3.99 hrs ADT = 14.77 hrs Losses last 24 hrs. = 798 bbl Total losses = 1295 bbls 3/27/2003 00:00 - 00:00 24.00 DRILL P PROD1 Directional drill from 6151' to 7949'. On directional plan through Schrader. 189 klbs up, 91 klbs down, 123 klbs rotate. 310 gpm @ 2688 psi. Backream every stand with reduced pump rate on the down stroke. Circulate Hi-vis sweep every 200' drilled. String in 6 sxs/hr. Barofibre. Losses stabilized at 20-25 bph. Monitor ECD's and circulate as necessary to keep within 1.0 ppg of calculated. AST last 24 hrs. = 4.23 hrs ART last 24 hrs. = 9.5 hrs ADT = 28.5 hrs. Losses last 24 hrs = 636 bbls Total losses = 1931 bbl 3/28/2003 00:00 - 03:30 3.50 DRILL P PROD1 Directional drill from 7949' to 8280'. Sliding to maintain angle and hit driller's target at TO. 190 klbs up, 93 klbs down, 125 klbs rotate. 310 gpm @ 2688 psi. Backream every stand with reduced pump rate on the down stroke. Circulate Hi-vis sweep every 200' drilled. String in 6 sxs/hr. Barofibre. Losses stabilized at 20-25 bph. Monitor ECD's and circulate as necessary to keep within 1.0 ppg of calculated. 03:30 - 04:00 0.50 DRILL P PROD1 Weight up mud to 9.7 ppg. Reciprocate DP @ 100 RPM, 310 gpm. Losses increased to 90 bpm with 9.7 mud 04:00 - 21 :30 17.50 DRILL P PROD1 Directional drill from 8280' to 8931'. On directional plan to hit driller's target at TO, rotate 100% from 8496'. 190 klbs up, 93 klbs down, 125 klbs rotate. 310 gpm @ 2688 psi. Backream every stand with reduced pump rate on the down stroke. Circulate Hi-vis sweep every 200' drilled. Stringing in Barofibre @ 6 sxs/hr., Baracarb 5 @ 4 sxs/hr, and Baracarb 50 @ 4 sxs/hr. Losses reduced to 42 bph. Monitor ECD's and circulate as necessary to keep within 1.0 ppg of calculated 21 :30 - 23:00 1.50 DRILL P PROD1 Increased flow while drilling. PU and flow check well. Shut in for 30 minutes, DP pressure 50 psi. Opened the choke and bled to o psi, 60 bbls returns. Monitor well slight flow. Shut in well again for 15 minutes, DP pressure 11 psi. Opened choke and bled to 0 psi, 14 bbls returns. Monitor well slight flow. 23:00 - 00:00 1.00 DRILL P PROD1 Drill from 8931' to 8980'. Rotate 100%. 226 klbs up, 105 klbs down, 139 klbs rotate. 310 gpm @ 2800 psi. Backream every stand with reduced pump rate on the down stroke. Circulate Hi-vis sweep every 200' drilled. AST last 24 hrs. = 9.45 hrs ART last 24 hrs. = 4.68 hrs ADT = 42.63 hrs Printed: 4/8/2003 9:04:38 AM ) ) BP Op.erationsSllmm~ry Report Page 50f 7 . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-118 L-118 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 3/21/2003 Rig Release: 4/1/2003 Rig Number: Spud Date: 3/22/2003 End: 4/1/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/28/2003 23:00 - 00:00 1.00 DRILL P PROD1 Losses last 24 hrs = 1092 bbls Total losses = 3023 bbls 3/29/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Circulate and condition hole for short trip to casing shoe. Reciprocate DP @ 100 RPM, 310 gpm 01 :00 - 03:00 2.00 DRILL P PROD1 Well breathing monitor well. Initial flow 100 bph, decreased and stabilized at 10-15 bph. 170 bbls returns 03:00 - 06:00 3.00 DRILL P PROD1 Pump dry job and POH for short trip to casing shoe. flow stabilized at 10-15 bph. Monitor flow and displacement for increases. 06:00 - 06:30 0.50 DRILL P PROD1 Monitor well. 3 bbl static loss 06:30 - 07:00 0.50 DRILL P PROD1 Rig service; top drive, blocks and crown. 07:00 - 09:30 2.50 DRILL P PROD1 RIH from csg shoe to 6800'. Hole is taking fluid not giving displacement. 09:30 - 10:00 0.50 DRILL P PROD1 Stage pumps to 242 gpm @ 1490 psi. CBU. Reciprocate DP @ 110 rpm. 135 bblloss while circulating. 10:00 - 10:30 0.50 DRILL P PROD1 RIH from 6800' to 8887'. Hole taking fluid, 50 bbl on TIH. 10:30 - 12:30 2.00 DRILL P PROD1 Stage pumps, establish circulation. wash last stand to bottom at 8980'. At 300 gpm pump rate the hole took 200 bph, reduce pump rate to 200 gpm @ 1038 psi to minimize losses. Circulate and condition hole to POH, reciprocate DP @ 110 rpm. bring pumps up to 310 gpm @ 2000 psi. 12:30 - 14:00 1.50 DRILL P PROD1 Monitor well, flowing back. POH 6 stands to above HRZ. Continue POH to 7200' laying down DP. 14:00 -15:00 1.00 DRILL P PROD1 Break circulation, stage pumps to 250 gpm @ 1350 psi. Hole still taking fluid. Pump Steel Seal pill. Monitor well - No Flow. 15:00 - 21 :00 6.00 DRILL P PROD1 Continue POH laying down DP. Monitor well at the casing shoe - no flow. 21:00 - 21:15 0.25 DRILL P PROD1 PJSM with Co. Rep, TP, rig crew and service company on laying down BHA and unloading the nuclear source. 21 :15 - 23:30 2.25 DRILL P PROD1 LD HWDP and BHA. Unload nuclear source. 23:30 - 00:00 0.50 DRILL P PROD1 Clean and clear rig floor 3/30/2003 00:00 - 00:30 0.50 BOPSUR P COMP Pull wear bushing. Make dummy run with hanger. 00:30 - 01 :30 1.00 CASE P COMP Change out bails. RU 3-1/2" csg equipment. 01 :30 - 01 :45 0.25 CASE P COMP PJSM with Co. Rep., TP, Rig crew and service co. hands on running 3-1/2" /5-112" tapered csg. string. 01 :45 - 03:00 1.25 CASE P COMP PU 3-1/2" float equipment and latch in assembly, check float. Run 3-1/2" 9.2# csg. 13 joints plus jewelry. 03:00 - 03:30 0.50 CASE P COMP RU 5-1/2" casing equipment and fill up tool. 03:30 - 08:30 5.00 CASE P COMP Run 5-1/2" 15.5# casing, 1 minute per jt. slip to slip, fill every joint, break circulation for 5-10 minutes every 15 joints to the 7-5/8" csg shoe. 20 bbl under displacement at csg shoe, taking fluid during circulation. 08:30 - 09:00 0.50 CASE P COMP Circulate 1-1/2 times bottoms up, 4 bpm @ 256 psi 09:00 - 14:00 5.00 CASE P COMP Continue run 5-1/2" csg. 1 minute per jt. slip to slip, fill every jt., break circulation every 5 jts., circulate 15 minutes every 15 jts. 14:00 - 14:30 0.50 CASE P COMP CBU, stage pumps to 3 bpm @ 380 psi. Pumped 102 bbls, lost 90 bbls. 14:30 - 22:00 7.50 CASE P COMP Continue run 5-1/2" csg, 206 jts and 1 pup below the hanger. Total losses while running csg. = 825 bbls Printed: 4/8/2003 9:04:38 AM ") ) BP Ope.ratiöns Summary Report Page 6 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-118 L-118 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 3/21/2003 Rig Release: 4/1/2003 Rig Number: Spud Date: 3/22/2003 End: 4/1/2003 Date From·.;. To Hours Task Code ··NPT Phase Description of Operations 3/30/2003 22:00 - 22:30 0.50 CEMT P COMP RD fill up too', blow down top drive. RU cement head 22:30 - 22:45 0.25 CEMT P COMP stage pumps up to 6 bbl/min, circulate and condition for cement, Reciprocate csg 10' while circulating, 204 klbs up, 84 klbs down. 22:45 - 23:00 0.25 CEMT P COMP PJSM CO. Rep., TP, rig crew and service co. hands on cementing procedures and precautions. 23:00 - 23: 15 0.25 CEMT P COMP switch to cementers and pump 10 bbl spacer and pressure test lines to 4000 psi. Reciprocate pipe 10' throughout cement job 23: 15 - 23:20 0.08 CEMT P COMP pump 10 bbl spacer @ 2 bbl/min 23:20 - 23:25 0.08 CEMT P COMP Pump 25 bbl alpha spacer weighted to 10.7 ppg at 5 bbl/min. 23:25 - 23:35 0.17 CEMT P COMP Pump 62 bbls ( 148 sxs) 12.5 ppg HOWCO SilicaLite lead cement @ 5 bbl/min. 23:35 - 23:40 0.08 CEMT P COMP Pump 24 bbls (112 sxs) 15.8 ppg HOWCO class G premium cement @ 8 bbl/min. 23:40 - 23:55 0.25 CEMT P COMP Wash down cement lines with sea water tthrough "T" to the pits. Load latched top and bottom plugs in cement into the cement head and verify they are out of the head. 23:55 - 00:00 0.08 CEMT P COMP Switch to rig pump and displace with sea water. Initial rate 5 bbl/min @ 286 psi 3/31/2003 00:00 - 00:45 0.75 CEMT P COMP Continue using rig pump to displace cement with seawater at 5 bbl/min @ ICP of 286 psi. Reciprocate pipe 10' until tail cement entered annulus then landed casing on hanger. Reduced rate to 2 bbl/min to bump, FCP 1250 psi. Bump plug at 205 bbls displacement, as calculated, with 1800 psi. CIP @ 00:45 hrs. Bleed off pressure & break cement line - floats holding OK. RD cement head. 00:45 - 03:00 2.25 CEMT P COMP Well flowing from the back side at -30 bph. Shut Hydril, annular pressure 47 psi. Wait on cement 03:00 - 03: 15 0.25 CEMT P COMP Open kill line, well still flowing. Bleed off -1 0 bbl from the backside. Shut in Hydril, annular pressure 24 psi 03:15 - 07:30 4.25 CEMT P COMP Wait on cement. 07:30 - 08:30 1.00 WHSUR P COMP Back out landing joint. Install packoff and test to 5000 psi - OK 08:30 - 09:30 1.00 RUNCOIVP COMP Rig up 3-1/2" tbg equipment. MU tbg hanger, make dummy run 09:30 - 17:30 8.00 RUNCOIVP COMP Run 3-1/2" 9.2# L-80 tubing. Establish injection rate on 7.625" X 5.5" annulus of 3 bpm @ 375 psi, injected 80 bbl total. 17:30 - 19:00 1.50 RUNCOIVP COMP RU head pin and circulation hose. Pump down and stab into PBR, continue in to no-go. rig down head pin and circulation hose. Space out 19:00 - 20:00 1.00 RUNCOIVP COMP MU tbg hanger and landing jt. RU head pin and circulation hose. Pump down to verify space out - OK 20:00 - 21 :00 1.00 RUNCOIVP COMP Pick up tubing out of PBR. reverse circulate 74 bbls clean seawater followed by 43 bbls corrosion inhibited seawater. 4bpm @ 750 psi. 21 :00 - 22:00 1.00 RUNCOIVP COMP Land tbg with seal assembly -15' into seal receptacle. RILDS. Back out landing joint. 22:00 - 23:30 1.50 RUNCOIVP COMP Pressure test tbg to 4000 psi for 30 min. - OK, bleed down tbg press. to 2500 psi. Pressure test annulus to 4000 psi for 30 min. - OK. bleed down tbg and annulus pressure to 0 psi. Pressure up annulus at 4 bpm, DCK valve sheared at 2700 psi. 23:30 - 00:00 0.50 RUNCOIVP COMP Install TWC and test to 1000 psi from below - OK 4/1/2003 00:00 - 01 :30 1.50 BOPSUR P COMP ND BOPE 01 :30 - 04:00 2.50 WHSUR P COMP NU tree and adapter. Test tree, adapter and packoff to 5000 psi - OK Printed: 4/8/2003 9:04:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . Date From - To 4/1/2003 04:00 - 04:30 04:30 - 09:00 09:00 - 10:00 10:00 -12:00 ) ) BP Ope.rationsSummary Report Page.? of 7 L-118 L-118 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 3/21/2003 Rig Release: 4/1/2003 Rig Number: Spud Date: 3/22/2003 End: 4/1/2003 Description of Operations 0.50 WHSUR P 4.50 WHSUR P COMP COMP RU DSM. Pull TWC with lubricator. RD DSM RU Little Red. Freeze protect 3.5" X 5.5" annulus - reverse circulate 99 bbl diesel, allow to U-tube. Freeze protect 7.625" X 5.5" annulus - inject 46 bbl diesel Set BPV w/ DSM. Test to 1000 psi-OK. Blow down lines. Remove secondary annulus valve. Secure tree & cellar. Rig released @ 1200 hrs on 4/1/2003. 1.00 WHSUR P 2.00 RIGD P COMP COMP Printed: 4/8/2003 9:04:38 AM ) ) Well: Field: API: Permit: Date L-118 Prudhoe Bay Unit 50-029-23043-00 201-187 Accept: Spud: Release: Rig: 03/21/03 03/22/03 04/01/03 Nabors 9ES PRE-RIG WORK 04/15/03 PULL BPV - SET 3-1/2 X-CATCHER SUB - RAN IN TO PULL SHEAR VALVE - PULL STA-1 (NOT A SHEAR VALVE, IS A DUMMY) - PULL STA-4 (DMMY) - ATTEMPT TO PULL STA-2 CAME BACK WI NO VALVE - RAN LIB TO STA-2 NO VALVE - RAN LIB TO C-SUB NO VALVE 04/16/03 RE-SET X-CATCHER SUB - RUN LIB TO STA-1 FOUND SHEAR VALVE - PULLED SHEAR VALVE - SET 1" DGLV (I NT) STA-4 - SET 1" DGLV (INT) STA-2 - SET 1" DGLV STA-1 - MIT-IA TO 4000# (PASS WI NO PRESSURE LOSS DURING 2ND TEST) - D&T 2-1/2 DG TO 8830' SLM (BELOW TARGET). WELL LEFT SI. 04/17/03 LOGGED GR-CCL-TEMP JEWELRY LOG FROM TD (TAGGED TD @ 8834' MD) TO SURFACE. PERFORATED FROM 8726'-8776' MD (SWS VISION LOG - 29.MAR.03) W/10 DEG OFFSET FROM BOTTOM IN 2 GUN RUNS OF 2.5/1 HSD PF-2506 6-SPF GUNS. PULLED 500# OVERPULL AFTER SHOOTING 2ND GUN. SLACKED OFF AND PULLED FREE. POOH. NOTIFIED PAD OPERATOR WELL IS TO BE LEFT SHUT IN. 04/20/03 PERFORMED SUCCESSFUL SBHP SURVEY. LEFT WELL SHUT IN. 04/21/03 FRAC'D KUPARUK C4-- C1 WITH YF125LG AND 202.2 K# OF 16/20 C-LlTE. EXPERIENCED NWB SIO TO 8000 PSI WHEN 10 PPGA HIT PERFS. PLACED 180.5 K# BEHIND PIPE, LEFT 23.5 K# IN CSG (38.6 BBLS PROP). TOS - SAND TO SURFACE. MAX TREAT = 7990 PSI, AVG TREAT= 4900 PSI. LOAD TO RECOVER= 1862 BBLS, TBG IS NOT FREEZE PROTECTED. 1.0. HEATER LEFT ON IN WELLHOUSE. RECOVERED TREESAVER DRIVE CUP BUT LOST THE SEALING CUP (2.98/1 O.D X 1.25/1 H X 1/4" THICK RUBBER ELEMENT) IN TREE. 04/22/03 MADE SEVERAL ATTEMPTS TO FISH OUT TREE SAVER WI ASSORT. WIRE GRABS WI NO SUCCESS. LEFT WELL SHUT IN. 04/23/03 RBIH AND JET SAND FROM 3200 TO 8600. PUMP FLO-PRO PILL AND CHASE OUT AT 80%. RBIH AND CLEAN OUT FROM 8600' TO 8800' CTM USING HEC SWEEPS. AFTER OPENING PERFS, LOSSES WERE UP TO 70%. POOH AT 70% BASED ON RETURNS RATE. FREEZE PROTECT WELL TO 3000' WITH NEAT METH. LEFT WELL SHUT IN. JOB COMPLETE. 04/25/03 DRIFT WI 2.60 CENT, TD @ 8763WLM. SET X-CATCHER SUB @ 8420WLM. . PULL SAT # 4,2,1 DGLVS. SET STA # 1 OGLV @8372 WLM. 04/26/03 SET STA #2 @ 7662 WLM, 1786 TRO, 16/64 PORT. SET STA #4 @ 4774 WLM, 1746 TRO, 16/64 PORT. PULL CIS @ 8420 WLM. LEFT WELL SII. 05/11/03 HOT OIL IA WITH DSL, BEGINNING PSI TIIIOI = 01010 PUMPED 100 BBLS HOT DSL AND 20 BBLS NEAT METH END PSI = TIIIO = 320/300/4001. bp L-118 Survey Report - Geodetic Schlumbepgep Report Date: 29-Mar-03 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 27.320° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: L-Pad 1L-118 TVD Reference Datum: KB Well: L-118 TVD Reference Elevation: 76.900 ft relative to MSL Borehole: L-118 Sea Bed I Ground Level Elevation: 44.100 ft relative to MSL UWUAPI#: 500292304300 Magnetic Declination: +25.588° Survey Name I Date: L-1181 March 29, 2003 Total Field Strength: 57511.847 nT Tort I AHD I DDII ERD ratio: 163.049° /5158.67 ft 16.0491 0.764 Magnetic Dip: 80.785° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: April 03, 2003 -- Location Lat/Long: N 70.35060808, W 149.32497053 Magnetic Declination Model: BGGM 2002 Location Grid N/E YIX: N 5978271.550 ftUS, E 583141.710 ftUS North Reference: True North Grid Convergence Angle: +0.63572444° Total Corr Mag North -> True North: +25.588° Grid Scale Factor: 0.99990785 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (°11 DOft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5978271.55 583141.71 N 70.35060808 W 149.32497053 100.00 0.59 35.51 100.00 0.51 0.42 0.30 0.59 5978271.97 583142.00 N 70.35060923 W 149.32496810 200.00 1.25 28.88 199.98 2.11 1.79 1.12 0.67 5978273.36 583142.81 N 70.35061298 W 149.32496140 300.00 1.78 27.10 299.95 4.75 4.13 2.36 0.53 5978275.71 583144.02 N 70.35061937 W 149.32495138 400.00 3.09 21.72 399.86 8.99 8.02 4.06 1.33 5978279.61 583145.68 N 70.35062998 W 149.32493754 500.00 3.31 20.54 499.70 14.54 13.22 6.07 0.23 5978284.84 583147.64 N 70.35064421 W 149.32492122 600.00 3.92 20.52 599.50 20.80 19.13 8.29 0.61 5978290.77 583149.78 N 70.35066034 W 149.32490327 700.00 4.54 16.76 699.23 28.08 26.12 10.63 0.68 5978297.78 583152.04 N 70.35067944 W 149.32488427 754.92 5.55 16.42 753.94 32.83 30.75 12.00 1.84 5978302.43 583153.37 N 70.35069209 W 149.32487309'-" 846.95 6.58 23.83 845.45 42.46 39.84 15.39 1.40 5978311.56 583156.66 N 70.35071693 W 149.32484558 940.40 8.54 19.96 938.08 54.69 51.26 19.92 2.17 5978323.03 583161.06 N 70.35074813 W 149.32480879 1033.47 12.06 24.36 1029.64 71.26 66.62 26.30 3.87 5978338.45 583167.26 N 70.35079008 W 149.32475706 1126.90 16.00 21.00 1120.27 93.81 87.54 34.94 4.30 5978359.47 583175.67 N 70.35084724 W 149.32468689 1219.85 19.66 22.21 1208.74 122.13 113.99 45.44 3.96 5978386.02 583185.88 N 70.35091948 W 149.32460161 1313.31 21.94 21.98 1296.10 155.18 144.74 57.92 2.44 5978416.91 583198.02 N 70.35100349 W 149.32450030 1406.94 26.08 20.00 1381.61 193.02 180.31 71.52 4.50 5978452.63 583211.21 N 70.35110068 W 149.32438995 1499.61 30.79 20.11 1463.08 236.78 221.75 86.65 5.08 5978494.23 583225.88 N 70.35121388 W 149.32426711 1589.37 35.57 22.19 1538.19 285.61 267.52 104.42 5.47 5978540.19 583243.14 N 70.35133893 W 149.32412285 L-118 ASP Final Survey.xls Schlumberger Private Page 1 of 4 5/15/2003-4: 18 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NI-S EJ-W DLS Northing Easting Latitude Longitude (ft) n (0) (ft) (ft) (ft) (ft) (°/1000) (ftUS) (ftUS) 1683.45 38.26 22.67 1613.40 341 .90 319.75 125.98 2.88 5978592.65 583264.12 N 70.35148160 W 149.32394777 1777.00 40.71 22.28 1685.59 401.17 374.71 148.71 2.63 5978647.86 583286.24 N 70.35163176 W 149.32376320 1870.38 43.36 21.14 1754.95 463.39 432.80 171.83 2.95 5978706.19 583308.71 N 70.35179046 W 149.32357556 1963.34 47.10 21.27 1820.40 529.00 494.32 195.69 4.02 5978767.96 583331 .89 N 70.35195851 W 149.32338176 2055.58 51.57 22.13 1880.50 598.61 559.30 221.57 4.90 5978833.23 583357.04 N 70.35213604 W 149.32317164 2148.32 52.63 21.66 1937.46 671 .46 627.20 248.86 1.21 5978901.42 583383.57 N 70.35232153 W 149.32295009 2240.95 51.93 21.27 1994.13 744.35 695.39 275.67 0.83 5978969.89 583409.63 N 70.35250782 W 149.32273239 2334.55 53.37 19.94 2050.92 818.24 765.04 301.85 1.91 5979039.82 583435.03 N 70.35269808 W 149.32251984 2427.66 53.51 19.60 2106.38 892.38 835.42 327.15 0.33 5979110.47 583459.54 N 70.35289035 W 149.32231444 2521.54 52.76 19.31 2162.70 966.78 906.24 352.16 0.84 5979181.55 583483.77 N 70.35308382 W 149.32211130·__' 2614.65 52.01 19.30 2219.53 1039.82 975.85 376.55 0.81 5979251 .42 583507.37 N 70.35327398 W 149.32191330 2708.54 52.25 18.75 2277.17 1113.16 1045.91 400.71 0.53 5979321.75 583530.75 N 70.35346539 W 149.32171712 2801.71 53.53 18.59 2333.38 1186.61 1116.30 424.49 1.38 5979392.39 583553.75 N 70.35365769 W 149.32152398 2895.31 53.26 18.69 2389.20 1260.89 1187.50 448.51 0.30 5979463.84 583576.97 N 70.35385219 W 149.32132895 2989.80 52.84 18.54 2446.00 1335.53 1259.06 472.61 0.46 5979535.66 583600.28 N 70.35404768 W 149.32113321 3083.71 55.21 19.35 2501.16 1410.72 1330.94 497.29 2.62 5979607.80 583624.16 N 70.35424403 W 149.32093278 3177.30 55.10 18.72 2554.63 1486.72 1403.55 522.34 0.56 5979680.67 583648.40 N 70.35444239 W 149.32072934 3251.57 54.99 18.46 2597.18 1546.89 1461.24 541.75 0.32 5979738.57 583667.16 N 70.35460000 W 149.32057174 3322.06 55.43 21.08 2637.41 1604.27 1515.71 561.33 3.12 5979793.25 583686.14 N 70.35474880 W 149.32041271 3414.32 55.52 22.05 2689.70 1679.90 1586.40 589.27 0.87 5979864.24 583713.29 N 70.35494191 W 149.32018582 3507.78 56.24 21.67 2742.12 1756.92 1658.21 618.07 0.84 5979936.36 583741.29 N 70.35513808 W 149.31995186 3603.22 57.14 21.54 2794.53 1836.28 1732.36 647.44 0.95 5980010.83 583769.83 N 70.35534066 W 149.31971335 3695.93 55.58 21.52 2845.89 1913.07 1804.16 675.77 1.68 5980082.93 583797.36 N 70.35553679 W 149.31948330 3789.84 54.48 21.95 2899.72 1989.66 1875.64 704.26 1.23 5980154.71 583825.05 N 70.35573207 W 149.31925187 3882.71 54.30 22.15 2953.79 2064.84 1945.62 732.61 0.26 5980225.00 583852.62 N 70.35592324 W 149.31902165 3975.99 54.86 22.56 3007.85 2140.57 2015.93 761.52 0.70 5980295.61 583880.75 N 70.35611530 W 149.31878681·~ 4068.38 53.83 21.13 3061.71 2215.29 2085.60 789.46 1.68 5980365.58 583907.91 N 70.35630563 W 149.31855989 4161.39 54.14 20.00 3116.40 2290.00 2156.04 815.88 1.04 5980436.30 583933.55 N 70.35649805 W 149.31834525 4255.25 52.90 18.58 3172.20 2364.73 2227.26 840.82 1.80 5980507.79 583957.69 N 70.35669262 W 149.31814269 4348.72 52.71 17.51 3228.71 2438.21 2298.05 863.88 0.93 5980578.83 583979.96 N 70.35688601 W 149.31795533 4442.48 51.81 18.28 3286.10 2511.35 2368. 61 886.66 1.16 5980649.63 584001.96 N 70.35707876 W 149.31777028 4536.33 50.62 20.76 3344.89 2583.82 2437.56 911.09 2.42 5980718.84 584025.62 N 70.35726711 W 149.31757185 4628.15 51.20 21.88 3402.79 2654.69 2503.94 937.00 1.14 5980785.50 584050.79 N 70.35744846 W 149.31736135 4721.58 51.83 23.34 3460.93 2727.58 2571.45 965.12 1.40 5980853.31 584078.15 N 70.35763288 W 149.31713293 4814.78 51.05 23.14 3519.03 2800.27 2638.42 993.88 0.85 5980920.58 584106.16 N 70.35781580 W 149.31689933 Schlumberger Private L-118 ASP Final SUNey.xls Page 2 of 4 5/15/2003-4: 18 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NI-S Ej-W DLS Northing Easting Latitude Longitude (ft) (") (") (ft) (ft) (ft) (ft) ("/100ft) (ftUS) (ftUS) 4907.42 50.19 23.02 3577.80 2871.68 2704.29 1021.95 0.93 5980986.76 584133.50 N 70.35799576 W 149.31667129 5000.76 49.82 23.47 3637.79 2943.01 2769.99 1050.17 0.54 5981052.76 584160.99 N 70.35817524 W 149.31644204 5093.99 50.64 23.16 3697.43 3014.49 2835.80 1078.53 0.92 5981118.87 584188.61 N 70.35835501 W 149.31621164 5187.48 50.60 20.29 3756.76 3086.39 2902.92 1105.27 2.37 5981186.28 584214.61 N 70.35853836 W 149.31599437 5280.32 53.64 19.49 3813.75 3159.05 2971.82 1130.19 3.34 5981255.44 584238.76 N 70.35872658 W 149.31579193 5373.86 53.47 20.95 3869.32 3233.71 3042.42 1156.20 1.27 5981326.33 584263.97 N 70.35891946 W 149.31558065 5467.09 53.13 21.39 3925.04 3308.03 3112.13 1183.19 0.53 5981396.32 584290.19 N 70.35910987 W 149.31536133 5561.20 50.86 22.16 3982.98 3381.83 3180.99 1210.69 2.50 5981465.48 584316.92 N 70.35929798 W 149.31513791 5654.72 50.72 23.03 4042.10 3454.05 3247.89 1238.53 0.74 5981532.68 584344.01 N 70.35948073 W 149.31491171 5746.59 51.41 25.08 4099.84 3525.39 3313.14 1267.66 1.89 5981598.23 584372.42 N 70.35965897 W 149.31467503~/ 5841.38 51.59 25.71 4158.85 3599.53 3380.15 1299.48 0.55 5981665.59 584403.48 N 70.35984203 W 149.31441655 5934.77 51.21 28.23 4217.12 3672.50 3445.19 1332.57 2.15 5981730.99 584435.85 N 70.36001970 W 149.31414769 6027.56 51.17 32.37 4275.29 3744.68 3507.60 1369.03 3.48 5981793.79 584471.62 N 70.36019016 W 149.31385144 6119.64 51.90 36.86 4332.59 3816.16 3566.90 1409.98 3.90 5981853.53 584511.90 N 70.36035214 W 149.31351877 6213.46 52.13 39.48 4390.33 3888.77 3625.02 1455.68 2.21 5981912.16 584556.94 N 70.36051091 W 149.31314756 6306.79 52.24 42.35 4447.56 3960.42 3680.73 1503.96 2.43 5981968.39 584604.60 N 70.36066306 W 149.31275533 6400.33 51.28 42.62 4505.46 4031.33 3734.91 1553.58 1.05 5982023.11 584653.61 N 70.36081105 W 149.31235223 6493.84 50.27 43.06 4564.59 4101.13 3788.02 1602.83 1.14 5982076.76 584702.26 N 70.36095613 W 149.31195210 6586.13 48.55 43.57 4624.64 4168.50 3839.02 1650.90 1.91 5982128.28 584749.76 N 70.36109541 W 149.31156155 6679.25 47.25 43.26 4687.07 4234.88 3889.20 1698.39 1.42 5982178.99 584796.69 N 70.36123249 W 149.31117577 6772.08 45.35 43.21 4751.20 4299.42 3938.09 1744.36 2.05 5982228.38 584842.11 N 70.36136603 W 149.31080229 6865.43 44.51 43.03 4817.29 4362.85 3986.22 1789.42 0.91 5982277.00 584886.63 N 70.36149746 W 149.31043618 6958.47 43.69 42.55 4884.10 4425.25 4033.73 1833.41 0.95 5982324.99 584930.08 N 70.36162723 W 149.31007882 7051.63 40.93 44.34 4952.99 4485.49 4079.27 1876.50 3.23 5982371.00 584972.66 N 70.36175161 W 149.30972868 7146.70 37.03 45.45 5026.88 4542.50 4121.64 1918.69 4.17 5982413.83 585014.37 N 70.36186734 W 149.3093859E 7239.70 33.18 45.16 5102.95 4593.36 4159.24 1956.70 4.14 5982451.85 585051.96 N 70.36197004 W 149.30907710~; 7332.75 30.84 46.74 5181.85 4640.10 4193.55 1992.13 2.67 5982486.55 585087.01 N 70.36206373 W 149.30878925 7426.11 27.50 47.49 5263.36 4682.91 4224.52 2025.46 3.60 5982517.88 585119.98 N 70.36214832 W 149.30851849 7520.91 24.32 50.12 5348.62 4721.46 4251.84 2056.58 3.57 5982545.54 585150.80 N 70.36222292 W 149.30826563 7614.84 23.27 50.21 5434.56 4756.38 4276.11 2085.68 1.12 5982570.14 585179.62 N 70.36228922 W 149.30802920 7708.13 22.18 53.33 5520.61 4789.19 4298.42 2113.97 1.74 5982592.76 585207.66 N 70.36235015 W 149.30779939 7801.75 21.04 55.38 5607.65 4819.90 4318.53 2141.97 1.46 5982613.17 585235.44 N 70.36240505 W 149.30757186 7895.09 18.78 57.39 5695.41 4847.70 4336.14 2168.42 2.53 5982631.08 585261.69 N 70.36245316 W 149.30735699 7987.91 14.79 55.70 5784.26 4871.06 4350.88 2190.80 4.33 5982646.06 585283.90 N 70.36249339 W 149.30717515 8080.79 13.30 53.20 5874.36 4891.10 4363.96 2209.15 1.73 5982659.34 585302.10 N 70.36252911 W 149.30702607 Schlumberger Private L-118 ASP Final Survey.xls Page 3 of 4 5/15/2003-4: 18 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NI-S EI-W DLS Northing Easting Latitude Longitude (ft) (0) C) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 8174.39 13.79 48.85 5965.36 4911.17 4377.75 2226.17 1.21 5982673.32 585318.97 N 70.36256677 W 149.30688778 8267.90 14.70 44.33 6055.99 4932.88 4393.57 2242.86 1.54 5982689.32 585335.47 N 70.36260998 W 149.30675222 8360.73 13.85 40.88 6145.96 4954.95 4410.40 2258.36 1.30 5982706.32 585350.79 N 70.36265594 W 149.30662625 8454.74 14.22 38.77 6237.16 4977.20 4427.91 2272.95 0.67 5982723.99 585365.19 N 70.36270376 W 149.30650766 8547.70 12.78 37.78 6327.55 4998.50 4444.94 2286.40 1.57 5982741.16 585378.44 N 70.36275027 W 149.30639837 8640.66 11.09 33.66 6418.50 5017.50 4460.51 2297.66 2.03 5982756.85 585389.52 N 70.36279280 W 149.30630690 8733.87 9.53 33.65 6510.20 5034.08 4474.39 2306.90 1.67 5982770.84 585398.61 N 70.36283072 W 149.30623177 8826.36 9.34 34.44 6601 .44 5049.14 4486.96 2315.39 0.25 5982783.49 585406.96 N 70.36286504 W 149.30616280 8918.97 8.18 33.56 6692.97 5063.15 4498. 64 2323.28 1.26 5982795.27 585414.72 N 70.36289696 W 149.30609866 8926.13 8.11 33.09 6700.06 5064.15 4499.49 2323.84 1.35 5982796.12 585415.27 N 70.36289928 W 149.30609413~/ 8980.00 8.11 33.09 6753.39 5071.72 4505.86 2327.99 0.00 5982802.53 585419.35 N 70.36291667 W 149.30606042 ~ L-118 ASP Final Survey. xis Schlumberger Private Page 4 of 4 5/15/2003-4: 18 PM Ì'- ~ ~ Ç) ({S ANADRILL SCHLUMBERGER Survey report Client........... ........: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Borealis Well.....................: L-118 API number...............: 50-029-23043-00 Engineer. .......... ......: St. Amour ~~TY:............ ......: Nabors 9ES :::, _A.TE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..... .....: Drill Floor GL above permanent.... ...: 48.70 ft KB above permanent... ....: N/A Top Drive Used DF above permanent.......: 76.90 ft ----- Vertical section origin---------------- Latitude (+N/S-)... ......: 0.00 ft Departure (+E/W-).. ......: 0.00 ft ,/~ -- Platform reference point--------------- La tit ude ( + N / S -) . . . . . . . . . : - 999 . 25 f t Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 27.20 degrees [(c)2003 Anadrill IDEAL ID6_1C_10J 29-Mar-2003 01:16:10 Spud date.. . . .. . . . . . . . . . . : Last survey date...... ...: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 5 22-Mar-03 29-Mar-03 99 0.00 ft 8980.00 ft ----- Geomagnetic data ---------------------- Magnetic model. .... ... ...: BGGM version 2002 Magnetic date.. ..........: 18-Mar-2003 Magnetic field strength..: 1150.24 HCNT Magnetic dec (+E/W-).....: 25.60 degrees Magnetic dip.......... ...: 80.78 degrees ----- MWD survey Reference Reference G..............: Reference H.... ..........: Reference Dip.. ... .......: Tolerance of G.... .......: Tolerance of H...........: Tolerance of Dip. ........: Criteria --------- 1002.68 mGal 1150.24 HCNT 80.79 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.60 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.60 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N). .......: No degree: 0.00 [ (c) 2003 Anadrill IDEAL ID6__1C_10J ANADRILL SCHLUMBERGER Survey Report 29-Mar-2003 01:16:10 Page 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 100.00 0.59 35.51 100.00 100.00 0.51 0.42 0.30 0.51 35.51 0.59 GYR 3 200.00 1.25 28.88 100.00 199.98 2.11 1.79 1.12 2.12 32.10 0.67 GYR 4 300.00 1.78 27.10 100.00 299.95 4.75 4.13 2.36 4.76 29.73 0.53 GYR 5 400.00 3.09 21.72 100.00 399.86 8.99 8.02 4.06 8.99 26.88 1.33 GYR .- 6 500.00 3.31 20.54 100.00 499.70 14.54 13.22 6.07 14.55 24.67 0.23 GYR 7 600.00 3.92 20.52 100.00 599.50 20.80 19.13 8.29 20.85 23.42 0.61 GYR 8 700.00 4.54 16.76 100.00 699.23 28.09 26.12 10.63 28.20 22.14 0.68 GYR 9 754.92 5.55 16.42 54.92 753.94 32.84 30.75 12.00 33.01 21.32 1.84 MWD I FR MSA 10 846.95 6.58 23.83 92.03 845.45 42.47 39.84 15.39 42.71 21.12 1.40 MWD I FR MSA 11 940.40 8.54 19.96 93.45 938.08 54.70 51.26 19.92 55.00 21.24 2.17 MWD IFR MSA 12 1033.47 12.06 24.36 93.07 1029.64 71.27 66.62 26.29 71.62 21.54 3.87 MWD I FR MSA 13 1126.90 16.00 21.00 93.43 1120.27 93.83 87.54 34.94 94.26 21.76 4.30 MWD IFR MSA 14 1219.85 19.66 22.21 92.95 1208.74 122.15 113.99 45.44 122.71 21.74 3.96 MWD I FR MSA 15 1313.31 21.94 21.98 93.46 1296.10 155.21 144.74 57.92 155.90 21.81 2.44 MWD IFR MSA 16 1406.94 26.08 20.00 93.63 1381.61 193.06 180.31 71.52 193.98 21.63 4.50 MWD I FR MSA 17 1499.61 30.79 20.11 92.67 1463.08 236.83 221.75 86.65 238.08 21.34 5.08 MWD IFR MSA 18 1589.37 35.57 22.19 89.76 1538.19 285.67 267.52 104.42 287.18 21.32 5.47 MWD I FR MSA 19 1683.45 38.26 22.67 94.08 1613.40 341.98 319.75 125.98 343.67 21.50 2.88 MWD IFR MSA 20 1777.00 40.71 22.28 93.55 1685.59 401.25 374.71 148.71 403.15 21.65 2.63 MWD IFR MSA f~ .1 1870.38 43.36 21.14 93.38 1754.95 463.48 432.80 171.83 465.66 21.65 2.95 MWD I FR MSA 22 1963.34 47.10 21.27 92.96 1820.40 529.11 494.32 195.69 531.65 21.60 4.02 MWD I FR MSA 23 2055.58 51.57 22.13 92.24 1880.50 598.74 559.30 221.57 601.59 21.61 4.90 MWD I FR MSA 24 2148.32 52.63 21.66 92.74 1937.46 671.60 627.20 248.86 674.77 21.64 1.21 MWD I FR MSA 25 2240.95 51.93 21.27 92.63 1994.13 744.50 695.39 275.67 748.04 21.62 0.83 MWD I FR MSA 26 2334.55 53.37 19.94 93.60 2050.92 818.41 765.04 301.85 822.43 21.53 1.91 MWD I FR MSA 27 2427.66 53.51 19.60 93.11 2106.38 892.57 835.42 327.15 897.19 21.39 0.33 MWD IFR MSA 28 2521.54 52.76 19.31 93.88 2162.70 967.00 906.24 352.16 972.26 21.24 0.84 MWD IFR MSA 29 2614.65 52.01 19.30 93.11 2219.53 1040.05 975.85 376.55 1045.97 21.10 0.81 MWD IFR MSA 30 2708.54 52.25 18.75 93.89 2277.17 1113.42 1045.91 400.71 1120.05 20.96 0.53 MWD I FR MSA [(c)2003 Anadrill IDEAL ID6 lC_10J ANADRILL SCHLUMBERGER Survey Report 29-Mar-2003 01:16:10 Page 3 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2801.71 53.53 18.59 93.17 2333.38 1186.89 1116.30 424.49 1194~29 20.82 1.38 MWD IFR MSA 32 2895.31 53.26 18.69 93.60 2389.20 1261.19 1187.50 448.51 1269.38 20.69 0.30 MWD IFR MSA 33 2989.80 52.84 18.54 94.49 2446.00 1335.86 1259.06 472.61 1344.84 20.57 0.46 MWD IFR MSA 34 3083.71 55.21 19.35 93.91 2501.16 1411.07 1330.94 497.29 1420.81 20.49 2.62 MWD IFR MSA 35 3177.30 55.10 18.72 93.59 2554.63 1487.10 1403.55 522.34 1497.59 20.41 0.56 MWD I FR MSA ~·6 3251.57 54.99 18.46 74.27 2597.18 1547.28 1461.24 541.75 1558.43 20.34 0.32 MWD IFR MSA J7 3322.06 55.43 21.08 70.49 2637.41 1604.68 1515.71 561.33 1616.31 20.32 3.12 MWD IFR MSA 38 3414.32 55.52 22.05 92.26 2689.70 1680.32 1586.40 589.27 1692.30 20.38 0.87 MWD IFR MSA 39 3507.78 56.24 21.67 93.46 2742.12 1757.36 1658.21 618.07 1769.65 20.44 0.84 MWD I FR MSA 40 3603.22 57.14 21.54 95.44 2794.53 1836.74 1732.36 647.44 1849.40 20.49 0.95 MWD IFR MSA 41 3695.93 55.58 21.52 92.71 2845.89 1913.54 1804.16 675.77 1926.56 20.53 1.68 MWD IFR MSA 42 3789.84 54.48 21.95 93.91 2899.72 1990.14 1875.64 704.26 2003.50 20.58 1.23 MWD IFR MSA 43 3882.71 54.30 22.15 92.87 2953.79 2065.34 1945.62 732.61 2078.98 20.63 0.26 MWD IFR MSA 44 3975.99 54.86 22.56 93.28 3007.85 2141.09 2015.93 761.52 2154.96 20.69 0.70 MWD IFR MSA 45 4068.38 53.83 21.13 92.39 3061.71 2215.83 2085.60 789.46 2230.02 20.73 1.68 MWD IFR MSA 46 4161.39 54.14 20.00 93.01 3116.40 2290.55 2156.04 815.88 2305.25 20.73 1.04 MWD IFR MSA 47 4255.25 52.90 18.58 93.86 3172.20 2365.30 2227.26 840.82 2380.69 20.68 1.'80 MWD IFR MSA 48 4348.72 52.71 17.51 93.47 3228.71 2438.81 2298.05 863.88 2455.07 20.60 0.93 MWD_IFR_MSA 49 4442.48 51.81 18.28 93.76 3286.10 2511.97 2368.61 886.66 2529.13 20.52 1.16 MWD IFR MSA 50 4536.33 50.62 20.76 93.85 3344.89 2584.46 2437.56 911.09 2602.26 20.49 2.42 MWD IFR MSA /--. ,1 4628.15 51.20 21.88 91.82 3402.79 2655.35 2503.94 937.00 2673.52 20.52 1.14 MWD IFR MSA 52 4721.58 51.83 23.34 93.43 3460.93 2728.25 2571.45 965.12 2746.60 20.57 1.40 MWD IFR MSA 53 4814.78 51.05 23.14 93.20 3519.03 2800.95 2638.42 993.88 2819.40 20.64 0.85 MWD IFR MSA 54 4907.42 50.19 23.02 92.64 3577.80 2872.37 2704.29 1021.95 2890.94 20.70 0.93 MWD IFR MSA 55 5000.76 49.82 23.47 93.34 3637.79 2943.71 2769.99 1050.17 2962.38 20.76 0.54 MWD IFR MSA 56 5093.99 50.64 23.16 93.23 3697.43 3015.20 2835.80 1078.53 3033.97 20.82 0.92 MWD IFR MSA 57 5187.48 50.60 20.29 93.49 3756.76 3087.12 2902.92 1105.27 3106.21 20.84 2.37 MWD IFR MSA 58 5280.32 53.64 19.49 92.84 3813.75 3159.79 2971.82 1130.19 3179.47 20.82 3.34 MWD I FR MSA 59 5373.86 53.47 20.95 93.54 3869.32 3234.48 3042.42 1156.20 3254.71 20.81 1.27 MWD IFR MSA 60 5467.09 53.13 21.39 93.23 3925.04 3308.81 3112.13 1183.19 3329.46 20.82 0.53 MWD IFR MSA ANADRILL SCHLUMBERGER Survey Report 29-Mar-2003 01:16:10 Page 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/s- +E/w- displ Azim (degl tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 61 5561.20 50.86 22.16 94.11 3982.98 3382.63 3180.99 1210.69 3403.60 20.84 2.50 MWD IFR MSA 62 5654.72 50.72 23.03 93.52 4042.10 3454.86 3247.89 1238.53 3476.02 20.87 0.74 MWD IFR MSA 63 5746.59 51.41 25.08 91.87 4099.84 3526.20 3313.14 1267.66 3547.37 20.94 1.89 MWD IFR MSA 64 5841.38 51.59 25.71 94.79 4158.85 3600.35 3380.15 1299.48 3621.33 21.03 0.55 MWD I FR MSA 65 5934.77 51.21 28.23 93.39 4217.12 3673.32 3445.19 1332.57 3693.93 21.15 2.15 MWD I FR MSA .-- '6 6027.56 51.17 32.37 92.79 4275.29 3745.50 3507.60 1369.03 3765.30 21.32 3.48 MWD IFR MSA 07 6119.64 51.90 36.86 92.08 4332.59 3816.96 3566.90 1409.98 3835.47 21.57 3.90 MWD I FR MSA 68 6213.46 52.13 39.48 93.82 4390.33 3889.54 3625.02 1455.68 3906.37 21.88 2.21 MWD IFR MSA 69 6306.79 52.24 42.35 93.33 4447.56 3961.15 3680.73 1503.96 3976.13 22.23 2.43 MWD IFR MSA 70 6400.33 51.28 42.62 93.54 4505.46 4032.02 3734.91 1553.58 4045.13 22.59 1.05 MWD IFR MSA 71 6493.84 50.27 43.06 93.51 4564.59 4101.78 3788.02 1602.83 4113.17 22.93 1.14 MWD IFR MSA 72 6586.13 48.55 43.57 92.29 4624.64 4169.11 3839.02 1650.90 4178.94 23.27 1.91 MWD IFR MSA 73 6679.25 47.25 43.26 93.12 4687.07 4235.45 3889.20 1698.39 4243.87 23.59 1.42 MWD IFR MSA 74 6772.08 45.35 43.21 92.83 4751.20 4299.95 3938.09 1744.36 4307.13 23.89 2.05 MWD IFR MSA 75 6865.43 44.51 43.03 93.35 4817.29 4363.35 3986.22 1789.42 4369.43 24.18 0.91 MWD IFR MSA 76 6958.47 43.69 42.55 93.04 4884.10 4425.71 4033.73 1833.41 4430.84 24.44 0.95 MWD IFR MSA 77 7051.63 40.93 44.34 93.16 4952.99 4485.91 4079.27 1876.50 4490.18 24.70 3.23 MWD I FR MSA 78 7146.70 37.03 45.45 95.07 5026.88 4542.88 4121.64 1918.69 4546.35 24.96 4.17 MWD I FR MSA 79 7239.70 33.18 45.16 93.00 5102.95 4593.70 4159.24 1956.70 4596.52 25.19 4.14 MWD IFR MSA 80 7332.75 30.84 46.74 93.05 5181.85 4640.41 4193.55 1992.13 4642.67 25.41 2.67 MWD I FR MSA ~, 11 7426.11 27.50 47.49 93.36 5263.35 4683.19 4224.52 2025.46 4684.98 25.62 3.60 MWD IFR MSA 82 7520.91 24.32 50.12 94.80 5348.62 4721.71 4251.84 2056.58 4723.09 25.81 3.57 MWD IFR MSA 83 7614.84 23.27 50.21 93.93 5434.56 4756.60 4276.11 2085.68 4757.65 26.00 1.12 MWD IFR MSA 84 7708.13 22.18 53.33 93.29 5520.61 4789.38 4298.42 2113.97 4790.12 26.19 1.74 MWD IFR MSA 85 7801.75 21.04 55.38 93.62 5607.65 4820.06 4318.53 2141.97 4820.55 26.38 1.46 MWD IFR MSA 86 7895.09 18.78 57.39 93.34 5695.41 4847.82 4336.14 2168.42 4848.11 26.57 2.53 MWD IFR MSA 87 7987.91 14.79 55.70 92.82 5784.26 4871.15 4350.88 2190.80 4871.32 26.73 4.33 MWD I FR MSA 88 8080.79 13.30 53.20 92.88 5874.36 4891.18 4363.96 2209.15 4891.27 26.85 1.73 MWD IFR MSA 89 8174.39 13.79 48.85 93.60 5965.36 4911.22 4377.75 2226.17 4911.27 26.95 1.21 MWD IFR MSA 90 8267.90 14.70 44.33 93.51 6055.99 4932.92 4393.57 2242.86 4932.94 27.04 1.54 MWD IFR MSA ·~" [(c)2003 Anadrill IDEAL ID6_1C_10J . " ' ANADRILL SCHLUMBERGER Survey Report 29-Mar-2003 01:16:10 Page 5 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8360.73 13.85 40.88 92.83 6145.96 4954.97 4410.40 2258.36 4954.98 27.11 1.30 MWD I FR MSA 92 8454.74 14.22 38.77 94.01 6237.16 4977.22 4427.91 2272.95 4977.22 27.17 0.67 MWD IFR MSA 93 8547.70 12.78 37.78 92.96 6327.55 4998.51 4444.94 2286.40 4998.51 27.22 1.57 MWD IFR MSA 94 8640.66 11.09 33.66 92.96 6418.50 5017.50 4460.51 2297.66 5017.50 27.25 2.03 MWD IFR MSA 95 8733.87 9.53 33.65 93.21 6510.20 5034.08 4474.39 2306.90 5034.08 27.27 1.67 MWD IFR MSA -... 5 8826.36 9.34 34.44 92.49 6601.44 5049.13 4486.96 2315.39 5049.14 27.29 0.25 MWD IFR MSA :J7 8918.97 8.18 33.56 92.61 6692.97 5063.14 4498.64 2323.28 5063.15 27.31 1.26 MWD IFR MSA 98 8926.13 8.11 33.09 7.16 6700.06 5064.14 4499.49 2323.84 5064.15 27.31 1.35 MWD IFR MSA 99 8980.00 8.11 33.09 53.87 6753.39 5071.70 4505.86 2327.99 5071.72 27.32 0.00 Projected To TD - .) ) é)¡DJ-ró7 " . -- ,,_.,._--,~.... MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No L-118 Date Dispatched: 19-Mar-03 Installation/Rig Nabors 9ES Dispatched By: Franklin Alabi Data No Of Prints No of Floppies Surveys 2 REC'=IVED APR 2 1 2003 Alaska Oü & Gaa Cons. Cornmilei.vl An,J ~rt.!,e Received By: Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 @ C:-::1 /-\ L:-~.:1 -.J æ). Ju '" ,f (~ .~ J ') ~~~~~~.~~ ) \,'~...... FRANK H. MURKOWSKI, GOVERNOR AlASKA OIL AM) GAS CONSERVATION COMMISSION 333 w. rrn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit L-118 BP Exploration (Alaska) Inc. Permit No: 201-187 (revised) Sur Loc: 2551' NSL, 3773' WEL, SEC. 34, T12N, RIlE, UM Btmhole Loc. 1847' NSL, 1412' WEL, SEC. 27, T12N, RIlE, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does 110t exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pernlits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations 111uSt be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this pennit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~¿?-~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this /Ý'day of February, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section YJ'GI\- -:-//51 Cs 12. Distance to nearest property line 13. Distance to nearest well ADL 028238,1412' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Casina Weiaht Grade CouDlina 34" x 20" 91.5# H-40 Weld 7-5/8" 29.7# L-80 BTC 5-1/2" 15.5# L-80 BTC-M 3-1/2" 9.2# L-80 IBT-M Hole 42" 9-7/8" 6-3/4" 6-3/4" -, STATE OF ALASKA, ALASKA _IL AND GAS CONSERVATION COMM~-,110N PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test B Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Plan RKB = 76.9' Prudhoe Bay Field / Borealis 6. Property Designation Pool (Undefined) ADL 028239 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / L-118 9. Approximate spud da~' 03/05/03 Amount $200,000.00 /' 14. Number of acres in property 15. Pro~ed depth (MD and TVD) 2560 9031' MD / 6753' TVD o 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} / 58 Maximum surface 2543 psig, At total depth (TVD) 6570' I 3200 psig Setting Depth Top Bottom MD TVD MD TVD Surface Surface 110' 110' Surface Surface 3141' 2576' Surface Surface 8681' 6411' 8681' 6411' 9031' 6753' Revised: 02/11/03 '\ 1 a. Type of work B Drill 0 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 583142, Y = 5978272 2551' NSL, 3773' WEL, SEC. 34, T12N, R11E, UM At top of productive interval x = 585400, Y = 5982825 1799' NSL, 1455' WEL, SEC. 27, T12N, R11E, UM At total depth x = 585443, Y = 5982873 1847' NSL, 1412' WEL, SEC. 27, T12N, R11E, UM 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 Lenath 80' 3141' 8681' 350' Quantity of Cement (include staae data) 260 sx Arctic Set (Approx.) 381 sx PF 'L', 200 sx Class 'G' 148 sx Class 'G', 112 sx Class 'G' (5-1/2" x 3-1/2" CementinÇJ ProÇJram) / ./ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner ¡l::~ 1r:: ~i" ~ .;,'f~~: 1~1'~~ t'> Perforation depth: measured IA~aSKa ,'~ (It true vertical 20. Attachments B Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch B Drilling Program B Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report B 20 AAC 25.050 Requirements Contact Engineer Name/Number: Neil Magee, 564-5119 / Prepared By NameJNumber: Terrie Hubble, 564-4628 21. I hereby certify that the for " oing is true)~<;porrect to the best of my ~nowl~~ge . Signed Lowell Crane ~ /~ Title Sentor Drilling Engineer Date;)- J;}. - , ' .- ",.,-': i:om.p¡~!U$t:Qnlï:,;':, ",I, . Permit Number 201-187 Conditions of Approval: API Number Approval Date See cover letter 50- 029-23043-00 10103/01 for other reauirements Samples Required 0 Yes ~ No Mud Log Required 0 Yes ŒI No Hydrogen Sulfide Measures 0 Yes ŒI No Directional Survey Required E1 Yes 0 No Required Working Pressure, for ~OPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: Test-BoPE- to 400ft.":: f' ~l '\ ORIGINAL S.IGNEO BY: comrriissi6n~'( M l, ,Qi¡~ by order of the commission '}~fJ L/~f/J ,"? Date .~ I ,,V? S bmit I Triplicate Approved By Form 10-401 Rev. 12-01-85 . " ) ') I Well Name: IL-118 Drill and Complete Plan Summary I Type of Well (service 1 producer 1 injector): 1 Producer /' Surface Location: As-Built Target Location: Kuparuk Tgt. Bottom Hole Location: x = 583,141.71' Y = 5,978,271.55' 25501 FSL, 37721 FEL, Sec. 34, T12N, R11E X = 585,400' Y = 5,982,825' 17991 FSL, 14551 FEL, Sec. 27,T12N, R11E X = 585,442.76' Y = 5,982,873.44' 18471 FSL, 14111 FEL, Sec. 27,T12N, R11E / // / I AFE Number: 1 BRD5M4030 1 I Estimated Start Date: 13/5/2003 I MD: 19031' 1 TVD: 16753' 1 Rig: 1 Nabors 9ES / I / I Operatin!:l days to complete: 112.6 I 1 BF/MS: 148.5' 1 I RKB: 176.9' I Well Design (conventional, slim hole, etc.): I Microbore (Iongstring) I Objective: 1 Kuparuk Formation Mud Program: 9-7/8" Surface Hole (O-3141 '): Initial below Permafrost interval TD Densitv (ppg) 8.5- 9.2 9.0 - 9.5 / 9.5 max Viscosity (seconds) 250-300 200 150-200 Fresh Water Surface Hole Mud Yield Point Tau 0 API FL (lb/1 OOft~) (mls/30min) 50 - 70 >20 15-20 30 - 45 > 15 <8 20 - 35 > 15 <8 PH 8.5- 9.5 8.5- 9.5 8.5- 9.5 63A" Intermediate 1 Production Hole (3141' - 9031 '): Interval Density Tau 0 YP PV (ppg) 9.7 pH Fresh Water LSND API HTHP Filtrate Filtrate 6-10 Upper Interval Top of HRZ 4-7 27 -32 1 0-15 8.5-9.5 9.8 /1 3-7 17-25 1 0-15 8.5-9.5 4-6 <10 by HRZ L-118 Drilling Program - Draft Page 1 ) ) Hydraulics: Surface Hole: 9 7/8" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-1965' 550 4" 17.5# 130 1600 10.2 N/A 18,18,18,16 .942 1965'-3141 ' 600 4" 17.5# 150 2600 10.4 N/A 18,18,18,16 .942 Production Hole: 6 3M" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 3141 '-9031' 330 4" 17.5# 210 1700 - 2500 11.1 N/A 5X12 .552 Hole Cleaning Criteria: Interval Interval ROP Drill Pump Mud Hole Cleaning Condition Pipe GPM Weight Rotation 110'-2139' Surface Superior hole cleaning practices at to SV-1 connections will greatly enhance cuttings transport particularly in sliding mode 210 60 500 9.5 Acceptable 250 60 600 9.5 Acceptable 300 60 700 9.5 Acceptable 250 90 500 9.5 Acceptable 315 90 600 9.5 Acceptable 300 90 700 9.5 Acceptable 3141 '-6799' To Base ROP's greater than 400'/hr must be Schrader accompanied by a GPM of 330 and fully ,// reamed connections to maintain minimum hole cleaning requirements 250 80 330 9.7 Marginal 250 100 330 9.7 Acceptable 300 80 330 9.7 Marginal/Poor 300 100 330 9.7 Marginal/Manageable 400 80 330 9.7 Very Poor 400 100 330 9.7 Poor 6799'-TD Base ROP's greater than 200'/hr must be Schrader accompanied by maximum pump rates toTD and fully reamed connections to /' maintain minimum hole cleaning requirements 150 80 330 9.8 Acceptable 200 80 330 9.8 Marginal L-118 Drilling Program - Draft Page 2 Directional: Ver. Anadrill P7 Slot NK KOP: 400' Maximum Hole AnQle: Close Approach Wells: Survey Program: LOQQinQ PrOQram: Surface Production Hole Formation Markers: Formation Tops SV6 SV5 SV4 Base Permafrost SV3 SV2 SV1 UG4A UG3 UG1 Ma WS2 (Na sands) WS1 (Oa sands) Obf Base CM2 (Colville) CM1 THRZ BHRZ (Kalubik) K-1 TKUP Kuparuk C LCU Kuparuk B Kuparuk A TMLV (Miluveach) TD Criteria L -118 Drilling Program - Draft ') ) 55 degree~ at 2513' MD All Wells Pass Major Risk Criteria L-117 - 15' Ctr-Ctr to 400' MD L-115 - 29' Ctr-Ctr to 450' MD /"" Standard MWD surveys (IFR+MSA Correction) An electronic gyro survey will be required for surface hole close approach issues to 1000' MD. Drilling: MWD / GR Open Hole: Cased Hole: None Drilling: MWD/GR/PWD/DEN/NEU/RES Open Hole: Cased Hole: TVDss 895' 1475' 1600' 1670' 1955' 2120' 2455' 2770' 3145' 3635' 3925' 4150' 4310' 4700' 4955' 5545' 6105' 6352' 6410' 6435' 6435' 6570' 6715' 6800' Estimated Pore Pressure Hydrocarbon Bearing Hydrocarbon Bearing, 8.6 ppg Hydrocarbon Bearing If.% Hydrocarbon Bearing 2925 psi, 8.7 ppg / Hydrocarbon Bearing 3200 psi, 9.4 ppg 110' below Top Kuparuk B Page 3 ') ) CasinQITubinQ ProQram: ~ - - Hole Csgl Wt/Ft Gra~ Co~ Length Top Btm Size Tbg O.D. MDITVD MDITVD bkb 42" Insulated 91.5# H-40 WLD 80' GL 110/110 34"x20" 9-7/8" 7 5/8" 29.7# L-80 STC 3141' GL 3141 '/2576' 6-3/4" 5-1/2" 15.5# L-80 STC-m 8681' GL 8681 '/6411' 6-3/4" 3-1/2" 9.2# L-80 1ST -mod 350' 8681 '/6411' 9031 '/6753' TubinQ 3-1/2" 9.2# L-80 1ST-Mod 8681' GL 8681 '/6411' InteQrity Testin$1: Test Point Depth Surface Casing Shoe 20' min from su rface shoe Test Type LOT EMW 12.6 ppg (minimum for a 25bbl kick tolerance) /" Cement Calculations: The following surface cement calculations are based upon a single stage job The production cement calculation assumes cement will be required to cover 500' above the top of the Schrader Ma sands with 1000 psi ultimate compressive strength and covering the entire Kuparuk interval with 2000 psi/24 hours compressive strength cement. Casinq Size 17-5/8" Surface I Basis: Lead: Based on 1856' of annulus in the permafrost @ 2250/0 excess and 423' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOe: To surface Tail: Based on 750' MD open hole volume + 300/0 excess + 80' shoe track volume. Tail TOe: At -2389' MD -") Total Cement Volume: Lead 282 bbl I 1582fe /¡ 38,,:k'sks of Halliburton Permafrost L at 10.7 ppg and 4.1pk. Tail 41 bbl I 230 ft;j I OO''Sks of Halliburton Premium 'G' at '" 15.8 ppg and 1.' S'-éf/sk. Casing Size 5-1/2"x3-1/2" Production Longstring Basis: Lead: Based on TOe 500' MD above the top of the Schrader Bluff Ma formation + 300/0 excess and base of cement 500' MD above top of Kuparuk formation. ')IS-8' Tail: Based on TOe 500' MD above top of Kuparuk formation + 300/0 excess + 90' shoe track volume. ,,/'-'\ Total Cement Volume: Lead 62 bbl I 348fe I;i 46Sks of Halliburton Premium 'G' + 15 Ibs/sk Microlit~~ ppg and 2.36 cf/sk. Tail 23 bbl I 130 fe 1¡(1z!sks of Halliburton Premium 'G' (KUP Latex Design) ~.8 ppg and 1.16 cf/sk. L-118 Drilling Program - Draft Page 4 ") ) Well Control: Surface hole will be drilled with diverter. The intermediate and production hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test f70rfuture frac job considerations, the BOP equipment will be tested to 4000 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: 9.4 ppg EMW, 3200 p~@ 6570' TVDss - KUP-B 2543 psi @ su rface (based on 3200 psi at TKUPB and a full column of gas @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 4000 psi (for future frac stimulation treatments) 8.6 ppg filtered seawater / 6.8 ppg Diesel Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. H2S: · H2S has not been recorded on L-Pad wells. As a precaution Standard Operating Procedures for H2S should be followed at all times. / L-118 Drilling Program - Draft Page 5 ') ) DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor was installed November 2001. 1. Weld a FMC landing on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. L-117 and perhaps L-115 well house will have to be removed for the move in. Rig Operations: 1. MIRU Nabors 9ES on Slo~. 2. Nipple up diverter spool and lines. Function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 9 7/8" drilling assembly with MWD/LWD (see page 4) and directionally drill surface hole to approximately 100' TVD above below SV1 sands (see Anadrill directional plan). An intermediate bit ~ trip to surface will be performed prior to exiting the Permafrost. 4. Run and cement the 7-5/8", 29.7# L-80 surface casing back to surface. A Tam port collar will be run /" as a contingency on the chance that cement returns are not seen at the surface. 5. NO diverter spool and NU casing I tubing head. NU BOPE and test to 4000 PSi.'/ 6. MU 6-3/4" drilling assembly with drill mill and MWD/LWD (see page 4) and RIH to float collar. Test the 7-5/8" casing to 3500 psi for 30 minutes. /' 7. Drill out shoe joints and displace well to 9.7 ppg LSND drilling fluid. Drill new formation to 20' below 7- 5/8" shoe and perform Leak Off Test. 8. Drill to ±200' above the HRZ, ensure mud is in good condition at 9.8 ppg and perform short trip as needed. During this time hold the 'Pre-Reservoir' meeting highlighting kick tolerance and detection. / Drill ahead to -110' below top Kuparuk B. 9. Short trip to surface casing shoe and RIH working through any obstruction. Spot a lube pill on bottom and spotting Steel Seal pill from base of Schrader to surface casing shoe. POOH standing back DP. 10. Run and cement the tapered production casing as required from TO to 500' above the Schrader Ma "....- sands. Displace the casing with filtered seawater during cementing operations and freeze protect the 5 Y2" x 7-5/8" annulus as required. 11. Run the 3-1/2",9.2#, L-80 gas lift completion assembly. Circulate around corrosion inhibitor. Sting seal / assembly into tieback receptacle and test to 4000 psi for 30 minutes both the tubing and annulus. Release tubing pressure and shear RP valve. 12. Install TWC and test from below to 1000 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 13. RU hot oil truck and freeze protect the well by reverse circulating in a sufficient volume of diesel to reach the lower GLM. 14. Rig down and move off. .,./ L-118 Drilling Program - Draft Page 6 ') ) L-118 Drilling Program Job 1: MIRU Hazards and Contingencies ~ L-Pad is not designated as an H2S site. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. ~ The closest surface location will be L-117. L-117 will be -15' wellhead to wellhead. The well is expected to be on production and will require a surface shut-in during move in. ~ Check landing ring height on L-118, the BOP nipple up may need review. / Reference RPs .:. ¡¡Drilling! Work over Close Proximity Surface and Subsurface Wells Procedure" ¡'!Nnlm,mmmm:W--)Jm;;:.:'mmmmmmPm;¡m )m,mmWJ/Wmmmmmmmmmm;;.mmmm¡.mmfiA-.-:<"Imm»iM;)MmAA-;';'h·i"MmmmmmmNAA-;~';;.mmmmm~mJJ;.mt.m;;;mmmmmf,"M1Ilþfm»N"mWJm;.AA-mmm.oommmm);m.---f----þ(,-_-.-:f~mNmÞfflmmmmmmm';--------:!,-,-::¡-:þf"-r.)(KiÞI',-'-ff'-'-Þ!''-'-I.X~mP)>>mJ/mmm mK'Immmm;mm;.;;/¡¡m;;.m Job 2: DrillinQ Surface Hole Hazards and Contingencies ~ No faults are expected to be penetrated by L-118 in the surface interval. ~ Drilling Close Approach: The nearest well is L-117 which will have a center-center distance of approximately 15' at the surface. ~ A limited amount of gas hydrates have been observed on the surface holes drilled on L-Pad from the base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to Baroid mud recommendation ~ Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. Reference RPs .:. uPrudhoe Bay Directional Guidelines" .:. uWell Control Operations Station Bill" I,W;»W».IJo.I.I.INh,.,:.,,--'\I,----.'\I,'\I,-w.--"fifI ,'nmAIÞ;..;..,,;;J.<.~,-__\_K',_Xi_--, x-- n.",'",--- --,,-~'1,.)iII.,.;;.-.-._s "..;:.--..-.-:.K;-,þflll"---_r-~Ammfflm;~Io»;W ~~~~-:.-,:,;..-;~-.-.....-.-,-}I!,---NL_.\ JOKI::.»rmNl'WM".·.\_ _\_----.--- -.--~-- -. -::::.:.-.r¡l.vt: Job 3: Install Surface CasinQ Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. Plan 225% excess cement through the permafrost zone and 300/0 excess below the permafrost. A 7-5/8" port collar will be positioned at ±1 OOO'MD to allow a secondary circulation should cement to surface not be achieved. ~ "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement. 2. Cement - Top of tail >500' TVD above shoe, (using 30% excess.) 3. Casing - Shoe set -100' TVD below SV1 sand. L-118 Drilling Program - Draft Page 7 ) ) Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Halliburton Cement Program" .:. "Surface Casing Port Collar Procedure" 1II1II,m:IIIIIIII1:i::It'!II::lllrlllllmllnll:l:mll::II:IIITI1111:"'III:I lmm-:II:I--: I~':11:~I:II,;~'lm:II::II:lDam'"ml-:-m:II1I:#<IIICIlIIIII;IIII:I::I:I:mllml:III:IIIIIIIIII-!:~::Hllllm:IC!III::III;,,:II:_--::,mUI,mml:::,¡o¡;r:IIU::I':',.-:mm:,I:IUI:m:II:¡CIIII:lllllllllr:::rm:mllllmnll.WIIII::1::I:'I-II::II:m:rml--.IIII"mlmlll:IDI:».;;;),lm:mnm::i::TIIUIIIII---;-:nlll::III:nnrlllt'lll!llllm Job 7: Drillina Production Hole Hazards and Contingencies ~ KICK TOLERANCE: In the worst case scenario the reservoir pressure of the Kuparuk B has been estimated to be 9.4 ppg from offset wells L-119 and L-117. Assuming gauge hole, a fracture gradient of 12.6 ppg at the surface casing shoe, 9.8 ppg mud in the hole the kick tolerance is 25 / bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Manager if LOT is less than 12.6 ppg. ~ Two faults are expected to be penetrated by L-118 in the production hole. The first near the base of the Ugnu at 4900' MD (3580' TVD +/- 100'). This fault is very small, less than 50' of throw and is not expected to be an issue for lost circulation. The second fault near the base of the Colville at 8408' MD -6080' TVDSS +/100' is more substantial. The throw is estimated @ -150' and is considered a risk for loss circulation. It is feasible however that losses may be encountered when running the production casing string if adequate precautions are not taken including running speed, staging in and optimal mud properties. ~ L-Pad development wells have kick tolerances in the 35-50 bbl range. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. ~ There are no "Close Approach" issues with the production hole interval of L-118. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "Shale Drilling- Kingak & HRZ" ·,c wmIlIIlIlIIUI~::llll allll¡m:I IIIU,: a'lllm v.aJlllaIl111'1I1:1aaa'aIIIClmlll:mn__,I:: :I;I ::-X- ~I :lnlU:m~lUall m-lII mm11¡I,I,1111I11II111m'III I:II::UlrmmU:la¡I.:I¡::lmlmml-.11I111I¡II /If~IIUI::WI-I IIII¡r I:III.IIIII II:¡o!III III_IIIIIIICIII::IIII-JIIIII-UI!I,m'1,11,1II1I1:-::I:-'-IIIIIIIII/IIIT;J/' II,JI_III::I:U:.):_a:n:'-III:"I"C:-:IIII.I-_mllllm!llIIl:U:II:'II ~IIIIIIIII: r:-I-I-a-!mmm:-,II'WU_ Job 9: Case & Cement Production Hole Hazards and Contingencies / ~ The 5-1/2" casing will be cemented to 500' above the top of the Schrader Bluff Ma sands with a single stage-two slurry cement. Due to the small annular spacing, a two stage job is not an option. Getting casing to bottom while maintaining returns is a critical operation. ~ Considerable losses during the running and cementing of the production casing has occurred on L and V-Pad. A casing running program will be jointly issued by the ODE and Drilling Supervisor detailing circulating points and running speed. In addition, a LCM pill composed of "Steel Seal" will be placed across the Schrader and Ugnu to help arrest mud dehydration. L-118 Drilling Program - Draft Page 8 ) ) ~ Ensure the upper production cement has reached at least a 70BC thickening value prior to freeze protecting. After freeze protecting the 7-5/8" x 5-1/2"" casing outer annulus with dead crude to 2200' MD, 2024'TVD, the hydrostatic pressure will be 7.7 ppg vs 8.5 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 110 psi underbalance to the open hole. ~ Ensure a minimum hydrostatic equivalent of 9.8 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Loss of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. ~ The well will be under-balanced after displacing the cement with sea-water. Verify that the floats are holding before continuing operations and hold pressure on the well if they are not holding. ~ The X- Nipples, with 1.0. of 2.813" is the tightest tolerance for the Weatherford Dual- Plug system, (tapered cement plugs to be used in the 5 Y2" X 3 Y2" tapered casing string.) Caliper and confirm the 1.0. of all X-Nipples prior to make-up to ensure conformity with proposed design. The By-Pass plug head has been milled down to an 0.0. of 2.5". Caliper to confirm, prior to use. Note: Based on ongoing studies relating to wiper plug failures, drop the top and bottom plug together prior to displacement of cement. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Halliburton Cement Program" Attached. .:. "Freeze Protecting an Outer Annulus" ~mw..Mw.mþm¡.¡mmmmm~mm;m).,:»m¡,v;m;.~mmmÞ;mmJQ~w;mImw/IFF1:II¡II ·"all;aa;laII;IWIþmmp},Ip¡';":i4),·;;;;m;~mÞAAmm.lJ.mmm»~~¡.,-m;.mmAAmmN»lJfWlmJ m¡.;.mmm;;;mmmmMn>~···'tÞf, '.f(Jflf m»f'ÞW'JIfitf_-_-~:..~m.--"f'AA ~-mNm»¡m~~~mmmmm»Jm;~~mlNmmm Job 12: Run Completion Hazards and Contingencies ~ Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The well will be under-balanced if there is a casing integrity problem. ~ Shear valves have been failing at lower than the 2500 psi differential pressure. When testing annulus maintain no more than a 1500 psi differential: 2500 psi tubing pressure, 4000 psi annulus pressure. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. /' Reference RPs .:. "Completion Design and Running" .:. "Freeze Protection of Inner Annulus" ,I :----.-.\JO__ __r.-'-A'-:-"¡~'-.W" Job 13: ND/NU/Release Riq Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Standard practices apply. .:. Freeze Protection of Inner Annulus. L-118 Drilling Program - Draft Page 9 ) ) L-118 Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates may be encountered near the base of the Permafrost at 1814'MD and near the TD hole section as well. · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Production Hole Section: · A majority of the L-Pad development wells will have "kick tolerances" in the 35-50 bbl. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. · The production section will be drilled with a recommended mud weight of 9.8 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk B 9.4 ppg pore pressure. There is a possibility that the B interval could have a pore pressure as high as 3450 psi (10.1 ppg EMW) but offset data indicates this has a low probability. · Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. · L-118 will cross a fault at the base of the Ugnu at 4900'MD -3580' TVD (+/-100'). The estimated throw of the fault is approximately 50'. Loss circulation is considered a minor risk. A second fault will be crossed at 8408' -6150' TVD (+/-150'). Lost circulation is considered to be a moderate risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. · Do not add any LCM (including Walnut sweeps, Barofibre) other than Baracarb during the drilling of the production hole section without prior discussions with the Drilling Supervisor. HYDROGEN SULFIDE - H2S / · This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE L-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies TREE = 3-1/8" 5M CIW , WELLHEAD::: 11" FMC Ã"êfuÃTÕR'; NA ~K'Er'Ë[EV,,,;w-'"_W'_"W~W'M_'^-ã=rõÎ' BF.ËTEV~;~M-~^"'-~~-56:'4:f" 'Kõ'p";"-""""",-"··"",,,·,,,,,,,,,··m.,,,,,,,.,,,,w,,....,,,,,,. Mäx Anglë~-""'w,.",~^^, ·ÕåturñWMÕ";-"^"·",,,",,,··__m,,..,,,,^,,.,,,",... 'Datum"WÕ;;~-_"'WM'~M"~~~- ) 7-5/8"CSG,29.7#,L-80,ID=6.875" I~ 3141' ~ 13-1/2" TBG, 9.2#, L-80, TC-II, .0087 bpf, ID = 2.992" 1-1 XXXX' 5-1/2" CSG, 15.5#, L-80, BTC, ID = 4.950" 1- 15-1/2" X 3-112" CSG XO, ID = 3.000" 1- PERFORA TION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE None PBTD I~ 8946' 13-1/2" CSG, 9.2#, L-80, .0087 bpf, ID = 2.992" I~ 9031' DA TE REV BY COMMENTS 02/05/03 nm Proposed Col'Y'pletion (P7) L-118 / J ~ ... -'1FETY NOTES: 1000' I~ 7-5/8" TAM Collar, ID = 6.875" I I I 2200' 1~3-1/2" HES 'X' NIP, ID = 2.813"1 ~ L GAS LIFT MANDRELS ìYPE VLV LATCH PORT DATE KBG2-9 DV BTM 3.5x 1 KBG2-9 DV BTM 3.5x1 KBG2-9 DV BTM 3.5x 1 KBG2-9 DCK-2 BTM 3.5x 1 I I I XXXX' 1~3-1/2" BKR CMD SLIDING SLV, ID = 2.813" 1 ~ r-t \ I r 1 I 1 1 I~BKRLOCSEALASSY, ID=3.00" I I~ TOP OF BKR PBR, ID = 4.00" 1 1-1 BTM OF 3-1/2" BKR SEAL ASSY, ID = 3.00" I~ 3-1/2" HES X NIP, ID = 2.813" I 1~3-1/2" HES X NIP, ID = 2.813" 1 ~1 I.., PUP JT WI RA TAG 1 jt I above TKUPB -¡ ~ I.., PUP JT WI RA TAG 2 jt I above TKUPA DA TE REV BY COMMENTS PRUDHOE BAY UNIT WELL: L-118 ÆRMIT No: API No: SEC 34, T12N, R11 E, 2550' FSL & 3772' FEL BP Exploration (Alaska) I KBE KOP Bid 1/100 G1 Bid 2/100 Bid 3/100 SV6 SV5 Report Date: Client: Field: Structure J Slot: Well: Borehole: UWIJAPI#: Survey Name J Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid N/E YIX: Grid Convergence Angle: Grid Scale Factor: L-118 Proposed Well Profile - Geodetic Report February 5, 2003 Survey I DLS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Prudhoe Bay Unit - WOA (Drill Pads) d Vertical Section Origin: L-Pad 1 Plan L-118 lilt)' stu Y TVDReferenceDatum: L-118 11II b 11I111 TVD Reference Elevation: L-118 Fea51 Sea Bed I Ground Level Elevation: 50029 Magnetic Declination: L-118 (P7) / February 5,2003 Total Field Strength: 106.712° /5211.92ft/5.871/0.77í. Magnetic Dip: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: N 70.35060808, W 149.32497053 Magnetic Declination Model: N 5978271.550 ftUS, E 583141.710 ftUS North Reference: -+0.63572444° Total Corr Mag North -> True North: 0.99990785 Local Coordinates Referenced To: Schlumbøpgøp Minimum Curvature / Lubinski 27.200° N 0.000 ft, E 0.000 fI KB 76.9 ft relative to MSL 44.100 ft relative to MSL 25.608° 57511.022 nT 80.784° March 15, 2003 B88M 2002 True North +25.608° Well Head '~ Grid Coordinates Geographic Coordinates MD I Incl I Azim I TVD VSec NI-S EI·W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (°/1 o Oft) (ftUS) (ftUS) 0.00 0.00 21.13 0.00 0.00 0.00 0.00 0.00 5978271.55 583141.71 N 70.35060808 W 149.32497053 300.00 0.00 21.13 300.00 0.00 0.00 0.00 0.00 5978271.55 583141.71 N 70.35060808 W 149.32497053 331.90 0.32 21.13 331.90 0.09 0.08 0.03 1.00 5978271.63 583141.74 N 70.35060830 W 149.32497029 400.00 1.00 21.13 399.99 0.87 0.81 0.31 1.00 5978272.36 583142.01 N 70.35061029 W 149.32496801 500.00 2.00 21.13 499.96 3.47 3.26 1.26 1.00 5978274.82 583142.93 N 70.35061699 W 149.32496030 600.00 3.00 21.13 599.86 7.81 7.32 2.83 1.00 5978278.90 583144.46 N 70.35062808 W 149.32494756 700.00 5.00 21.13 699.61 14.74 13.83 5.35 2.00 5978285.44 583146.91 N 70.35064586 W 149.32492710 800.00 7.00 21.13 799.06 25.14 23.58 9.11 2.00 5978295.23 583150.56 N 70.35067250 W 149.32489657 900.00 9.00 21.13 898.08 38.98 36.56 14.13 2.00 5978308.26 583155.43 N 70.35070796 W 149.32485582 974.99 11.25 21.13 971.90 52.08 48.86 18.88 3.00 5978320.61 583160.04 N 70.35074156 W 149.32481726 ~ 1000.00 12.00 21.13 996.40 57.10 53.56 20.70 3.00 5978325.33 583161.81 N 70.35075440 W 149.32480249 1100.00 15.00 21.13 1093.62 80.31 75.33 29.11 3.00 5978347.19 583169.98 N 70.35081388 W 149.32473421 1200.00 18.00 21.13 1189.49 108.55 101.82 39.35 3.00 5978373.79 583179.92 N 70.35088624 W 149.32465108 1300.00 21.00 21.13 1283.75 141.74 132.95 51.38 3.00 5978405.05 583191.61 N 70.35097129 W 149.32455342 1400.00 24.00 21.13 1376.13 179.79 168.64 65.18 3.00 5978440.89 583205.01 N 70.35106879 W 149.32444138 1500.00 27.00 21.13 1466.37 222.59 208.79 80.69 ,3.00 5978481.20 583220.07 N 70.35117848 W 149.32431547 1597.29 29.92 21.13 1551.90 268.69 252.04 97.40 3.00 5978524.63 583236.30 N 70.35129663 W 149.32417981 1600.00 30.00 21.13 1554.25 270.03 253.30 97.89 3.00 5978525.90 583236.77 N 70.35130007 W 149.32417583 Station ID L-118 (P7) report.xls Page 1 of 3 2/5/2003-11 :32 AM Grid Coordinates Geographic Coordinates Station ID MD I Incl I Azim TVD I VSec NI-S EI-W DLS Northing Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/10Oft) (ftUS) (ftUS) 1700.00 33.00 21.13 1639.50 321.98 302.03 116.72 3.00 5978574.83 583255.06 N 70.35143320 W 149.32402295 SV4 1744.94 34.35 21.13 1676.90 346.76 325.27 125.71 3.00 5978598.16 583263.79 N 70.35149669 W 149.32394997 1800.00 36.00 21.13 1721.90 378.30 354.86 137.14 3.00 5978627.88 583274.89 N 70.35157752 W 149.32385717 End Bid 1806.18 36.19 21.13 1726.90 381.92 358.25 138.45 3.00 5978631.28 583276.16 N 70.35158678 W 149.32384653 Formation 1830.96 36.19 21.13 1746.90 396.47 371.90 143.73 0.00 5978644.99 583281.29 N 70.35162407 W 149.32380366 Cry 3/100 1855.74 36.19 21.13 1766.90 411.02 385.55 149.00 0.00 5978658.69 583286.41 N 70.35166136 W 149.32376088 1900.00 37.51 21.13 1802.31 437.41 410.30 158.57 3.00 5978683.55 583295.70 N 70.35172898 W 149.32368318 2000.00 40.51 21.13 1880.00 500.00 469.01 181.26 3.00 5978742.50 583317.74 N 70.35188937 W 149.32349896 2100.00 43.51 21.14 1954.30 566.55 531.43 205.39 3.00 5978805.18 583341.17 N 70.35205989 W 149.32330305 2200.00 46.51 21.14 2024.98 636.87 597.39 230.90 3.00 5978871.41 583365.95 N 70.35224009 W 149.32309592 2031.90 644.16 604.23 233.54 3.00 5978878.28 583368.51 N 70.35225877 W 149.32307449 .~ SV3 2210.08 46.82 21.14 2300.00 49.51 21.14 2091.87 710.78 666.71 257.70 3.00 5978941.02 583391.97 N 70.35242946 W 149.32287832 2400.00 52.51 21.14 2154.78 788.07 739.20 285.73 3.00 5979013.80 583419.19 N 70.35262749 W 149.32265073 SV2 2470.95 54.64 21.14 2196.90 844.83 792.44 306.33 3.00 5979067.27 583439.20 N 70.35277294 W 149.32248346 End Cry 2499.86 55.51 21.15 2213.45 868.40 814.55 314.87 3.00 5979089.47 583447.49 N 70.35283334 W 149.32241412 SV1 3062.22 55.51 21.15 2531.90 1329.32 1246.85 482.08 0.00 5979523.55 583609.88 N 70.35401432 W 149.32105633 7-5/8" Csg pt 3141.68 55.51 21.15 2576.90 1394.45 1307.93 505.70 0.00 5979584.89 583632.82 N 70.35418118 W 149.32086451 UG4A 3618.48 55.51 21.15 2846.90 1785.24 1674.46 647.47 0.00 5979952.93 583770.50 N 70.35518247 W 149.31971316 UG3 4280.70 55.51 21.15 3221.90 2328.01 2183.52 844.36 0.00 5980464.10 583961.71 N 70.35657312 W 149.31811397 UG1 5146.00 55.51 21.15 3711.90 3037.22 2848.69 1101.63 0.00 5981132.02 584211.56 N 70.35839021 W 149.31602404 /rv 3/100 ~-) 55.51 21.15 3982.62 3429.06 3216.19 1243.77 0.00 5981501.04 584349.61 N 70.35939413 W 149.31486920 Ma 5657.90 ../' 55.01 22.22 4001.90 3456.72 3242.02 1254.04 3.00 5981526.98 584359.59 N 70.35946469 W 149.31478576 "- - - ----- 5700.00 54.39 23.57 4026.23 3490.99 3273.68 1267.40 3.00 5981558.78 584372.59 N 70.35955117 W 149.31467721 5800.00 53.00 26.87 4085.44 3571.51 3346.57 1301.72 3.00 5981632.04 584406.10 N 70.35975029 W 149.31439837 5900.00 51.71 30.29 4146.53 3650.65 3416.10 1339.57 3.00 5981701.98 584443.17 N 70.35994022 W 149.31409087 6000.00 50.51 33.82 4209.32 3728.18 3482.06 1380.85 3.00 5981768.39 584483.71 N 70.36012039 W 149.31375550 Na 6027.55 50.20 34.82 4226.90 3749.23 3499.58 1392.81 3.00 5981786.04 584495.48 N 70.36016825 W 149.31365834 -- 6100.00 49.43 37.48 4273.65 3803.90 3544.27 1425.45 3.00 5981831.08 584527.62 N 70.36029032 W 149.31339317 6200.00 48.47 41.25 4339.34 3877.60 3602.57 1473.25 3.00 5981889.90 584574.76 N 70.36044957 W 149.31300485 End Cry 6221.50 48.28 42.07 4353.62 3893.16 3614.57 1483.93 3.00 5981902.02 584585.31 N 70.36048234 W 149.31291809 Oa 6271.49 48.28 42.07 4386.89 3929.22 3642.27 1508.93 0.00 5981929.99 584610.00 N 70.36055800 W 149.31271500 Shrader Tgt 6271.50 48.28 42.07 4386.90 3929.23 3642.28 1508.93 0.00 5981930.00 584610.00 N 70.36055803 W 149.31271500 Cry 3/100 6800.38 48.28 42.07 4738.90 4310.74 3935.29 1773.42 0.00 5982225.90 584871.19 N 70.36135835 W 149.31056624 Obf Base 6856.56 46.59 42.07 4776.90 4350.73 3966.01 1801.14 3.00 5982256.92 584898.57 N 70.36144225 W 149.31034103 6900.00 45.29 42.07 4807.11 4380.89 3989.18 1822.05 3.00 5982280.32 584919.22 N 70.36150554 W 149.31017115 L-118 (P7) report.xls Page 2 of 3 2/5/2003-11 :32 AM Grid Coordinates Geographic Coordinates Station ID MD I Incl I Azim I TVD I VSec NI-S El-W I DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 7000.00 42.29 42.07 4879.29 4447.77 4040.54 1868.41 3.00 5982332.19 584965.00 N 70.36164582 W 149.30979449 7100.00 39.29 42.07 4955.00 4510.90 4089.02 1912.18 3.00 5982381.15 585008.23 N 70.36177823 W 149.30943887 CM2 7197.37 36.37 42.07 5031.90 4568.60 4133.35 1952.18 3.00 5982425.91 585047.73 N 70.36189931 W 149.30911388 7200.00 36.29 42.07 5034.02 4570.11 4134.50 1953.23 3.00 5982427.08 585048.77 N 70.36190245 W 149.30910535 7300.00 33.29 42.07 5116.14 4625.25 4176.85 1991.45 3.00 5982469.84 585086.51 N 70.36201812 W 149.30879481 7400.00 30.29 42.07 5201.13 4676.15 4215.95 2026.74 3.00 5982509.33 585121.36 N 70.36212491 W 149.30850808 7500.00 27.29 42.07 5288.76 4722.69 4251.69 2059.00 3.00 5982545.42 585153.22 N 70.36222252 W 149.30824597 7600.00 24.29 42.07 5378.79 4764.73 4283.98 2088.15 3.00 5982578.03 585182.01 N 70.36231071 W 149.30800912 7700.00 21.29 42.07 5470.98 4802.16 4312.73 2114.09 3.00 5982607.06 585207.62 N 70.36238923 W 149.30779835 7800.00 18.29 42.07 5565.06 4834.87 4337.85 2136.77 3.00 5982632.43 585230.02 N 70.36245784 W 149.30761407 ~ CM1 7859.56 16.50 42.07 5621.90 4852.08 4351.07 2148.70 3.00 5982645.78 585241.80 N 70.36249395 W 149.30751713 7900.00 15.29 42.07 5660.79 4862.78 4359.29 2156.12 3.00 5982654.08 585249.13 N 70.36251640 W 149.30745684 End Crv 7909.72 15.00 42.07 5670.17 4865.23 4361.17 2157.82 3.00 5982655.98 585250.81 N 70.36252153 W 149.30744303 Top HRZ 8439.49 15.00 42.07 6181.90 4997.71 4462.92 2249.66 0.00 5982758.73 585341.51 N 70.36279943 W 149.30669678 Base H RZ 8695.19 15.00 42.07 6428.90 5061.66 4512.04 2293.99 0.00 5982808.34 585385.29 N 70.36293358 W 149.30633657 K-1 8755.24 15.00 42.07 6486.90 5076.67 4523.57 2304.40 0.00 5982819.98 585395.57 N 70.36296507 W 149.30625199 Kuparuk Tgt 8781.12 15.00 42.07 6511.90 5083.15 4528.54 2308.89 0.00 5982825.00 585400.00 N 70.36297865 W 149.30621550 Top Kuparuk / C 8781.13 15.00 42.07 6511.91 5083.15 4528.54 2308.89 0.00 5982825.00 585400.00 N 70.36297865 W 149.30621550 LCU I Kup B 8920.88 15.00 42.07 6646.90 5118.10 4555.38 2333.12 0.00 5982852.10 585423.93 N 70.36305195 W 149.30601861 TO / 5-1/2" Csg Pt 9030.88 15.00 42.07 6753.15 5145.60 4576.51 2352.19 0.00 5982873.44 585442.76 N 70.36310966 W 149.30586365 Leqal Description: Surface: 2550 FSL 3773 FEL S34 T12N R 11 E UM Shrader Tgt: 912 FSL 2257 FEL S27 T12N R11E UM Kuparuk Tgt: 1798 FSL 1455 FEL S27 T12N R11E UM BHL: 1846 FSL 1412 FEL S27 T12N R11E UM Northina (Y) rftUSl 5978271.55 5981930.00 5982825.00 5982873.44 Eastina (X) rttUSl 583141.71 584610.00 585400.00 585442.76 ~ L-118 (P7) report.xls Page 3 of3 2/5/2003-11 :32 AM ...- +-' Q) ...- JE~ 8:2: o Q) N > II .8 c:: m .- .¡: T"""o -0) .c:: . ë.~ Q) - DID Cã~ u.¡...: :e Q) Q)e::: > [; ~W L.. I- -4000 ) ) VERTICAL SECTION VIEW Client: BP Exploration Alaska Well: L-118 (P7) Field: Prudhoe Bay Unit - WOA Structure: L-pad Section At: 27.20 deg Date: February 05, 2003 Schlumberger . ..,._...._......._..______L -2000 ------------- _ _ _ _ _ _ _ _. - End CIV 2500 MD 2213 TVD 55.51' 21.15' az 868 departure 7-518" Cag Pt3142 MD 25 7 TVD 2000 ~'~-·:=-'",:;:·,~~';"~A::~~'-' -"'~V'Z~ :~·I~·~~·~~fi~~·~· ~~ ~~~~:~ UGô 42<11 MD :,;<;::1 TVi:¡ 6222 MD 4354 TVD .,... /..,::;::e~rt~~:az,... ..... ..... ..... ..... ........,.....,.... ..-:::::,~~,~~!.~..T.,Q~".. ,........,..,......,..,...... 6272 MD 4387 TVD u_ "48.28. 42:07·n"'" '"., ,.... '"3929'ëfepãiturë'" ..... '"..'" CIV 3/100 ..... "Ëi80Õ't"ID "'4739 TÌÏ6 "1I 8.2tI· "2.07"''QZ ...... 4311 de~arture End CIV 79-0 MD 5670 TVD .- "-¡;~,IT 7~,j(, ~,m 5(';];, f\7() -- - .- - - -- - -- -- - .- .- - - .- - -. -15:00' 42.07- ai- ,.- 6000,;,';~-~-;~"~~~~¡~~~~~~§o~-,-~~~;:~~~~:~~~~:~~r:~·-;~'~:,~f~Ji~:;~ 0- 4000 -..,..... -~ ~ -." ._~ -~ KOP Bid 1/100300 MD 300 TVD /0.00' 21.13'az Odeparture '/~. ~:;~:~f~~~~ / / - --3l19' ïÙ3- aZ382depiirturë- I CIV 3/100 1856 MD 1767 TVD 36.19' 21.13' az 411 departure / ..._.~._-_...... --(,·t'in2M() 7J2 Tv!:)"" .~--,_......_~_.- ......_~_._- -sv7f 9i"in.1¡:)'<,)¡'f'¡y¡j-- ...., '''''UG1 fii;¡(; tltiIJ ô7'iJ ¡vb '"... """"":·~;;:~::¡~;;::~~;~~~~i~~'~t~[:"··'::~::'"":~:: ·"'Ot;'f't)"i" (":~':,~ ~,!r.j' Jlï T'\ït) ..... ·""¡;r,ï7.· I FY, ~m ,;'(j'3;~ ý\j'() ..... ........................................ ..... ..... ..... ..... I I"'" '"... 1- ...... '..... ..... ..... ..... ....., ...... ..... i .....·"t··..·.. ! ; ! ! ""''''''''Ì i TD / 5·1'2" Cag Pt 9031 MD 6753 TVD 15.00' 42.07' az 5146 departure I 8000 _,....,..,....1...................",.................,..,...,...",..",.. ! I ! ·""""'''''''·''''''''''''''·''''''''''''''''''''''''''·T''''''·''''''''''''''·'''''''''''''''''' I i I i ! .................................................................,................................................................. 1 0000 _......~..._...._._..,....._-..._...._......-._.+--_._...__.__.._._.. i ~ -2000 ...._.~..._..__.._-_.._._-_.-----_....._._-_.... ----~._._._.._.__...~. I o I 2000 6000 I 4000 Vertical Section Departure at 27.20 deg from (0.0, 0.0). (1 in = 2000 feet) End Cry 250C MD 2213 TVD 55.51' 21.15·az ~ 815N 315E '\: ----- Cry 31100 1856 N1D 1767 TVD ....m'...'3.~,:,~,9.:j..,?,~,:,~,3.~..~...., 386 N¡ 149 E End Bid i 1806 MD 1i727 TVD 36.19' 21.\3' az 358N 13* ~ <;::) ~. ,i"" TD 15-112" Csg PI is' ".".".,.",\),,-9.' , .) 9031 IIID 6753 TVD ;:> </', ,'. ",.' 15.00' 42.07' az 4000--- 3f".".,k(~""",·,·i 4577~ 2352E -------.---- ~y- ~/ "'-'" ....._.m.... __...___............._ (} ~ 87&1 MD 6512TV ----~----- -----~~;:~~~---4000 , 42,07' az \',.,"',.". Crv3/100 4361N 215~E '~ 6800 MD 4739 TVD 48.28' 42,07' az 3935 N 1773 E , Shrader TgI , 6272 MD 4387 TVD 48,28' 42.07' az End ~rv 3642 N 1509 E ~~c-4~M1VO Cry 3/100 . 42.07' az 5624 MD 3~;~~D 1464 E 55.51' 21.15' az 3216 N 1244 E I 3000 2000 EAST »> I 1000 ....m........,..m.............._ -1 000 .................... ........ m.....m..m..........m......'....,......................,_ 0 ................................. - 1000 - l> ~, 7.518" Cag Pt f ~ 314~MP....:?,§~7JY,Q.., ..'..'m..................,..'··......iiÙ1· 2;ö~5E az 1308 N ......... 2000 3000 ..m.........m........._........... .......,.-,...........-.............,...., _ 5000 .._...~.._..___..... ._..._.._....._ _......_.q., .~......_..~..... M' ....,........N...~...~ .......... I o «< WEST I -1000 .J.... -1000 _...... ; i ·r"~~:":;~"~';~'~~""""·""',,·,---/m............T\,..........,..,....".., i 300MD 300; II i 0.00' 21.13' az ! i ON OE I I ¡ i Bid 2/100 ! Bid 3/100 I 600 MD 600 TVD ¡ 900 MD 898 TVD 3.00' 21.13' az ! 9.00' 21.13' az 7 N 3 E ! 37 N 14 E o -................, ~...." 1 000 _...... b ~. rv S :::J .§ ! 0= :e 5000 _.._....m.._... _...........m..'_n.........m... -1000 0 1000 2000 3000 6000-..m.mmm'..m -m..........m....m....m....mm........,..................,..r....,..,....'..........mm..........'........,..'..........m......I..mm'..................,...........................m....mm.."m......m............'..........m'..mm....m..m..m....'''........'..m....'........"'m...'....."'.."'...6000 True North Mag Dee ( E 25.61° PLAN VIEW Client: BP Exploration Alaska Well: L-118 (P7) Field: Prudhoe Bay Unit - WOA Structure: L-pad 1 in ::;: 1000 ft 05-Feb-2003 Schlumberuer Scale: Date: bp ) I I- ::::> o en V V V 2000 3000 ^ ^ ^ I l- e:: o z )BP Exploration Alaska ) Anticollision Report ..... .. ......... . çô~paÏ1yf . · "'I3PAmOCQ Fi¢~d: ..... '. ... '.. '. .... ·.P~4qt1QêBªY R ti ... . Sit . . ... ::PB.ÞAéI~:;·· Ï{;f:~:h~::~~~::>¡ ...... plaht~r1a'" .' ~efer.~~ce~ellp.~I1:; Pla.nt;~118::·' NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.40 to 9030.88 ft Maximum Radius: 3000.00 ft Survey Program for Definitive Well path Date: 12/26/2000 Validated: No Planned From To Survey ft ft 28.40 1200.00 Planned: Plan #7 V1 1200.00 9030.88 Planned: Plan #7 V1 Casing Points 1\1)) ft. 3141.86 9030.88 .: TY:ö ':;, .¡; Diåmetef . ·ft; · '.' . ;;; in 2577.00 7.625 6753.16 5.500 Summary Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Version: 7 Toolcode Tool Name GYD-GC-SS MWD+IFR+MS Gyrodata gyro single shots MWD + IFR + Multi Station HòlêSize .".' . .. ".in "¡ '..' 8.750 6.750 75/8" 5 1/2" Offset Wellpath: "'---8~ ." . . "-> .,.' ". Well:' "We1Iea,th ' EX NWE#1 EX NWE#1 EX NWE#1 PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad delete me NWE1-01Ar\1WE1-01A V4 NWE1-01 NWE 1-02 L-01 L-02 L-02 L-102 L-102 L-102 L-103 L-104 L-105 L-106 L-107 L-108 L-109 L-110 L-111 L-112 L-114 L-115 L-116 L-117 L-119 L-120 Plan L-121 Plan L-121 NWE1-01 V3 NWE 1-02 V2 L-01 V14 L-02 V1 L-02PB1 V21 Plan: L-02 L-102 V2 L-102PB1 V10 L-102PB2 V2 L-103 V23 L-104 V7 L-105 V4 L-106 V14 L-107 V14 L-108 V18 L-109 V12 L-110V11 L-111 V24 L-112V8 L-114 V14 L-115 V7 L-116V10 L-117V11 L-119V9 L-120 V8 Plan L-121 "A" V7 Plan Plan L-121 ST "C" V1 P : Reference '.' Offset ,. <Ctr-Ctr 'Nò+Go ";Álïôwabh~ '1\1"D MD' .. . Distance Areå : ;; >Deviåtiôn At fF 'ft . "<~ :ft 300.00 300.05 262.37 5.04 257.34 Pass: Major Risk 299.98 300.00 262.37 5.04 257.34 Pass: Major Risk 1410.66 1450.00 105.00 26.51 80.15 Pass: Major Risk 349.37 350.00 194.56 5.65 188.91 Pass: Major Risk 591.63 600.00 89.95 9.78 80.18 Pass: Major Risk 591.63 600.00 89.95 9.89 80.07 Pass: Major Risk 248.00 250.00 296.43 3.93 292.50 Pass: Major Risk 248.00 250.00 296.43 4.02 292.41 Pass: Major Risk 248.00 250.00 296.43 4.02 292.41 Pass: Major Risk 961.42 950.00 156.62 15.79 140.86 Pass: Major Risk 397.40 400.00 271.53 6.51 265.03 Pass: Major Risk 397.26 400.00 244.19 7.06 237.14 Pass: Major Risk 1133.00 1150.00 216.98 19.39 197.66 Pass: Major Risk 199.68 200.00 199.59 4.26 195.32 Pass: Major Risk 839.12 850.00 214.00 14.76 199.27 Pass: Major Risk 300.00 300.00 179.24 6.13 173.11 Pass: Major Risk 299.89 300.00 186.97 5.37 181.60 Pass: Major Risk 300.00 300.00 236.25 5.23 231.02 Pass: Major Risk 344.46 350.00 107.25 7.10 100.15 Pass: Major Risk 445.24 450.00 215.40 6.96 208.44 Pass: Major Risk 449.35 450.00 28.82 7.49 21.35 Pass: Major Risk 640.23 650.00 183.07 9.93 173.15 Pass: Major Risk / 399.75 400.00 15.85 6.23 9.62 Pass: Major Risk 1334.40 1300.00 209.99 23.17 186.97 Pass: Major Risk 297.88 300.00 237.19 5.01 232.18 Pass: Major Risk 348.97 350.00 195.67 6.28 189.40 Pass: Major Risk 348.97 350.00 195.67 6.28 189.40 Pass: Major Risk Site: PB L Pad Î)) Drilling Target Conf.: 99'h Description: Map Northing: 5981930.00 ft Map Easting : 584610.00 ft Latitude: 70021'38.009N Shape: Circle Target: L-118 Schdr Tgt \ d o 0 ~ o 0 J J o ~ J ~ J J C) C) ---=l- o o Ln o o LO "ell: Plan L-1l8 Ased on: Planned Program Vertical Depth: 4310.00 ft below Mean Sea Level Local +N/-S: 3642.27 ft Local +E/-W: 1508.93 ft Longitude: 149°18'45.774W Radius: 100 ft o C) I 900 3800 3100 3500 3500 o o CD Polygon 1 2 3 4 Site: PB L Pad ) Drilling Target Conf.: 99%, ' Description: Map Northing: 5982825.00 ft Map Easting : 585400.00 ft Latitude: 70°21 '46. 723N +N/-S ft 324.73 106.56 -276.56 -22.56 Target: L-118 Kup Tgt +E/-W ft 28.61 311.23 136.95 -220.28 \ell: Plan L-118 ,!sed on: Planned Program Vertical Depth: 6435.00 ft below Mean Sea Level Local +N/-S: 4528.53 ft Local +E/-W: 2308.89 ft Longitude: 149°18'22.376W Northing ft 5983150.00 5982935.00 5982550.00 5982800.00 Easting ft 585425.00 585710.00 585540.00 585180.00 5000 4-900 4-800 I" 4-l00 ~ / 4-500 4-500 4-4-00 4-300 4-200 4-100 ~ C) C) C) C) C) C) C) C) C) C) ~ C) C) C) C) C) C) C) C) C) C) ~ C) N CD -=f- Ln LD I OJ 0- ~ N N N N N N N N N N ~ ~ ~ ~ ') ) Per Alaska Oil and Gas Conservation Commission Regulation 20 AAC 25.015 Changes to a Program in a Penllit to Drill sub section (a) (1) SUblllit and obtain the conlmission's approval of a new application for a Penllit to Drill if the surface location is changed, if the bottom-hole location or the location of an objective formation is changed by more than 500 feet laterally or vertically, or if the change requires a spacing exception under 20 AAC 25.055; however, no additional fee is required Pllú WELL PERMIT CHECKLIST COMPANY _~p ~ WELL NAME /. - / / g' FIELD & POOL ' ,G 7' ó /3ð INIT CLASS 4v J -6/ / ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . 3. Unique well name and number. . . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. .'. 6. W ell located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . APPR DATE {!L dWa3 (Service Well Only) (Service Well Only) ENGINEERING APPR DATE 'yJc,A-- 'L/13! () ~ (Service Well Only) GEOLOGY APPR DATE ø~ z)3~~ ~ (E~ploratory Ö"r;''TY) PROGRAM: Exp _ Dev X Redrll L Re-Enter _ Serv _ Well bore seg _ GEOL AREA f?J Ó UNIT# ó /) ~ ... ~ C> ON/OFF SHORE ~ 0~t . I J .r; f ' J ~ N ~ Tfl.1 IS 4. 5''1J1VIi'l'U", rl'un5,or; ~ ~1l:'"-~''' -/ jP"Þ<, 1- :t?,._ r.. M/,'~ : ð" <: , élJ N"f ~~ p~ J ~r*?,._-I. - ¡f?~./ 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . èY> N I 9. Operator only affected party.. . . . . . . . . . . . . . . . . . C9 N 10. Operator has appropriate bond in force. . . . . . . . . . . . . ! N 11. Permit can be issued without conservation order. . . . . . . . N 12. Permit can be issued without administrative approval.. . . . . P /ì 13. Well located w/in area & strata authorized by injection order #_ Y ,/LI. r-¡ . 14. All wells w/in X mile area of review identified. . . . . . . . .. " N 15. Conductor string provided. . . . . . . . . . . . . . . .. . . ~ N 16. Surface casing protects all known USDWs. . . . . . . . . N 17. CMT vol adequate to circulate on conductor & surf csg. . . Y/ N 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . ~ 19. CMT will cover all known productive horizons. . . . . . . . N 20. Casing designs adequate for C, T, B & permafrost. . . . . .. N ¡J. b' S; 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . ,N'fÑ Or~ c¡ ¡; 22. If a re-drill, has a 10-403 for abandonment been approved. . . If) "'lit- 23. Adequate wellbore separation proposed.. . . . . . . . . . . . :f¿ N , t~ .1 24. If diverter required, does it meet regulations. .. . . . . .' . . ~ NtP tI"-Ia.,,, ýa-y ~·b IIU?-c;' c..o. , 25, Drilling fluid program schematic & equip lis,t adequate. . . . . . , N /Ý¡A./~ fìÎ1/J 9· ~ ppq . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N, 27. BOPE press rating appropriate; test to 4000 psig. ~N mç p 25 4"5 fJ~t. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 29. Work will occur without operation shutdown. . . . . . . . . . . , ~ J, 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ 31. Mechanical condition of wells within AOR verified. . . . . . . . ,-¥-N- Ail It-- 32. Permit can be issued wlo hydrogen sulfide measures. . . . . & N 33. Data presented on potential overpressure zones. . . . . . .. ¡r, ' 'A \ /) 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y / '-' , H " 35. Seabed condition survey (if off-shore)., . . . ... ...... N 36. Contact name/phone for weekly progress reports. ...... Y 'N i() C "'". C>~ ¡¡r-~ Yt:4' e.t /-J ( / '\. GE;¡;: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING ule ENGINEER COMMISSIONER: Commentsll nstructions: RP ~~ TEM JDH JBR COT 11)& ~f /103 DTS ../ MJW MLB /TIM 2../iJ'µ3 SFD WGA Rev: 10/15/02 - G:\geology\perm its\checklist.doc ) ) TONY KNOWLES, GOVERNOR ALASIiA. OIL AND GAS CONSERVATION COMMISSION / 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Stone Senior Drilling Engineer . BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit L-118 BP Exploration (Alaska) Inc. Permit No: 201-187 Sur Loc: 2550' NSL, 3772' WEL, SEC. 34, T12N, RIlE, UM Btmhole Loc. 3456' NSL, 1762' WEL, SEC. 27, T12N, RIlE, UM Dear Mr. Stone: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay L-118. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ,.: ~ c. DuL,~ C~echsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 3rd day of October, 2001 , jjclEnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work III Drill 0 Redrill 1 b. Type of well ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2550' NSL, 3772' WEL, SEC. 34, T12N, R11 E, UM At top of productive interval 3307' NSL, 17951WEL, SEC. 27, T12N, R11E, UM At total depth 3456' NSL, 1762' WEL, SEC. 27, T12N, R11E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028238, 1762' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin9 Program Specifications $Ize Casing Weight Grade CouDlina 20" 91.5# H-40 Weld 7-5/8" 29.7# L-80 BTC 5-1/2" 15.5# L-80 BTC-M 3-1/2" 9.2# L-80 IBT-M Hole 30" 9-7/8" 6-3/4" 6-3/4" Length 80' 3213' 8307' 741' 'A,^~,". \:',:,'"j\ ~ iJ' .. ,:}r \ \ìJ \0 l Ð(7:J \ /C.J/yð /' o Exploratory 0 Stratigraphic Test III Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Plan RKB = 76.2' Prudhoe Bay Field I Borealis 6. Property Designation Pool (Undefined) ADL 028239 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) Prudhoe Bay Unit 8. Well Number Number 2S100302630-277 9. Approximate spud date ¡."1I71J'i' Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10243' MD 17132' TVD o 17. Anticipated pressure se 20 AAC 25.035 (e) (2)} 58 Maximum surfa~ ig, At total depth (TVD) 6487' I 3376 psig Setting Depth TQP Botom MD TVD MD TVD Surface Surface 80' 80' Surface Surface 3213' 2577' Surface Surface 9400' 6320' 9400' 6320' 10243' 7132' 117 sx Class 'G' Quantitv of Cement (include staae data) ¡260 sx Arctic Set (Approx.) 380 sx AS Lite, 197 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet III Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch III Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer NamelNumber: Neil Magee, 564-5119 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true a~ correct to the be~t of my ~nowl~~ge . Signed Dan Stone c::::::::::>- ~ '- ¿ '----> Title Senior Dnlllng Engineer Date ~ 1'1 J 0) :., .,' :,1 . 1 ::. . .~ ,p",;,~¡""';':.v.; 1,L...".,~'h~'1 ' , , I' . . ~~'!"~~~_~. ~ ,~N.,,,,.·, I ':1 .". Permit Num~Õ¡-167 :1 ~2..tqr _ ;23CtI3-0Ò (tP¡rov3&.Ö I ~~~::re;~~i~:ments Conditions of Approval: Samples Required 0 Yes œI No Mud Log Required 0 Yes ~ No Hydrogen Sulfide Measures 0 Yes œ No Directional Survey Required ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K tiL5K 0 10K 0 15K 0 3.5K psi for CTU Other: ~CJ'CR)~~" ""''-<''- \.J\..~~ \S~ --V ~~+-. Approved By Or!ginal Signed~ R I G I N A Lcommissioner Form 10-401 Rev. 12-01Qø1my Oech¿U; Casing Structural Conductor Surface Intermediate Production Liner Length Size Perforation depth: measured true vertical 20. Attachments Cemented MD TVD f:»E'...... " '. ~ (~ E' i l\tl'E' ~) SEP 1 8 2001 Alaska Oil & G C as OriS, Commission Anchorage . by order of the commission I i Date lC), 3 D { Subrr'it In T iplicate ) ) IWell Name: IL-118 Drill and Complete Plan Summary I Type of Well (service 1 producer 1 injector): I Producer Surface Location: As-Staked Target Location: Top Kuparuk Bottom Hole Location: x = 583,141.71' V = 5,978,271.55' 2550' FSL (27291 FNL), 37721 FEL (15071 FWL), Sec. 34, T12N, R11 E X = 585,040.00' V = 5,984,330.00' 33071 FSL (19711 FNL), 17951 FEL (34841 FWL), Sec. 27, T12N, R11E X = 585,070.71' V = 5,984,479.02' 34561 FSL (1823) FNL), 17621 FEL (35161 FWL), Sec. 27, T12N, R11E I AFE Number: 15M4030 1 Estimated Start Date: 110/10/2001 I 1 MD: 110243' I I TVD: 17132' 1 I RiQ: 1 Nabors 9ES I OperatinQ days to complete: 116.6 I BF/MS: 148.2' I I RKB: 176.2' I Well DesiQn (conventional, slimhole, etc.): I Microbore (Iongstring) I Objective: I Kuparuk Formation Mud Program: 9-7/8" Surface Hole (0-3213'): Densitv (ppg) 8.5 - 8.6 9.3 - 9.5 9.6 max Initial below Permafrost interval TD Viscosity (seconds) 300 300 200-250 Fresh Water Surface Hole Mud Yield Point API FL PH (lb/1 OOft~) (mls/30min) 50 - 70 15 - 20 50 - 70 15 - 20 50 - 70 15 - 20 8.5-9.5 8.5 - 9.5 8.5 - 9.5 6 %" Intermediate 1 Production Hole (3213' - 1 0243'): Interval Density Tau 0 YP PV (ppg) 9.3-9.5 10.3 5-8 20-25 8-14 pH API Fi Itrate 8.5-9.5 4-6 8.5-9.5 3-5 LSND HTHP Fi Itrate Upper Interval Top of HRZ 4-7 20-25 8-14 <10 by HRZ L-118 Permit to Drill Page 1 ) Directional: Ver. Anadril P-5, Slot No. NK KOP: 300' Maximum Hole Angle: Close Approach Wells: LOQQing PrOQram: Surface ) 58° at 2446' MD All wells pass major risk criteria. Drilling: MWD / GR Open Hole: Gas Detection Cased Hole: None Drilling: MWD / GR / Res Open Hole: GR-Res-Neu-Den, Gas Detection, Cuttings samples Cased Hole: USIT cement evaluatioll~~"~i:"":" I ntermed iate/Prod uction Hole Formation Markers: Formation Tops MDbkb SV5 SV4 Base Permafrost SV3 SV2 SV1 UG4A UG3 UG1 Ma WS2 (N sands) WS1 (0 sands) Obf Base CM2 (Colville) THRZ BHRZ (Kalubik) K-1 TKUP Kuparuk C LCU Kuparuk B Kuparuck A TMLV (Miluveach) TD Criteria L-118 Permit to Drill TVDss 1465' 1610' 1775' 1950' 2120' 2440' 2775' 3160' 3610' 3905' 4185' 4305' 4665' 4990' 6160' 6350' 6420' 6487' 6493' 6910' ~\,)\"~Qd0-[-1( ",,:J Hydrocarbon Bearing, 1850 psi Hydrocarbon Bearing Y\~ Hydrocarbon Bearing 3376 psi, 10.0 ppg Hydrocarbon Bearing 150' below Miluveach top Page 2 ) ) CasinglTubinQ Program: Hole Csgl WtlFt Grade Conn Length Top Btm Size TbQ O.D. MDfTVD MDfTVD bkb 30" 20" 91.5# H-40 WLD 80' GL 80/80 9-7/8" 7 5/8" 29.7# L-80 BTC 3213' GL 3213'/2577' 6-3/4" 5-1 /2" 15.5# L-80 STC-m 8307' GL 9400' /6320' 6-3/4" 3-1/2" 9.2# L-80 1ST-mod 741' 9400' /6320' 10243'/7132' Tubing 3-1 /2" 9.2# L-80 1ST-mod 8307' GL 9400'/6320' InteQrity TestinQ: Test Point Depth Suriace Casing Shoe 20' min from su riace shoe Test Type LOT EMW 13.5 ppg target Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. ' Based on open hole logging results, the production cement job may be brought up 500' above the top of the Schrader. Casinq Size 17-5/8" Surface 1 Basis: Lead: Based on 1886' of annulus in the permafrost @ 250% excess and 577' of open hole from top of tail slurry to base permafrost @ 300/0 excess. Lead TOG: To surface Tail: Based on 750'MD open hole volume + 300/0 excess + 80' shoe track volume. Tail TOG: At -2463' MD (2175' TVDbkb). Total Cement Volume: Lead 301 bbl I 1688 fe I 380 sks of Dowell ARTIGSET Lite at 10.7 ppg and 4.44 dIsk. Tail 41 bbl I 230 fe I 197 sks of Dowell Premium 'G' at 15.8 ppg and 1 .17 dIsk. Casing Size 5-1/2"x3-1/2" Production Longstring Basis: Lead: Based on TOG 1000' above top of Kuparuk formation & 30% excess + 80' shoe. Lead TOG: 8655' MD, 6564' TVDbkb (155F BHST) Total Cement Volume: Lead 50.0 bbls I 280 fe I 117 sks of Dowell LiteGrete at 12.0 ppg and 2.39 dIsk. L-118 Permit to Drill Page 3 ') ) Well Control: Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 4000 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: 3376 psi @6487' TVDss - Kuparuk Sands 2727 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 4000 psi (for future frac stimulation treatments) 8.6 ppg filtered seawater / 6.8 ppg Diesel Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. L-118 Permit to Drill Page 4 ') ) DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor is in place. 1. Weld an FMC landing ring for the FMC Ultra slim hole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and lor well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig Operations: 1. MIRU Nabors _Îi\ 2. Nipple up diverter spool and riser. Function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 9 7/8" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3213' MD I 2577' TVD. The actual surface hole TD will be +1-100' TVD below the top of the SV1 sand. POH LD BHA. 4. Run and cement the 7-5/8", 29.7# surface casing back to surface. A port collar will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. 5. ND diverter spool and NU casing I tubing head. J~l1'ee'Pl!:I;:ãht.ftttest4(};4000:¡¡psili~1~ 6. MU 6-3/4" drilling assembly with MWD/GR/NEU/DENS/RES and RIH to float collar. Test the 9-5/8" casing to 4000 psi for 30 minutes. 7. Drill out shoe joints and displace well to LSND drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 8. Drill to ±100' above the HRZ, ensure mud is condition to 10.3 ppg and perform short trip as needed. During this time hold the 'Pre-Reservoir' meeting highlighting kick tolerance and detection. Drill ahead to -150' of rat hole into the Miluveach formation. Condition hole for production casing and POOH. 9. Run and cement the tapered production cas.ing as required from TD to 1000' above the Kuparuk. (Ib,is._m.a~.Þ.ê .,.rey,ised "to·"eo"'è'I'~'SQ.tu:a.der~i: gås'ed¡;;;éÂiijOg~~$.) Displace the casing with seawater during cementing operations and freeze protect the 5 Y2" x 7-5/8" annulus as required. (Annular Disposal Requirement - Prior to freeze protecting annulus, perform second leak off test below the 7 5/8" shoe. Record on chart and submit to town.) 1 O. If the cement job is suspect, be prepared to immediately run a temperature log to confirm TOe. 11. Test the casing to 4000 psi for 30 min. 12. Run the 3-1/2",9.2#, L-80 gas lift completion assembly. Circulate around corrosion inhibitor. Sting seal assembly into tieback receptacle and test to 4000 psi for 30 minutes both the tubing and annulus. Release tubing pressure and shear RP valve. 13. Install TWC and test from below to 2900 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 14. RU hot oil truck and freeze protect the well by reverse circulating in a sufficient volume of diesel to freeze protect both the tubing and annulus to -2200' TVD. Allow diesel to U-tube from annulus to tubing and equalize at -2000' TVD 15. Rig down and move off. Estimated Spud Date: 10-10-2001 L-118 Permit to Drill Page 5 ) ') L-118 Hazards and Contingencies Job 1: MIRU Hazards and Contingencies ~ L-Pad is not designated as an H2S site. NWE1-01 and NEW 1-02 did not report H2S as being present. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. ~ The closest surface location is L-117. L-117 will be -15' wellhead to wellhead. The well is not producing and will not require a surface shut-in. (To be confirmed) ~ Due to the elevated landing ring height on L-Pad, the BOP stack will need to be run with a double flange on bottom (13-5/8" x 11") Reference RPs .:. OperaüonalSpeciñcs . ¡'¡'li'iJ;';':'/;!'~~~'>¡ò'''~~''i'I:'f1¥ ,mnmrmll'm\ "ff_-;'¡';"''''~'''><~~~:~'~) .m~'i'I'mmm:¥:«:¡:m.'!I.'Wi»~r,._m~l\'I'''~_nllt'ff:"':I\~I\'!'1I"':~I~ilW/m_,m~-_m_>r'''_''',,\) .';I,J¡I,IMI;''''>¡:~mv~..'iMõc'''_¥\I'\'I':l'_",_,:\'\,wr:"'m'i:\m"'l\m'lll~~'\'''''''':'h\'m~~~:~,^'''/)'f'I't1I'.\\':.-, Job 2: DrillinQ Surface Hole Hazards and Contingencies ~ No faults are expected to be penetrated by L-118 in the surface interval. ~ There is a nudge at 300' MD to increase distance from L-117 in the surface hole. A surface gyro will be required while drilling the surface hole. All wells pass major risk criteria. ~ Gas hydrates have been observed on the last seven surface holes drilled on L-Pad from the base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with appropriate mud products. Refer to Baroid mud recommendation ~ Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situation.) Reference RPs .:. Operational Specifics . 1I1I1I11,¡:r;-- .I~·u'q mY' " ·"nll:ITI:·'I..~ .':'.1.1;> .,. ^ .'-.1 : Iml'>!.!. .!. ._. ...·T· ·:w·......n..,..·'wlm· ~~ Job 3: Install surface CasinQ Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. Plan 250% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. As a contingency, a 7-5/8" port collar will be positioned at ±1000'MD to allow a secondary circulation as required. . ~ "Annular Pumping Away" criteria for future permitting approval for annular injection. o Pipe reciprocation during cement displacement. o Cement - Top of tail 750' MD above shoe, (using 30% excess.) L-118 Permit to Drill Page 6 '} ') o Casing - Shoe set -100' TVD below SV1 sand. Reference RPs .:. Operational Specifics . ~'i'lYm~~.,'i'~_~~~'i$ ~~'Þ'f:II"/~_~"<".u;.~~~~~~'_~ ;:"';"'..)I.o¡'¡U;: '¡'·~¡':;"'¡"':'_'(p:,\'tI'i:"I*""",1'...,...N#;~':'I:~..,..~\~",'m1A-- _~.~---'~""'''''f'~'f1'«''':'':':':'':':':~'.~:','''i-;;''M;_'''''''~T!,~~'tiffl''~_Y_'i<.W:U,''';IIN Job 7: DrillinQ Production Hole Hazards and Contingencies ~ KICK TOLERANCE: In the worst case scenario of 10.1 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 13.4 ppg at the surface casing shoe, 10.3 ppg mud in the hole, kick tolerance is 25 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 13.4 ppg. ~ Two fault are expected to be penetrated by L-118. The first in the Ugnu at -3475' TVDss. The throw is -30' to the South. The second fault is in the Colville at -5635' TVDss. The throw is -100' to the East. These are not considered a high risk for lost circulation while drilling, however, losses maybe encountered when running/cementing the production casing string. Consult Lost Circulation Decision Tree for details. ~ A majority of the L-Pad development will have "kick tolerances" in the 25 bbl range or less. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. A redundant flow meter (EPOCH), has been installed for increased kick detection. Reference RPs .:. OperaüonalSpecifics . ~-:m-'!~'/If'Ni'i'!':'~,'~;';:'¡~W'·N~' fI/.»W¡¡'~'/1i$fYi~Hì'''';;';';'';;;,...;,~'''''~'m'i''"i--O<·_''''''-''''','·,","':','I·;'r't.m~'ÞI:",~~ii#W/iIIi.~~'t'_\\1:"IT'I'I:I~:':'i'Yi:!C'Htltlj:'(i1l:jm?l'.ll4#+~f.'I(.'It;-¡,¡.r.-¡,;w.':~,;fJ"""'foi):"Ofi.:f.',;¡,¡¡"',...,-;I;)tI(.'IV;'i.;'¡';';';'iØt!»:'T'·_W_'t:I'_''i_";-x::T.::~~~~:""'.""'--"';l>"'«-:<:''''''~I-~r:'1'Ii'i~Y'!'l'l{:y:'ftW~'_Y''''Y_'nf_\,r_'t:"",(:'lril!'~'1'i'I..I:I.mMiHt.>if'lf;Y,:_\Y'/'firl..!.i''''HXf-,\'ÞI. Job 9: Case & Cement Production Hole Hazards and Contingencies ~ The 5-1/2" casing will be cemented to 1000' above the Kuparuk sand; the upper most expected hydrocarbon bearing zone. The top of the hydrocarbon interval should be verified with LWD resistivity log. If logs indicate the Schrader is productive the cement job will be amended to provide 500' coverage. » If losses are encountered while running the production casing, be prepared to treat with barafiber when circulating on bottom prior to the cement displacement. Consider increasing cement volume if 1000/0 returns are not established. » After freeze protecting the 5 Y2" x 7-5/8" casing annulus to 2500' with 41 bbls of dead crude, the hydrostatic pressure will be assuming a diesel column to surface casing point at 2200' TVD, with 1000' of 12.0 ppg cement above the top of Kuparuk at 5658' TVD and 10.3 ppg mud to 2200' TVD, the hydrostatic pressure will be equivalent to 9.5 ppg or 3252 psi. (This is below the reservoir pressure of 3377 psi at top of Kuparuk) It is essential that freeze protection of the 7" annulus be performed only after the UCA indicates 500 psi compressive strength is indicated. (A second LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping permits.) ~ Ensure a minimum hydrostatic equivalent of 10.3ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. L-118 Permit to Drill Page 7 ) ) )0> The well will be under-balanced after displacing the cement with Sea Water. Verify that the floats are holding before continuing operations and hold pressure on the well if they are not holding. )0> The X- Nipples, with 1.0. of 2.813" is the tightest tolerance for the Weatherford Dual- Plug system, (tapered cement plugs to be used in the 5 Y2" X 3 Y2" tapered casing string.) Caliper and confirm the I.D. of all X-Nipples prior to make-up to ensure conformity with proposed design. The By-Pass plug head has been milled down to an 0.0. of 2.5". Caliper to confirm, prior to use. )0> If the cement job indicates uncertainty in TOC, be prepared to immediately run an e-line temperature log. Reference RPs .:. OperaüonalSpecifics · aaIIDI~II¡ I:¡:UIII:II,III:I_I:!I:I-_:_D-II:¡lllIlIlIrl:111mlll:I:I IIIUlm::I::ml:'¡,:a~·::·::lr'll,rl:I,II lml_:I)~.W'1!"<"-c' 'l>("~I>WIII:II :~lmlll'II¡I_I'III:r_~I\:-I:IIC~!I II,Hmm:,II,HIII,'lcrlmt~:I:II,__U!III L,m,rll,:mallll,II,1,:,I!¡nr¡I)I,IIII,:m,:a:I¡I,UnIHlaI':~I :m:III:I:,:a: I :11:mr:flCm¡,IWIIWlllllrmlll,lal:lllla¡mll:¡:m::I¡:I:.Cljll:1__llaIIlCIl~::"' ",\I,:i_,II'~''''''''~!'I,I,I:I_,II~mI11'111:HI~ Job 12: Run Completion Hazards and Contingencies )0> No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Operational Specifics · ~4:-II,IIC ~:+~·:">~J¡·~·.·:·.·W::;·),I:m::IIIIII,III:11111_11.ILUil.l:aii:: i: ~lla~:; il',iial,I:I~I:II:.::liH·..."~,-::::IIII:II:::a:lnl:','i:':I:.a::.u::::I~:~llla~111~·t;:::::::::::.H+:,II;ml,»IC!W;+;::>I.:.;¡::::*K,:m~,;_ :I;:I-'11:11::' ~'lm:'W::#W_lli:m:'I: ::II:: II. -:II :.:I~:il :~nilli::,:I:li:.:¡::I;I:rlll ,I:Ci,II.::.II':':~¡I rlll:~I:.I~I' Job 13: ND/NU/Release RiQ Hazards and Contingencies )0> No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Operational Specifics · ·""'.m~""~.'1'r'Ir.'i^'.~~.>t.~x .mA'oJrll"'l': '-''I''II·~·mn .I....\, ..\' 1",,,,.,,,,1, I.' .'.~..."IU,\ l,A__II. .u. .,.~_ .r. ."'1"'. . f. .1. .r¡tn:~.'.Il.~>t.U"',\. ... - :r.:I'I.'A"f ' 'I!\.~ .,..,. - '/ftf.'.."''iII' m".'.I'!r. . .\i!I'¥....... ."'~'~':r .~.,,,. .1, '. ..\.11': .,. ". .~"'. x..~· 'I.' . \,.~.U. .\1..\,. ... .'.'T"" L-118 Permit to Drill Page 8 ) ) . - . Borealis L-118: Proposed Completion TREE: 3-1/8" - 5M CIW L-80 Cellar Elevation = 48.2' WELLHEAD: 11" - 5M FMC G5 RKB = 76.2' I . 3-1/2" "BP-6Ii SSSCVLN with 2.813" seal bore. I 2200· I 7-5/8",29.7 #/ft, L-80, BTC I 3213' I ~ .. 3-1/2" x 1" KBG-2 Gas Lift Mandrels with handling pups installed. L GAS LIFT MANDRELS ---~_._.._-_.__...._._._._--------- --..----.---.---..----.-- # MD Size Valve Type 1 2 3 4 TBD TBD TBD TBD 1" 1" 1" 1" DK-1 DK-1 DK-1 Shear L -~ 3-1/2" 9.3# IBT L-80, Tubing L L . . 3-1/2" 'X' Landing Nipple with 2.813" seal bore 5-1/2",17 #lft, L-80, BTC- Mod (reduced clearance cplg) " ......- 3-1/2" Seal Asembly -4-:- 3-1/2" PBR ,,7' 5-1/2"x3-1/2" XO Plug Back Depth I 10,163' . . 3-1/2" 'X' Landing Nipple with 2.813" seal bore J C 3-1/2" 'X' Landing Nipple with 2.813" seal bore, placed at +/-150' above the Kuparuk Formation. 3-1/2", 9.2 #Ift, L-80, IBT Mod 10,243' Date 7/17/01 9/1 0101 Rev By JAS NM Comments Borealis WELL: L-118 API NO: 50-029-????? Proposed Seal Bore Completion Microbore with 5-1/2"x3-1/2" tapered longstring BP Alaska Drilling & Wells :Li. ø_ Report Date: Client: Field: Structure / Slot: Well: Borehole: UWlfAPI#: Survey Name / Date: Tort f AHD I DOli ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid N/E YIX: Grid Convergence Angle: Grid Scale Factor: I KBE KOP Bid 1/100 Station ID Bid 2/100 Bid 3/100 SV5 L-118 (P5) report.xls L-118 Schlumbøruør Proposed Well Profile - Geodetic Report September 10,2001 Alaska Drilling & Wells Prudhoe Bay Unit - WOA L-PAD 1L-118 L-118 L:-118 50029 L-118 (P5) / September 10, 2001 106.818° /6516.25 ft /6.000/0.914 NAD27 Alaska State Planes, Zone 04, US Feet N 70.35060808, W 149.32497053 N 5978271.550 ftUS, E 583141.710 ftUS -+Û.63572444° 0.99990785 ØI Fea51 ility MD Incl Azim TVD VSec Nf-S (ft) (0) (0) (ft) (ft) (ft) 0.00 0.00 20.75 0.00 0.00 0.00 300.00 0.00 20.75 300.00 0.00 0.00 400.00 1.00 20.75 399.99 0.87 0.82 500.00 2.00 20.75 499.96 3.49 3.26 600.00 3.00 20.75 599.86 7.84 7.34 700.00 5.00 20.75 699.61 14.81 13.87 800.00 7.00 20.75 799.06 25.25 23.64 900.00 9.00 20.75 898.08 39.15 36.65 1000.00 12.00 20.75 996.40 57.35 53.69 1100.00 15.00 20.75 1093.62 80.66 75.52 1200.00 18.00 20.75 1189.49 109.02 102.08 1300.00 21.00 20.75 1283.75 142.36 133.29 1400.00 24.00 20.75 1376.13 180.58 169.07 1500.00 27.00 20.75 1466.37 223.57 209.33 1586.01 29.58 20.75 1542.10 264.28 247.44 1600.00 30.00 20.75 1554.25 271.22 253.94 1700.00 33.00 20.75 1639.50 323.40 302.80 Page 1 of 3 tu Survey I DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 17.900° y Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: KB TVD Reference Elevation: 77.1 ft relative to MSL Sea Bed I Ground Level Elevation: 49.000 ft relative to MSL Magnetic Declination: 26.218° Total Field Strength: 57465.856 nT ~ Magnetic Dip: 80.756° Declination Date: October 17, 2001 Magnetic Declination Model: BGGM 2001 North Reference: True North Total Corr Mag North -> True North: +26.218° Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Ef·W DLS Northing Easting Latitude I Longitude (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 5978271.55 583141.71 N 70.35060808 W 149.32497053 0.00 0.00 5978271.55 583141.71 N 70.35060808 W 149.32497053 0.31 1.00 5978272.37 583142.01 N 70.35061032 W 149.32496801 1.24 1.00 5978274.82 583142.91 N 70.35061699 W 149.32496046 2.78 1.00 5978278.92 583144.41 N 70.35062813 W 149.32494796 5.25 2.00 5978285.48 583146.81 N 70.35064597 W 149.32492791 8.96 2.00 5978295.29 583150.41 N 70.35067266 W 149.32489779 13.89 2.00 5978308.35 583155.19 N 70.35070821 W 149.32485777 20.34 3.00 5978325.46 583161.45 N 70.35075476 W 149.32480541 - 28.61 3.00 5978347.38 583169.48 N 70.35081439 W 149.32473827 38.67 3.00 5978374.04 583179.24 N 70.35088695 W 149.32465660 50.50 3.00 5978405.38 583190.72 N 70.35097222 W 149.32456056 64.06 3.00 5978441.30 583203.88 N 70.35106996 W 149.32445048 79.31 3.00 5978481.73 583218.69 N 70.35117995 W 149.32432667 93.75 3.00 5978519.99 583232.70 N 70.35128406 W 149.32420944 96.21 3.00 5978526.52 583235.09 N 70.35130182 W 149.32418947 114.72 3.00 5978575.58 583253.05 N 70.35143530 W 149.32403919 9/10/2001-4:06 PM Grid Coordinates Geographic Coordinates I Station ID MD Incl Azim TVD I VSec I N/-S I E/-W I DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) SV4 1757.32 34.72 20.75 1687.10 355.30 332.66 126.03 3.00 5978605.56 583264.03 N 70.35151687 W 149.32394737 1800.00 36.00 20.75 1721.90 379.96 355.76 134.78 3.00 5978628.75 583272.52 N 70.35157998 W 149.32387633 1900.00 39.00 20.75 1801.23 440.76 412.68 156.35 3.00 5978685.90 583293.46 N 70.35173548 W 149.32370120 End Bid 1933.53 40.01 20.75 1827.10 462.06 432.62 163.91 3.00 5978705.92 583300.79 N 70.35178995 W 149.32363982 Base Permafrost 1966.17 40.01 20.75 1852.10 483.02 452.24 171.34 0.00 5978725.62 583308.01 N 70.35184355 W 149.32357950 Cry 4/100 1998.81 40.01 20.75 1877.10 503.97 471.86 178.77 0.00 5978745.32 583315.22 N 70.35189715 W 149.32351917 2000.00 40.05 20.75 1878.01 504.74 472.58 179.05 4.00 5978746.04 583315.49 N 70.35189912 W 149.32351690 2100.00 44.05 20.75 1952.25 571.62 535.21 202.77 4.00 5978808.93 583338.51 N 70.35207022 W 149.32332432 2200.00 48.05 20.75 2021.64 643.52 602.52 228.28 4.00 5978876.51 583363.27 N 70.35225410 W 149.32311719 SV3 2208.20 48.38 20.75 2027.10 649.63 608.24 230.44 4.00 5978882.25 583365.37 N 70.35226973 W 149.32309965 2300.00 52.05 20.75 2085.83 720.07 674.20 255.43 4.00 5978948.48 583389.62 N 70.35244992 W 149.32289675 -- 2400.00 56.05 20.75 2144.52 800.91 749.89 284.11 4.00 5979024.48 583417.46 N 70.35265670 W 149.32266388 End Cry 2446.12 57.90 20.75 2169.65 839.53 786.05 297.81 4.00 5979060.78 583430.75 N 70.35275548 W 149.32255264 SV2 2497.77 57.90 20.75 2197.10 883.23 826.96 313.31 0.00 5979101.86 583445.80 N 70.35286724 W 149.32242678 SV1 3099.93 57.90 20.75 2517.10 1392.69 1303.96 494.04 0.00 5979580.79 583621.21 N 70.35417033 W 149.32095919 7-5/8" Csg Pt 3212.83 57.90 20.75 2577.10 1488.22 1393.40 527.93 0.00 5979670.59 583654.10 N 70.35441467 W 149.32068397 UG4A 3730.31 57.90 20.75 2852.10 1926.04 1803.33 683.24 0.00 5980082.18 583804.84 N 70.35553453 W 149.31942262 UG3 4454.79 57.90 20.75 3237.10 2538.98 2377.22 900.68 0.00 5980658.39 584015.88 N 70.35710228 W 149.31765644 UG1 5301.57 57.90 20.75 3687.10 3255.42 3048.01 1154.84 0.00 5981331.90 584262.55 N 70.35893471 W 149.31559166 Ma 5856.69 57.90 20.75 3982.10 3725.08 3487.75 1321.45 0.00 5981773.42 584424.26 N 70.36013597 W 149.31423793 Tgt 1/ Cry 2/100 6374.17 57.90 20.75 4257.10 4162.90 3897.67 1476.76 0.00 5982185.00 584575.00 N 70.36125575 W 149.31297587 Na 6383.57 57.86 20.53 4262.10 4170.85 3905.13 1479.57 2.00 5982192.49 584577.73 N 70.36127613 W 149.31295303 6400.00 57.79 20.15 4270.85 4184.74 3918.16 1484.40 2.00 5982205.57 584582.41 N 70.36131172 W 149.31291378 6500.00 57.41 17.83 4324.43 4269.16 3997.99 1511.88 2.00 5982285.69 584609.00 N 70.36152979 W 149.31269045 6600.00 57.08 15.48 4378.54 4353.22 4078.55 1535.99 2.00 5982366.51 584632.21 N 70.36174986 W 149.31249449 Oa 6606.55 57.06 15.33 4382.10 4358.71 4083.85 1537.45 2.00 5982371.82 584633.61 N 70.36176434 W 149.31248262 6700.00 56.78 13.12 4433.11 4436.85 4159.75 1556.69 2.00 5982447.92 584652.01 N 70.36197168 W 149.31232621 ~ End Cry 6735.67 56.69 12.28 4452.68 4466.55 4188.84 1563.25 2.00 5982477.08 584658.24 N 70.36205115 W 149.31227288 Obf Base 7262.68 56.69 12.28 4742.10 4904.86 4619.19 1656.90 0.00 5982908.40 584747.11 N 70.36322677 W 149.31151142 Drp 2/100 7571.03 56.69 12.28 4911.44 5161.31 4871.00 1711.69 0.00 5983160.78 584799.09 N 70.36391466 W 149.31106589 7600.00 56.11 12.28 4927.47 5185.32 4894.57 1716.82 2.00 5983184.40 584803.96 N 70.36397904 W 149.31102418 7700.00 54.11 12.28 4984.67 5266.95 4974.71 1734.27 2.00 5983264.73 584820.52 N 70.36419797 W 149.31088227 7800.00 52.11 12.28 5044.69 5346.54 5052.86 1751.27 2.00 5983343.05 584836.65 N 70.36441145 W 149.31074402 CM2 7836.19 51.39 12.28 5067.10 5374.82 5080.63 1757.31 2.00 5983370.88 584842.38 N 70.36448731 W 149.31069490 7900.00 50.11 12.28 5107.47 5424.00 5128.91 1767.82 2.00 5983419.27 584852.35 N 70.36461920 W 149.31060943 L-118 (P5) report. xis Page 2 of 3 9/10/2001-4:06 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NI·S EI·W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 8000.00 48.11 12.28 5172.93 5499.23 5202.78 1783.90 2.00 5983493.31 584867.61 N 70.36482100 W 149.31047866 8100.00 46.11 12.28 5240.99 5572.14 5274.36 1799.48 2.00 5983565.05 584882.39 N 70.36501654 W 149.31035195 8200.00 44.11 12.28 5311.56 5642.64 5343.59 1814.54 2.00 5983634.44 584896.68 N 70.36520566 W 149.31022947 8300.00 42.11 12.28 5384.56 5710.64 5410.36 1829.07 2.00 5983701.36 584910.47 N 70.36538806 W 149.31011130 8400.00 40.11 12.28 5459.90 5776.08 5474.60 1843.05 2.00 5983765.74 584923.74 N 70.36556355 W 149.30999760 8500.00 38.11 12.28 5537.49 5838.85 5536.24 1856.47 2.00 5983827.52 584936.47 N 70.36573193 W 149.30988845 8600.00 36.11 12.28 5617.23 5898.89 5595.19 1869.30 2.00 5983886.61 584948.64 N 70.36589297 W 149.30978410 8700.00 34.11 12.28 5699.03 5956.13 5651.39 1881.53 2.00 5983942.93 584960.25 N 70.36604649 W 149.30968463 CM1 8781.44 32.48 12.28 5767.10 6000.62 5695.07 1891.03 2.00 5983986.71 584969.26 N 70.36616582 W 149.30960736 8800.00 32.11 12.28 5782.79 6010.49 5704.76 1893.14 2.00 5983996.42 584971.27 N 70.36619229 W 149.30959019 ~' 8900.00 30.11 12.28 5868.40 6061.90 5755.24 1904.13 2.00 5984047.02 584981.69 N 70.36633018 W 149.30950080 9000.00 28.11 12.28 5955.77 6110.32 5802.78 1914.47 2.00 5984094.67 584991.50 N 70.36646005 W 149.30941670 9100.00 26.11 12.28 6044.78 6155.67 5847.30 1924.16 2.00 5984139.29 585000.70 N 70.36658167 W 149.30933788 9200.00 24.11 12.28 6135.32 6197.89 5888.77 1933.19 2.00 5984180.85 585009.27 N 70.36669496 W 149.30926443 9300.00 22.11 12.28 6227.29 6236.95 5927.12 1941.53 2.00 5984219.29 585017.18 N 70.36679972 W 149.30919659 Top HRZ 9310.58 21.90 12.28 6237.10 6240.90 5930.99 1942.38 2.00 5984223.17 585017.99 N 70.36681029 W 149.30918968 9400.00 20.11 12.28 6320.58 6272.79 5962.31 1949.19 2.00 5984254.56 585024.45 N 70.36689585 W 149.30913428 9500.00 18.11 12.28 6415.06 6305.37 5994.29 1956.16 2.00 5984286.61 585031.06 N 70.36698321 W 149.30907759 Base H RZ 9512.66 17.86 12.28 6427.10 6309.26 5998.11 1956.99 2.00 5984290.44 585031.85 N 70.36699364 W 149.30907084 K-1 9585.91 16.39 12.28 6497.10 6330.73 6019.19 1961.57 2.00 5984311.56 585036.20 N 70.36705123 W 149.30903358 9600.00 16.11 12.28 6510.63 6334.65 6023.04 1962.41 2.00 5984315.42 585036.99 N 70.36706175 W 149.30902675 Top Kuparuk 9655.49 15.00 12.28 6564.09 6349.46 6037.58 1965.58 2.00 5984330.00 585040.00 N 70.36710147 W 149.30900096 End Orp / Tgt 2 9655.50 15.00 12.28 6564.10 6349.46 6037.58 1965.58 2.00 5984330.00 585040.00 N 70.36710147 W 149.30900096 Kuparuk C 9661.71 15.00 12.28 6570.10 6351.06 6039.15 1965.92 0.00 5984331.57 585040.32 N 70.36710576 W 149.30899820 TMLV 10093.41 15.00 12.28 6987.09 6462.26 6148.33 1989.68 0.00 5984441.00 585062.87 N 70.36740401 W 149.30880492 TO /5-1/2" Csg pt 10243.42 15.00 12.28 7131.99 6500.90 6186.27 1997.94 0.00 5984479.02 585070.71 N 70.36750765 W 149.30873773 '- LeQal Description: Northing (Y) rftUSl Easting (X) rftUSl Surface: 2550 FSL 3773 FEL S34 T12N R11E UM 5978271.55 583141.71 Tgt 1 : 1167 FSL 2289 FEL S27 T12N R11E UM 5982185.00 584575.00 Tgt 2: 3307 FSL 1796 FEL S27 T12N R11E UM 5984330.00 585040.00 BHL: 3456 FSL 1763 FEL S27 T12N R 11 E UM 5984479.02 585070.71 L-118 (P5) report. xis Page 3 of 3 9/10/2001-4:06 PM I ".. . IQ.QI -2000 - 0- ............ ..... Q) .- ~ ~ 2000 8~ o 0) N > II .8 "£: ctI T"""4= __ 0 :E. ~ 4000 0)-- OlD -~ ~~ t: Q) O)Q:: > > 0) ~ 6000 :::JW ~ I- 8000 10000 ) ) VERTICAL SECTION VIEW Client: Alaska Drilling & Wells Well: L-118 (P5) Field: Prudhoe Bay Unit - WOA Structure: L-PAD Section At: 17.90 deg Date: September 10, 2001 Schlumberger j... I .,,·..i..... i KOP Bid 11100300 MD 300 TVD /' 0,00' 20,75' iaz ° departure //' Bid 2/10d 600 MD 600 TVD - ..".. 3:00":iq.7S"Öz8ëtapöiiura ,. Bid ~/100 900 MD 898 TVD 9,Oor 20,75' az 39 departure End Bid 1934 MD 1827 TVD ,// to.01· 20.75' az 462 departure ../ Crv 4/100 1999 MD 1877 niD -/1' 40.01' 20.75' az 504 dapa~ure I "~'I"~ ~.... .~ .~ ~- / ~'~9f' j~~er.<Hì) J~;4:C1V(i.::: ~·)V·1 1f'~r fv1() '1i5~rt '¡"\I'D ~.': ~~:;~~~t~;:'~~ð¡~7~ë:&;;~ .. "'" ...'.'.'.'......".'.' .'" ... ".'.'. .. '" .F!:;,,',f;;,!,,;'ïil:~";¡'·.1\¡i\Lt,:1¡)'1!ii;:: IYi:~ ... ..... ...... ..... ..... f ..... ..... ~i0~ [,\,~~·t~g ..~?;~~r:~~~~".. .... I 7·5/8" Csg P13213¥D 2577 TVD I '57.90' '20.75' az"1~a'8'departure !;\i1:ïiûor~¡02~ri"lv¡)' Hbid Angle 57.90° i. .....:: Tg11/ Crv 2/1006374 MD 4257 TVD : :,. 57.:~O' .?o. 7.~.' !a~.41 ~~ de.~.artu'.~ ..... I /' ¡End Crv 6736 MD 4453 TV~'" I ". .,. ,.... . 5~.69·· '12:28' '~.~"'4~~d~P'ätl~tl""·· "l:)rP2.'10o..!57!Mi:>. 49.1.' ry~ 56.69' 12.28' az 5161 defarture I I /~~:SD~6/1~~~~ TVD 1Š:ÖO'''1~,2ä' az ,····...···63~9·d~~r~të··· ~~.: :;~: I:::.: o 4000 I 6000 I 8000 Vertical Section Departure at 17.90 deg from (0.0, 0.0). (1 in = 2000 feet) 2000 I 3000 I 2000 EAST »> «< WEST I 1000 I -1000 CN 4/100 1999 MD 18771VD 40.01' 20.75' az 472 N 179 E KOP Bid 1/100 300 MD 3001VD 0,00· 20.75· az ON 0 E -0 o '- End CN 2446 MD 21701VD 57,90' 20,75' az 786 N 298 E End Bid' 1934 MD 18271VD 40,01' 20,75' az Bid 3/100 900 MD 898 1VD 9,00' 20.75' az 37 N 14 E Bid 2/100 600 MD 600 1VD 3,00' 20.75' az 7 N 3 E 1393 N 528 E - 1000 1000 _.... 7-518" Csg PI 3213 MD 25771VD '"- - 6000 End Drp / TgI ~ 9656 MD 65$ TVD 15,00' 12.281 az 6038 N 1966 !E r 0 ~ C\j 1"- r\r~ r- S 5000 - i~ ...~ 5000 Drp 21100 7571 MD 49111VD 56.69' 12.28· az 4871 N 1712 E r ^ ^ ^ I End CN I- 4000 56,69· 12,28· az 0::: / 4189 N 1563 E 0 TgI 1/ CN 2/100 Z 6374 MD 42571VD 57,90· 20.75' az 3898 N 1477 E 3000 - 3000 I I- :.:J 0 2000 -"''''''''.. .', "'" ................... ..................~; ...... ...... ... .... ... ······,1 .. ""i . .... .", ... ....... ......¡'''''' ..., .. ......... - 2000 (j) V V V True North Mag Dee ( E 26.22° 6000 - 3000 I 2000 1000 I o -1000 Schlumberuer VIEW Alaska Drilling & Wells L-1l8 (P5) Prudhoe Bay Unit - WOA L-PAD 1 in = 1000 ft 10-Sep-2001 PLAN Client: Well: Field: Structure: Scale: Date: .. ) \ j ) ) Schlumberger Anticollision Report ----------,--.-..---,----- -....---..--.--........----.-.---- ._-.-------.-- Company: BPAI1'1Oco Field: Prudhoe Bay RCference Site: PB LPad Referel1ce Well: L~118 Reference Wellpath: Plan L-118 --,-_._-_...._-_._.__._..._-,_.._---~_..__..~_.._,.._-_._,-.--".-- Date: 9/10/2001 Time: 15:52:,39 Page: Co-ordinate(NE) Reference: Vertical, (TVD) Reference: WeU:L-t18. Trué North L-1t8 plan 77.1 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 28.50 to 10243.42 ft Maximum Radius: 1211.96 ft Reference: Error Model: Scan Method: Error Surface: Db: .. . Sybase .----.-- ---.----.-,-.-.-------.---------..-.-.- Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing ..--,...--..------,.-- -.--.--..----.------. --"-' ..--------".---.-- .. .. __~_..___._...,.,_,___._,.__.,_._.'._____ 0"' ."., __. "__'.",___.._._~.._ . .'. _"_.._,, .."_.._.._._.._,_.__._.__...__,,.__.___ . - '. -.. - .,- .. -"......- ... _.'--~---.".'.--_..-..~.-'~"- ..---.---.--...-.-,"---.- -.'-..-'----'-.----......-..,..--,-.,..---. '-"-'~ ---~._~_.._._.'-- .---.----.--..--- --,._--_._-------------,--,._._-_.._..~---- --...~ -. -..----...-..-...,.....,.,--- --.-.-----.-..- _.._----._,--_.._,._---~-,_.._.__._._..- Survey Program for Definitive Wellpath Date: 12/26/2000 Validated: No Version: 7 Planned From To Survey TooIcode ft ft ~._-~_._-_.._--,-,-_.- ------,-_.~--,_._.__..- --~---_._-_._-,-_.__._-,.._-_._---,_._-,_._.._-_._._,-_.__...,.~,--_.,_._--_.__.- 28.50 1200.00 Planned: Plan #5 V1 CB-GYRO-SS 1200.00 10243.42 Planned: Plan #5 V1 MWD+IFR+MS Tool Name _~_.___..~__.'.._____._._____.____._,_,____.._.___,__,w__.._..__,__ Camera based gyro single shots MWD + IFR + Multi Station ·_____~__.__'_R___.___.."_.__..____.__._. --.,---------..-------.-- Casing Points .._' ....__~~_..,.._ .·,__".~....._.___.,,_._.__..~.,w~,...~".~.__"'..,,_ _.__"y ._~,_._.___._,.~..~__."......_.w..__'T_,~_...._...,_.,_.....,...___._............____.._.'. ~__...__..'_".._....~__ ..~~..¥.____.'_,_"_.~._____,_.~,~.~~_". MD TVD ft ft ---,._~.,--".,..__. -,-~,--_._._.._--,-~..---._- 3212.91 2577.10 10243.42 7131.85 Diameter in Hole Size in Name ~._.·_·.___..___··_~.__..._._____,_._..__.___.w___.___,~_,......._..._.._.___......._._.__...__..,_..._. _...____.___~...___ 7.625 5.500 9.875 6.750 75/8" 5 1/2" __._._..__.__.__.____".___.,.."__.~,_~.__~._.._.,.. ."_,.c·_.__. __..'.~.___..~___._..__.____._.__._.......__.._~...____._.....,_._.__".__,......___.__,...".._______<0_.,____._ ..__.__.___.________..."._..______.____.~ _.__'_____________..~__,._._.____._....__.._. Summary ..______.__'"...~__.........,___. .~_._".,_ ... _,' .__~ _..__.,_,_.~_.._."...___. _ ..._.,_._..,_ _._...__,.__ ..____,_ ,~_"_,___._._._..._,,___._..____.____.__,~..' _,_..~... __..~_ ." .._ _.__....~ ___,____ _.··_M____._.·. ..._ _...~_..__.__,.,_,...___".._..__.~ .~_.__,.__...._._...____..__._"_.___,_._____.__.,_,___.._. .__.._._"._.___".....____.__.,.._...__._~_._"_..,._.___". <-----~-~-~--------~-- ,OffsefWellpath -~~-~~---~--~--~---~-> Reference Offset Ctr-Ctr·.. No-Go Allowable Site Well Well path MD MD Distance' Area Deviation Warnil1g ft ft ft ft ft ._--_._-----~-_.._._----~.__._..._.._..._-,---- _._._.__ø__..___~__._._._._________.___ .-.-..-.-.--.- --------.---- EX NWE#1 NWE1-01 NWE1-01 V3 299.99 300.00 262.37 6.22 256.15 Pass: Major Risk EX NWE#1 NWE1-01 NWE1-01A VO 299.99 300.00 262.37 6.22 256.15 Pass: Major Risk EX NWE#1 NWE1-02 NWE 1-02 V2 1410.97 1450.00 1 04.44 28.97 78.09 Pass: Major Risk PB L Pad L-01 L-01 V12 349.07 350.00 194.69 7.33 187.36 Pass: Major Risk PB L Pad L-107 L-107 V13 224.97 225.00 200.05 5.84 194.22 Pass: Major Risk PB L Pad L-110 L-110V11 299.99 300.00 186.97 6.56 180.41 Pass: Major Risk PB L Pad L-114 L-114 V14 444.56 450.00 215.39 8.33 207.06 Pass: Major Risk PB L Pad L-116 L-116V10 639.44 650.00 183.10 11.49 171.63 Pass: Major Risk PB L Pad _~1,!~~~'~:~:(, :f:·' ,."~',t:':.;i,~;:''õ·;~j';R:J,~~¡hr1ct·~T~~~:I~~n~,::~!;';'/(,~-;.,.1~~~~~!j}'i;,,~:~~,9tW~~:;;'··, :::~1~~@1~' 12.02 4.92 Pass: Major Risk ,....~..._._._.. --, - - ..-- --,~,-. Polygon I 2 3 4 --_._----~----_.._--- IÌ ~ ~ ~ ~ Site: PB L Pad Drilling Target Conf.: 99% Centre Location: Map Northing: 5984330.00 ft Map Easting : 585040.00 ft Latitude: 70022'01.565N +N/-S ft 404.44 395.58 -404.44 -395.58 ...------.--. -.. _._--"._--~--,._....... ) Target: L-118 Kup Tgt +E/-W ft -395.58 404.44 395.58 -404.44 --- - -~--------- -- - -- -- -------------- - -- ----. -- . I l_ ,. .__..'_ . __. ·_.~n_...'__._. ....~...._._n__ ,_ ., ,.___ . _,..,., . n ,. o o --3- o o LD o o CD o o o N -_._-_._~---,..~'.-- -' -_." --..-. -.-..-.-.----.....---- o o N N ,)ell: L-118 Based on: Planned Program Vertical Depth: 6487.00 ft below Mean Sea Level Local +N/-S: 6037.61 ft Local +E/-W: 1965.46 ft Longitude: 149°18'32.404W Northing ft 5984730.00 5984730.00 5983930.00 5983930.00 -.,------ . ..,_.,.___,_~J o o -+ N Easting ft 584640.00 585440.00 585440.00 584640.00 -----..-.-..-..--.,..---.----,. o o LD N lOI S8[ SSC 54-[ 520 5001 S80[ 550C 54-DC o o CD N ) ) L-118 Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates were observed in all offset wells. These are expected to be encountered near the base of the Permafrost at 1966' and near the TD hole section as well. · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity and yield point is maintained to avoid stuck pipe situations. Production Hole Section: · The production section will be drilled with a recommended mud weight of 10.3 ppg to ensure shale stability in the HRZ shale. Read the Shale Drilling Recommended Practice. · Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. · FAULTS: The well trajectory is expected to intersect two faults while drilling L-118. The first in the UGNU at 3475' TVDss and the second in the Colville at 5635' TVDss. These are considered a risk for loss circulation. Consult Lost Circulation Decision Tree for recommended LCM treatments. · KICK TOLERANCE: With 10.0 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 13.4 ppg at the surface casing shoe, 10.3 ppg mud in the hole, the kick tolerance is 25 bbls. (Offset wells have shown fracture gradient of 13.5 ppg to 15.6ppg at the surface shoe depth. ) · A majority of the L-Pad development will have "kick tolerances" in the 25-35 bbl range or less. At least 100' prior to entering the Kuparuk reservoir, the drill crews will hold a safety meeting to discuss steps to ensure that a heightened awareness of kick detection will be in place while drilling/tripping through the intermediate/production intervals. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells NWE 1-01 and NWE 1-02 did not report H2S as being present. As a precaution Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page 1 of 1 ) ) H 194711 DATE 07/31/01 CHECK NO. 00194711 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR ALASKAO I LA DISCOUNT NET 00 D72701 CK072701B PYMT COMMENTS: HANDL:NG INST: 100.00 100.00 PerMit To Drill Fee StH - Terrie Hubble X4628 ~:.~-~::.t~~ ..,._"-~..J'-!-=4.. L- t \ ~ E ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ ' 100.00 100.00! BP EXPLORATION, (ALASKA) INC. p.o. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No~ H 19 4 711 CONSOLIDATED COMMERCIAL ACCOUNT 56·389 4""1"2 00194711 PAY ONE HUNDRED 8< 00tl00~************************************ US DOLLAR DATE 07/31/01 AMOUNT $100.00 To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 NOT VALID AFTER 120 DAYS n l'JAIlJ¡~ ,~ \<-c-^" VVEV~I _r ._.___ . III ~ 9 L. 7 ~ ~ III I: 0 L. ~ 20 j a 9 5 I: 00 a L. L. ~ 9 III CHECK 1 ST ANDARD LETTER DEVELOPMENT j DEVELOPMENT REDRlLL EXPLORATION INJECTION WELL INJECTION WELL RED RILL ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME fl:d L - / I f3 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DJŠPOSAL L.J¿jNO ANNULAR DISPOSAL L-J YES "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. . In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50___-70/80) from records, data and logs acquired for well (name on permit). -- Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . ~-- "'-'),'1 -"... ,. "..,., ~-'---_." ., ". ------- r::;NULAR DISPOSAL Annular Disposal O,f drilling was,.tes will not be approved... \... THIS WELL ' ./ DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS L---> YES + SP ACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved, subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. ~~ ' *,fo ~~~~\L-~ ~ Templates are located m drive\jody\templates 1fJ5¿1 _ WEll PERMIT CHECKLIST COMPANY ¡Sð WEll NAME £. -I If; PROGRAM: exp _ dev ,/ redrll_ serv _ well bore seg _ann. disposal para req_ FIELD & POOL (, t..j(j I~:z¿) INIT CLASS ~Ev I ()/ L GEOL AREA Bm UNIT# () / / ~ÇD ON/OFF SHORE On ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ~N 2. lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y;¡ N /:J / ,/ ~ I -, eJ 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y C!Ð r;~c1 {~ &.J ~T'¿Qí/S /c:r-~ t<) tLndë..r",; . 5. Well located proper distance from drilling unit boundary. _ N 6. Well located proper distance from other wells.. . N 7. Sufficient acreage available- in drilling unit.. . . . . . . . . . . N, 8. If deviated, is wellbóre plat included.. . . . . . . . . . . ... . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . APkR DATE I 12. Permit can·be issued withoL1. administrative approval.. . . . . ,ði>-. t:t. ¡C}.j) 13. Can permit be approved before 15-day wait.. . . . . . . . . . .ENGINEERING 14. Conductor string provided . . . . . . . . .. . . . . . . . . . 15. Surface casing protects all known USDWs. . .. . . . . 16. CMT vol adequate to circulate on conductor & suñ csg. . . . . 17. GMT vol adequate to tie-in long string to suñ csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . ; . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate well bore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations . . . . . . . . . . 24. Drilling .fluid program schematic & equip list adequate. . ~ . . 25. BOPEs, do they meet regulation . . . . . . . . . . . . . . . . 26. BOPE press rating appropriate; test to l..\'C:RC) psig. . 27. Choke manifold complies w/API RP-53 {May 84}. . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . ..N-~ 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . YQi) 30. Pennit can be issued w/o hydrogen-sulfide measures. . . . '. fY) N 31. Data presented on potential overpressure zones. . . .~. . ~N 32. Seismic analysis of shallow gas zones. . . . . . . . . . ',' . N AP~ DATE 33. Seabed condition survey {if off-shore}. . . . . . . . . . . . . Y N ~ ~ () ']'. ¡e¡. 0 1 34. Contact name/phone for weekly progress reports [explo ory only] Y N , -.: ANNULAR DISPOSAL35. With proper cementing records, this plan. o.t"\,,~\.o.' "G'\~ ~~\ ~ ~~~~\'\ "\>\o.,,~\ \p~ ~~\~ ~'<:. ~'\-~~~ (A) will contain waste in a suitable receiving zone; . . . . . . . Y N (B) will not contaminate fréshwater; or cause drilling waste. .. Y N to surface; , (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and . (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLO~~: ENGINEERING:,· UIC/Annular COMMISSION:. ~ÞBÆ~~ ~~ .IJà WM '8~s r~, 7 1c?Z h /, ~5/)/ TEM~4)t}<ò(( JMH ~'~~7.mlø¿Jul . , '~~,' {bA,TE ~~YIII )( l GEOLOGY APPR DATE c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ·N Y N ~~ ø t ~\C~~\ t<'c.1'\ tt "\-\\N<.>-"-:\'i ~~-=.;J ~ N ~~\\.....~ ~~I t-C\ ~'<Jé"'-,,«"~\~ . N ('\.~ c \o~ C\.~~" ~~'\~\~ Y N N N ~ \J\~ÿ>~<;.;\-~ d-'lë)'l ~~, \ l\l)C'('\ ,Ç\"\ ~ ~~~ ~è\.~\ ~\ \(:~..\- c o z o -f ~ :;0 -f' m ( -' Z -f J:' en :Þ :xJ m :Þ { Comments/Instructions:
