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Home My WebLink About203-001Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity<PBFieldWellIntegrity@hilcorp.com> Sent: Wednesday, August 12, 2020 5:09 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Stan Golis; Bo York; Aras Worthington; Oliver Sternicki Subject: NOT OPERABLE: WAG Injector 14-17A (PTD #2030010) TxIA communication Mr. Wallace, WAG Injector 14-17A (PTD # 2030010) failed an MIT -IA on 07/25/20. The failed MIT -IA verifies failure of one or more well barriers. The well will now be classified as NOT OPERABLE and will remain shut in until well barriers have been restored. Please respond with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity/ Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity Sent: Thursday, July 23, 2020 10:25 AM To: chris.wallace@alaska.gov • Regg, James B (CED) <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Bo York <byork@hilcorp.com>; Aras W o rtWLngton <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: DER EVALUATION: WAG Injector 14-17 (PTD #2030010) TxIA communication Mr. Wallace, WAG Injector 14-17 (PTD # 2030151 was called in by the Drillsite Operator on 07/22/20 for requiring multiple bleeds of the inner annulus pressure. A recent AGQCC witnessed MIT -IA passed on 07/21/20 and shortly thereafter required multiple bleeds on the inner annuls. The w- l Was on stable injection and the number of bleeds exceeded the amount that could be expected by thermal events. The will now be classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan forward: 1. Wellhead Technician: PPPOT-T \ 2. Fullbore(Pending): online MIT -IA, Establish LLR if fails \� 3. Wireline (Pending): LDL 4. Well Integrity: Additional diagnostics as needed Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity /Compliance andrew.oee(@hilcorr).com P: (907) 659-5102 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission ' I DATE: Wednesday, July 29, 2020 TO: Jim Regg P.I. Supervisor SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 14-17A FROM: Brian Bixby PRUDHOE BAY UNIT 14-17A Petroleum Inspector Src: Inspector Reviewed By: P.1. Supry —J NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 14-17A Insp Num: mitBDB200721105439 Rel Insp Num: API Well Number 50-029-20562-01-00 Inspector Name: Brian Bixby Permit Number: 203-001-0 Inspection Date: 7/21/2020 Packer Well 14-17A 'Type Inj W TVD 010 Type Testi SPT _Test psi BL i 2030 — — --- --- Pumped: �S.l BBBL Returned: Interval' 4YRTST IP/F Notes: Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 8519 Tubing 1148 - 1147 - 1146 - 1146— --- 2130 IA 300 2508 2424 2389 5.6 _ OA 156 276 275 - 268 - P — Wednesday, July 29, 2020 Page 1 of I Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWel[Integrity@hilcorp.com> Sent: Thursday, July 23, 2020 10:25 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Stan Golis; Bo York; Aras Worthington; Oliver Sternicki Subject: UNDER EVALUATION: WAG Injector 14-17 (PTD #2030010) TxIA communication Attachments: 14-17A.PDF Mr. Wallace, WAG Injector 14-17 (PTD # 2030010) was called in by the Drillsite Operator on 07/22/20 for requiring multiple bleeds of the inner annulus pressure. A recent AOGCC witnessed MIT -IA passed on 07/21/20 and shortly thereafter required multiple bleeds on the inner annuls. The well was on stable injection and the number of bleeds exceeded the amount that could be expected by thermal events. The well will now be classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan forward: 1. Wellhead Technician: PPPOT-T 2. Fullbore(Pending): online MIT -IA, Establish LLR if fails 3. Wireline (Pending): LDL 4. Well Integrity: Additional diagnostics as needed Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/Compliance andrew.ogg@hilcorp.com P:(907)659-5102 M: (307)399-3816 203001 3130$ 7=23 CASED 1 HOLE Well Log Transmittal To: AOGCC Natural Resources Technician 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 1) Injection Profile 2) Signed Print Name: BP Exploration (Alaska), Inc. SIM Data Manager Attn: Merion Kendall MB 7-5 900 Benson Blvd. Anchorage, AK 99508 GANCPDCnaUSAANChouxwhBPcom and READ Cased Hole, Inc. Attn: Diane Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Diane.williams@readeasedhole.com 19-JUI-19 14-17 RECEIVED OCT 092019 AOGCC CD 50-529-20562-01 Date: 1lN06 zdq PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: READ-ANCHORAGE((DREADCASEDHOLECOM WEBSITE: WWW.READCASEDHOLE.COM https.. reedcasedhole-mysharepoinc com'personal/diene_williems_reedcesedhole_c mDawmems. DeAlp,BP_Transmh d. STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMA. REPORT OF SUNDRY WELL OPERATIONS ` 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well RI Re-enter Susp Well 0 Other:Set Tubing Patch I3 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 203-001 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-20562-01-00 7. Property Designation(Lease Number): ADL 0028314 8. Well Name and Number: PBU 14-17A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 12585 feet Plugs measured feet 7 true vertical 9028 feet Junk measured feet AUG 1 1 Z016 Effective Depth: measured 12549 feet Packer measured 10129 feet true vertical 9029 feet Packer true vertical 8520 feet O GCC Casing: Length: Size: MD: TVD: Burst: Collapse: �s Structural Conductor 80 20"91.5#H-40 31-111 31-111 1490 470 Surface 2470 13-3/8"72#L-80 29-2500 29-2499 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10707-10732 feet 10732-10752 feet 10785-10825 feet 11897-12447 feet 12497-12547 feet True vertical depth: 8971-8981 feet feet 8981-8988 feet 8995-9001 feet 9053-9029 feet 9029-9029 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 7-5/8"FB-1 Perm Packer 10129 8520 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: ' Ai 'f 2,n q ? 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 8861 100 1287 Subsequent to operation: 9688 260 1638 14.Attachments:(required per 20 MC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Ef Exploratory ❑ Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG RI 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: 316-220 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ALAI, Co, ---- Phone +1 907 564 4424 Date 8/10/16 Form 10-404 Revised 5/2015 V T(r ' l Z /1 f-4 V6. RBDMS Lf--, AUG 1 2 2016 Submit Original Only • • 0 ma p � NTru iz= VCNpr- C.) 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N-80,0.0152 bpf,D=3.958" 10849' —I 4-1/2"TIEING TAI. PBTD H 11368' TO H 11400' 1111111111111111 7"LNR,29#,L-80 BTC,0.037:f bpf,D=6.184" 11400' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHCE BAY INT 05/23/82 ORIGINAL COMPLETION 06/06/16 JMS/JMD RILED EVOTRIEVE(06/05/16) WELL: 14-17A 01/18/03 TMM/TP CTD HORIZONTAL SIDETRACK 06/27/16 BTTYJMD SET TWO ONE TRP PATO 1E3 PERMIT No: 2030010 10/24/12 NS/AID CORRECTED PERMIT NUMBER AR No: 50-029-20562-01 02/23/15 SR7/JM0 ADPBRFS(02/18-19/15) SEC 9,T1ON,R14E,2480'FM_8 1610'FE. 12/07/15 JLS/JMD SET EVOTREVE(11/09/15) 02/09/16 GTW/JMC RESET EVO PLUG(02/06/16) BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday,June 29, 2016 7:32 AM To: AK, OPS FS3 OSM;AK, OPS FS3 Field OTL;AK, OPS FS3 Facility OTL;AK, OPS FS3 DS Ops Lead;AK, GWO SUPT Special Projects;AK, GWO SUPT Slickline; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC EOC IL;G GPB FS3 Drillsites;Vohra, Prachi; 'chris.wallace@alaska.gov' Cc: AK, GWO Projects Well Integrity;AK, GWO DHD Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers,Jessica; Dickerman, Eric; Regg, James B (DOA);AK, GWO SUPT Well Integrity Subject: OPERABLE:Injector 14-17A(PTD#2030010) MIT-IA Passed All, Injector 14-17A(PTD#2030010) passed an MIT-IA on June 28, 2016 after setting two tubing patches.The passing test indicates two competent well barrier envelopes.The well is now reclassified as Operable. Plan Forward: 1. Operations: Put on produced water injection. Use caution and anticipate annular fluid expansion. 2. Fullbore:AOGCC MIT-IA once on stable injection Please call with questions and concerns. Ryan Holt (Alternate Lee Gre') t1q BP Alaska-Well Integrity O ��t DEC9�Q 1� GWGlobalrganization Wells 5` Office: 907.659.5102 WIC Email:AKDCWeIIIntegrityCoordinator(a�bp.com From: AK,& ell Integrity Coordinator Sent: Tuesday, Nov- ••er 10, 2015 9:58 PM To: AK, OPS FS3 OSM; A , ••S FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superinten•- • 'K, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RE .•: East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Chou, Irwin; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C P ••-cts Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Mor ' • , Spencer; Sayers, Jessica; Dickerman, Eric; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Subject: NOT OPERABLE: Injector 14-17A (PTD #2030010) MIT-T and.,MIT-IA Failed All, Injector 14-17A(PTD#2030010)failed an MIT-T and a MIT-IA on November 10, 2015. The failing testindicates a lack of two competent downhole barriers. The well is reclassified as Not Operable until tubing integrity is restored and confirmed. The well has been secured with a down hole plug. 1 OF Thtyt, • • 4 \�\II/7:'•• THE STATE Alaska Oil and Gas F �� , ofLAsKA. Conservation Commission -:,,,,, s � - i �� 333 West Seventh Avenue w GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 U� P Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Irwin Chou Production Engineer i-: „ . , k BP Exploration(Alaska), Inc. %WED P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 14-17A Permit to Drill Number: 203-001 Sundry Number: 316-220 Dear Mr. Chou: 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, , 4)-(. 52c Cathy P. Foerster Chair DATED this f.3lira y of April, 2016. RBDMS t.`-' APR 1 4 2016 STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMI.ON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 I1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well RI - Operations shutdown 0 I Suspend ❑ Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other 5e f 1-1,47)„,1 M 74 h 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 203-001 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic 0 Service O. 6. API Number: 50-029-20562-01-00 - 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No Q PBU 14-17A - RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: APR 0028314 • PRUDHOE BAY,PRUDHOE OIL• APR 0 5 2016 11. PRESENT WELL CONDITION SUMMARY VV �14 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MDJ,ra N CC 12585 - 9028 - 12549 9029 10173 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 31 -111 31 -111 1490 470 Surface 2470 13-3/8"72#L-80 30-2500 30-2500 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 7-5/8"FB-1 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 10129.23 MD /8519.54 TVD No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ❑ Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program H BOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development ❑ Service IBJ- 14.Estimated Date for Commencing Operations: 4/30/2016 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 0 WAG B• GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Chou,Irwin be deviated from without prior written approval. Email Irwin.Chou@bp.com Printed Name Chou,Irwin Title Production Engineer Signature --- -1T4---c.5 C r,. Phone +1 907 564 5538 Date 4/4/2016 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number -kit.. - 220 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes El No ❑ Spacing Exception Required? Yes 0 No ❑ Subsequent Form Required: /fj 4-0 4-- APPROVED BYTHE Approved by: )1x-i-,4 __ COMMISSIONER COMMISSION Date: 41.43.../6 agtZ4/12-/ t (.. ORIGINAL RBDMS APR 1 4 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate e�zr%6 ., -.s:> V'7/4 • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information I I Well Name: 14-17A Well Type: I WAG Injection Well API Number: 50-029-20562-01 Well Activity Conventional 4 Classification: Activity Description: Set Patches Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Mech-Patch Estimated Cost, $K: AWGRS Job Scope: PATCH TUBING/LINER Other regulatory - requirements? None Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Irwin Chou Contact numbers: (907) 564-5538 (907) 632-3992 Well Intervention Engineer: Ryan Thompson Contact numbers: (907) 564-4535 (907)301-124C Lead Engineer: Bernhard Stechauner Contact numbers: (907) 564-4594 (907)360-7485 Date Created: March 22, 2016 Revisions (date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injectior Date Choke Setting Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) Cut(%) (Mscf/Day) (psi) 2/11/2016 0 0 427 Current Status: Not Operable Shut In Inclination>70°at Depth(ft) 10,741' MD Recent H2S (date,ppm) NA 0 Maximum Deviation (Angle and ppm Depth) 96' 11,658' MD Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 25° 10,708' MD Reservoir pressure(date, psig) Estimated -3300 Minimum ID and Depth 2.372" 10,713' MD Reservoir Temp,F Estimated -200°F Shut-in Wellhead Pressure 150 psi Known mech. integrity Found leaks at 5,412' &6,077' MD problems(specifics) Last downhole operation(date, operation) 2/6/2016 Leak detect log on memory. Most recent TD tag (date,depth, toolstring OD) 9/17/2015 10,713' MD 2.60"CEN.., 1-3/4"SAMPLE BAILER If well has been shut in for> 1 year or job cost>$500M, fill out Non Rig Surface Kit Fit-for-Service? YES If No,Why? Surface Equipment Checklist. Comments,well history, 14-17A is a WAG injector that has failed an MIT-T and MIT-IA to 2500 psi. However, it did pass a CMIT- background information, TxIA to 2500 psi. The LLR from the MIT-T was found to be -7.56 GPM or 0.18 BPM. A caliper log etc: performed in Sept. 2015 shows a max wall penetration of-52%at 645' MD. Based on the evidence, it is suspected the well has developed TxIA communication. A leak detection log was run on 2/6/2016 which found tubing leaks at 5,412' &6,077' MD. The plan forward is to set patches to restore integrity to the well. • • Well Intervention Details Suspected Well Problem: Tubing leaks at 5,412' &6,077' MD Specific Intervention or Well Objectives: 1 Set patches over tubing leaks. 2 3 Key risks,critical issues: Mitigation plan: 1 Does not need nipple reducer. ID of patches will be 2.965" 2 Tie into SSSV 3 Patches used will be Weatherford Widepak One-Trip Straddle Packers. Summary Ste # Service Line Activity P 1 S Pull plug 2 E Set Patches 3 S Set& Pull plug 4 F MIT-IA Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 S Pull EVO-Trieve from 10173' MD • Set first patch with top element at 6067' and bottom element at 6087' • Set second patch with top element at 5402' and bottom element at 5422'. 2 E Note: Use Weatherford Widepak One-Trip Straddle Packers with 20'element to element spacing. Schematic attached. Patches were ordered on 3/2/16 with 10-12 week delivery. PO#is 4300600929. Please contact Butch/Chris @ WFD,659-2356 to confirm patches have arrived prior to scheduling this portion of the job. 3 S Load tubing and set plug in XN nipple at 10,204' MD Pull plug if MIT-IA passes. 4 F Load tubing and leave 1000 psi on tubing post plug set, prior to MIT-IA. MIT-IA to 2500 psi. Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: 9000 Expected Production Rates: FTP(psi): Choke setting: PI (bfpd/psi dp) Post job POP instructions: If MIT-IA passes, have WIC review operable status. If made operable, turn over to OPS to P01 (9000 bwpd). Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: • 0 • ` 1 y 1 4 r 5100 — I j i t I : - * ; , 5200 - i' a 1 II. — t I t 'i fl P f Scale Change S I 5300 i 1.. I I 5400 ti, Leak S�pnaiure lr► i ' S 5500 ,. I It 9 ! i f H 56o4 1 ' i I 1 i111 .- } 5704 I z iII �` t 1 E; l S t 1` 1 • 0 �. E 5740 - 1 1 i ik - E ' -- 5800 f .‘ I I i e. 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LL CO d CC • S a> w OO O O O O co O O O O 1C 'cr O Q co N LU C N V 10L-' r I- r CO N- U y o 0 0 0 0 0 0 0 0 L O) M I- Ln O CO cor �rcoco � ro�0 OLc) vrnCOCOCOOr O CO r CO O N CO r LO 0) CO CO CO CA O LC) CO r N I- CO CO CO CO C)) 00 CO H N— O CO CO CO CO I"- cr CO CO CO N Cr) U') CO O) N I[) f� CO CO CO 00 CO Q� r O 0) LO CO r CO N CO OLo M V LC) Nr N r N O 0 Co 0 0 N 0 0 t V C - 4.0 Q M co C CD CO N r O CO CO O in r Co r N •:1" a) Ncs)M C7 N O O O O N 0 r r r r r � J Q � 0 °) o CO1.0 COoOD JCO O OCO J CO J CO • a7 N *k O J N *k N L.0M _ •N � r - N- O COO) U p) 00 = N O co Lf 0p N co O Ln co L.i C10 c, O M M c C CO (` CO L° co r a1 N C, r M CO r = O r J r W W Q Q C� LLJ00 U co 0 [tCCctc Z Z zwwwwwwmm ODHHZZZZDJ U U) Z Z —I I HE!_= GRAY GEN 3III VVflLtEAD= GRAY /� NOTES:H2S READINGS AVERAGE 125 ACTUATOR= AX�SON 1 '7'- ppmEN OWN MLNMI.WELL REQUIRES SSSV H2S W EL *W ELL ANGLE 0*@ , OKB.ELEV= 71' BF.ELEV= 10741'*** KOP= 2900' 20"GOND, H Nix Angie= 96'@ 11658' 91.5#,H-40, 2226' H5-1/2"CAM BAL-O SSSV NP,D=4.562" Datum ND= 10562' ID=19 124" ' [ ---- DaCItum TVD= 8800'SS ! A 1-ca lis e 5412 i G D"7-7. 13-3/8"CSG,72#,L-80,D=12.347" H 2600' SCT 77 tC/1 t 5 1 10126 H5-112 BAKER LOC SEAL ASSY,ID=4.875". 1 Minimum ID =2.372" @ 10713' XO TO 2-7/8" STL LINER B I 10129' j—9-518"X 5-1/2"BKR PERM PKR 5-1/2"TBG-IPC,17#,L-80,0.0232 bpf,ID=4.892" — 10149' 10149' —15-1/2"X 4-1/2-X01 TOP OF 4-112"TBG PC —1 10149' 10173 4-1/2"FSS EVOTRIEVE PLUG(02/06/16) I10186' —13 70"DEPLOY NENT SLEEV E,D=3.00" 1 10204' H3-1/2"HOWCO XN NPD 2.750" 1 TOP OF 7"LNR — 10202' I I 10231' H4-1/2"OTIS XN tom,D=3.725" 4-1/2"TBG-IPC, 12.6#,L-80,0.0152 bpf,D=3.958" — 10243' 10242' 14-112"BKR SHEAROUT SUB WLEG N/ \ j 10243' H4-1/2"TUBING TAIL f$S 1111 I 10234' HELMO IT LOGGED 05/16/91 1 11. 111 1 9-5/8"CSG,47#,L-80 BTC/S00-95 BTC,D=8.681" —{ 10492' 11111 �1�1 II 10350' —TOP OF C84ENT 111. 1111 1114 1111 3-1/2"TBG,8.81#,L-80 STL,.0087 bpf,ID=2.992" H 10659' 1'1. Ci'1' 10559' —13 1r2"X 3-3/16"XO,ID=2.800" 1111 111111 TOP OF WPSTOCK w/2 RA TAGS(01/13/03) —1 10688' V•Y1; ;11;1 H 111 114 1 PERFORATION SUMMRY •1V14, 104 j NMLLOUT WINDOW(14-17A) 10589'- 10606' .1l i REF LOG: 14-17A SPERRY MVVD ON 01/17/03 4•14*1i ANGLE AT TOP :62"©10707' ��'� 41i 4A,•, ' 10713' -13-3116"X 2-718"XO,D=2.441" Note:Refer to Production DB for historical pert data .1s SIZE SPF INTERVAL Opn/Sqz SHOT 507 2" 6 10707- 10752 0 02/19/15 2" 6 10785-10825 0 02/18/15 T 4 11897-12447 0 01/18/03 T 4 12497- 12547 0 01/18/03 t♦♦♦♦♦t�♦ 12549' PBTD ay.1.1111111,1.1.1 ` M 1111 e X1111/ ' TOP OF 4-1/2"TBG-IPC 10838' _ 3-3/16"LNR,6.2#,L-80, I- 10713' ! ,`\ A. .0076 bpf,D=2.80" TOP OF BRIDGE PLUG — 10848' I -------------- 1 12586' 1-1-2-7/8"LNR,6.16# L-80 STL,.0058 bpf,D=2.441" , 10849' N-80,0.0152 bpf,D=3.958" 10849' —1 4-1/2"TUBING TAL PB1D — 11358' To -� 11400• �1�1�1�1�1�1�1�1�1 1 7"LNR,29#,L-80 BTC,0_0371 bpf,D=6.184.-71-1 11400' DATE REV BY CONVENTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 05/23/82 ORIGINAL COMPLETION 10/24/12 NSIJND CORRECIID PERMIT M LEER VVELL: 14-17A 01/18/03 TMM/TP CTD HORIZONTAL SIDETRACK 02/23/15 SRIYJND ADPERFS(02/18-19/15) FERMI No:82030010 02/24/03 TWKAK PERE CORRECTIONS 12107/15 JLS/JND SET EVOTREVE(11/09/15) All No: 50-029-20562-01 05/31/06 DTM WELLt-EAD CORRECTION 02/09/16 GTW/JIVC RESET EVO PLUG(02106/16) SEC 9,T1ON,R14E,2480'FNL&1610'Fa 02/14/11 NB/JND ADDED SSSV SARI Y NOTE ' 01/16/12 TM'YJM)ADDED H2S SAFETY NOTE BP Exploration(Alaska) • '00 Verg2o IktIS • WELL LOG TfPANSMITTA CEivED PROACTIVE DIAGNOSTIC SERVICES, INC. MAR 11 2016 DATA LOGGED E/114/201Cs M K BENDER A®GCC To: AOGCC Makana Bender 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 %AWED APR 0 8 2U16 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: Analisa Steger LR2— 1 900 Benson Blvd. Anchorage, AK 99508 dancbdc@bp.com and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 06-Feb-16 14-17A BL/CD 50-029-20562-01 2) Signed : �.4.4grA.fruv '✓"eittat Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx STATE OF ALASKA RECEIVED ' i .KA OIL AND GAS CONSERVATION COM11,. .ION MAR 31 2015 REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon U Repair Well U ,p`Plug Perforations ❑ Perforate Other ❑^ \GCC Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver Time Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended W❑ 2 Operator 4.Well Class Before Work. 5 Permit to Dnll Number Name BP Exploration(Alaska),Inc Development ❑ Exploratory 203-001-0 3.Address P O Box 196612 Stratigraphic ❑ Service 6.API Number Anchorage,AK 99519-6612 50-029-20562-01-00 7.Property Designation(Lease Number). 8 Well Name and Number ADL0028314 PBU 14-17A 9.Logs(List logs and submit electronic and pnnted data per 20AAC25.071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 12585 feet Plugs measured None feet true vertical 9027 74 feet Junk measured None feet Effective Depth measured 12549 feet Packer measured 10129 23 feet true vertical 9028 64 feet true vertical 8519 54 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91 5#H-40 30 59-110 59 30 59-110 59 1490 470 Surface 2470 11 13-3/8"72#L-80 30 09-2500 2 30 09-2500 03 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10707-10732 feet 10732-10752 feet 10785-10825 feet 11897-12447 feet 12497-12547 feet True Vertical depth 8970 81 -8981 25 feet 8981.25-8987 81 feet 8995 25-9001.19 feet 9052 94-9029 36 feet 9029 43-9028 68 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) 7-5/8"FB-1 Perm Packer 10129 23 8519 54 Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured). EU Treatment descnptions 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 16127 320 1736 Subsequent to operation 0 0 9270 560 1575 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Garry Catron Email Garry.Catron(a BP.Com Printed Name Garry Catron Title PDC PE Signature Xf` COIPhone 564-4424 Date 3/31/2015 VEL 4/11/7- RBDM4k AYR - 6 2015 Form 10-404 Revised 10/2012 v 01Submit Onginal Only a) m• O (O 000 M N cor- 000 O mr_ NrOr M N NON- V 'E0 0 0 S 0 0 666 • . r C'O N � m � CO CO CO � Nr r- 00 M • O N 00 66 r-.: 666 C/ 010000) f- NON ' 000000OO u) i (O f� 0 W W W N 00 00 OO � (0 . com ) NN- o r- cO O � 666 O c N M N 00 0c0 000 co M N 000 f+ N 0) 0) M_ 10 N M Tr492 r 530 ' N N 0 0 0 0 N N O O . . . . . r r .�.r V 1 1 1 1 1 1 1 1 �+ r M 0 N 0) M N ‹ M _ 00 O In �W M N N O O O O M (V O N r r r r C ▪ O = 0 � = wOo61CI Lo 111 � J d 4# 0# M g N o N # (mO N 10 # M 4t (O •N N _ f� O co (O - r 0) p07r - NCO _ -0\9CV o N O (v) M N 0 0) t 00 1.0_ O M MO = 000 M I� W F F O d 0 M M N 0 O N- J W W v) UWWAD22 ° 00 W ZWWWWWWWEE OttZZZZ » D UZJJJJU) HH 4 .) 2 6 / \ a) C. § E $ I 0 k _ �_ % ® ^ Ct : / ,- / \ a) 4 0 % / \ 6 = -o o c 2 \ z / ) \ § \ 0 ( 2 / < § k / S $ L. k > a D c 0 E / & S D S N 0 0 2 r - - 5 2 / / / _§ a) = n w \ - = _ - 0 = £ / m 7 & a ° k ot a) / .// i 5 -d8 o / / 22k o # ƒ �/ 2 + o &\ 2 0 ° a - - G G © / $ E / / E / / Cf)y m - _ E0 - A / \ 0 •c . \ / / $ $ ) kIii - Ts- 0 EL keo E 3 0, 2c5 \m \ RI _ © � 0 \ 2 $ $ °/ / 5 / E \ / k \ / g / c\ . -/ E \ = / 0) _ f2Oa w 0_ , 2 CO eL 05 i \ 0cs t r- .%— o co E a .- I _e q C C t t & \ t / 6 C 0 t \ o § \ a) a) � @ _ ƒ / $ E 7 Cl) / D \ / 2 2 \ 0 2 \ % / \ / 2 / y/ ƒ a 6 \ a ƒ W / / 6 \ J C / /i a. 2 * 0* \ q - - 4' 00 * / > % \ > \ 'T E k / k \ / k / k . ¥ g & g •g CO G »G e CO R D Cr) C . p @ & ■ a & a m $ 4 , a o o a = " e # 7 r . p ,0-• f // Q o & f & _ \ y ® o \ & \ 5 t •-•-s. \ / O § f \ / O § E \\ \ \ O o ZN / ƒ / \ 2/ G > / G / \ § 2 / G \ 03 \ / ? 27 $ / / ® \ 0 \ � � © ® / a) ® R � � § 6 ? ® a) / ' - o a § R % DDC E i t $ \ »7 k •7 I \ / / k 7 £ c § ® / o / » 7 / 7 / -Th a) -1::3 0 k � § � § $ 2 2 \ � \ ( ® § 2 2 \ » (1) ,._ / / � �CI * - \ L-=0-* / � / 2 - C0LLom ; Ot2 $ = OtOt » oo - ocC ; O ; � = : e r r ii IP,t \\R & i TREE= GRAY GEJ 3 1 TY NOTES:H2S READINGS AVERAGE 125 H1ELLI1EAD= GRAY ACTLWTOR= AXELSON 14-17 Appm W WHEN ON MI. WELL REQUIRES A SSSV OKB.E EV= 71' WHEN ON Ml. H2S WELLWELL ANGLE>70" BF.ELEV= 10741'*** Mex Angle= 96 @ 11658' tum MD= 10562 W 1 2226' H 5-1/2'CAM BAL-O SSSV MP D=4.562" Datum D= 8800'SS 13-3/8"CSG,72#,L-80,D=12.34r H 2500' F-4 i • 10126' —1 5-1/2"BAKER LOC SEAL ASSY Minimum ID =2.372" @ 10713' XO TO 2-7/8" STL LINER 8 S' 10129' —I 9-5/8"X 5-1/2"BKR PERM PKR 5-1/2"TBGFC,17#,L-80,0.0232 bpf,D=4.892" H 10149' _ � ' 10149' 5-1/2"X 4-1/2"XO TOP OF4-1/2"TBGPC 10149' 1 10185• —p--1/2'DEPLOYMENT SLEEVE,E,D=3.00" TOP OF 7'UR H 10202' 1---7.: ' . 10204' —3-1/2"HOWCO NO-GO XN MP,0=2.750" I I 10231' H 4-1/2"OTIS XN NY?D=3.725" 4-1/2-TBG-PC,12.6#,L-80,0.0152 bpf,DH=3.958" 10243' I--- 10242' 4-1/2"BKR SF AROUT SUB WLEG 3-112"TBG, #,L-80,.0000 bpf,D=2.992" -I 10492' \ 10243' 4-1/2"TUBNG TAR_ 4111 1�1� 10234' —1 E LMD TT LOGGED 05/16/91 9-5/8"CSG,47#,L-80,D=8.681' H 10492' I '� ,�'� , 10350' --I TOP CEMENT 111 1111 TOP OF WHEPSTOCK H 10588' 11 11 4 14 TOP OF WINDOW H 10589' 11111 1111 10559' 13-1/2"X 3-3/16"XO,D=2.800" 414 14141 PERFORATION Sliv MARY 1114 ►1111 REF LOG: 14-17A SPEiRY MND ON 01/17/03 1�1� ►411 ANGLE AT TOP PERF:62'@ 1070T .., Note:Refer to Production DB for historical pert data 4�4�4t •1i. SIZE SPF INTERVAL Opn/Sqz DATE '4*14t1,� 10713' —13-3/16'X 2-7/8"XO,D=2.441" 2" 6 10707-10752 0 02/19/15 ' 2" 6 10785-10825 0 02/18/15 2" 4 11897-12447 0 01/18/03 2" 4 12497-12547 0 01/18/03 1.11111.1.1. L 12549' HMO ��~11C 11111 ri TOP OF 4 112"TBG-IPC 10838' 4� 3-3/16"LNR,6.2#,L-80, --1 10713' 4`� _ ' .0000 bpf,D=2.80' I.ITOP OF BRIDGE PLUG -� 10848' j l 12585' —{2-7/8"LNR,6.16#,L-80,.0000 bpf,D=2.441' 4-1/2"TBG-PC,12.6#, —1 10849 1 N-80,0.0152 bpf,D=3.958" ' 10849' H 4-1/2"TUBUJG TA PBTD H 11358' I '1'1'1'11111 TD --I11400• 111111111 7"LNR,29#,L-80,0.0371 bpf,D=6.184" H 11400' DA IE RE=V BY COMMENTS DATE REV BY COM ENTS PR DHOE BAY UNFT 05/23/82 ORIGINAL COMPLETION 10/24/12 NS/JMD CORRECTED PERMIT NUMBER MIL: 14-17A 01/18/03 T INTP CTD HORIZONTAL SIDETRACK 02/23/15 SRLYJ1.13 ADPE2FS(02/18-19/15) PERMIT No:"1030010 02/24/03 T1-VKAK PERF CORRECTIONS AR No: 50-029-20562-01 05/31/06 DTM VUEFUFEAD CORRECTION SEC 9,T1ON,R14F 2480'FNL&1610'FEL 02/14/11 M3/JMD ADDED SSSV SAFETY NOTE 01/16/12 TIMYJM3 ADDED I12S SAFETY NOTE BP,,Exploration(Alaska) ) -) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q 03 - 00 1 Well History File Identifier Organizing (done) o Two-sided 11111111111111 11111 ~scan Needed RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, No/Type: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: Scanning Preparation x 30 = 3D D Other:: \ . Date: ~ ar¡. 0 -S Isl \1110 1 Date: í3 ¿}ßf OS Isl mf + 'J..fo = TOTAL PAGES "-~ (Count dœs not ·'.lclude cover sheet)1A A P Date:6 & q (J~ 151 , VV I BY: Helen L~ Project Proofing BY: Helen~ BY: Helen ("Maria ) Production Scanning Stage 1 Page Count from Scanned File: 5 7 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YfS Stage 1 If NO in stage 1, page(s) discrepancies were found: NO ') Date:ß ,d-'¡ ~ 151 rn- YES NO BY: Helen Í Maria ) BY: Helen Maria Date: 151 11I11I111 II Scanning is complete at this point unless rescanning is required. ReScanned I BY: Helen Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 STATE OF ALASKA ACA OIL AND GAS CONSERVATION COMM ON t REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Repair Well U Plug Perforations U Perforate U Other U Brightwater Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdowr0 Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 203 -001 -0 3. Address: P.O. Box 196612 Stratigraphir❑ Service 0 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20562 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: 1 ADL0028314 PBU 14 -17A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 12585 feet Plugs measured None feet true vertical 9027.74 feet Junk measured None feet Effective Depth measured 12549 feet Packer measured 10129 feet true vertical 9028.64 feet true vertical 8519.36 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H-40 30 - 110 30 - 110 1490 470 Surface 2471 13 -3/8" 72# L -80 29 - 2500 29 - 2499.83 4930 2670 Intermediate None None None None None None Production 10464 9 -5/8" 47# L -80 28 - 10492 28 - 8814.38 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11897 - 12447 feet 12497 - 12547 feet RECEIVED True Vertical depth 9052.94 - 9029.36 feet 9029.43 - 9028.68 feet OCT O n �I Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment S GCC Packers and SSSV (type, measured and true vertical depth) 5 -1/2" Baker Perm Packer 10129 8519.36 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: SCANNED JAN 2 3 2013 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 8077 0 1436 Subsequent to operation: 0 0 2679 ! „ ...0 .. 719 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorL❑ Development ❑ Service El Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: ,,, Oil ❑ Gas ❑ WDSPLLJ GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP ❑ SPLUC-❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summ [ abp Printed Name Nita Summer Title Petrotechnical Data Technician SignatA /�j� �� Phone 564-4035 Date 10/10/2012 O r-. /#147e/ RR IT OCT 11 20 � I n 4 0 ` Form 10-404 Revised 10/2012 r !� Submit Original Only • • Daily Report of Well Operations ADL0028314 ACTIVITYDATE SUMMARY TIO= 1320/ 440 /150 (Reservoir weep Y o• T ove equipmen o location, rig up and pressure test. 9/13/2012 * ** *Job Contiued on 09 -14 -2012 WSR * * ** 171/0 = 1160/440/150 ** *Continued WSR from 09- 13- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 6000 bwpd. Pumped 319 gal. EC9360A (Surfactant) Average of 26.5 gph for 12 hrs. Pumped a total of 319 gal. since start of project. Pumped 1574 gal. EC9398A ( Polymer) Average of 131.1 gph for 12 hrs. Pumped a total of 1574 gal. since start of project. 9/14/2012 ** *Continued on WSR 09 -15- 2012 * ** 1 /I /O = 1199/400/150 ** *Continued WSR from 09 -14- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 6000 bwpd. Pumped 648 gal. EC9360A (Surfactant) Average of 27 gph for 24 hrs. Pumped a total of 967 gal. since start of project. Pumped 2939 gal. EC9398A ( Polymer) Average of 122.4 gph for 24 hrs. Pumped a total of 4513 gal. since start of project. 9/15/2012 ** *Continued on WSR 09 -16- 2012 * ** ? /I /O = 1178/300/100 ** *Continued WSR from 09 -15- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 6000 bwpd. Pumped 723 gal. EC9360A (Surfactant) Average of 30.1 gph for 24 hrs. Pumped a total of 1690 gal. since start of project. Pumped 3237 gal. EC9398A ( Polymer) Average of 134.5 gph for 24 hrs. Pumped a total of 7750 gal. since start of project. 9/16/2012 ** *Continued on WSR 09 -17- 2012 * ** T /I /O = 1210/280/100 ** *Job continued from 09 -16 -12 WSR * ** Rig down brightwater project FWHP = 1200/280/100 SW= CLOSED WV, SSV, MV =OPEN IA, OA= 9/17/2012 OTG FLUIDS PUMPED BBLS 3 DIESEL 3 METH 6 TOTAL FLUIDS PUMPED GALS 1690 EC -9360A SURFACTANT 7750 EC -9398A POLYMER • • Daily Report of Well Operations ADL0028314 9440ITOTAL Casing / Tubing Attachment ADL0028314 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H -40 30 - 110 30 - 110 1490 470 LINER 374 3 -1/2" 9.3# L -80 10185 - 10559 8564.16 - 8868.94 10160 10530 LINER 387 7" 29# L -80 10202 - 10589 8577.81 - 8893.12 8160 7020 LINER 154 3- 3/16" 6.2# L -80 10559 - 10713 8868.94 - 8973.54 LINER 1872 2 -7/8" 6.16# L -80 10713 - 12585 8973.54 - 9027.74 13450 13890 PRODUCTION 10464 9 -5/8" 47# L -80 28 - 10492 28 - 8814.38 6870 4760 SURFACE 2471 13 -3/8" 72# L -80 29 - 2500 29 - 2499.83 4930 2670 • TUBING 10122 5 -1/2" 17# L -80 27 - 10149 27 - 8535.33 7740 6280 TUBING 94 4 -1/2" 12.6# L -80 10149 - 10243 8535.33 - 8610.83 8430 7500 • I TREE = GRAY GEN 3 • TY NOTES: H2S READINGS AVERAGE 125 WELLHEAD = GRAY ACTLiATOEa = ° AXELSON 1 ppm WHEN ON MI. WELL REQUIRES A SSSV 4-1 7 a WHEN ON ML H2S W ELL "" "W ELL ANGLE > 70° KB ELEV = 71' BF ELEV = 10741*** KOP = 2900' Mx Angle = 96° @ 11658 Datum MD = 10 --- - 567 -- 2226' --I 5 -1/2" CAM BAL -O SSSV NIP, ID = 4.562'" I Datum TV D = 8800' SS O I 13 -3/8" CSG, 72#, L -80, ID = 12 347" H 2500' I 10126' H 5 -1/2" BAKER LOG SEAL ASSY Minimum ID = 2.372" c@ 10713' XO TO 2 -7/8" STL LINER 0 10129' H 9 -5/8' X 5-1/2" BKR PERM PKR 15 -1/2" TBG -IPC, 17 #, L -80, 0.0232 bpf, ID = 4.892" H 10149' ' 10149' H 5-1/2" X 4 -1 /2" XO TOP OF 4-1/2" TBG -IPC H 10149' I ) i I- 10185' - 3-1/2" = DEPLOYMENT SLEEVE, ID 3.00" I TOP OF 7" LNR 1 - 1 --- i0202' I 10204' - 13 - 1/2" HOWCO NO -GO XN NIP, ID = 2.750" I r 102 4 -1I2" OTIS XN NIP, 10 = 3.725' 14-1/2" TBG -IPC, 12.6#, L -80, 0.0152 bpf, ID = 3.958" 1-1 10243' 10242' H 4 -1/2" BKR SHEAROUT SUB WLEG I \ 10243' - 4 -1/2" TUBING TAIL I 3 -1/2" TBG, #, L -80, 0000 bpf, ID = 2.992" I 10492' 1 1 1 1 ► 1 1 1 1 L 10234' _I ELMD TT LOGGED 05/16/91 I 9 -518" CSG, 47 #, L -80, ID = 8.681" H 10492' 1 1 10350' H TOP OF GWENT I ■1••■ 411 TOP OF WHIPSTOCK H 10588' 4 MI 1 MI I TOP OF WINDOW H 10589' � (4 �1 10559' —I3 -1 /2" X 3- 3/16 "" XO, ID = 2.800" I 1 1 PERFORATION SUMMARY rt......': 111 1, REF LOG: 14 -17A SPERRY MD ON 01/17/03 1 #'111 ANGLE AT TOP PERF 93° @ 11900' 414t1 Note Refer to Roduction DB for historical perf data 114 ' 10713' H3 -3/16" X 2 -7/8" X0, ID = 2.441" SIZE SPF INTERVAL Opn/Sgz DATE 2" 4 11897 - 12447 Opn 01/18/03 ''' 2" 4 12497 - 12547 Opn 01/18/03 f •YA♦ � 11.11 11.1.1.1 12549' -I PBTD ( TOP OF 4 -1 /2" TBG -IPC 10838' 111 T ' ►�� 1 ►�� 1111 1 (TOP OF BRIDGE PLUG - 10848' 3-3/16" LNR, 6.2 #, L -80, H 10713' imi 0000 bpf, ID = 2.80" 4 -1/2" TBG -IPC 12.6#, H 10849' • ' N -80, 0,0152 bpf, ID = 3 958" 1 12585' 1-12-7/8" LNR, 6 16#, L -8 .0000 bpf, ID = 2.441" I I 10849' H 4 -1/2" TUBING TAIL I I PBTD H 11358' WATAW1 ■ I TD 11400' 1 .1• 1 • 1 ■1.1■WW4 ■ I 7" LNR, 29 #, L -80 0 0371 bpf, ID = 6.184" -I 11400' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/23/82 ORIGINAL COMPLETION WELL 14-17A 01/18/03 TMM/TP CID HORIZONTAL SIDETRACK PERMIT No '1810210 02/24/03 TH/KAK PERF CORRECTIONS API No 50- 029 - 20562 -01 05/31/06 DTM WELLHEAD CORRECTION SEC 9 Ti ON R14E 4282 68' FEL & 1682.64' FNL 02/14/11 MB /JMD ADDED SSSV SAFETY NOTE 01/16/12 TMN/JMD ADDED I-2S SAFETY NOTE BP Exploration (Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, November 17, 2011 TO: Jim Regg k ' i� P.I. Supervisor l ( ( 7 l It SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 14 -17A FROM: Bob Noble PRUDHOE BAY UNIT 14 -17A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 14 - 17A API Well Number: 50 029 - 20562 - 01 - 00 Inspector Name: Bob Noble Insp Num: mitRCN111113082526 Permit Number: 203 - 001 - Inspection Date: 11 /10 /2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. r Well 14-17^ 'Type Inj. W - TVD 8519 ' IA 545 2402 - 2403 2412 - P.T.D 2030010 ' TypeTest SPT Test psi 2129 OA 533 575 590 601 Interval 4YRTST P/F P ✓ Tubing l 660 670 680 685 Notes: l � 4 Thursday, November 17, 2011 Page 1 of 1 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 07, 2009 f~'~~~~~ EJ~,I~! `:~ ~~ 2~ x~~x'L by p `~ ~ _,- l!~C ~ ~O~J9 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, r, _ k ~._., ~~E.. .~~i~~ ~° . ~D3-D8~ ~~'l7p Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 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. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-14 Date: 12/05/09 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al t4-01A 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292031803 Sealed Conductor NA NA 14-03A 1961290 500292031901 Sealed Conductor NA NA 14-04A 1961640 500292032001 Sealed Conductor NA NA 14-OSA 1920010 500292032701 Sealed Conductor NA NA 14-06A 2040360 500292032801 Sealed Conductor NA NA 14-07 1780660 500292032900 Sealed Conductor NA NA 14-OSA 2022100 500292033001 Sealed Conductor NA NA 14-09B 1820340 500292053402 Sealed Conductor NA NA 14-10 1801300 500292052800 Sealed Conductor NA NA 14-11A 2051260 500292052901 Sealed Conductor NA NA 14-12 1811090 500292063100 Sealed Conductor NA NA 1a-13 1811010 500292062400 Sealed Conductor NA NA 14-14 1811020 500292062500 Sealed Conductor NA NA 14-t5 1810840 500292061100 Sealed Conductor NA NA 14-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 14-186 2071290 500292055102 Sealed Conductor NA NA 1a-19 1810450 500292057800 Sealed Conductor NA NA 14-20 1810700 500292059800 Sealed Conductor NA NA 14-21A 2051070 500292075601 Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20/2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 14-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25/2009 14-28 1820120 500292070800 Sealed Conductor NA NA 14-29 1811680 500292068000 Sealed Conductor NA NA 14-30 2050940 500292067901 Sealed Conductor NA NA 14-31 1831110 500292098900 Sealed Conductor NA NA 14-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 14-35 1831420 500292101800 Sealed Conductor NA NA 14-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 14-37 1880490 500292181000 NA 1.3 NA 5.10 10/20/2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 14-40A 2011350 500292187501 Sealed Conductor NA NA 14-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11/24/2009 01/23/09 Schlumberg~r Alaska Data & Consulting Services a(~ 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Q/ a ATTN: Beth e*J aa QG ll ~'~k ` W/ PII \ O .Inh B N0.5047 ~, ,~ } ,_ ~ ~~ ,: ~ ~ tl rr `~ Company: State of Alaska ~~~~`~~ ~. ~ ° ' ' ~ Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 i .... ne ..•:.... H-35 11970840 PRODUCTION PROFILE 08/12/08 1 1 -11 12111927 IBP & CROSS-FLOW STP ~ 1 11/24/08 1 1 MPS-41 11966291 SCMT - ~ 11/24/08 1 1 K-O5C AWJB-00016 MEM PROD PROFILE p _ ~'S 12/29/08 1 1 14-17A AXOY-00010 MEM INJECTION PROFILE 0 -C5() 01/15/09 1 1 F-33 ALYF-00010 CEMENT IMAGE LOG (p- ~'r 12/30/08 1 1 K-16AL2 AXIA-00009 MEM PROD PROFILE 0 - b 01/10/09 1 1 01-29 AP30-00011 USIT 'a - 1 01/04/09 1 1 09-30 AY1M-00007 STATIC SPINNER &IBP 1.,~ 01/15/09 1 1 N-18A AZCM-00005 JEWELRY LOG/PRESS/TEMP - 01/06/09 1 1 R-24 AY3J-00004 USIT ~ 01/16/09 1 1 N-18A AWLB-00002 USIT 12/26/08 1 1 V-212 AXBD-00010 MEM INJECTION PROFILE ~ 01/16/09 1 1 V-222 ALYF-00011 INJ PROFILE/WFL .. (~'~ 01/08/09 1 1 07-OS'3A AY00-00009 USIT L 01/22/09 1 1 N-12 12014053 RST j - 09/30/08 1 1 E-32B AXOY-00005 MCNL 11/18/08 1 1 P2-15A 11594511 SCMT (PDC) (REVISION 2) i l~.e': cJ~ 06/15/07 1 B-27A 11999059 RST ~l0/ ~ ~s' +a 11/07/08 1 1 12-37 40018138 OHM D/LWD EDIT ~ ~ ~'~-- 11/07/08 2 1 N-18A 08AKA0037 OH MWD/LWD EDIT ~~ -~ '~ 12/24/08 2 1 H-38 08AKA0031 OH MWD/LWD EDIT C 12/07/08 2 1 G tb S.' °L ~-U . __. __-.._.-.-_..____.~..~.. ~.. ... ............. .-..... ..`..vn..u~aa vim vvr~ ~rwn ~v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 n Date Delivered Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 9503 2~3~' .~ ~ ~' ATTN: Beth ~ i Received by: ~ r.; dlr 6`at. :r~n~.l~ilr`,'o9f?t`). • • • :` -~ -~ 03101/2008 DO NOT PLACE ..` ._ q~: ,_ .: ~~ y;,..- ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\C~rPgs_InsertslMicrofilm Marker.doc MEMORANDUM TO: Jim Regg ~^ P.I. Supervisor ~ FROM: John Crisp Petroleum Inspector Src: Inspector .oaf ~~3 State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, November O5, 2007 StiBJECT: Mechanical Intea~ityTests BP E~PLOR4TION (ALASKA) INC 14-l7A PRUDHOE BAY UNIT 14-17A NnN-CnNFIDENTIAL Reviewed By: P.[. Suprv ~ ~~' Comm Well Name: PRUDHOE BAY UNIT 14-17A API Well Number 50-029-20562-01-00 Inspector Name: John Crisp mitJCr07 1 1 05061 627 Insp Num: Permit Number: 203-001-0 Inspection Date: l l%4/2007 Rel Insp Num: Packer Depth Pretest Initial --- -- 15 Min. 30 Min. 45 Nlin. 60 Min. Well I t4-17A Type Inj. j `~' TVD T ~ 8519 ~ IA I 600 ___ z4oo I ~ ~zs6o I z3so - - P.T. ~ 2osoolo TypeTest ~, sPT j Test psi ~I ziz9_~s ~ p~ ~i, zso ' zso j zso ~ zso~ Interval 4YRrsT p/F P Tubing lloo ttoo Iloo _lloo NOteS: 4 bbl's pumped for test. ~~~~~~~ NCV ~ ~ 200? Monday, November O5, 2007 Page 1 of I . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14,2006 RE: MWD Formation Evaluation Logs: 12-14 Ll_Ll PBl, 14-17A, 14-30A, 15-38A_PBl. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 l2-14A LI LI PBl: QOd -tdd # /¿¡¿IS-¡ Digital Log Images: 50-029-20659-60, 71 I CD Rom 14-17 A: U I~ 803 -DO l"'I'fLI4(~ Digital Log Images: 50-029-20562-01 14-30A: d oS- - 0 q~1 tr /'-1(/5-0 Digital Log Images: 50-029- 20679-01 1 CD Rom 1 CD Rom 15-38A_PBl: d03-0/~ tt. fL/L/Llo, Digital Log Images: 50-029-20679-01 1 CD Rom SCANNE.D FEB 0 1 ZOO? ) e e /3553- WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn,: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, AJaska 99501 February 23,2004 RE: MWD Formation Evaluation Logs: 14-17A, AK-MW-30004 14-17A: Digital Log Images 50-029-20562-01 J' '(1 I\.....--. 1 CD Rom 90S -DO \ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd, Anchorage, AJaska 99518 BP Exploration (Alaska) Inc, Petro-technical Data Center, LR2-1 900 E. Benson Blvd, Anchorage, AJaska 99508 ---f Date:~ SìgnedtY~fì '<I ',-i:},':::,'<':"- M F~ .:LOd r- DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Permit to Drill 2030010 Well Name/No. PRUDHOE BAY UNIT 14-17A Operator BP EXPLORATION (ALASKA) INC .5 (1 i.Æ¿ API No. 50-029-20562-01-00 MD 12585 -// ND 9028 / Completion Date 1/20/2003 < -' Completion Status WAGIN Current Status WAGIN ulc~2_~. - - ------ --- -- - -- ------- REQUIRED INFORMATION Mud log No Samples No Directional Survey Yes - ---- ---- - -- --------- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, Memory GR, CCl Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number ---- - ------ EÐ D 11651 (data taken from logs Portion of Master Well Data Maint) '---' Name l4&-VerifR.dliull- Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments (b~ 1 10571 12546 Open 4/29/2003 C,-lr 9977 12529 Case 1/27/2003 10571 12546 Open 4/29/2003 10500 12585 Open 2/26/2003 ED D Rpt ---R:jJt 11619 LI~ \!p.rjfic¡:)tinn l/tIS Verification ~u"[jirectional Survey --- ----- --------- Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y 'Ð Chips Received? .---~ ----- Analysis Y / N Received? Daily History Received? ~lN Ç() N --- ForrnationTops .--- -- -- -- -------- -- --- ---- -- -- --- ------------ Comments: Compliance Reviewed By: ~ Date: ;2.)... ~ ~ ,- - - ---- -- ----- ----- .~----- ---- - ) J ¡' MEMORANDUM State of Alaska {J~õ5flaska Oil and Gas Conservation Commission TO: Randy Reudrich ~ DATE: May 15, 2003 commiSSioner.. .. A ,,,þ\w (]!J -y\/J SUBJECT: Mechanical Integrity Tests THRU: Jim Regg \"'\~- BPXA P.I. Supervisor DS-14, S,M,D Pads 14-17A, 14-21, S-215, M-29A, D-24 FROM: Jeff Jones PBU Petroleum Inspector Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 14-17 A Type Inj. G TV.D. 8519 Tubing 2560 2575 2575 2575 Interva 4 P.T.D. 2030010 Type test P Test psi 2130 Casing 270 3500 3440 3420 P/F P Notes: Test fluid 6.9 bbls 60/40 me~1 Well 14-21 Type Inj. 8 T.V.D. 8643 Tubing 360 3040 3020 3010 Interva 2N uB(Þ/' P.T.D. 1820860 Type test P Test psi 1500 Casing 400 3040 3010 3000 P/F P Notes: Test fluid 17 bbls 60/40 methanol. 2 year CMIT TxlA : TBG leak @ 5566 MD; TTP set @ 11762 MD Well 8-215 Type Inj. 8 TV.D. 4,624' Tubing 1010 1020 1020 1020 Interva I v/ P.T.D. 2021540 Type test P T est psi 1500 Casing 880 2040 1900 1840 P/F P Notes: Test fluid 1 bbl60/40 methanol Well M-29A Type Inj. 8 T.V.D. 7731 Tubing 940 949 940 940 Interva 4 P.T.D. 2000990 Type test P T est psi 3500 Casing 560 3520 3500 3500 P/F P Notes: Test fluid 3.2 bbls 60/40 methanol Well 0-24 Type Inj. N TV.D. 8041 Tubing 325 325 325 325 Interva 0 "5M/ P.T.D. 1852990 Type test P Test psi 2010 Casing 60 2240 2150 2125 P/F P Notes: Test fluid 4.6 bbls 60/40 methanol. (MITIA post-patch set on a category B-3 well) Well 0-24 Type Inj. N T.V.D. 8041 IA 2125 2230 2230 2230 Interva 0 P.T.D. 1852990 Type test P T est psi 3000 OA 85 3000 2880 2840 P/F P Sß(!/ Notes: Test fluid 2.3 bbls 60/40 methanol (MITOA on a catagory B-3 well) Type INJ. Fluid Codes F = FRESH WAT~R INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test 0= ~ther (describe in notes) May 15, 2003: I traveled to BPXA's Prudhoe Bay Field wells 14-17A, 14-21, 8-215, M-29A and D-24 to witness Mechanical Integrity Tests. Jeff Rea was the BPXA representative for the tests today. The pretest pressures on each well were monitored and found to be stable and the standard armulus pressure tests were then perfonned with each well passing the MIT. Well 14-21 has a known tubing leak at 5566' MD and a tubing tail plug was set at 11762' MD to accomplish a successful 2 year interval combination Tx IA MIT for 8undry #399-248 . Well D-24 is a BPXA designated catagory B-3 well and both the IA and the OA passed the MIT. Five well houses were inspected with no exceptions noted. Summary: I witnessed successful ìv1IT's on BPXA's Prudhoe Bay Field wells 14-17A, 14-21, 8-215, M-29A and D-24. Five well house inspections conducted. / M.I.T.'s performed: .§ Number of Failures: Q Attachments: well bore schematics (5) Total Time during tests: 7.5 hrs ~ MIT report form 5/12/00 L.G. MIT PBU 14-17A,14-21,S-215,M-29A,D-24 5-14-03 JJ.xls 5/20/2003 ) TREE = WELLHEAD = AciïJAtóR;;; kB:äEV; BF.ELèJ;;' ï<ÖÞ;;' ¡¡¡ax" Angie = bätum·Wö = Datum lVD = GRAY GEN3 CALICO F m ......... .... ÄxËi.sÒN if' 14-17 A SAFETY NOTES: H2S W B..L 29ÖÖ' 96 @ 11658' 10562' 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 1---1 2500' ~ Minimum ID = 2.372" @ 10713' XO TO 2-7/8" STL LINER :8: 1 0149' 7 10149' ~ 15-1/2"TBG-IPC, 17#, L-80, 0.0232 bpf, ID =4.892" 1-1 ITOPOF 4-1/2" TBG-IFC 1--1 1 TOP OF 7" LNR 1-1 10202' h 14-1/2" TBG-PC, 12.6#, L-80, 0.0152 bpf,lD = 3.958" 1-1 10243' 3-112" 1BG, #, L-80, .0000 bpf, ID = 2.992" 1-1 10492' 9-5/8" CSG, 47#, L-80, D = 8.681" 1-1 10492' r-JI I TOP OF WHIPSTOCK l-i 10588' 1 ITOPOFWINDOW 1-1 10589' 1 ÆRFORA llON SUv1MARY REF LOG: 14-17 A SÆRRY MWD ON 01/17/03 ANGLE AT TOP PERF: 93 @ 11900' Note: Refer to Production œ for historical perf data SIZE SFf INTffiVAL Opn/Sqz DA 1E 2" 4 11897 - 12447 Opn 01/18/03 2" 4 12497 - 12547 Opn 01/18/03 ITOPOF4-1/2" 1BG-IPC 1-1 10838' 1 TOP OF BRDGE PLUG 1-1 10848' 4-1/2"TBG-IFC,12.6#, -I 10849' N-80, 0.0152 bpf, ID = 3.958" 1 A31D 1-1 11358' ~ 11400' T'LNR, 29#,L-80, 0.0371 bpf,ID=6.184" 1-1 11400' DATE REV BY COMtv£NfS DATE REV BY OS/23/82 ORIGINAL COMR...ETlON 01/18/03 TMM'TP C1D I-DRlZONTAL SIDErRACK 02/24103 lH/KA K PffiF CORRECllONS '.i.II.: m ) 2226' 1-1 5-1/2"CAMBAL-O SSSV NIP, ID=4.562" I . i .. 1 10126' 1-1 5-1/2"BAKERLOCSEALASSY I 10129' 1-1 9-5/8"X 5-1/2" BKR ÆRM A<R 10149' 1-1 5-1/2" X 4-1/2" XO I ~ I , 10185' 1---13-1/2" DER...OYMB\lT SLEEVE, ID = 3.00" I 10204' 1-13-112" I-DWCO NO-GO XN NIP, D = 2.750" I ~ I 10231' 1-1 4-1/2" OTIS XN NIP, ID = 3.725" I ~ 10242' 1---1 4-1/2" BKR SHEA ROUT SLB WLEG ......- I~ \ 1 10243' 4-1/2" lUBING TAIL I 1 10234' 1---1 B..MD TT LOGGED 05/16/91 10350' I---1TOPOFC8v1ENf I I 1 10559' 1-I3-112"X3-3/16"XO, D=2.800" 1 1 10713' 1-i3-3I16"X2-7/8"xo,'D=2.441" I L 12549' 1-1 A31D I 3-3/16" LNR, 6.2#, L-80, -I 10713' I .0000 bpf, ID = 2.80" I 12585' H2-7/8" LNR, 6.16#, L-80, .0000 bpf. D =2.441" I 10849' 1-1 4-1/'2' TLBING TAIL I - 00 rvTv1B\1TS PRUIJ-iOE SA Y UNIT WB..L: 14-17A ÆRMT No: 1810210 API No: 50-029-20562-01 SEC 9 T1 ON R14E4282.68' FEL & 1682.64' FNL BP Exploration (Alaska) ') TREE = GRA Y GEN 2 WELLHEAD = GRAY AClliA TOR = AXELSON Kä: ECèJ = .. 71' BF. B..EV = KOP = 2800' Max Angle;' '56 @ 9600ï 'Datum Mõ;; ,., ''''1iðiii 'óâtùlñ'l\¡ õ = 'WN' 'S8ÕÕ"'^ SS' I 13-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2517' 'í~ LetVt..@. .5'5W Þt:> Minimum ID = 3.750" @ 11796' 4-1/2" CAMCO DB NIPPLE 5-1/2" TBG-PC, 17#. L-80, .0232 bpf. ID = 4.892" 1-1 11725' ITOP OF 4-1/2" TBG-PC H 11725' I TOP OF T' LNR I-{ 11762' PERFORATION SUMfV\A. RY REF LOG: BHCS ON 08/07/82 ANGLEA TTOP PERF: 42 @ 12091' I\bte: Refer to R'oduction DB for historical perf data SIZE I SFF I INlERVAL I Opn/Sqz I DATE SEE PAGE 2 FOR PERFORATION DATA I 9-5/8" CSG, 47#, L-80, ID = 8.681" H 12036' r-A 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 11804' 1 TOP OF 4-1/2" TBG H 12395' 14-1/2" lEG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 11805' 4-112" lBG, 12.6#, L-80, .0152 bpf, D = 3.958" H 12451' ~ 13018' 14-21 8"'k> :~~~;'::~~' '~::::.::,.., ~ :> L ') SAFEfY NOTES: WAIVEREDWB..L. *""'T x IA COMM UNICATION AT 5566' (02/07/03 WAIVER)""''' FLOWLINE FROZEN, CORROSION DAMAGE, TWINNs) WITH 14-17. 2156' H 5-1/2" CAM BAL-O SSSV NIP,ID =4.562" GA S LIFT fV\A. NDRB.. S DEV TYÆ VLV LATa; PORT 26 MMH RK 52 MMH RK 52 MM-I RK 54 MM-I RK 49 MM-I RK 47 MMH RKP II I ~ ST rvD ND 1 3552 3513 2 5746 5011 3 7869 6302 4 9928 7530 5 11375 8418 6 11523 8517 D6.TE vq~4; 'TvP :8: &----1 11707' l-i 9-5/8" X 5-1/2" BKR FB-1 PKR \J II 1111772095" II-i- 5-1/2"BAKERSBEASSY 5-1/2"X 4-1/2" XO I I 11796' 1-1 4-1/2" CAI'v1CO DB NIP ID = 3.75" 1 ... 11804' H 4-1/2" TT W/ SA KER WLEG 1 11781' H EUvD TT LOGGED 02105/88 I 12395' H 7" X 4-1/2" BKRFB-1IS0PKR 1 12435' H 4-1/2" MAGNA PLUG I 12441' r- 4-1/2" CAI'v1CO DB NP ID = 3.687" W/BLANKlNG PLU3 12449' H 4-1/2" TT W/SA KER WL EG I 13050' H CA-RKEDW/O PRONG I 13055' H 22' PERF GUN & CCL 3-1/8" I COMtvENTS ffiLOHOE SA Y UNIT WB..L: 14-21 PERMIT No: 1820860 API No: 50-029-20756-00 SEC 9, TION, R14E 1364.03 FB.. 4846.25 FN.... BP Exploration (Alaska) 7" LNR, 29#, L-BO, .0371 bpf,lD = 6.184" H 13060' W DATE REV BY OOM'v1ENTS D6.lE REV BY 08/13/82 ORIGINAL OOrvPLETION 01/25/88 LAST WO~OVER 02/22/01 SIS-LG REVISION 01 /08/02 RN'TP OORRECTIONS 02/20/03 IlLH WArvER SAFETY NOTE ) ') TRæ = aN 4-1/16" 5M WB..U"EAD = FMC Gß\J 5 A erûAtÖR:n;" kB~ ËLË'iÏ·;;'· nnn .. .nn..·72, BF. e.:ï3/ = ······41ï k öÞ··;,;· ...n 00 ···.··.......nn 223ä' Max Angle::· . 56 @ 3723' Datum MD = 6256' ... . ...... -...... Datum TV D :: 5000' SS 5-215 SAFETY NOTES: 4·112" CHROMETBG. .A I ~--t 114' H 20" X 34" 215.5 bItt, A53 ffiW INSULATEÐ I =-t 976' l-i TAM RJRTCOLLAR 1 l 2224' H 4-1/2" HES X NIP, ID = 3.813" 1 ~ GAS LIFT MANDRELS ST MD TVD DEV 1Y Æ VL V LATa; PORT DATE 1 3476 3203 50 KBG-2 RP BK 08/16/02 = 19"5/8"CSG, 40#, L-BO, 10=8.835" 1-1 2946' ¡-JI L Minimum ID = 3.725" @ 5648" 4-1/2" H ES XN NIPPLE 4-1/2" TBG, 12.75#, 13·CR·80, .0153 bpf, 10 = 3.958" 1-1 5659' J :&- 5599' 1 5626' 5648' 5660' 5651' 5535' 1- 4-1/2" BKRCMDSLlDINGSLV, WI 4-1/2" X NIP, 10 = 3.813" NOTE: SHiff SLEEV E DOWN TO OPEN, SHiff LP TO CLOSE - 04/28/03 H7" X 4-1/2" BKRPRM PKR, 10 = 3.875" I I I lfL Z L . ;> 8 TJ'þ ÆRFORA 1l0N SLtv1MA. RY REF LOG: SÆRRY MND ON 08106102 ANGLE AT TOP PERF: 45° @ 6098' Note: Refer to Production œ for historical perf data ,SIZE SR= INTffiVAL Opn/Sqz DATE 2-7/8" 2 6098 - 6110 0 05/06103 2-7/8" 2 6120 - 6130 0 05/06103 2-7/8" 2 6150 - 6170 0 05/06103 2-718" 2 6240 - 6260 0 05/06103 2-7/8" 2 6265 - 6280 0 05/06103 2-7/8" 2 6302 - 6342 0 05/06103 2-7/8" 2 6335 - 6380 0 05/06103 2-7/8" 2 6430 - 6450 0 05/06103 2-7/8" 6 6505 - 6525 0 03/31/03 2-7/8" 2 6525 - 6545 0 05/06103 2-7/8" 2 6585 - 6595 0 05106103 l-f 4-112" HES X NIP, 10 = 3.813" 1 1-1 4-1/2" HES XN NP, 10 = 3.725" 1 I~ 4-1/2" WLEG, ID= 3.958" I 1-1 EUv'DTT LOOOEÐ 03/31/03 , 5741' H 7" MARKffi JOINT 1 t 6204' 1-1 7" MARKffi JOINT 1 [ 1 PBm 1-1 6834' ~ 7" CSG, 26#, L-80, 10 = 6.276" Ii 6915' Dð.1E 08116102 03114103 03131/03 04108103 04128103 05106103 REV BY COMrvENTS DAV A<K ORlGINA.L COMR..ETION JJITLH CORRECllON CAOI1LH AI:FERF DRSffP TVD/MJ CORRECTIONS RI../lP NOTEAOOEDTO SSLV-5535' BJMlKK A [PERFS DATE REV BY OOMfv£NTS POLARIS UNIT W8..L: S-215 PffiMT f\b: 2021540 API f\b: 50-029-23107-00 SEC 35, T12N, R12E, 3276' NSL & 4563' WEl. 8P Exploration (Alaska) ) TREE = WB...LHEA 0 = AC1UATOR = kB. äBï~ 'SF.' ËLBï;'; kÒþ;····· Mïiïx'A ng'ie· = Öatum rii1ò =' Datuïll tv [j ,,; ., 7-1/16" OW McEVOY OTIS '56:11' 28:11' ·3'189' 1Ö3' @991ii ·'·105"8'1i .,. .. 880'6;'58' M-29A 113-3/8" CSG, 72#, L-80-BTRS,ID = 12.347" 1-1 2693' ~ ~ Minimum ID = 2.37" @ 8648' TOP OF 2-7/8" LINER 17" TBG, 26#, L-80-NSCC, .0382 bpf, ID = 6.276" l-i 8498' I 1 TOP OF 5-1/2" TBG 1-1 8498' \ I I :g ~ . . 1 TOP OF 2-718" LNR l-i 8648' 1 . . 15-1/2" TBG, 17#, L-80-BTRS, .0232 bpf, ID = 4.892" 1--1 8720' ~( ~~ ITOPOF7" LNR l-i 8720' !) 19-5/8" CSG, 47#, L-80-BTRS, ID = 8.681" 1--1 9522' ITOP OF T' BAKER WHIPSTOCK l-i 9530' 12-718" LNR 6.16#, L-80, .0058 bpf,lD =2.44" l-i 10696' ~ 10256' LT' LNR, 29#, L-80, .0371 bpf, ID = 6.184" H 10270' ÆRFORA TION SUfvTv1ARY RB= LOG: SÆRRY MWD/GR ON 07116/00 ANGLEATTOP ÆRF: 89° @ 10145' Note: Refer to Production DB for historical perf data SIZE SA= NTffiVAL Opn/Sqz DA. TE 2 6 10145-10170 0 04118/03 2 6 10245 - 10270 0 04118/03 2 6 10350 - 10375 0 04118/03 2-7 {8" 1 0696 - 10761 SL TD 07/21/00 DATE REV BY COMrvENTS 02/04189 INITIAL COrvPL AS NJECTOR 07/18/00 JCM cm SIDEfRACK 01/15/01 SIS-MD INITIAL REDRA W 03/08/02 RNffP CORRECTIONS 04/18/03 OONffLH ADD PERF & CIBP 2-7/8" SLTD LNR 6.16#, --i L-80, .0058 bpf, 10 = 2.44" ) SAFETY NOTES: SL TD LNR 1 0696' -10761' - 70° @ 9744' & 900@ 9847' 2098' Hr 011S SSSV LANDING NP, 10 = 5.962" I 8498' 1-i7" X 5-112" XO 1 8509' 1"5.1/2" 011S XA SLIDING SLV, 10 = 4.562" 1 8573' 1--19.5/8" X 5-112" l1W HBBP A<R 1 8631' l-i 5-1/2" 011S X NP, 10 = 4.562" 1 8648' 1-1 DER..OY rvENT SlJ3 1 8675' 1-i5-1/2" 011S XN NIP,ID =4.455" 1 8725' 1-17" TIW SEAL ASSY W/O SEALS 1 7" MLLOur WINDOW 9533' - 9540' 10640' l-i HES aBP (04118/03) 1 TOPOF2-7/8"SLTDLNR l-i 10696' 1 , , , , , , , , , , I 10761' TOPOF2-7/8" LNR l-i 10761' 1 FISH - (3) 1-1/16" ROLLERS IN WB...L LOCA 1l0N Uf\KNOWN 12-7/8" LNR, 6.16#, L80-SlL, .0058 bpf, D = 2.37" H 10773' 1 DATE REV BY COtvfv1ENTS PRUDHOE BAY UNrr WELL: M-29A ÆRMT No: 2000990 API N::>: 50-029-21904-01 SEC 1, T11 N. R1 2 E BP Exploration (Alaska) ) \ 6" tv'CEVOY tv'CEVOY OTIS ··71.67' 44~3:i ., ···1'650; ... ,~~~, ~?0.9.:, 1 0720' 8800' TREE = W8...LHEAD= ACfQï\tÖR= . KS. ElEV = .... 'ŠF. ElEV = ''kÖÞ; ,~,~..~~~,~==, Datum MD = DatumTVDss= 11 3-3/8" CSG, 72#, L80 ID = 12.347" H 2798' ~ 15-1/2" EQIPSEPKR, ID = 2.970" (05/11/03) 1-17545. 76051 (~ fc(¡~) Minimum ID = 2.970" @ 7545' 5-112" ECLIPSE PACKER 15-1/2" TBG, 17#, L-80, .0232 bpf, ID =4.892" 1-1 9920' I TOP OF 7" LNR 1-1 10047' 1 I 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 10302' I~ ÆRFORA 1l0N SUMMA.RY REF LOG: SWS-BHCS ON 12(26/85 ANGLE AT TOP PERF: 19 @ 10833' Note: Refer to Production 00 for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4" 4 10833 - 10843 S 01/01/90 4" 4 10856-10873 S 01/01/90 4" 4 10878 - 10891 S 01/01/90 3-318" 4 10840 - 10842 0 03107/92 3-318" 4 10856- 10873 0 01/04191 3-318" 4 10878-10891 0 01/04191 3-318" 4 10894 - 10900 0 01/04/91 PBTD 1-1 11057' IT' LNR, 29#, L-80, .0371 bpf. ID = 6.184" l-i 11098' DATE REV BY CO rvTv1ß\JTS OA.TE REV BY 12/30/85 ORlGINÞ.L COMR..ETlON 05119/01 RNIlP CORRECllONS 05106103 BJMiKK SEf 5-1IZ' EQ.IPSEPKR 05111/03 BJMiKK S Ef 5-1/Z' EQ. IPS E PKR D-24 L ~ ~ I I i i :g & ~ ]I ~ ~ COMM:NTS ) SA ÆTY \()TES 2086' 1-15-1 (2" OTIS SSSV LAND NIP, ID = 4.562" 1 ~ GAS LIFT MANDRELS ST rv1D TVD DEV TYPE SIZE LA TCH 6 3388 3119 40 OTIS-LSD 1-1(2" RA 5 5412 4619 44 OTIS-LSD 1-112" RA 4 7326 5940 41 OTIS-LSD 1-1(2" RA 3 8593 6943 33 OTIS-LSD 1-1 (2" RA 2 9310 7554 30 OTIS-LSD 1-1 (2" RA 1 9548 7761 29 OTIS-LSD 1-1(2" RA 9705' 1-i5-1 (2" OTISXA SLIDING SLV, ID= 4.562" 9768' l-ilBG SEAL ASSY 1 9783' l-i 9-518" x 5-1/2" TIW PKR, ID = 4.75"1 9835' l-t 5-1 (2" OTIS 'X' NIP, ID = 4.562" 1 9878' 1-i5-1 (2" OTISXNNIP, 10= 4.455" 1 9920' 9962' 1-15-1 (2" OTIS TBG TA IL 1 l-i B.rv1D-lT - DA TE NOT A VA ILABLE 1 ... 1 10867' l-t MA. RKER JOINT I FRLDHOE SA Y UNIT WB.L: [)'24 PERMIT No: 1 852990 A PI No: 50-029-21506-00 SEC 23, T11 N, R13E BP Explo ration (Alas k a) RE: MIT for Well 14-17 A (WAG injector) ) I ) Prb Z])3- 001 Subject: RE: MIT for Well 14-17A (WAG injector) Date: Mon, 12 May 2003 16:35:35 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP .com> To: "'Jim Regg'" <jim_regg@admin.state.ak.us>, ?€1á' 61 -z..,û3 "NSU, ADW Well Integrity Engineer" <NSUADWW~IÌÍMegf¡ty3ngineer@BP.com> CC: Winton GAubert <winton_aubert@admin.state.ak.us>, Steve McMains <steve_mcmains@admin.state.ak.us>, Admin AOGCC Prudhoe Bay <aogcc-prudhoe_bay@admin.state.ak.us> Hi Jim, PBU 14-17 (PTD 1810210) was coil tubing sidetracked in January 2003. The new sidetrack is PBU 14-17A (PTD 2030010). Because the sidetracking of the well did not involve releasing the packer or pulling tubing, and did not affect the mechanical integrity of the well, we assumed that the 4 year MITIA that was performed on 14-17 in January 2000 was still valid. I have attached a MIT form for the MITIA that was conducted on January 3, 2003 (pre-CTD sidetrack) and will schedule an AOGCC witnessed MITIA for the well to be conducted later this week or early next. Please call if you have any questions. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 -----Original Message----- From: Jim Regg [rnailto:jirn regg@admin.state.ak.us] Sent: Monday, May 12, 2003 12:05 PM To: NSU, ADW Well Integrity Engineer Cc: Winton G Aubert; Steve McMains; Admin AOGCC Prudhoe Bay Subject: MIT for Well 14-17A (WAG injector) I can find no record of an MIT for PBU 14-17A (PTD 203-001); records show well was completed 1/20/03 and began injection in February (1 day) followed by 31 days injection in March. We need to schedule an MIT for this well; please coordinate with our North Slope office and copy me. If your records indicate something other, please advise. Thanks. Jim Regg ,--...-----.---.-....---.- --........---------.. - ......_--~._._..- ,............-.-....-___......._..._....._.._....__......................_.......c......c...............__......._......_....._....._..._.."[_..............._............................__...__.....___._....._._........................................................._........._..._............................................_...__...___...........___................_.._.....................c..............._............¡ I Name: MIT PBU 14-17 01-03-03.xls I OMIT PBU 14-17 01-03-03.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) I Encoding: base64 j ---.._._-_........._.._.._....._.............._...-....~................_...._.........-...~...._._....._....,._..._....._............._-=........._..._.--_...._....._._.__._..........._~....~...__._........_............_.............-....__....N......__.__........___..........._._._._~._...___._..._.__....H........._....H..N_.._....__..........-.....................__..........-..........._. 1 of 1 5/12120033:55 PM ') ') i a03 ~oo I 1/(05/ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COmtll. Attn.: Lisa Weepie 33 3 West 7th Avenue, Suite 100 Anchorage, Alaska April 21, 2003 RE: MWD Formation Evaluation Logs 14-17 A, AK-MW-30004 1 LDWG f01111atted Disc with verification listing. API#: 50-029-20562-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Setvices Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~¡yi~~ ~ RECEIV~D APR 29 2003 Alaats ~ m& GasCon Anch~ Commiteio,¡ t }, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 03/11/03; Put on Injection ) ) ). 1. Status of Well Classification of Service Well o Oil 0 Gas 0 Suspended 0 Abandoned 181 Service ~"'''''''i:ji,''W'~~''''~''''¡\L Water & Gas Injector 2. Name of Operatorl~,~~t:~:'I:t¡r~)'~ 7. Permit Number BP Exploration (Alaska) Inc. t '::i~ j¡\ 203-001 3. Address l'~~:);~l.,.;~:' 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 J:.i~'~;'~~'i~};:\·,:ii 50-029-20562-01 4. Location of well at surface 9. Unit or Lease Name 2481' SNL, 1611' WEL, SEC. 09, T10N, R14E, UM X = 674893, Y = 5937852 Prudhoe Bay Unit At top of productive interval 1392' SNL, 4043' WEL, SEC. 16, T10N, R14E, UM X = 672568, Y = 5933607 10. Well Number At total depth 2825' SNL, 5150' WEL, SEC. 16, T10N, R14E, UM X = 671499, Y = 5932148 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field 1 Prudhoe Bay Pool RKB = 71' ADL 028314 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 1/14/2003 1/17/2003 1/20/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12585 9028 FT 12549 9029 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, Memory GR, CCL 14-17A 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2226' MD 1900' (Approx.) 23. CASING SIZE 20" 13-3/8" 9-518" 7" WT. PER FT. 91.5# 72# 47# 29# 8.81# / 6.2# / 6.16# GRADE H-40 L-80 L-80 I SOO-95 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 80' 36" Surface 2500' 17-1/2" Surface 10492' 12-1/4" 1 0202' 1 0589' 8-1/2" 10185' 12585' 3-3/4" CEMENTING RECORD 375 sx Permafrost II 3000 sx AS III, 400 sx AS I 400 sx Class 'G', 300 sx PF 'C' 400 sx Class 'G' 118 sx Class 'G' AMOUNT PUllED .. 3-1/2" x 3-3/16" x 2-7/8" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD MD TVD 11897' - 12447' 9053' - 9029' 12497' - 12547' 9029' - 9029' 25. TUBING RECORD SIZE DEPTH SET (MD) 5-1/2", 17#, L-80 10149' 4-1/2", 12.6#, L-80 10149' - 10243' 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with 50 Bbls of Diesel PACKER SET (MD) 10129' 27. Date First Production February 28, 2003 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water & Gas Injection PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl TEST PERIOD CHOKE SIZE GAS-Oil RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . r \~~ t" .~'~~~ Oll-BBl GAs-McF WATER-BBl Oil GRAVITY-API (CORR) .,.... ":::' .....--..~ ... ~ . ';, ,- .'. ~ No core samples were taken. L~~I...: I.:. r ' , .~ ...::;"',, \ ... ..' .. ......, ~ , '. . .. '.' .... ~ ..... . . I, ,f Form 10-407 Rev. 07-01-80 RBDMS 8Ft i vj;W , ") 't.. Submit In Duplicate ) ) Marker Name Geologic Markers Measured Depth 30. Formation Tests 29. True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sadlerochit 10686' 8960' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~~ ~ Trtle Technical Assistant Date o.a -/ to O~ 14-17 A 203-001 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Ted Stagg, 564-4694 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. ITEM 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 ~9rtinent 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. I-rEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well o Oil 0 Gas 0 Suspended 0 Abandoned ". ,181 S~rvice 2. Name of Operator :! BP Exploration (Alaska) Inc. ./,~.,~~~.~ 3. A~.~~:x 196612. Anchorage. Alaska 99519-6612 ;,..:.~:;::.: 4. Location of well at surface 2481' SNL, 1611' WEL, SEC. 09, T10N, R14E, UM At top of productive interval 1391' SNL, 4044' WEL, SEC. 16, T10N, R14E, UM X = 672568, Y = 5933607 10. Well Number At total depth 2824' SNL, 5151' WEL, SEC. 16, T10N, R14E, UM X = 671497, Y = 5932149 S'. 11. Field and Pool Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool RKB = 71' ADL 028314 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 1/14/2003 ; 1/17/2003 ' 1/20/2003 / 17. Total Depth (MD+ TVD) 18. Plug Back Dept~'(MD+ TVD) 19. Directional Survey 12585 9028 FT 12549 9029 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, Memory GR, CCL -.IVI,W",,'f\j¡1'-,...... Classification of Service Well ?t.()(!.AT~~ Water & Gas Injector \. ~. y~.. ,.J :7. Permit Number "Su~ ~":'_.!".~ . 203-001 1 (]. H~~4t8. API Number "';;..",~ :"'!"tl~~~"-:¡!,\¡'¡\"''''''':~·'~~t~,; 50- 029-20562-01 9. Unit or Lease Name X = 674893, Y = 5937852 Prudhoe Bay Unit 14-17A 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2226' MD 1900' (Approx.) 23. CASING SIZE 20" 13-3/8" 9-518" 7" GRADE H-40 L-80 L -80 I SOO-95 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 80' 36" Surface 2500' 17-1/2" Surface 10492' 12-1/4" 1 0202' 10589' 8-1/2" 1 0185' 12585' 3-3/4" CEMENTING RECORD 375 sx Permafrost II 3000 sx AS III, 400 sx AS I 400 sx Class 'G', 300 sx PF IC' 400 sx Class 'G' 118 sx Class 'G' · 3-1/2" x 3-3116" x 2-7/8" TUBING RECORD SIZE DEPTH SET (MD) 5-1/2", 17#, L-80 10149' 4-1/2", 12.6#, L-80 10149' - 10243' 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with 50 Bbls of Diesel Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. WT. PER FT. 91.5# 72# 47# 29# 8.81# / 6.2# /6.16# 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD MD TVD 11897' - 12447' 9053' - 9029' 12497' - 12547' 9029' - 9029' 25. 27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR Oll-BBl TEST PERIOD GAs-McF OIL -BBL GAs-McF No core samples were taken. Form 10-407 Rev. 07-01-80 ROOMS Drl AMOUNT PUllED PACKER SET (MD) 10129' WATER-BBl GAS-Oil RATIO CHOKE SIZE WATER-BBl Oil GRAVITY-API (CORR) (~ i~ l} { FEB ? 4 ?!J03 Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sadlerochit 10686' 8960' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I ~erebY certify that the fo~oin: is true and correct to the best of my knowledge Signed Terrie HUbble,/{.R AJ\J.1 J~ Title Technical Assistant Date O~.:;tO.. Q ~ 14-17 A 203-001 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Ted Stagg, 564-4694 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. ITEM 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ) ) BP EXPLORATION Operations Summary Rep.ort Page 1 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-1 7 14-1 7 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 1/11/2003 Rig Release: 1/20/2003 Rig Number: Spud Date: 4/24/1982 End: 1/20/2003 Date From - To Hours Task Code NPT Phase Description· of Operations 1/10/2003 00:00 - 00:30 0.50 MOB P PRE Move from D Pad to DS 14 1/11/2003 16:00 - 16:30 0.50 MOB P PRE Rig Released from D-30A @ 16:00 on 1/11/2003. Make general preparations to move rig off well. 16:30 - 16:45 0.25 MOB P PRE PJSM for moving rig off well. 16:45 - 18:30 1.75 MOB P PRE Pull rig off well to edge of pad. Roll-up tarps & clean-up location. Conduct post-operations pad inspection & report with pad operator. 18:30 - 21:45 3.25 MOB P PRE PJSM. R/U & LID windwalls. R/U tilt cylinders. LID derrick. 21 :45 - 22:00 0.25 MOB P PRE Held pre-move safety meeting with Security, tool service, CPS & all personnel. 22:00 - 00:00 2.00 MOB P PRE Move rig from D pad to Spine road. Move down Spin road towards DS 14. 1/12/2003 00:00 - 03:00 3.00 MOB P PRE Continue moving rig from D pad to DS#14. Set rig @ pad entrance. 03:00 - 06:30 3.50 MOB P PRE PJSM. Raise derrick & windwalls. Retract tilt rams. 06:30 - 09:00 2.50 MOB P PRE PJSM. P/U injecter head. M/U guide arch & stab CT into injector head. 09:00 - 12:00 3.00 MOB P PRE PJSM. Cut 1500' of CT for fatigue management. Install Baker CTC & pull test to 35klbs. 12:00 -13:30 1.50 MOB P PRE Standby & W. O. 14-17 well prep. 13:30 - 13:45 0.25 MOB P PRE PJSM for moving rig close to 14-17 well. 13:45 - 14:15 0.50 MOB P PRE Move rig from DS#14 entrance to 14-17 well house. 14:15 - 22:00 7.75 MOB P PRE Standby & continue W. O. DSM to pull 14-17 wellhouse and remove and blind MI injection line. 22:00 - 23:30 1.50 MOB P PRE Standby while DSM leveled location for rig. 23:30 - 23:45 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for backing rig over well. 23:45 - 00:00 0.25 MOB P PRE Back rig over well with no problems. 1/13/2003 00:00 - 03:30 3.50 RIGU P PRE ACCEPT RIG AT 0001 HRS, 01-13-2003. Rig up tanks and berms, trailers and hardline. 03:30 - 08:30 5.00 BOPSURP DECOMP Perform initial BOPE Pressure 1 Function test. Witness waived by AOGCC inspector, Chuck Scheve. Send test report to AOGCC. Grease crew pump open SSV. Open up well & observe pressures: WHP = Opsi, lAP = 25psi, OAP = 52psi & FLP = Opsi. 08:30 - 09:15 0.75 RIGU P PRE R/U new "LIFT-IT" sling for raising & lowering injector with blocks without climbing onto frame to hook-up shackle (as per Nordic-2). Meanwhile fill rig pits with 2% KCL bio-water. 09:15 - 09:30 0.25 STWHIP P WEXIT Held pre-operations safety meeting. Reviewed well plan, potential hazards (H2S) & BHA M/U procedures. 09:30 - 10:45 1.25 STWHIP P WEXIT Install dart catcher. Load wiper dart. Launch, chase & fill CT with 2% KCL. Dart hit @ 51.5bbls. Press test inner reel valve & CTC to 3500psi - OK. 10:45 - 11 :45 1.00 STWHIP P WEXIT M/U window milling BHA # 1 with HCC DSM, diamond string reamer, Baker X-Treme straight motor, MHA & 2 jts of PH6 tbg. Stab injector on well. 11 :45 - 13:35 1.83 STWHIP P WEXIT RIH with BHA #1 circ out FP MeOH. Wt check @ 10190', Up = 41k, dwn = 21k. Continue RIH BHA#1& tag @ 10232'. Assume XN & correct CTD (-10') to ELM of 10222'. Establish freespin @ 2.7bpm & 1650psi. 13:35 - 14:00 0.42 STWHIP P WEXIT Ease into milling from 10215' & mill thru (likely schmoo) without much resistance. RIH & tagged hard on the XN @ 10244'. P/U Printed: 1/27/2003 9:53:33 AM ) ) BP EXPLORATION Operations Summary r~eport Page 20f 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-17 14-1 7 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 1/11/2003 Rig Release: 1/20/2003 Rig Number: Spud Date: 4/24/1982 End: 1/20/2003 Date From - To Hours Task Code NPT Phase Descriptiol'1 of Operations 1/13/2003 13:35 - 14:00 0.42 STWHIP P WEXIT & retag @ same depth. Correct depth (-22') to the XN ELM of 10222'. Mill XN nipple with 2,7bpm, 1800psi. Make few passes with & without pumping to ensure there are no restrictions/overpu lis. 14:00 - 14:50 0.83 STWHIP P WEXIT Continue RIH BHA #1. Tag cement bridge @ 10561'. Ream in hole. Tag TOWS @ 10588.1' & pinch point @ 10592.4'. Pinch pt is 4.6' below TOWS'"" correct (-3,8) to 1 0588.6' (total -35.8' correction) & flag CT. 14:50 - 17:30 2.67 STWHIP P WEXIT Mill 3.80" window out of 7", 29# liner from 10588.6' with 2.6/2.6bpm, 1600/1750psi, 1-3k WOB & 1-3fph. Continue milling, stall1x & breakout @ 10594.8' (btm of window). 17:30 - 18:45 1.25 STWHIP P WEXIT Mill formation to 10605' with 2.7/2.7bpm, 1530/1750 psi, 3k WOB & 1 Of ph ave Rap. 18:45 - 20:30 1.75 STWHIP P WEXIT Backream up thru window clean at 1 FPM, 2.7/2.7 bpm, 1500 psi, Ream down at 1 fpm, clean to 10,605'. Back ream up at 1 FPM, no motor work. Clean window. Ream down clean. Swap well over to re-conditioned FloPro while reaming window. 20:30 - 22:45 2.25 STWHIP P WEXIT RIH thru window with no pump. Clean window. Back ream up thru window, clean. POH while circulating well to FloPro. Flag CT at 10,400' EOP. POH. 22:45 - 23:45 1.00 STWHIP P WEXIT LlO milling BHA, Mill and reamer at 3.80" gauge. Cut off BKR CTC and M/U DS CTC. Pull test and press test CTC. 23:45 - 00:00 0.25 DRILL P PROD1 PRE-SPUD SAFETY MEETING. Review well plan and hazards with crews. Review BHA M/U procedure, hazards and mitigation. 1/14/2003 00:00 - 01 :00 1.00 DRILL P PROD1 M/U MWD build BHA with new 3,75" M09BX bit, 2.0 deg motor and Sperry MWD tools. BHA total length = 66.2'. 01 :00 - 03: 1 0 2.17 DRILL P PROD1 RIH with BHA #2, build BHA with 2.0 deg motor. Shallow hole test MWD tools. RIH. Correct to flag at 10400' EOP, -34 ft CTD. 03:10 - 03:30 0.33 DRILL P PROD1 Orient TF to High side. Ran thru window with no wt loss. Tagged TD at 10,605'. 03:30 - 05:00 1.50 DRILL P PROD1 Drilling Shublik, 2.7/2.7 bpm, 3100 - 3800 psi, 8L TF, 5K WOB, 20 FPH. Drilled to 10630'. 05:00 - 06:00 1.00 DRILL P PROD1 Drilling Shublik, 2.7/2.7 bpm, 3100 - 3800 psi, 10L TF, 5K WOB, 20 FPH. Drilled to 10645'. 06:00 - 07:00 1.00 DRILL P PROD1 Drilling Shublik, 2.7/2.7 bpm, 3100 - 3800 psi, 10L TF, 5K WOB, 20 FPH. Drilled to 10660' 07:00 - 07:30 0.50 DRILL P PROD1 PUH to 10610' & tie-in RA pip tag to top of Shublik. Added 4' to CTD. Corrected depths are: TOWS = 10588', TOW = 10593', RA Pip Tag = 10598' & BOW = 10599'. RBIH to btm. 07:30 - 08:50 1.33 DRILL P PROD1 Continue drilling to 10701' with HS TF, 2.7/2.7bpm, 3100/3400psi, 4k WOB & 30fph ave Rap. 08:50 - 09:15 0.42 DRILL P PROD1 Drill to 10715' with 20L TF, 2.7/2.7bpm, 3000/3350psi, 4k WOB & 35fph ave Rap. 09:15 - 09:55 0.67 DRILL P PROD1 Orient 1 click & drill to 10748' with 20L TF, 2.7/2. 7bpm, 3000/3350psi, 4k WOB & 50fph ave Rap. 09:55 - 10:45 0.83 DRILL P PROD1 Drill to 10785' with 20L TF, 2.7/2.7bpm, 3000/3350psi, 4k WOB & 57fph ave Rap. Estimate 82degs @ the bit. 10:45 - 12:35 1.83 DRILL P PROD1 POOH for lateral BHA. Printed: 1/27/2003 9:53:33 AM ) ) BP EXPLORATION Operations Summary· Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-1 7 14-1 7 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From-To 1/14/2003 12:35 - 13:30 0.92 DRill P 0.50 DRill P 2.08 DRill P 0.92 DRill P 13:30 - 14:00 14:00 - 16:05 16:05 - 17:00 17:00 - 17:20 0.33 DRill P 17:20 - 17:45 0.42 DRill P 17:45 - 17:50 0.08 DRill P 17:50 - 18:10 0.33 DRill P 18:10-19:00 0.83 DRill P 19:00 - 21 :00 2.00 DRill P 21 :00 - 22: 15 1.25 DRill P 22:15 - 22:45 0.50 DRill P 22:45 - 00:00 1.25 DRill P 1/15/2003 00:00 - 01 :15 1.25 DRill P 01 :15 - 01:45 0.50 DRill P 01 :45 - 02:30 0.75 DRill N 02:30 - 02:50 0.33 DRill P 02:50 - 03:00 0.17 DRill P 03:00 - 04:00 1.00 DRill P 04:00 - 04:20 0.33 DRill P 04:20 - 05:30 1.17 DRill P 05:30 - 06:00 0.50 DRill P 06:00 - 07:15 1.25 DRill P 07: 15 - 07:30 0.25 DRill P 07:30 - 07:50 0.33 DRill P 07:50 - 08:40 0.83 DRill P 08:40 - 08:55 0.25 DRill P 08:55 - 09:35 0.67 DRill P 09:35-10:15 0.67 DRill P 10: 15 - 11:40 1.42 DRill P 11:40 - 12:40 1.00 DRill P 12:40 - 13:45 1.08 DRill P 13:45 -14:10 0.42 DRill P Page 3 of 10 Start: 1/11/2003 Rig Release: 1/20/2003 Rig Number: Spud Date: 4/24/1982 End: 1/20/2003 Code NPT Phase Descri þtionof Operations PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 SFAl PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 OOH. LlO M09 bit - grade 0,1,1. Adjust motor bend to 1.04degs & C/O bit to used HYC DS49. Held H2S drill. Evacuate rig & account for personnel. Review emergency procedures. RIH with lateral MWD BHA #3 with 1.04 deg motor & used DS49 Bit #3. Tag bottom @ 10785, orient 1 click, drill ahead, 78l TF, 80.79 INC, 2.6/2.6 bpm, 3000/3400 psi, 3K WOB, 130 fph. Drill to 10885' in Zone 4, 90l TF, 84 INC, 2.6/2.6bpm, 3000/3300psi. Orient to lowside. Drill to 10905'md 2.6/2.63000/3400 Orient to 90l Drill to 10940'md Wiper to window and tie-in. Add 2'. RIH to TD. Drilling, 2.7/2.7 bpm, 3100 -3600 psi, 93l, 82 deg incl, 50-110 FPH, Drilled to 11050'. Drilling, 2.7/2.7 bpm, 3100 -3600 psi, 90R, 82 deg incl, 50-110 FPH, Drilled to 11150'. Wiiper trip to window. Clean hole. RIH to bottom. Drilling, 2.7/2.7 bpm, 3100 -3600 psi, 70R, 85 deg incl, 50-110 FPH, Drilled to 11250'. Drilling lateral in Zone 4. 2.7 / 2.7 bpm, 3100 - 3800 psi, 70l, 87 deg incl. Drilled to 11305'. Wiper trip to window. Clean hole. Replace leaking hardline gasket inside reel. Pressure test seal. OK. RIH to TD. Clean hole. Orient TF. Drilling, 2.7/2.7 bpm, 3100 - 3800 psi, 87 deg incl, 90R, 110 FPH, Drilled to 11400' Orient TF. Drilling, 2.7/2.7 bpm, 3100 - 3800 psi, 90 deg incl, 60R, 100 FPH, Drilled to 11500'. Predicted fault crossing was near 11450', no sign of losses. Wiper trip to window. Clean hole. RIH. IA=566,OA=102psi Continue drilling in HOT, 2.7/2.7bpm, 90deg Inc, 90R, 150-190fph. Drill to 11620'. Full returns. Orient TF to high-side. PVT=271 Drilling, drill to 11650'md Wiper trip to window. Clean hole. Orient on bottom. Drilling, 2.7/2.7bpm, 3100/3400psi, 95deg inc, Drill to 11750. Orient TF. Drilling, 2.7/2.7bpm, 3100/3400psi, 95deg inc, 65-130FPH, Drill to 11780. Wiper to window. Paul Hyatt on site, rig hands start acting civilized. Drilling, 2.7/2.7bpm, 3100/3500psi, 92deg INC, 40-60fph. ROP slowing. Drill to 11850'md. New mud system out bit at 11850' (2% lubeTex, 4ppb KlaGard, 65K lSRV). Made 1245' with 1 st reconditioned Flo-Pro system. PROD1 Drilling getting ratty, a couple stalls. 2.8/2.8bpm, 2850/3700psi, 90deg INC, 30-50fph. Drill to 11870'md Printed: 1/27/2003 9:53:33 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') BP EXPLORATION Operations Summary· Report 14-1 7 14-1 7 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 1/15/2003 From - To Hours Task Code NPT Phase 14:10 - 14:25 14:25 - 16:15 16:15 - 18:00 18:00 - 19:45 19:45-20:10 20: 1 0 - 20:45 20:45 - 21 :15 21:15-22:30 22:30 - 23:45 23:45 - 00:00 1/16/2003 00:00 - 01 :00 01 :00 - 02:30 02:30 - 02:45 02:45 - 03:00 03:00 - 03:45 03:45 - 06:00 06:00 - 06:10 06:10 - 06:30 06:30 - 10:40 10:40 - 10:55 10:55 - 11: 1 0 0.25 DRILL P 1.83 DRILL P 1.75 DRILL P 1.75 DRILL P 0.42 DRILL P 0.58 DRILL P 0.50 DRILL P 1.25 DRILL P 1.25 DRILL P 0.25 DRILL P 1.00 DRILL P 1.50 DRILL C 0.25 DRILL C 0.25 DRILL C 0.75 DRILL C 2.25 DRILL C 0.17 DRILL C 0.33 DRILL C 4.17 DRILL C 0.25 DRILL C 0.25 DRILL C PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: 1/11/2003 Rig Release: 1/20/2003 Rig Number: Spud Date: 4/24/1982 End: 1/20/2003 Descri ption of Operations Orient TF. Drilling break at 11898'md as we exit the shale. 2.7/2.7bpm 2900/3300psi, 90-130fph ROP, Drill to 11949'md. White clay seen in Geo sample from 11,850'. Wiper to window, Log tie-in To RA marker at 10598', added 1.5' CTD. Set down in shale at 11817' while tripping back in. PU, work. Raise Kla-Gard to 10ppb. Ream shales from 11900-11770'. 1 OK overpull, stacking wt. Ream until hole was clean. Orient TF to 70R. Drilling, 2.7/2.7 bpm, 2850 - 3400 psi, 94 deg incl, 120 fph, Drilled to 12002'. Orienter rotated 180 deg while trying to get 1 click. Orient TF. Drilling, 2.7/2.6 bpm, 2700 - 3400 psi, 93 deg incl, Drilled to 12042' . 6 BPH mud loss. Drilling, 2.7/2.6 bpm, 2700 - 3400 psi, 93 deg incl, 95 fph, Drilled to 12,100'. Up Wt = 35K, 2480 psi, free spin at 2,5 bpm. Backream 200' at 33 fpm, 2.5/2.4 bpm, 2480 psi. Up wt = 37K at 33 fpm. Ream down to TD at 10 FPM, 2.5 bpm, 2480 psi, 16-17K down wt. Up wt off bottom = 36K at 19 fpm, 2.5 bpm, 2480 psi. Wiper trip to window. Reamed shales from 11900-11770' and reamed from 10900-10800'. POH to pick up Andergauge Agitator tool. At surface, Stand back BHA. SAFETY MEETING. Review procedure, hazards and mitigation for BHA M/U. Review concept and M/U of Andergauge Agitator tool. Check bit OK, [ 1-1-1 ], check motor, C/O Sperry MWD tools to download memory data, M/U Agitator [ length = 6.40' ], between orienter and MHA. BHA = 71.73' RIH with BHA #4, DS49 bit, 1,04 deg motor and Agitator tool above orienter. Shallow test Sperry tools - OK. RIH, Test orienter at 2740'. OK, RIH. Orient TF to highside above window. RIH, set down at 10625', just below window, work down to 10639' with highside toolface. Stacking wt and stalling motor while reaming down at 4 FPM. Work past. IA=390, OA=93psi. Cont RIH, lose wt at 11770' start reaming down, 2.2/2.0, high side left TF. Work down to 11861', stack-out, PU heavy, 1 0-20K overpull up thru 11800. Cont working, sitting down, losing wt, PU look clean. Tag TD, correct CT depth -15.8'. PU to 11960'md. RIH @ 20fpm, 3050psi freespin. Tag TD. Agitator testing for change in up and dwn wts. PU 39-40K at TD, Freespin 3050psi, 2.5bpm. POH to 11900'md at 14FPM, 2.5bpm, 2950-2980psi. Getting overpulls Printed: 1/27/2003 9:53:33 AM ) ) BP EXPLORATION Operations.·Summary Report Page 5 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-17 14-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 1/11/2003 Rig Release: 1/20/2003 Rig Number: Spud Date: 4/24/1982 End: 1/20/2003 Date From - To Hours Task Code NPT Phase Description· of Operations 1/16/2003 10:55-11:10 0.25 DRILL C PROD1 to 65K (25K over) near 11900'md. 11:10-11:30 0.33 DRILL C PROD1 Ream down to TD at 10fpm, 2.5bpm, 3050psi, 15-18K RIH wt. Same up and down wts as before picking up Agitator, but benefit of Agitator may be masked by existing hole conditions. 11:30-11:40 0.17 DRILL C PROD1 Tag TD, orient TF 70R. 11:40-13:00 1.33 DRILL P PROD1 Drilling, 3380psi, 2.5/2.4bpm. 60fph avg ROP, No WOB. Drill to 12174'md. Losing approx. 6bph. 13:00 - 13:05 0.08 DRILL P PROD1 Drilling, 3515psi, 2.5/2.4bpm. 170fph, No WOB trying to get reactive torque, no good. Can drill as fast as we want thru this area, unfortunately Inclination is nearing 95deg, we want 92-93deg. 13:05-13:30 0.42 DRILL P PROD1 Orient TF. 13:30 - 14:45 1.25 DRILL P PROD1 Drilling 3360psi, 2.5/2.4, 931NC, 74RTF, 60Avg ROP. Drilled to 12250' . 14:45 - 17:55 3.17 DRILL P PROD1 Wiper to window. Several overpulls 20K over from 11840'md up to 11790'md, backream and work past shale area up to window. Increase Kla-Gard to 12ppb, start bringing LubeTex up to 4%. RBIH, ream down through shale area 11770-11900, much easier this time. 17:55 - 19:15 1.33 DRILL P PROD1 Drilling 2.5/2.4 3350psi, 92inc. Still losing fluid at about 10 bph. Drilled to 12,350'. Lost 135 bbls FloPro since 0700 hrs today, [11 BPH ave]. 19:15-20:00 0.75 DRILL P PROD1 Drilling, 2.5/2.4 bpm, 3350 - 3800 psi, 91 deg inc, 100 FPH, Drilled to 12,420'. 10 BPH fluid loss. 20:00 - 21 :30 1.50 DRILL P PROD1 Wiper trip to window. Back ream shales at 12060', 15K overpull, stack wt and motor work. and 11840' wi 1 OK overpull and motor work. Overpulls of 10K at 10880'. FloPro presently has 12 PPB KlayGard and 3% Lubetex. 21 :30 - 22:30 1.00 DRILL P PROD1 RIH, Set down wt at 11770', ream down, stack wt at 11800', ream down, Stack full wt at 11825', ream down at 5 fpm, Stack wt at 11850', Stack full wt at 11880', Stack full wt at 11890', Ream down to 11950'. 22:30 - 23:30 1.00 DRILL P PROD1 Back ream up to 11750',10 fpm, 10k overpull, Ream down and set down full wt at 11770 and 11780 ft. Ream down, stack 10K at 11840', Ream down. Stack 10K at 12030'. RIH to TD. 23:30 - 00:00 0.50 DRILL P PROD1 Drilling, 2.5/2.5 bpm, 3200 - 3800 psi, 74R, 91 deg incl, Drilled to 12,480'. 1/17/2003 00:00 - 01 :15 1.25 DRILL P PROD1 Drilling, 2.5/2.5 bpm, 3200 - 3800 psi, 91 deg, 70R, 100 FPH. Drilled to TD of 11,580' 01 :15 - 02:45 1.50 DRILL P PROD1 Wiper trip to window. 5-1 OK overpull in shales from 11900-11770'. Stalled motor at 11810', backream slow with motor work, 1 OK overpull at 11775', RIH and stacked full wt, Backream at 2 F, packed-off and lost 50% returns while backreaming, Clean trip up from 11730' to window. 02:45 - 03: 1 0 0.42 DRILL P PROD1 Log tie-in with RA tag at 10598'. Added 3 ft to CTD. 03: 1 0 - 04:30 1.33 DRILL P PROD1 RIH clean to 11040', some motor wrk, RIH clean to 11780', stall motor and stack wt, pick up and ream down slow. Ream shales from 11,780- 11900', RIH, stack full wt at 12080', Ream down, RIH Clean to TD. Tag final corrected TD at 12,585'. 04:30 - 05:30 1.00 DRILL P PROD1 Wiper trip to window, clean up to 11800', packed-off, lost 50% returns, back ream up to 11750', ream in hole with some motor Printed: 1/27/2003 9:53:33 AM ') ) BP EXPLORATION Operations SumrnaryReport Page 60f 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-17 14-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 1/11/2003 Rig Release: 1/20/2003 Rig Number: Spud Date: 4/24/1982 End: 1/20/2003 Date From - To Hours Task Gode NPT Phase . Description of Operations 1/17/2003 04:30 - 05:30 1.00 DRILL P PROD1 work to 11950' 05:30 - 06:00 0.50 DRILL P PROD1 Back ream shales 11900 - 11770', 1 OK overpull and 200 psi motor work, Shales are getting better. Less motor work, less overpull. 06:00 - 09:15 3.25 DRILL P PROD1 Continue backreaming at 4fpm, 2590psi, 2.0/1.9bpm to 11600', Very little motor work if any, looks clean from 11700' to 11550' . IA=604,OA=185psi. Start RBIH, 16-17K RIH wt, 2830psi circulating press, 2.2/2.2bpm. Set down wt with motor work, stall near 11850'md. Cont reaming in hole with motor work to 11900'. PU, backream through shale area, looks like it is cleaning up, still getting some motor work as we pull up thru the trouble area. Work the trouble spots. 09:15 - 10:30 1.25 DRILL P PROD1 Continue working the trouble shale areas where we have set down and seen motor work. Wating on NaCI delivery to weight up mud from 8.6 to 9.1 ppg. Start sending 9.1 ppg mud downhole at 10:30. 10:30 - 15:00 4.50 DRILL P PROD1 Swap well to 9.1 ppg Flo-Pro, make a couple of wipers in the mean time. PU to 11600' then RBIH. Seeing small amounts of motor work and a few weight bobbles from 11770-11900 but it generally has cleaned up well. See 1 OK overpull and motor work 12020'md. Ream to 12585', backream to 11600', working the tight spots, ream back down to TD. Stack full wt at 12040'md, 12080, 12160' with motor work. Tag TD, 12588'md. 15:00 - 16:15 1.25 DRILL P PROD1 POH at 35fpm, 1.7bpm, laying in clean 9.1 ppg Flo-Pro 12ppg KlaGard, 4% LubeTex. 11770-11900 looks clean, Ream the tights spots once again on our final up pass. Slight overpull and motor work at 12050' and 11 050'md. Losses are consistent at 10bph. Backreaming, see some motor work at 1 0890'. Pull heavy through window, 16:15 - 18:15 2.00 DRILL P PROD1 POH, Paint EOP flag at 10135' (50 off bottom w/liner), Paint 2nd EOP flag at 8138' (50' above window). POH pumping 2.2bpm. 18:15 - 18:30 0.25 DRILL P PROD1 Stand back injector. 18:30 - 18:45 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for BHA layout and liner running. 18:45 - 19:15 0.50 DRILL P PROD1 UO MWD BHA. Bit still in new condition. 19:15 - 22:00 2.75 CASE P COMP RIH with 63 jts of 2-7/8", STL, 6.16#, L-80 Liner and 10' pup Jt. Fill liner with water. 22:00 - 23:00 1.00 CASE P COMP RIH with 5 Jts, 3-3/16", TCII, 6.2#, L-80 Liner and XO. RIH with 12 Jts of 3-1/2", STL, 8.81#, L-80 Liner. M/U Halco 3-1/2" XN Nipple and 10',3-1/2" STL, Pup Jt. 23:00 - 23:45 0.75 CASE P COMP M/U BKR CTLRT with 3.70" Deployment sleeve and 3-1/2", STL pup Jt. M/U BKR CTC, Pull test and press test. M/U CTC to Liner BHA. BHA total length = 2,408.9'. 23:45 - 00:00 0.25 CASE P COMP RIH with 2-7/8" Liner on CT. Circ. FloPro at 0.5 bpm, 1100 psi. 1/18/2003 00:00 - 01 :15 1.25 CASE P COMP RIH with liner on CT. Correct to CT flag, -39 ft CTD. Up wt = 41K at 10,500', DWn = 21K, Ran thru window with no wt loss. 01:15 - 01:45 0.50 CASE P COMP Run liner in open hole, sat down wt early at 10750 ft, work down to 10836', Sat down full wt several times, must have been a solids bridge near window. Work Liner. Clay balled aound lower Turbos, causing loss of returns each time we set down. Pick up and get returns. Get full down wt after each pick Printed: 1/27/2003 9:53:33 AM ) ) BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-17 14-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 1/11/2003 Rig Release: 1/20/2003 Rig Number: Spud Date: 4/24/1982 End: 1/20/2003 Date Frain';; To Hours Task Code NPT Phase Descri pHon of Operations 1/18/2003 01:15 - 01:45 0.50 CASE P CaMP up, then stack full wt, Work down to 10872'. 01 :45 - 02:30 0.75 CASE P CaMP Circ. at 1.6 bpm, 1900 psi, while POH slow to clean off liner. Full returns. RIH, Broke thru plug and RIH with 20K down wt at 80 fpm. RIH clean to 11,795'. Stack full wt on shale. Work liner. Work liner 5 times and worked thru shale. RIH clean to 12040' and sat down full wt on shale, Work liner thru shale. RIH at 12,100' with 15K down wt. Land liner at TO at 12,587' CTD, Correct depth at 12,585', Full returns at 0.7 bpm. Liner top at 10,185'. PBTD = 12,550'. 02:30 - 03:30 1,00 CASE P CaMP Drop 5/8" steel ball, Displace with FloPro at 2.0 bpm, 2150 psi, full returns. Ball on seat at 44.3 bbls. Sheared at 3800 psi. Pick up free at 32K. Stack Wt. Clean pits, 03:30 - 06:00 2.50 CASE P CaMP Circ 2% KCL water with friction reducer. Recover FloPro and send to MI plant for reconditioning. Phase 2 Weather conditions. Circ. 2.6 bpm, 2150 psi, full returns with FloPro on formation. 95% returns with KCL water on formation. 2.6/2.5 bpm, 1450 psi. Circ. 3 bpm, with 2.9 bpm returns [95% returns]. Rig up DS Cementers. Phase 1 weather 06:00 - 06:30 0.50 CASE P CaMP PJSM, Discuss cement job, everyone's role and good communication, ensure all spill prevention is in place for Dowell cement pumpers. 06:30 - 07:00 0.50 CASE P CaMP Cementers test lines, continue to rig up. IA=164,OA=68psi 07:00 - 08:00 1.00 CASE P CaMP Pump 24bbls of 15.8ppg Class G cement (D065=0.4%BWOC, D800= 0.17%BWOC, D047=0.2GAL/SK, D600G=2GAL/SK, BHST=210degF, BHCT=145degF). Shut down, flush hardlines from cementers to reel. Launch dart, pump 0.1 bbl, check for launch. Displace cement with 30bbls of BIO Water at 2.6/2.4bpm, 1220psi, double slick KCI behind BIO. Zero out totals with cement at shoe, 42.6bbls. Slow to 1.5bpm, 2bbls prior to dart latch with LWP. See CT dart latch LWP at 52.6bbl. Shear LWP at 3300psi, cont. pumping at 2.3/2.1 bpm 1400-psi. Slow down to 1 bpm prior to LWP bump. 67.5bbls, 14.9 bbls from latch up to float collar. Test floats, holding. Dart and liner wiper plug both seen on caculated volumes. Lost 2bbls of cement during job, planned & pumped 2bbls excess so cement top should be as desired at 10350'. Unsting from liner pumping <1 bpm, trying to minimize ECD at liner top. PU 20' above TaL and circulate at 1.5bpm for 7bbls, then start OOH. 08:00 - 10:30 2.50 CASE P CaMP POOH at 80%. 10:30 - 10:45 0.25 CASE P CaMP Stand back injector, LID CTLRT. 10:45 - 12:00 1.25 CASE N WAIT CaMP Wait on Schlumberger Carrier, 1 st one that was sent out did not have the right XO to the motor below. 12:00 - 12:15 0.25 CASE P CaMP PJSM. Discuss Mem GRlCCL log, PU CSHydril. Keep hole full. Watch pinch points, good communication. Anyone can stop the job if anything looks out of ordinary. 12:15-15:30 3.25 CASE P CaMP PU PDS Memory GRlCCL tool, Schlumberger Carrier, Navidrill motor and HCC used 2.3" Diamond mill (D331), HDC, CIRC sub, 82jts 1-1/4" CS HYDRIL, Dowell MHA (minus NRJ), Baker CTC. Printed 1/27/2003 9:53:33 AM ) ) BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-1 7 14-1 7 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 1/11/2003 Rig Release: 1/20/2003 Rig Number: Spud Date: 4/24/1982 End: 1/20/2003 Date From- To Hours· Task Code NPT Phase Descri ptiorfofOþerations 1/18/2003 15:30 - 17:30 2.00 CASE N DPRB COMP Troubleshoot immediate 1000psi pressure build up in tools. Check flow path and surface lines. Pop off, circulate thru CT at surface, 400psi. Re-stab, pressure up to 2500psi at surface with ,5bpm, shut down pumps, pressure holds flat at 2500psi, bleed pressure. Try pressuring up to 2500 psi again, still holds with pumps shut down, bleed pressure. Pop off, drop 5/8" ball to 1-1/4" CS Hydril to open circ sub below Hydril. Pressure up to 2500 psi. No Circ. Now have 2500 psi trapped below double check valves. 17:30 - 19:00 1.50 CASE N DPRB COMP Order 3/4" rod connected to 2-3/8" reg sub from DS shop, to push open check valves using coil. 19:00 - 19:15 0.25 CASE N DPRB COMP SAFETY MEETING. Review plan, hazards and mitigation for lowering rod onto 1" check valves. 19:15 - 20:00 0.75 CASE N DPRB COMP M/U additional lubricator below injecter head to swallow rod and XO. M/U 3/4" x 20" rod to CTC. Pull up into lubricator. Lower injecter head with rig blocks until rod was inside CT check valve body. Clear rig floor and lower rod through both check valves, had approx 1 gallon of water flow out base of lubricator. Set back injecter head. Remove DS check valves and Hyd disconnect. 2Q:00 - 21 :30 1,50 CASE N DPRB COMP Stand back 41 Stds of CSH work string, Found BKR Circ sub filled with scale from CSH workstring, also ported carrier sub, XO to motor and mill were packed with scale. Phase 2 weather, convoy only. 22-40 mph, -36 F chill. 21 :30 - 22:30 1.00 CASE N DPRB COMP Clean out mill, M/U new BKR 2-1/8" motor, Carrier with memory GR/CCL, ported XO, new BKR circ sub and hyd disc. and XO. 22:30 - 00:00 1.50 CASE N DPRB COMP RIH with 41 Stds of CSH workstring. 1/19/2003 00:00 - 00:40 0.67 CASE N DPRB COMP Circ. down CSH at 1 bpm for 5 min. No problems. M/U DS Hyd Disc, check valves and NRJ. M/U CTC. BHA = 2588' Phase 2 weather. 00:40 - 02:30 1.83 CASE P COMP RIH with 2.3" mill, motor, carrier with GR/CCL on CSH. BHA #6. 02:30 - 03:45 1.25 CASE P COMP Log GRlCCL from 10,000', log down at 35 FPM, circ at 0.6 bpm at 720 psi. Tag PBTD of 12,550' at 12,474' CTD, Correct depth to 12,550'. We had some measuring wheel slippage while RIH above liner top, which accounts for large error. 03:45 - 05:00 1.25 CASE P COMP Log up from PBTD to 10,000'. 35 fpm, 1.0 bpm, 05:00 - 06:00 1.00 CASE P COMP Drop 5/8" steel ball to open circ. sub. RIH while circ. ball on seat at 1.6 bpm. 06:00 - 08:20 2.33 CASE P COMP Tag PBTD @ 12550'. Shear ball seat and open circ sub, start POH while swapping well to new, clean, unused 2% KCI. 70fpm, 2bpm, 3300-3350psi. IA=20,OA=47. 08:20 - 09:00 0.67 CASE P COMP Pop off, Stand back injector. 09:00 - 09: 15 0.25 CASE P COMP PJSM, review job roles, LD CS Hydril and standing some back. Review Phase II weather policy. Phase II Convoy only, -44WC, gusts 40-50mph. 09:15-11:10 1.92 CASE P COMP LD MHA, 24jts of CSHydril, stand back 29 stands. LD Memory GRlCCL tool. 11 : 1 0 - 11 :45 0.58 CASE P COMP Place cap on lubricator and PT liner lap to 2500psi for 30m in. I I Printed: 1/27/2003 9:53:33 AM ) ) Page 9 of 10 BP EXPLORATION Operations.Summary·Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/19/2003 14-17 14-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From-To H 0 LÏ rs Task Code NPT Phase 11: 1 0 - 11 :45 0.58 CASE P COMP 11 :45 - 12:15 0.50 PERF P COMP 12:15 -12:30 0.25 PERF P COMP 12:30 - 03:15 14.75 PERF P COMP 03:15 - 04:15 1.00 PERF P COMP 04:15-18:10 13.92 PERF P COMP 18:10 -19:50 1.67 PERF P COMP 19:50 - 20:00 0.17 PERF P COMP 20:00 - 22:00 2.00 PERF P COMP 22:00 - 22: 15 0,25 PERF P COMP 22: 15 - 00:00 1.75 PERF P COMP 1/20/2003 00:00 - 01 :00 1.00 PERF P COMP 01 :00 - 01: 15 0.25 RIGD P COMP 01 :15 - 03:30 2.25 RIGD P COMP 03:30 - 04:30 1.00 RIGD P COMP 04:30 - 06:00 1.50 RIGD P COMP 06:00 - 08:00 2.00 RIGD P COMP 08:00 - 11 :00 3.00 RIGD N WAIT COMP 11:00-12:15 1.25 RIGD N WAIT COMP 12:15 -16:30 4.25 RIGD N SFAL COMP Start: 1/11/2003 Rig Release: 1/20/2003 Rig Number: Spud Date: 4/24/1982 End: 1/20/2003 Description of Operations Load guns into pipe shed. Good 30min Test, bled 25psi over 30minutes, Continue loading guns and wait on memory GR/CCL data, Corrected PBTD=12,549'md PJSM: Discuss pu guns and CSHydril, Phase II conditions, Cellar is off limits. Verify 5/8" ball will pass thru MHA and lower disconnect. PU 31 perf guns, firing head, hyd disconnect, 52 jts 1-1/4" CSHydril, MHA. RIH with perf guns. Tag PBTD, PU, tag PBTD again. PU until we get up wt., position reel to drop ball. Launch ball. RBIH, Tag PBTD, postion bottom of guns l' off PBTD. Bottom perf charge located at 12,547' BKB. Circulate ball around at 2.1 bpm. Lost 1 bpm returns after guns fired. 2.1 bpm in, 1.1 bpm out. Perforate 2 intervals, 600' total: 11897-12447', 12497-12547' (2" HSD, 4SPF PowerJet) POH with fired guns. SAFETY MEETING. Review procedure, hazards and mitigation for laying out CSH singles. Layout CSH in singles. 54 jts. SAFETY MEETING. Review procedure, hazards and mitigation for recovering SWS perf guns. Layout SWS 2" perf guns and blanks. All shots fired. 600 ft, 4 SPF. Power Jet. Recover 100% of fired perf guns and blanks. Load onto SSW trailer from pipe shed. PHASE 2 WEATHER, 46 MPH WIND, BLOWING SNOW, -50 CHILL. SAFETY MEETING. Review procedure, hazards and mitigation for pumping N2. Displace KCL water in CT with N2. 1500 SCFPM for 15 min. Bleed down CT pressure. Freeze protect 5-1/2" tubing with diesel to 2000'. 50 bbls diesel. Fluid level in well out of sight. Close Master and Swab valves. Tree dry. Cut off CT connecter. Pull CT out of injecter head. Still Phase 2 weather, 40 mph wind, -46 chill. Service injector: grease chains, check rollers, store injector for move. Place cap on lubricator. Close SSV. Remain over well to wait out weather. Phase 2 weather fieldwide, 30MPH wind, BLOWING SNOW, -50 CHILL. Cannot lower wind walls until wind is below 20MPH. Phase 1 on Spine Rd., Phase 2 on pads, 25M PH wind, -38 CHILL. Visibility Clearing. KCI Leak reported from cuttings tank (green tank) on driller's side. Secondary containment also leaked due to holes in , herculite underneath tank. Contact BP environmental, report spil. Contact Herb Williams, drilling HSE. Order vac trucks to empty cuttings tank, in the meantime contain discharge, Printed: 1/27/2003 9:53:33 AM ) ') BP EXPLORATION Operations. Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-1 7 14-1 7 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From- To Hours Task Code NPT Phase 1/20/2003 12:15 - 16:30 4.25 RIGD N SFAL COMP 16:30 - 18:30 2.00 RIGD N WAIT COMP 18:30 - 18:45 0.25 RIGD N WAIT COMP 18:45 - 00:00 5.25 RIGD N WAIT COMP Page 10 of 10 Start: 1/11/2003 Rig Release: 1/20/2003 Rig Number: Spud Date: 4/24/1982 End: 1/20/2003 Descri ptionof Oþerations contained on pad. Traction Rpt#: 2003-IR-417467 Sent tank to Peak for inspection and repair. Continue RD, prep outside of rig for move, clean pits, empty tiger tank. Weather has cleared up nicely, 8-1 OMPH Wind, -12CHILL. Phase 1 on spine, still Phase 2 on pads. SAFETY MEETING. Review procedure, hazards and mitigation to pull rig off well. Continue WOW. Pull rig forward from well. Unable to move rig due to major snow drifts on both pads and all snow removal equipment in field busy with priority snow removal. Rig on WOW standby until pads cleared. Derrick down and rig ready to move. RELEASED RIG AT 2359 HRS, 01/20/2003. TOTAL OF 8 DAYS, 0 HOURS FROM RIG ACCEPT TO RIG RELEASE ON DS14-17A. Printed: 1/27/2003 9:53:33 AM ) ) Ó?03-00! 20-Feb-03 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 14-17 A Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 10,500.00 I MD Window / Kickoff Survey: 10,588.00' MD (if applicable) Projected Survey: 12,585.82' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED FEB 262003 ArasJœ¡ U¡'I & Gas Cons. Corrmfelln Anchorage Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 14 14-17A '-' Job No. AKMW30004, Surveyed: 17 January, 2003 Survey Report 19 February, 2003 Your Ref: API 500292056201 Surface Coordinates: 5937851.86 N, 674893.28 E (70014' 09.2091" N, 148035' 16.3014" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~" Surface Coordinates relative to Project H Reference: 937851.86 N, 174893.28 E (Grid) Surface Coordinates relative to Structure Reference: 1741.05 S, 701.78 E (True) Kelly Bushing: 71.00ft above Mean Sea Level Elevation relative to Project V Reference: 71.00ft Elevation relative to Structure Reference: 71.00ft sr..... ·....,y-5U1! D'R n:':'L~rl'fG-s-E?'R'\tft;E:$ A Halliburton Company Survey Ref: svy11444 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 - 14-17A Your Ref: API 500292056201 Job No. AKMW30004, Surveyed: 17 January, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10500.00 35.020 217.950 8749.93 8820.93 4096.19 S 2344.94 W 5933702.38 N 672643.98 E 4692.21 Tie On Point MWD Magnetic 10588.00 36.560 219.790 8821.31 8892.31 4136.25 S 2377.24 W 5933661.59 N 672612.61 E 2.135 4743.60 Window Point 10616.60 41 .230 219.560 8843.57 8914.57 4150.07 S 2388.70 W 5933647.51 N 672601.47 E 16.336 4761.52 10648.52 47.840 219.380 8866.31 8937.31 4167.34 S 2402.92 W 5933629.91 N 672587.66 E 20.712 4783.85 10679.67 55.330 219.210 8885.65 8956.65 4186.22 S 2418.37 W 5933610.68 N 672572.65 E 24.049 4808.20 ~ 10707.90 62.460 219.090 8900.22 8971.22 4204.95 S 2433.62 W 5933591.60 N 672557.84 E 25.259 4832.32 10740.95 70.560 218.960 8913.39 8984.39 4228.48 S 2452.69 W 5933567.63 N 672539.33 E 24.511 4862.56 10764.88 76.690 218.880 8920.13 8991 .13 4246.33 S 2467.10 W 5933549.45 N 672525.33 E 25.618 4885.48 10794.95 81.150 216.840 8925.91 8996.91 4269.63 S 2485.21 W 5933525.74 N 672507.77 E 16.257 4914.97 10824.75 82.470 211.380 8930.16 9001.16 4294.04 S 2501.74 W 5933500.95 N 672491.81 E 18.668 4944.43 10860.00 84.140 208.560 8934.27 9005.27 4324.36 S 2519.22 W 5933470.23 N 672475.03 E 9.250 4979.25 10899.67 81.320 203.450 8939.29 9010.29 4359.71 S 2536.47 W 5933434.49 N 672458.60 E 14.621 5017.98 10929.89 80.530 200.630 8944.06 9015.06 4387.37 S 2547.67 W 5933406.58 N 672448.05 E 9.578 5046.94 10966.42 79.650 198.510 8950.34 9021.34 4421.27 S 2559.72 W 5933372.41 N 672436.79 E 6.204 5081 .45 10997.42 80.090 192.350 8955.80 9026.80 4450.68 S 2567.84 W 5933342.83 N 672429.36 E 19.612 5110.01 11027.50 80.090 187.760 8960.98 9031.98 4479.84 S 2573.01 W 5933313.55 N 672424.86 E 15.032 5136.65 11056.84 80.260 186.180 8965.99 9036.99 4508.54 S 2576.52 W 5933284.78 N 672422.02 E 5.338 5161.92 11095.37 81.940 190.230 8971.95 9042.95 4546.20 S 2581.95 W 5933247.00 N 672417.46 E 11 .263 5195.59 11129.50 82.470 193.230 8976.58 9047.58 4579.31 S 2588.83 W 5933213.74 N 672411.36 E 8.846 5226.41 11160.02 83.440 195.520 8980.32 9051.32 4608.65 S 2596.35 W 5933184.24 N 672404.52 E 8.096 5254.57 11195.75 84.140 196.930 8984.19 9055.19 4642.75 S 2606.27 W 5933149.91 N 672395.39 E 4.385 5287.99 11222.47 85.640 199.750 8986.57 9057.57 4668.01 S 2614.65 W 5933124.46 N 672387.60 E 11.917 5313.35 ~ 11280.64 88.280 199.570 8989.65 9060.65 4722.71 S 2634.19W 5933069.33 N 672369.34 E 4.549 5369.09 11320.95 88.110 204.150 8990.93 9061.93 4760.09 S 2649.18 W 5933031.61 N 672355.21 E 11 .364 5408.15 11348.17 86.780 205.390 8992.14 9063.14 4784.78 S 2660.58 W 5933006.66 N 672344.39 E 6.677 5434.82 11389.04 87.140 209.610 8994.31 9065.31 4820.97 S 2679.42 W 5932970.04 N 672326.40 E 10.348 5475.17 11419.17 89.520 211.020 8995.19 9066.19 4846.97 S 2694.62 W 5932943.70 N 672311.80 E 9.180 5505.14 11454.72 90.220 215.080 8995.27 9066.27 4876.76 S 2714.00 W 5932913.46 N 672293.12 E 11.589 5540.63 11481.59 90.220 216.490 8995.16 9066.16 4898.56 S 2729.71 W 5932891.31 N 672277.91 E 5.247 5567.50 11515.20 90.310 222.830 8995.01 9066.01 4924.42 S 2751.15W 5932864.96 N 672257.08 E 18.865 5601.03 19 February, 2003 - 16:40 Page 2 of4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA OS 14 - 14-17A Your Ref: API 500292056201 Job No. AKMW30004, Surveyed: 17 January, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11559.29 90.480 220.720 8994.70 9065.70 4957.30 S 2780.52 W 5932831.41 N 672228.48 E 4.801 5644.89 11595.82 90.130 225.470 8994.51 9065.51 4983.96 S 2805.47 W 5932804.17 N 672204.15 E 13.038 5681.13 11627.20 91.810 228.820 8993.98 9064.98 5005.30 S 2828.47 W 5932782.31 N 672181.66 E 11.941 5711.91 11657.97 96.210 230.580 8991.83 9062.83 5025.15 S 2851.87 W 5932761.92 N 672158.72 E 15.395 5741.72 11689.97 95.510 232.700 8988.56 9059.56 5044.90 S 2876.83 W 5932741 .59 N 672134.23 E 6.944 5772.37 11731.29 93.390 236.400 8985.35 9056.35 5068.79 S 2910.38 W 5932716.93 N 672101.24 E 10.296 5811.42 ~ 11765.64 91.540 234.640 8983.87 9054.87 5088.22 S 2938.67 W 5932696.86 N 672073.41 E 7.430 5843.76 11797.14 89.960 227.760 8983.46 9054.46 5107.94 S 2963.20 W 5932676.57 N 672049.34 E 22.407 5874.14 11840.02 91.010 223.180 8983.10 9054.10 5138.00 S 2993.76 W 5932645.81 N 672019.49 E 10.958 5916.42 11887.07 91.190 218.600 8982.19 9053.19 5173.55 S 3024.55 W 5932609.55 N 671989.54 E 9.740 5963.28 11922.20 93.300 215.610 8980.82 9051.82 5201.54 S 3045.72 W 5932581.08 N 671969.02 E 10.411 5998.37 11956.22 93.220 209.790 8978.88 9049.88 5230.11 S 3064.06 W 5932552.09 N 671951.34 E 17.081 6032.26 11986.79 93.570 208.560 8977.07 9048.07 5256.76 S 3078.94 W 5932525.11 N 671937.09 E 4.176 6062.56 12025.09 93.390 207.850 8974.75 9045.75 5290.45 S 3097.01 W 5932491.01 N 671919.81 E 1.909 6100.44 12066.04 92.860 210.670 8972.51 9043.51 5326.12 S 3116.99 W 5932454.88 N 671900.66 E 6.997 6141.04 12098.00 92.420 214.550 8971.04 9042.04 5353.00 S 3134.19W 5932427.61 N 671884.08 E 12.205 6172.90 12133.57 94.010 218.950 8969.05 9040.05 5381.45 S 3155.43 W 5932398.67 N 671863.51 E 13.134 6208.40 12167.09 94.540 220.360 8966.55 9037.55 5407.19 S 3176.76 W 5932372.45 N 671842.78 E 4.483 6241.76 12201.92 92.250 223.180 8964.48 9035.48 5433.11 S 3199.92 W 5932345.99 N 671820.23 E 10.418 6276.35 12238.27 92.420 224.060 8963.00 9034.00 5459.41 S 3224.98 W 5932319.13 N 671795.79 E 2.464 6312.35 12271.29 92.420 228.650 8961.61 9032.61 5482.17 S 3248.84 W 5932295.81 N 671772.46 E 13.888 6344.79 12301.00 91.810 231.290 8960.51 9031.51 5501.26 S 3271 .58 W 5932276.20 N 671750.17 E 9.114 6373.60 12330.95 91.190 233.400 8959.73 9030.73 5519.55 S 3295.28 W 5932257.36 N 671726.90 E 7.341 6402.33 .~ 12365.02 91.190 237.460 8959.02 9030.02 5538.88 S 3323.32 W 5932237.40 N 671699.32 E 11.914 6434.44 12396.95 90.660 240.800 8958.50 9029.50 5555.25 S 3350.72 W 5932220.39 N 671672.30 E 10.590 6463.80 12453.70 89.520 243.620 8958.41 9029.41 5581.71 S 3400.92 W 5932192.77 N 671622.73 E 5.360 6514.71 12482.45 90.130 247.680 8958.50 9029.50 5593.56 S 3427.11 W 5932180.32 N 671596.83 E 14.280 6539.69 12514.27 90.750 251.380 8958.26 9029.26 5604.69 S 3456.91 W 5932168.50 N 671567.29 E 11.790 6566.21 12558.82 91.450 255.780 8957.40 9028.40 5617.27 S 3499.62 W 5932154.93 N 671524.88 E 9.999 6601.50 12585.00 91.450 255.780 8956.74 9027.74 5623.70 S 3524.99 W 5932147.91 N 671499.67 E 0.000 6621.61 Projected Survey 19 February, 2003 - 16:40 Page 3 of 4 OriJ/Quest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 - 14-17A Your Ref: API 500292056201 Job No. AKMW30004, Surveyed: 17 January, 2003 BPXA North Slope Alaska All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 216.000° (True). Magnetic Declination at Surface is 26.0000(13-Jan-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 12585.00ft., The Bottom Hole Displacement is 6637.14ft., in the Direction of 212.080° (True). ~ Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10500.00 10588.00 12585.00 8820.93 8892.31 9027.74 4096.19 S 4136.25 S 5623.70 S 2344.94 W 2377.24 W 3524.99 W Tie On Point Window Point Projected Survey Survey tool program for 14-17A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) '-' 0.00 10500.00 0.00 8820.93 10500.00 12585.00 8820.93 BP High Accuracy Gyro(14-17) 9027.74 MWD Magnetic(14-17A) 19 February, 2003 - 16:40 Page 4 of 4 DríllQuest 3.03.02.004 lds ~- II' ) WELL LOG TRANSMITTAL ) ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7m Street Suite # 700 Anchorage, Alaska 99501 d08~DO I (0l ~ RE: Distribution - Final Print(s) 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: Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration [Alaska), Inc. Petrotechnical Data Center lR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WEll DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR/ SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR COLOR Open Hole 1 Res. Eva!. CH 1 1 1 OS 14-17 Ai 1-19-03 Mech. CH 1 Caliper Survey c~~ RECEIVED Jigned : Date: JAN Z ( 2003 AJaeke on & Gas Cons. CoOll1lielion AndKr1ge )rint Name: PRoAcTivE DiAGNOSTic SERvicES, INC., } 10 K STREET SuiTE 200, ANChoRAGE, AK 99~0 I Phonc:(907) 245-8951 Fa.'X:(907) 245-8952 E-mail: pdsanchorage@memorylog.comWebsite:w\vw.memorylog.com /? :' ,~ i 01/09/2003 10:36 FAX 907 564 5510 ) bp 141 001 ~D ~ - 00 I TO: u) ø~ 1/.'¡3~V'r;:- DATE: ~p~ COMPANY: A-éJ ~ c-C- FAX: FROM: -¡E'"'i:::, $~-~. ~ FAX: PHONE: 5~ V- '-I,6?' t/ MESSAGE: ....... Ulw.:t - J 1~;I.~t¡;"/f~,¡r,· - A/) ~.,"" .(i ~ /) L ~ c:!!~ ~. ~e~_ ìt.€/!"dC r ~..V ~løI. trJ 6-- 1~-17-..,·. 9 M·ch' ~. W-L~..l CQ L ."-<J+ ~t'!t.. f C(·r""1 ~ , P fD 'Z;; ~ ,. 0 0 I · ¡µ($If-" '/'1103. . Number of attachments not including fax cover: / RECEIVED ",¡ ~ c; ~II Z Alaska C~¡ & GiS Corm. Commission A.r.chorage ~. I" t -. II·"· rl...... ~ ~1·IIIUIl..... ~. --- . '1111111 ~ II ,1"-"1 !~II . .1 II œ ~CÞI ~ ~~ .. .... ~ .f ~.:~ '" L.. ., 1(10600 ~ - '¡ .. - " J f ). - ~_. ---. ~ ¡- .~,: - .~-_.. 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" · · · · -~ . ..- -:~....... 5 . .L... ,. ~ ~ ~ ~ · - "- (.-' . .. · · . '- .---- , ( ~ t -. ~ - ) ,I ì ,,-' · (. -..----:---\".. , . ~ ,-- .,- . - . <-... ~: II""-- -. ..' S -l"- - I .~ . , \ .~ S ? :>. -.- _"J <. < ~ ,¿ ) bp 01/Q9/2Q03 10:37 FAX 907 564 5510 (J :f' ·~~I[ fE ~! " i!)b.. L (~~: -[ 'I p ~) "-J " !Æ~!Æ~:~!Æ } ", FRANK H. MURKOWSKI, GOVERNOR AI~A~KA. OIL AND GAS CONSERVATION COMMISSION 333 W. "JTH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)27~7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Unit 14-17A BP Exploration (Alaska), Inc. Permit No: 203-001 Surface Location: 2481' SNL, 1611' WEL, Sec 09, T10N, R14E, UM Bottomhole Location: 2693' SNL, 4964' WEL, Sec., 16, T10N, R14E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not 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 permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, . Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in. the revocation or suspension of the permit. 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 70 day of January, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section lJJe:j.A- , Ii", I 0 5 1 a. Type of work D Drill 181 Redrill D Re-Entry D 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 2481' SNL, 1611' WEL, SEC. 09, T10N, R14E, UM At top of productive interval 1321' SNL, 3984' WEL, SEC. 16, T10N, R14E, UM At total depth 2693' SNL, 4964' WEL, SEC. 16, T10N, R14E, UM '\ STATE OF ALASKA 1 ALASKA "-IL AND GAS CONSERVATION COMMI,-,oION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well D Exploratory D Stratigraphic Test D Development Oil 181 Service D Development Gas D Single Zone D Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 711 Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028314 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number ,// 14-17A 9. Approximate spud date 01/15/03 ./ Amount $200,000.00 14. Number of acres in property 15. P~osed depth (MD and TVD) 2560 12330' MD / 89531 TVDss 17. Anticipated pres~re {see 20 AAC 25.035 (e) (2)} 98 0 Maximum surface 2300 psig, At total depth (TVD) 8800' I 3360 psig Setting Depth Top Botom Quantitv of Cement Lenath MD TVD MD TVD (include staQe data) 2155' 10175' 8485' 123301 8953' 69 sx Class IG' 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 12. Distance to nearest property line 13. Distance to nearest well /'/" ADL 047475,316' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 105841 MD Maximum Hole Angle 18. Casin~ Program Specifications $Ize Hole Casing WeiQht Grade Couolina 3-3/4" 3-3116" x 2-7/8" 6.2#/6.16# L-80 ST-L 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 11400 feet 9567 feet 1 0769 feet 9039 feet Length Plugs (measured) Bridge Plug with Cement on Top, Tagged at 10769' (01/00) Junk (measured) Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner 80' 2500' 10492 11981 20" 13-3/8" 9-5/8" 375 sx Permafrost II 3000 sx Arcticset III, 400 sx AS I 400 sx Class 'GI, 300 sx PF 'C' 400 sx Class 'G' 80' 2500' 10492' 1 0202' - 11400' 80' 25001 88141 8578' - 9567' 7" Perforation depth: measured Open: 10560' - 105701, 106701 - 107501 Sqzd and I or Below Bridge Plug: 107501 - 112901 true vertical Open: 88701 - 88781, 88591 - 9024' Sqzd and lor Below Bridge Plug: 9024' - 94731 20. Attachments 181 Filing Fee D Property Plat 181 BOP Sketch D Diverter Sketch 181 Drilling Program 181 Drilling Fluid Program D Time vs Depth Plot D Refraction Analysis D Seabed Report 181 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. ~~:~:y ~~i;æ::at th~~nd correà to:::E~~:ineer Date 0-/0 ~ Permit Number API Number Appror:al,Dªte See cover letter ..2.03 - t:=::> ~ / 50- 029-20562-01 f J 7 ¡i) !J for other requirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Required 0 Yes ~ No Hydrogen Sulfide Measures !J Yes 0 No Directional Survey Required 1&1 Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU 8wr<'j,~[tG~~g~yfo !,ScO )Çt. #l LT, C<M-tZ,:;:~~ik\ tD~ V'fí't.{Nd. J Approved By M l. Bill "--Commissioner'¡ ~ the commission Date ,/ 1/0 3 Form 10-401 Rev. 12-01-85 Submit In Triplicate ) ) I BP 14-1,7a CTD Sidetrack Summary of Operations: A CTD through tubing sidetrack is plarTn d for 14-17. The coil sidetrack, 14-17a, will exit the 7" liner in the Shublik formation and will tar9c;:one . 14-17a will be completed as a WAG injector. /' , 14-17 is a WAG injectorthat is out of conformance due to the influence of a nearby conductive fault;rhe sidetrack, 14-17a, will re-position the injection interval to the s/w to improve injection conformance. / The planned completion is a 2 7/8" pre-drilled liner below a cemented 3 3/16" solid liner. The solid liner will be cemented from a point beyond the expected fault in order to provide isolation from the fault. The injection interval will be covered by pre-drilled liner. The cross-over from uncemented to cemented pipe will be at approx. 11,700' (8984ss) but will be adjusted as needed to provide standoff from conductive faults. ~ One fault with 15-20 ft of throw is expected to be crossed in Zone 4. The plannect well path will dip into the HOT as this fault is approached in order to minimize lost circ risk to this fault. ./ Resitivity logging is not planned for this sidetrack but may be run if HOT identification is in doubt. Phase 1: Prep work. Planned for between Jan. 3 to Jan 15, 2003. 1. Pump a Schmoo-B-Gone job to clean the tubing and liner. i 2. Drift and run a caliper log across the liner and tubing to identify extent of any corrosion. 3. Perform an MIT-IA. 4. Use e-line to set a whipstock at 10,584' MD (8818'ss). 5. Use service coil to pump a minimum of 25 bbls cement to squeeze existing perforations. Phase 2: Mill window, Drill and Complete sidetrack: Planned for Jan. 15,2003. Drilling coil will be used to mill the window in the 7" liner then drill and complete the directional hole as per attached plan. Maximum hole angle will be 98'degrees. ,,/ Mud Program: , · Phase 1 &2: Seawater and 8.6 ppg Flo-Pro /' · Phase 3: Mill and drill with Flo-Pro (8.6 - 8.7 ppg) Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: / The production liner will be a 3 3/16" C II x 27/8" ST-L solid and pre-drilled liner from TO to approx. /' 10,175' MD (8485'ss). The X-Q",ánd ementing collar between 3 3/16" x 27/8" will be at approx. 11,700' MD (8984'ss). A minimum 01-"{4 b of 15.8 ppg latex cement will be used for liner cementing. Top of liner cement is planned to be at 0 ,- MD (8627ss). Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. /' · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 98 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. ) ) Logging · An MWO/GR will be run over the entire open hole interval. Hazards . Maximum recorded H2S on OS 14 is 200 ppm on well ~7 on 6/29/02. The closest wells at surface measure 39 ppm (14-44) and 14 ppm (14-39). Lost circulation is a risk at the fault crossing. This risk is mitigated by designing the well to cross the fault in the HOT. If high losses are encountered then the well will be drilled with water from that point to TO. The completion will be designed to provide 200 ft of cement isolation between the fault and the injection interval. . Reservoir Pressure Res. press. is estimated to be =,so psi at 8800'ss ( 7.4 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2300 psi. TREE -= WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD = 14-17 A GRAYGEN3 CALICO F AXELSON 71' ') Proposed CTD Sidetrack 2900' 46 @ 9400' 10562' 8800' SS eft ~ SAFETY NOTES: 2~26' 1-1 5-1/2" CAMBAL-O SSSV NIP,ID = 4.562" 1 13-3/8" CSG, 72#, L-80, 10 = 12.347" 1-1 i ~ ~ 2500' í ì c, I 10~26' 1-1 5-1/2" BAKER LOC SEAL ASSY I Minimum ID = 3.725" @ 10231' 4-1/2" OTIS XN NIPPLE :g ~ 10129' 1-1 9-5/8" X 5-1/2" BKR PERM PKR I 5-1/2" TBG-IPC, 17#, L-80, 0.0232 bpf, 10 = 4.892" 1-1 10149' ~ 1 ~ 10149' 1-1 5-1/2" x 4-1/2" XO I TOPOF 4-1/2" TBG-IPC 1-1 10149' 8 I 10175' 1-1 Top of 3-3/16" Liner 1 TOP OF 7" LNR 1-1 10202' 1 l 10185' 1-13.5" XN Nipple II II I I 1 10231' 1-1 4-1/2" OTIS XN NIP, 10 = 3.725" 1 4-1/2" TBG-IPC, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1-1 10243' I ;I \. 9-5/8" CSG, 47#, L-BO, ID = 8.681" H 10492' ; iY;;:, ~ ,')'·'.:'·,'1; ',:~.'¡:.,:.:..,: :¡,'I,.':.'.'.',.'.". '!::,,:,.:;,?/,::I:'; , ",:i:",i:'; ·',·::',',;i: I ~ :, ':: ~ ¡": ':,; :' ¡i',>:' :.:.!,'.,..,!I..·...;,·,:,.:,:.f,...:,..:"..:.I,',..:..:.I..:.:,:.:: ',.";,,,1[::,,: . ~ ;,'I",':'¡'I PERFORA TION SUMMARY REF LOG: BHCS ON 05/10/82 ANGLEATTOPPERF: 36 @ 10560' Note: Refer to Production DB for historical perf data SIZE I SPF I INTERVAL IOpn/Sqz DATE '¡:I'ii ~~'i!;[t.0>.~':I'.::i.:.:.I.'~.i.'..,...,..,....... :·,~~··".,;..:...'.":.>I 1,,;,',,1 ",:,:,,;:,:':,;."':,:,:;,;,::,,1 j 'i \1\ SEE PAGE 2 FOR PERFORATION DATA I TOP OF 4-1/2" TBG-IPC 1-1 10838' 1 14-1/2" TBG-IPC, 12.6#, N-80, 0.0152 bpf. ID = 3.958" 1-1 10849' 1 1 PBTD 1-1 11358" I ~I ~-1 11400' ~ 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 1-1 11400' 1 DA TE REV BY COMMENTS OS/23/82 ORIGINAL COMPLETION 05/07/90 LAST WORKOVER 12/26/00 SIS-QAA CONVERTED TO CANVAS 02/20/01 SIS-MD FINAL 01/03/02 RN/TP CORRECTIONS DA TE REV BY COMMENTS 10242' 1-1 4-1/2" BKR SHEA ROUT SUB WLEG 10243' 10234' 4-1/2" TUBING TAIL 1 ELMD TT LOGGED 05/16/91 10350' 1-1 Top of Cement 11700' 1-1 Bottom of Bonzai Cement 1 I 11750'1-13-3/16 x 2-7/8 X-over '\ Il ,'..¡ o 0 o 0 o 0 2-7/8" pre-drilled liner 1-1 12350' 1 10584' 1-1 Mechanical Whipstock I I 10838' 1- 7" X 4-1/2" BAKER FB-1IS0 PKR W/BP SET IN ISO PKR W/1 0' CMf ON TOP 10848' 1-1 TOP OF BRIDGE PLUG 10849' 1-1 4-1/2" TUBING TAIL I PRUDHOE BAY UNIT WELL: 14-17 ÆRMIT No: 1810210 API No: 50-029-20562-00 SEC 9 T10N R14E4282.68 FB... 1682.64 FNL BP Exploration (Alaska) WELLPATH DETAILS PI..., 14-17" 10028205120' 14-'7 10500.00 - ~~~--~~-.ii. ------- o bp BfILs -~--~------~ ----- BP Amoco LEGEND 14-17 (14-17) PJan#3 14-17A Plan #3 T ^M A B Azimuths to True North Magnetic North; 26.03° Magnetic Field Strength: 57539nT Dip Angle: 80.79° Date: 12/12/2002 Model: BGGM2002 Plan: Plan #3 (14-17IPlan#314-17A) Created By: Bnj Potnis Date: 12/12/2002 ---- Contact Information: ß;...·· Direct: (907) 267-6613 E-mail: brij.potnis@inteqcom Baker Hughes INTEQ: (907) 267-6600 P.....t W.llpaÜlI Tie oa MD: 1It111 Ref. D.t.m: V.sectlo. ....... 2".00' h~TEQ- L-__~_ " H : 17 4II2AI11.Z 00:00 ~t'1~ ~~= ::::;to 8450 ---- -------. ~ 0.00 0.00 -41OD-::--- -~-~ --~-~----- REFERENCE INFORMATION -- ------- --- ---------- Co-~:~~~ ~¡ ~:¡::~~: ~y~ec;;n~:~~~ [~I North Sectjon (VS) Reference: 5101 - 17 (O.OON.O.OOE) Measured Depth Reference: 36: 17 4/2411982 00:00 71.00 CalculaUon Method: Minimum Curvature -4200-:-- " ~ ----=-- ----~------ ------------ -------- -43~~---,---------~ DLe. Target 1 10&00.00 ~5.02 217.85 .U8.eJ -40M.11 -23......SÞS 0.00 0.00 4Ø2.2' 2 1 osa.4. 00 ~.4SÞ 218.71 ..1..10 ..,UN.4' ·237'6.73 2.14 J.5.'8 474'.23 3 10604.00 ..... 211.21 aaJ18 -4141.71 ·:nu.45 ~oo 4751.35 . 10712.41 ".00 212A2 "1"'7 ......... -2......'" >50.00 ....... 5 1OM7.41 .2.10 181.28 .......11 -4411.'1' ·25_37 00 -ea.00 5081.17 e 11222.41 ".00 22....20 .,75.21 -46SJ'.5J ·:HS4.10 12.00 &.5.00 8321:..oe 7 11.447.41 .I.U 11'7..31 11064. .. ..u4I.11 ·2711I&.10 12.00 "'1.$0 ..40'" . 117J2.41 ".07 231.17 iffi~ ........ ·2127.08 12.00 ...00 5&30.57 D l1U7.41 87.51 210.54 aSleo..... 4000.7. 12.00 ..eo.OO ........ 1011M2.41 oo. to 208.7. -Use.17 -3071.28 12..00 .-112..00 6051.57 11 12UO.OO ".07 ....... ....- .U4tO..8 12.00 10.00 6408.... ANNOTATION' .~. TVD ND AllllotaUo_ j~¡¡~rl .EJ.W S:-",pe ~ä¡¡~g ~ ~OO -508229 -292829 Pert( ------~- 1748.13 '0100.00 '111.10 10.....0 ""'" 10&6&.00 "".17 10772A' ,_.10 1OU?A1 117'''' ft222..1 IIW.U "..7A' IIn.n 1nUA1 "".10 l1M?A' .H.... ft.UA' IIn.n 12.,0..0 1712.00 10511... 1101.00 10172.70 ii ::m:m~::;~ TIP KOP 1 2 3 .. . . ~ TO noR T1INU TSAIII TZU _ MHOT ---- ~~------- ----~-~~- -----~~-- ---~-- -~- 8400 -.---~------------ ----~ ~--- ~----------- -----~--'-- 8500 -5500~-'---- -- _8550 I: ~ 8600 , !!.8650 . .c Ã. 8700 at . a 8750 '5 8800 . i 8850 > at 8900 . 2 ... 8950 ~--- -------------- -- \ \ \\\ -5600 ~-------~ -570~- ~~--~-- -------- ----- ---- - - ------ -------~-----------------~--~- ---~--- -~----~----------~------------- \ \,\ [!iF'- , -- \\,., :J~~f ;:~lil[ " :-í(op \~---~ \,-- -1- , '," ""~ -4100 4000 -3900-3800 -3700 -3600 -3500-3400 -3300 -3200 -3100-3000 -2900 -2800 -2700 -2600 -2500 -2400 -2300 -2200 -2100-2000 -1900 -1800 -1700 -1600 -1500 West(-)/East(+) (100ft/in] ,-,,' ------- ---------- --- --------~~-- -~---~-~---- ------~~-- - -- -------------------------- -~---- -~----~- ~rsFJ:frTZ4B .- ----- --------- -----~ -~---- -~---------~ ---~--- ----~---- Plan#3 14-17A -~--\ }TD ¡ _~___~_J _=--= I -~--=--- - T . Œ, ____ __ -':~-=----~"J- __ __~-- "1 ~ ! , ~__j 14-17A T2.4'_ 14-17A T3.5! ---/-- ---------~ , J ~~HOT~~~17A T2.2 _~ ~_ ____ 14-17A T2.:f ---.------------ - --- -------- -- 9000 -, 14-17A T2.1 '------ ~ - ---------- ---- -- ---------, 9050 - ---------- ~--- - ------- -~ ---- ~--- ~------ ------------ 9100 ---------- ----~ - ------- --~- -------- 9150 :RTI:.<14-1!) " - ---_._~------ -------------------------~._---~--------~ ---- ---- -----.-------------- 4600 4650 4700 4750 4800 4850 4900 4950 5000 5050 5100 5150 5200 5250 5300 5350 5400 5450 5500 5550 5600 5650 5700 5750 5800 5850 5900 5950 6000 6050 6100 6150 6200 6250 6300 6350 6400 6450 6500 Vertical Section at 216.00" (50ft/in] - ----.-- 12/12/2002 1 :12 PM Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level ObP Company: Field: Site: WeU: I Wellpath: I ¡Field: BPAmoco Prudhoe Bay PBDS14 14-17 Plan#3 1~17A ) ) .-: IN'''IRQ BP Baker Hughes INTEQ Planning Report ._-",,,",,~, ,.._.,,~"..,,-,.,.-",..- ""'_'".'"~''''.''',':' ._,~__.,.... ',". ..~._.","'..~"..._..,~',.~._ .,."..__.._.__~~_~,,_.._..~, __. "._._"'''____''"_..,.~._.,----,~. ,"_.'_~'. ..".,.,~_,...'_,"_....._~'-"......~ .,..~"...,_.".,. _.,.,. ''''';"___. .U_' _"_"._.._...".,""'~.. ..".__.,." -,. """_'-"~'""-,.,,. ~,......~.. _. .., .. _ ,"., ", ........ ,_,.,'u....... ." Date: .12/1'2/2002 ... ... TiDle:·····..13.:1.3:20 Page: 1 . Co..or€iinate(NE) Reference: Well: ..14-17¡TrueNør1h Vertical (l'VI» Reference: System:Me~n Sea. Level Section (VS) Reference: Well. (0.00N,0.OOE,216.00Azi) .....~u.~~~!..~~I~_~I~.~~~::~~!:~~~.;::::=-::.~::~i~.i~.~~.~~~ry~~ure . _... :::.:.~~_:=::~:~~c.le Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: PB DS 14 TR-10-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5939577.43 ft Latitude: 70 14 26.346 N 674150.48 ft Longitude: 148 35 36.726 W North Reference: True Grid Convergence: 1.32 deg .."._..... .... _._ .._..,.,...."..". _ _ ..........,...."....._.... . . u..._..,..."._...,,~_ ,... Well: 14-17 Slot Name: 14-17 Well Position: +N/-S -1741.74 ft Northing: 5937852.51 ft Latitude: +E/-W 702.96 ft Easting: 674893.44 ft Longitude: Position Uncertainty: 0.00 ft Wellpath: Plan#314-17A 500292056201 Current Datum: 36 : 17 4/24/1982 00:00 Magnetic Data: 12/12/2002 Field Strength: 57539 nT Vertical Section: Depth From (TV D) ft 0.00 Targets Name Description Dip. Dir. 14-17A Polygon2.1 -Polygon 1 ·Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 14-17A Fault 1 -Polygon 1 -Polygon 2 14-17A T3.5 14-17 A T2.1 14-17A T2.4 14-17A T2.2 14-17A T2.3 Annotation MD TVD ft ft 10500.00 8749.93 TIP 10584.00 8818.10 KOP 10604.00 8833.99 1 10772.41 8918.57 2 10947.41 8946.10 3 17 70 14 9.215 N 148 35 16.296 W Height 71.00 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 14-17 10500.00 ft Mean Sea Level 26.03 deg 80.79 deg Direction +N/-S ft 0.00 216.00 .....,."".'-...".,,-.....,,-..," ""--""'-'---"-"-:,:--'"~''''-''''',''' ......,.~ ~'-.. '-~'''''- "--'...-".,,,.- .... _..'.'.'""-"''"''''''-'-'~'''--' Map < ,Map, <::--- . Lati.tude --.> ~..;... Longitude---> TVD +N/-S +E/-W Northing Easting Deg NUn· . .. Sec Deg Min Scc ft ft ft ft ft .. '."'._ .......~..,".. M..'."·...,.:...._......,..';..h..;.......""...... ." ""............,,.. ~'~'",""_''''~"''''.'_'''''' '.."."..."..,'.._~._~..,,_....~.......,,_w ...,.".__,,,,.. '.' ._".,~, _, _,." , ."....". ".".-,."..,,",~, .., ........' ,-'"~ ,.,...--..".....,......-.....'''."........." .. 0.00 -4275.54 -2733.52 5933515.00 672259.99 70 13 27.161 N 148 36 35.693 W 0.00 -4275.54 -2733.52 5933515.00 672259.99 70 13 27.161 N 148 36 35.693 W 0.00 -4325.74 -2294.54 5933475.00 672699.99 70 13 26.668 N 148 36 22.942 W 0.00 -5032.82 -2646.05 5932760.00 672365.00 70 13 19.713 N 148 36 33.145 W 0.00 -5745.39 -3407.83 5932030.00 671620.00 70 13 12.702 N 148 36 55.260 W 0.00 -5511.38 -3577.46 5932260.00 671445.00 70 13 15.002 N 148 37 0.189 W 0.00 -4714.07 -3018.79 5933070.00 671984.99 70 13 22.846 N 148 36 43.974 W I 0.00 -4346.43 -3127.29 5933435.00 671867.99 70 13 26.462 N 148 36 47.130 W 0.00 -4346.43 -3127.29 5933435.00 671867.99 70 13 26.462 N 148 3647.130 W 0.00 -5110.92 -2642.86 5932682.00 672369.99 70 13 18.945 N 148 36 33.052 W 8953.00 -5515.64 -3307.47 5932262.00 671714.99 70 13 14.962 N 148 36 52.348 W 8965.00 -4572.75 -2513.34 5933223.00 672486.99 70 13 24.238 N 148 36 29.295 W 8965.00 -5259.92 -3076.46 5932523.00 671939.99 70 13 17.478 N 148 36 45.643 W 8985.00 -4884.70 -2778.66 5932905.00 672228.99 70 13 21.169 N 148 36 36.998 W I 8985.00 -5082.29 -2928.29 5932704.00 672083.99 70 13 19.225 N 148 3641.342 W ._..., .0._.. _ ... __. n Company: BP Amoco Field: Prudhoe Bay Site: PB DS 14 Well: 14-17 Wellpath: Plan#314-17A Annotation MD ft 11222.41 11447.41 11732.41 11847.41 11962.41 12330.00 10551.65 10572.70 10680.07 11219.35 ) ) .. 'It~ffEd bp BP Baker Hughes INTEQ Planning Report ,,,.,_"..,.~...,,~ _,"U . '_'__"'" ...."____,...".,,, '" _ _"._ ,. ..__..,~ _.~.. ,_...... ...",_"~.~".,".~,, ,._"._.~_""...._,__.,.~._"__."_ .__w__._,,_o__ ..·~....,",,,_,,_.._".......,_,,.R,,.." .. --" .--.---..-....-..-"",-,--:,,-,. ,,- ..,..--~~.. .-"-..'-'--' ",..". '~'--"~'1 Date:.12/12/2002 ...,. ..... Time: 13:13:20 . Page: 2 Co-ordinate(N.E)~efe~em~e: Well: .14·17, True.North Vertical (TVD) Reference: System: Mean Sea Level Section(VS)Refel'e~ce:.. . Well (0.00N,O.00E,216.00Azi) SurveyÇalculatioo M.ethod: Minimum Curvature Db: OraGle ...._...~.....,,~. ....._....... '_"'.'__.'_. .".......'...'...' ,._,___":..,_,...,."._,~_.._:,_..~"..,,,_...:.,,,:.. .,:.,:."...,.;, ,.0·';4._.......,,;. ..¡:. ...~. .. ..., ~".._...,_".. '._., ~~h.,._"...,.....'. ..,. ._~ M"~._·w", ..._._ .._."_.,,. ._. ft 8975.21 8984.14 8983.83 8975.60 8965.85 8953.13 8792.00 8809.00 8885.00 8975.00 4 5 6 7 8 TD TSGR TSHU TSAD / TZ4B MHOT MOWC Plan: Plan #3 Lower DLS & new TD target. Principal: Yes Date Composed: Version: Tied-to: 12/12/2002 4 From: Definitive Path Plan Section Information I MD I ft 110500.00 10584.00 10604.00 10772.41 10947.41 11222.41 11447.41 11732.41 11847.41 11962.41 12330.00 Survey MD ft 10500.00 10525.00 10550.00 10551.65 10572.70 10575.00 10584.00 10600.00 10604.00 10625.00 10650.00 10675.00 10680.07 10700.00 10725.00 10750.00 10772.41 10775.00 10800.00 10825.00 10850.00 10875.00 10900.00 10925.00 . ""., _...h..._"....~..,.._._"..... ... . _.. ,_.~.~.,,_,.... ,. .,........h..~_~_.,.. ,'"'' "'~"'''_''''''.'''.''~'.'_''_''_~''~'~''''"'~' ~~. ..._,.......,..'..'....,.~...,,.._.., _,,'... ,.__.,,_ _.",~... '. '. . .... ."' '" ..... _.",~,,,..,,,..,,...~,, "'.,," ".-.~._.. [nel Azim TVD +N/-S +E/.W DLS..·. .·Build. . Tl1rn TFO···. Target deg deg ft ft ; ft deg/10Oftdeg/100ftdeg/10Pft deg, . .....,....."," ....... ,:.__.~,_.u,.~.... ...._,h,,__-',,_._".,,_,_.~.,_._L.._."~.~.·"'._~ ...._:. .,'_..~.:.._"'."":."~,...._._._ ,'_" .,,_.~. ~.__._.._". ,_...._.__,~_.~..,,_..._L..~.~.._.._., .;." .L,.....~.._"'_..;..~._ ..........".. :." ~,;..;. ..__ ,,_' ..:~".;.:.. ;.".."...",....,'''.....M.''......_ _;"."~,.-..;".:.. ,..,:':'_..". "'"''~'''''''''¡.''''_'h''''':''''''_'.'_''''' 35.02 217.95 8749.93 -4096.19 -2344.95 0.00 0.00 0.00 0.00 36.49 219.71 8818.10 -4134.41 -2375.73 2.14 1.75 2.10 35.69 38.26 219.21 8833.99 -4143.78 -2383.45 9.00 8.87 -2.52 350.00 80.00 212.42 8918.57 -4259.45 -2464.54 25.00 24.78 -4.03 350.00 82.10 191.26 8946.11 -4418.98 -2528.37 12.00 1.20 -12.09 -86.00 86.08 224.20 8975.21 -4657.53 -2654.10 12.00 1.45 11.98 85.00 89.45 197.39 8984.14 -4848.89 -2768.10 12.00 1.50 -11.92 -83.50 90.67 231.57 8983.83 ·5080.35 -2927.06 12.00 0.43 11.99 88.00 97.51 219.54 8971).60 -5160.44 -3008.79 ' 12.00 5.94 -10.46 -60.00 92.19 206.76 8965.85 -5256.17 -3071.25 12.00 -4.62 -11.12 -112.00 91.57 250.89 8953.13 -5492.09 -3340.98 12.00 -0.17 12.01 90.00 ..- -,-..-"..-.'''...,.-.''.......-....... . . .. ..".." '..'., ....,--,.-' .... .~~, . .."'''''.''-''''-. .".-.~....., .". ...- [Del Azim SSTVD N/S E/W MapN M:apE VS DLS TFO Tool deg deg ft ft ft ;ft ft ft deg/100ft deg .".",.." .~..., ,..,.:.... ,.,,_, ~:,........':" ~..__.... ___.~..._~.~~,.~_.._.~_.:........ _,_, ~_,~..:., ..:..~,_.:.~_._..._.._'"_...:.-~.__'_:_L.:....._~_~_..,.....,_ _.."'~ ,__~ ...._...__._ __....__l..., ."'~,_. _~,~_ _"~~" ._....,-----~. .....".__...~.._.,.,-_.~_..--._...- 35.02 217.95 8749.93 -4096.19 -2344.95 5933703.31 672644.27 4692.21 0.00 0.00 TIP 35.45 218.49 8770.35 -4107.52 -2353.87 5933691.77 672635.62 4706.62 2.14 35.69 MWD 35.89 219.01 8790.66 -4118.89 -2363.00 5933680.19 672626.76 4721.19 2.14 35.25 MWD 35.92 219.05 8792.00 -4119.64 -2363.61 5933679.43 672626.16 4722.15 2.14 34.83 TSGR 36.29 219.48 8809.00 -4129.24 -2371.46 5933669.65 672618.54 4734.53 2.14 34.80 TSHU 36.33 219.53 8810.86 -4130.29 -2372.32 5933668.58 672617.70 4735.90 2.14 34.45 MWD 36.49 219.71 8818.10 -4134.41 -2375.73 5933664.38 672614.39 4741.23 2.14 34.41 KOP 37.91 219.30 8830.84 -4141.87 -2381.88 5933656.78 672608.41 4750.88 9.00 350.00 MWD 38.26 219.21 8833.99 -4143.78 -2383.45 5933654.83 672606.89 4753.35 9.00 350.32 1 43.44 217.88 8849.87 -4154.53 -2391.99 5933643.89 672598.60 4767.06 25.00 350.00 MWD 49.62 216.60 8867.06 -4168.97 -2402.96 5933629.20 672587.97 4785.19 25.00 351.00 MWD 55.82 215.54 8882.20 -4185.05 -2414.66 5933612.86 672576.65 4805.08 25.00 351.88 MWD 57.07 215.34 8885.00 -4188.49 -2417.11 5933609.36 672574.28 4809.30 25.00 352.53 TSAD / 62.02 214.62 8895.10 -4202.56 -2426.95 5933595.06 672564.76 4826.47 25.00 352.64 MWD 68.22 213.80 8905.61 -4221.31 -2439_69 5933576.03 672552.46 4849.13 25.00 353.01 MWD 74.43 213.05 8913.61 -4241.07 -2452.73 5933555.97 672539.89 4872.78 25.00 353.35 MWD 80.00 212.42 8918.57 -4259.45 -2464.54 5933537.33 672528.50 4894.59 25.00 353.59 2 80.02 212.10 8919.02 -4261.60 -2465.90 5933535.14 672527.19 4897.13 12.00 274.00 MWD 80.25 209.06 8923.30 -4282.81 -2478.43 5933513.65 672515.16 4921.65 12.00 274.05 MWD 80.50 206.03 8927.49 -4304.66 -2489.83 5933491.55 672504.27 4946.03 12.00 274.57 MWD 80.78 203.01 8931.55 -4327.10 -2500.07 5933468.88 672494.56 4970.20 12.00 275.08 MWD 81.08 199.98 8935.49 -4350.06 -2509.11 5933445.71 672486.05 4994.10 12.00 275.57 MWD 81.41 196.97 8939.30 -4373.50 -2516.94 5933422.10 672478.77 5017.65 12.00 276.05 MWD 81.76 193.95 8942.96 -4397.33 -2523.53 5933398.12 672472.73 5040.81 12.00 276.51 MWD ibp Company: BP Amoco Field: Prudhoe Bay Site: PB 0814 Wen: 14-17·· WenJ?~th: Plan#314-17A Survey MD ft 10947.41 10950.00 10975.00 11000.00 11025.00 11050.00 11075.00 11100.00 11125.00 11150.00 11175.00 11200.00 11219.35 11222.41 11225.00 11250.00 11275.00 11300.00 11325.00 11350.00 11375.00 11400.00 11425.00 11447.41 11450.00 11475.00 11500.00 11525.00 11550.00 11575.00 11600.00 11625.00 11650.00 11675.00 11700.00 11725.00 11732.41 11750.00 11775.00 11800.00 11825.00 11847.41 11850.00 11875.00 11900.00 11925.00 11950.00 11962.41 11975.00 12000.00 12025.00 12050.00 Incl deg 82.10 82.12 82.40 82.69 83.01 83.34 83.70 84.06 84.45 84.85 85.26 85.69 86.03 86.08 86.12 86.46 86.82 87.18 87.56 87.93 88.32 88.71 89.10 89.45 89.46 89.57 89.67 89.78 89.89 90.00 90.11 90.22 90.32 90.43 90.54 90.64 90.67 91.72 93.22 94.71 96.19 97.51 97.39 96.25 95.11 93.95 92.78 92.19 92.19 92.19 92.17 92.16 Azim deg 191.26 191.57 194.59 197.60 200.60 203.61 206.60 209.60 212.59 215.58 218.56 221.54 223.84 224.20 223.89 220.91 217.92 214.94 211.96 208.98 206.01 203.03 200.06 197.39 197.70 200.70 203.70 206.70 209.69 212.69 215.69 218.69 221.69 224.68 227.68 230.68 231.57 229.74 227.14 224.53 221.91 219.54 219.25 216.46 213.67 210.90 208.13 206.76 208.27 211.27 214.27 217.27 ) ') BP Baker Hughes INTEQ Planning Report . -"'.-."":"'.,-".....~..~..,'....,~~-- -......".....'"...,.. __, ...~__..~ ."'~....._..,._~"...,.._w_,,...,. ,"_....._,,,..~."_..._ _._,.'.......,.H.._.n__' _"\_ ',._"_.~":"""'_~_..,.....'..,...---"._.,_._--.-...,__,__~ _"'_""~____':_'.___'I _._. ..... ,iI.......'... .. ~... .__._Þ,,~, _.'. .. ._...~___._._._... INI'EQ ,- ,- ~ ',.-- ,."--'~".'"~_.--:.__.._-~' .T-;7':~"r-,-,-'-'-_~__' '--..'.-"'!...., I)at~: ·141~2/20P2¡ ......'.... ..·.·...·Tlrne: .... ···13:13:20 ç()-ønl~nate(NE)l,teference: Well: 14.;17; True North ,y ertical{T~Q) R~fe~nce: 8yst~m:', Mean, 8~a L~vel Section{VS) Reference:\ivell (0.OON,'O.00E,216.00Azi) _. ~u~e~~ak.~.I!.t_i~_n_~~~~~':.,__._,.~~~i.':l1u~.~_~_~~ture __ _, _I?~.:.,.~~~cl~. _. SSTVD ft ".., .,.....,.,,,...-->-.,,...-~,_......... 8946.11 8946.46 8949.83 8953.07 8956.18 8959.15 8961.98 8964.64 8967.15 8969.48 8971.63 8973.60 8975.00 8975.21 8975.39 8977.00 8978.47 8979.78 8980.92 8981.91 8982.73 8983.37 8983.85 8984.14 8984.16 8984.37 8984.54 8984.66 8984.73 8984.75 8984.73 8984.66 8984.54 8984.38 8984.17 8983.91 8983.83 8983.46 8982.38 8980.65 8978.28 8975.60 8975.27 8972.30 8969.82 8967.85 8966.39 8965.85 8965.37 8964.41 8963.46 8962.52 ~ - - ..- . - - --. - .~, - .. ,Page: '3 . . 'rÙs -.. ,. n', E/W --" "M~·pN· -- --- - -- "'-i\ï;pE" -. -'··'---:·.'·VS"·.'·--..-..·-'fiCS'·----.-tF<i'·-..··.··-i~ói---'" ft ft ft ft ft'" deg/100ftde~>. .. . .,-..~,~......"',.~,.~,.~, ~ . "'."-""".'" .".......__... .... ......... .. ,..."..,:", ,:.!", ,.;..."..:.~.".',_,~"...~.,~'.... ...:'...._, ,:..;..~,~'~:.'.~,.~.:..,L~".i.:~~:~:....,:,.2~~.:~'L~~..:.."~~ ....;.,.,,,:.,,;.I.~~.::.I.¡; '" ~;..,..._ .'.... _._' "." . .._ .'. "....,'.. ..~.I.._, '." .... .........".", '. ,I~¡, ...~.~_,_~....,~.".,-"-_.,.~, :..~:_,,_~.,.:.:," "... -4418.98 -2528.37 5933376.36 672468.39 5061.17 12.00 276.95 3 -4421.50 -4445.62 -4469.44 -4492.87 -4515.87 -4538.36 -4560.29 -4581.58 -4602.20 -4622.07 -4641.14 -4655.33 -4657.53 -4659.38 -4677.80 -4697.08 -4717.16 -4738.00 -4759.53 -4781.69 -4804.42 -4827.67 -4848.89 -4851.36 -4874.96 -4898.11 -4920.73 -4942.76 -4964.14 -4984.82 -5004.73 -5023.83 -5042.06 -5059.36 -5075.70 -5080.35 -5091.50 -5108.07 -5125.44 -5143.58 -5160.44 -5162.42 -5182.02 -5202.38 -5223.45 -5245.16 -5256.17 -5267.32 -5289.01 -5310.01 -5330.28 -2528.88 -2534.49 -2541.36 -2549.47 -2558.81 -2569.35 -2581.06 -2593.91 -2607.85 -2622.86 -2638.90 -2651.98 -2654.10 -2655.90 -2672.72 -2688.57 -2703.39 -2717.16 -2729.82 -2741.36 5933373.84 5933349.59 5933325.63 5933302.01 5933278.80 5933256.08 5933233.89 5933212.30 5933191.37 5933171.16 5933151.71 5933137.23 5933134.99 5933133.09 5933114.28 5933094.65 5933074.22 5933053.08 5933031.26 5933008.84 -2751.73' 5932985.87 -2760.9~ 5932962.42 -2768;10 '5932941104 -2768.88 5932938.56 -2777.10 5932914.77 -2786.54 -2797.18 -2808.99 -2821.94 -2835.99 -2851.10 -2867.23 -2884.33 -2902.37 -2921.29 -2927.06 -2940.65 -2959.34 -2977.23 -2994.27 -3008.79 -3010.41 -3025.64 -3039.93 -3053.24 -3065.53 -3071.25 -3077.06 -3089.46 -3102.98 -3117.58 5932891.41 5932868.55 5932846.26 5932824.58 5932803.58 5932783.33 5932763.86 5932745.24 5932727.53 5932710.75 5932705.97 5932694.51 5932677.52 5932659.73 5932641.21 5932624.01 5932621.99 5932602.05 5932581.37 5932560.00 5932538.00 5932526.87 5932515.58 5932493.62 5932472.31 5932451.71 672467.95 672462.90 672456.59 672449.02 672440.21 672430.20 672419.00 672406.66 672393.19 672378.65 672363.06 672350.31 672348.24 672346.49 672330.10 672314.71 672300.35 672287.08 672274.91 672263.90 672254.06 672245.42 672238~ r2 672238.00 672230.33 672221.43 672211.31 672200.02 672187.57 672174.01 672159.37 672143.68 672127.01 672109.38 672090.85 672085.19 672071.85 672053.55 672036.08 672019.46 672005.34 672003.76 671988.99 671975.18 671962.36 671950.58 671945.12 671939.57 671927.67 671914.64 671900.52 5063.51 5086.32 5109.62 5133.36 5157.45 5181.84 5206.46 5231.24 5256.11 5281.01 5305.87 5325.03 5328.06 5330.62 5355.41 5380.32 5405.28 5430.22 5455.09 5479.80 5504.28 5528.49 5549.88 5552.34 5576.27 5600.54 5625.10 5649.86 5674.77 5699.75 5724.75 5749.68 5774.48 5799.08 5823.42 5830.57 5847.58 5871.97 5896.54 5921.23 5943.40 5945.96 5970.77 5995.64 6020.51 6045.30 6057.57 6070.01 6094.84 6119.78 6144.76 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 85.00 MWD 84.96 MWD 84.55 MWD 84.16 MWD 83.79 MWD 83.43 MWD 83.09 MWD 82.77 MWD 82.47 MWD 82.19 MWD 81.94 MWD 81.70 MHOT 81.54 4 276.50 MWD 276.52 MWD 276.71 MWD 276.89 MWD 277.04 MWD 277.18 MWD 277.30 MWD 277.40 MWD 277.47 MWD 277.53 5 88.00 MWD 88.00 MWD' . 87.97 MWD 87.95 MWD 87.94 MWD 87.93 MWD 87.93 MWD 87.93 MWD 87.94 MWD 87.95 MWD 87.97 MWD 88.00 MWD 88.03 6 300.00 MWD 299.96 MWD 299.85 MWD 299.67 MWD 299.42 7 248.00 MWD 247.96 MWD 247.63 MWD 247.35 MWD 247.14 MWD 246.97 8 90.00 MWD 90.06 MWD 90.17 MWD 90.29 MWD ) bp BP Baker Hughes INTEQ Planning Report ~) c - -- -" . ,- .._- -,. ~-_._---_., I N111.Q . ".".., _"_...M."_"·._,_...... __.. _.·..·...,.'_.._.".........___._."..w_'.....M' ".'. '.". '"'.,.....,._....__._ """."".0'.'.. ~._.,_.__._"_._",,. ._".~_..___..._..__..__._...____.,,"...,.._....._ "__"'_'~_'__' ....__ .._."' ,...... ,...~'~.._..,,~._., _._,....,,_....u....~.__,..._."_n:"_"._.._.._"..~.._._._"'.. ,,_ D~te: ... ..·12/12/2002 Time: ··13:13:20. . ... .. :P~ge: 4 Co~r(Unate(NE) Reference: Well: 14-17, True.North V ~rt~ça~>(TVD) Reference: ¡ Syst~rt1:Mean Se~ Level . ,Se~tiol1 (VS) Reference: Well(b .qON, O. dOE,?16.00Azi) . ... ........c. .___._._.~..;~_.:..~~~!]'.~~.~~.I¡~~.I~~~~.~~!~~~.:_L.,..}~~~!.~~~:(?~~~.~~_~~.._... ..._.. :J~~E::2.r-~PJ.~:..._...~,.~ Com pany: BP Amoco Field: Prudhoe Bay Site: PB OS 14 Well: 14-17 Wellpath: Plan#3 14~17A Survey MD loci Azim SSTVD ft deg deg ft .. 12075.00 92.13 220.28 8961.58 12100.00 92.10 223.28 8960.66 12125.00 92.07 226.28 8959.75 12150.00 92.03 229.28 8958.85 12175.00 91.98 232.28 8957.98 12200.00 91.93 235.28 8957.13 12225.00 91.87 238.29 8956.30 12250.00 91.81 241.29 8955.50 12275.00 91.74 244.29 8954.73 12300.00 91.67 247.29 8953.98 12325.00 91.59 250.29 8953.27 12330.00 91.57 250.89 8953.13 _. hn _ .,_ . ."... _ .._ . _h.__~ _ _ ."____ "._ ________...__._ ______ ___ . __..__ __ ~.___ ,. .___ _..._.__ _. _____ __ ____ ___ __. .._ N/S E/W ft ft u_. ,___ .._. - .. ~.- .-.. -- -5349.75 -3133.23 -5368.38 -3149.87 -5386.11 -3167.47 -5402.90 -3185.97 -5418.69 -3205.32 -5433.46 -3225.48 -5447.14 -3246.38 -5459.71 -3267.97 -5471.14 -3290.19 -5481.39 -3312.98 -5490.43 -3336.27 -5492.09 -3340.98 !: I MapN ft 5932431.88 ~93241~.87 5932394.74 5932377.53 593236~ .29 5932346.06 5932331.90 5932318.83 5932306.89 5932296.12 5932286.54 5932284.77 MapE vs DLS TFO Tool ft ft deg/100ft _. _d~gc -- - - - -..- -, - --. 671885.33 6169.71 12.00 90.40 MWD 671869.12 6194.56 12.00 90.51 MWD 671851.95 6219.25 12.00 90.62 MWD 671833.84 6243.70 12.00 9~.73 MWD 671814.86 671795.05 671774.48 671753.18 671731.24 671708.69 671685.62 671680.94 - -"" ..._~,. ,.- ,.. -~."~-'- -....-....,-"..... .. 6267.86 6291.65 6315.00 6337.87 6360.17 6381.85 6402.86 6406.98 I' I,': 12.00 90.84 MWD 12.00 90.94 MWD 12.00 91..05 MWD 12.00 91.~5 MWD 12.00 91,.24 MWD 12.00 9t.34 MWD 12.00 91.42 MWD 12.00 91.51 TD .' '. -"..T··--..'·..···..··w..'."-....'-..'''. TOTs /'. Mud Cross TOTs /' BAG 1/2/2003 Flow Tee 2 3/8" combi ram/slips ....................... .., middle of pipe/slips variable bore pipe 3 1/2"·2 7/S" ............... ..........., middle of blind/shears ----" ---' Mud Cross middle of flow cross ~ ~ 2 3/8" combi ram/slips ................... ....... middle of pipes ....................... Blind/Shears middle of slips bttm of bag top of bag s- O) en if All Measurements are from top of Riser ) ') ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us Well 14-17 Type Inj. P.T.D. 1810210 Type test Notes: Pre-CTD MITIA Well Type Inj. P.T.D. Type test Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: Type Inj. Type test Type Inj. Type test Type Inj. Type test BP Exploration (Alaska) Inc. Prudhoe Bay / PBU 114 01/03/03 Jeff Rea s P Packer Depths (ft.) MD/TVD 10,129' 8,519' Test psi 3000 Tubing Casing Pretest 1200 40 Initial 15 Min. 30 Min. Interva 0 3000 3000 3000 P/F P Interva P/F Interva P/F Interva P/F Interva P/F Test Details: Test was conducted to evaluate production casing condition prior to coil tubing sidetrack. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 06/19/02 MD/TVD Tubing Test psi Casing MD/TVD Tubing Test psi Casing MD/TVD Tubing Test psi Casing MD/TVD Tubing Test psi Casing TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test MIT PBU 14-17 01-03-03.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) DATE CHECK NO. p054974 11/18/02 P054974 DATE INVOICE I CREDIT MEMO GROSS VENDOR DISCOUNT NET DESCRIPTION 11/18/02 INV# CKll14020 PERMIT TO DRIL~ FEE RECEIVE') JAN 0 3 2003 !~laska Oil & Gas Cons. Com1\ission Anchorage THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASt(A)ING. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, PAY III 0 5 ~ g ? ~ III I: 0 t. ¡. 2 0 jag 5 I: 0 ¡. 2 ? a g b III H '- --~ ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) "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. HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates 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) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY ß/J ): WELL NAME/..ð~ /y- //r; FIELD & POOL ¡:g<Jð/5d INITCLASS ~/ ./'7 ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. . . . . . . . . . . . . . . . . 4. W ell located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . Ù /' (Service Well Only) 13. Well located wlin area & strata authorized by injection order #-L.l..L (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. ENGINEERING APPR DATE ~~)~ APPR DATE WGA- L I "/t") '5 (Service Well Only) GEOLOGY APPR DATE ðf~ ~A (Exploratory Only) 15. Conductor string provided. . . . . . . . . . . . . . . . . . . 16. Surface casing protects all known USDWs. . . . . . . . . 17. CMT vol adequate to circulate on conductor & surf csg. . . 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 19. CMT will cover all known productive horizons. . . . . . . . . . 20. Casing designs adequate for C, T, B & permafrost. . . . . . . 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. . . 23. Adequate well bore separation proposed.. . . . . . . . . . . . 24. If diverter required, does it meet regulations. .. . . . . . . . 25, Drilling fluid program schematic & equip list adequate. ., . . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 27. BOPE press rating appropriate; testto .1~(?O psig. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . .. . . . . . 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 31. Mechanical condition of wells within AOR verified. . . . . . . . 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . .. ...... 36. Contact name/phone for weekly progress reports. ...... PROGRAM: Exp _ Dev _ Redrll X- Re-Enter _ Serv £.- Wellbore seg _ GEOL AREA r¿; 7' /) UNIT# /J ,c: 5' rl ON/OFF SHORE ~ (y' N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N y' N Ii'~ ~ I~¡ Iii -IQ3 t N /</-.17, /~~ J1/ -¥-N *-N- -¥--N- ¡..IIA- Y N ~~GTDU *,Y N &2. N i¡V/fJr . ~ vY1~ fJ1 W f· 7. ffO¡ . ~~ me; p 2-300 f~t/, . ~~~q PfNl-2--VO r~M' / / v- I 95 - I (J 3. t,D l ~ I q 3 17' -0/0/ A / ,/ J -t i . Il! '2." I - /!r; /7" - 7"0 A ( GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Commentsllnstructioos: RP~ TEM JDH JBR COT DTS 0 ¡ (07 (03 /' MJW MLB o( /o? /ð.3 SFD WGA Rev: 10/15/02 - G:\geology\permits\checklist.doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly gemìane to the Well Permitting Process but is part of the history file. To inlprove the readability of the Well History file and to sim,plify finding information. information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ) ) dOo-{)ð I 1105( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri ApI.' 18 14:50:22 2003 Reel Header Service name...... ...... .L1S~PE Da t e. . . . . . . . . . . . . . . . . . . . . () 3 / () 4 / 18 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................ UNKNOWN Continuation Number......01 Pn,vLous Reel NaJm~....... UNKNOWN Comments. ...... . ..... .... STS LIS\'\1r.iting Library. Scientific Technical Services 'I'ape Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/04/18 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNOWN Continuation Number......01 Previous Tap(~ Name...... . UNKNOWN Comments................ .STS LIS Wr.íting L.ibra.r.y. Scientifi.c 'J'echni.cal Services Physical Eor Comment Record TAPE I-lEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API N1JMBE,R: OP\:;RNI'OR : LOGGING COMPANY: TAPE CREATION DJ-\'I'E: # JOB DATA 14-17Ai 500292056201 SF Exploration (Alaska) Inc. Sperry SlJn 1S-APR-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW3000400000 S. LA'l'Z EGBEJIMBA / MWD RUN 2 MW3000400000 B . LTAHN EGBE,TIMBl\ / MWD RUN :3 MW3000400000 B. JAI-IN ¡V¡CCARTY / [ÑH # SURFT\.CE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: fEL: fWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 9 lON 14E 2481 1611 71.00 .00 .00 # WELL CASING RECORD 1 ST STIUNG 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 3.750 3.750 3.750 CASING SIZE (nI) 7.000 7.000 7.000 DRILLERS DEPTH (fT) 10584.0 10:)84.0 10584.0 # REtvIARI<S: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE t'!OTED. ....) ALL VERTICAL DEPTHS ARE SUB SEA TRUE VERTICAL DEPTHS :: SST\'D) . · . ) ) 3. M1im RUNS 1-3 ARE DIRECTIONAL WITH SOLAR (13M) GAJVI~1f\ RAY UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 1 - 3 REPRESENT WELL l4-l7AI WITH API #50-029-20562-01. TI-nS WELL REACHED A TO'I'.AL DEPTH (TO) OF 12,585 MD, 8 957 ']'VD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAJVIMA RAY COMBINED. $ Fi leI-leader Service nam£.............8T8LI8.001 Service Sub Level Name... Ver"sion Numt,er.......... .1.0.0 Date of Generation.... ...03/04/18 Maximum Physical Record..65535 Fil e 'rype................ 1,0 Previous File Name.......STSLIB.OOO Comment Record F'I LE HEADER FILE NIJMBER: EDITED I"lE,RC;ED MWD Depth shi £ted DEPTH INCREMENT: #: FILE SUMMARY PBU TOOL CODE GR SRO!? $ 1. and clipped curves; all bit runs merged. .5000 START DEPTH 10,571.0 10606.5 STOP DEPTH 12546.5 12:574.5 If. BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (fv1EASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 10571.0 10572 . 5 10583.5 10~:,95.5 10602.0 10603.5 10609.0 10621.5 10624.5 10627.5 10639.0 10641.5 106,19.0 10659.0 10661.5 10668.5 10673.0 10683.0 10694.0 10737.0 lCn49.S 107(5f3.5 10779.0 102,03.5 10805.5 10837.5 10855.0 10899.5 1090:3. :) GR 10573.~) 10575.0 10585.5 10597.5 10604.0 10605.5 10612.0 10624.0 10627.0 10629.5 10642.5 H)(j44.:' 10652.0 10661.0 10663.5 10670.5 10675.0 10685.0 10695.5 10739.5 107~):.O 10768.0 10779.0 10804.:) 10806.5 10839.0 10858.0 10902.5 10911.5 ') ) 12354.5 12360.0 12362.0 12366.5 12446.5 12449.0 1245.1.0 12453.5 12458.0 12461.0 12465.0 12ÇIG.5 12479.0 12483.0 12512.0 12,519.0 12524.5 12574.5 $ 10933.0 10957.5 10959.0 10988.5 10997.5 11003.5 11008.0 11044.0 11090.0 11:L26.5 11388.0 11482.0 11564.0 11574.0 11593.5 11605.5 11615.5 11693.5 11724.0 11766.0 11789.0 11875.0 11887.0 12018.5 12066.0 12101.0 12147.5 1216.1. 5 12189.5 12310.5 12345.5 12360.0 12365.0 12367.5 12372.5 12456.5 12459.0 12462.0 12464.0 12469.0 12472.0 12475.5 12487.0 1:2489.0 12493.5 12522.0 12529.0 12535.0 1.2585.0 10928.0 10955.0 10956.5 10986.5 10995.5 11001.5 11005.0 11041.0 11087.0 111~?4. 0 11386.5 11479.0 11561. 0 11571. 0 11590.5 11602.5 11613.5 11691.5 11722.0 11763.5 11784.5 11872.0 11882.0 12013.0 12060.5 120%.0 12142.5 12157.5 12184.5 12305.5 12339.5 II HE:RGED DATA SOURCE PBU '1'OOL CODE HWD HWD MWD $ BIT' RUN NO 1 2 3 MERGE TOP 10573.5 10784.5 12099.5 HE:RGE BASE 10784.5 12099.5 12585.0 # REHARKS: tv1ERGED HAlN PASS. $ # Data Format Specification Record Data Rccord Type......... ......._.0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point...... ........Undefined Frame Spacing..................... 60 .1IN Hax frames per record... .... ......Undefined ,Ä.bsent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DE E'T FT 1 68 0 1 ) ) ROP MWD GR MWD FT/H API 1. 68 1. 68 4 8 2 -:¡ -, First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT F'I' lOS'll 12574.5 11S72.8 4008 10571 12574.5 ROP MWD FT/H 0.6 1142.04 98.8988 3937 10606.5 12574.5 GR lvIWD API 15.39 436.48 53.9994 3952 10571 12546.5 First Reading For Entire File..........1057l Last Reading For Entire Fi1e...........12574.5 File Trai.ler Service name.............STSLIB.OOl Service Sub Level Name... Version Number.. .........1.0.0 Date of Generation.......03/04/18 Maximum Physical Record..65535 File Type................ LO Next File Name........ ...8TSL1B.002 Physical Eor File HE~ader Service name..... ....... .8T81IB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/04/18 Maximum Physical Record..65535 File 'rype................ Jj) Previous [i'ile Nêlffie....... ¡3'J'S.L,.l8. 001 Comment Record FILE HEADER FILE NUJ:-v1BER: RA.W MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 10573.5 10609.0 STOP DEPTH 10757.0 10784.5 # LOG HEADER DATA DATI:; LO(;;C~I:;D: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MENORY OR REAL-TINE): 'I'D DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERV,z\L (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 14 -,-'AN-03 Insite 4.3 Nemory 10588.0 76~7 1* TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 82758 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 10584.0 ) ') BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RE',SI3TIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPE,RA'I'URE (MT): MUD AT MAX Clf\CULA.TING TEf\MPERATIJf\E: MUD FILTf\ATE AT MT: MU 0 CAKE A.T MT: Flü P1::0 8.60 65.0 9.0 21 000 12.2 .000 .000 .000 .000 .0 138.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWE FEEQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Da ta Spec:i. f:Lcation Block Type..... 0 Logging Direction... '" ..... ... ...Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .lIN Max frames per record... ..........Undefined f\bsent value...................... -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDOlO FT/H 4 1 68 4 2 GE MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam RE,ading RE~ading DEPT FT 10573.5 10784.5 10679 423 10573.5 10784.5 ROP MWD010 FT/H 0.6 99.41 41. 0516 352 10609 10784.5 GR MWD010 API 24.25 436.48 122.599 368 10573.5 10757 first Reading for Entire file..........10573.5 Last Reading For Entire File....... ....10784.5 File Trailer 8(,"rvice name............ .8T8L18.002 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03!04!18 Maximum Physical Record..65535 File T~i1='e............... .LO Next File Name... ..... ...ST3LI8.003 Physical EOF r'ile Header Service name............ .3TSLI8.003 Service Sub Level Name... Version ~JL:mber......... ..1.0.0 Date of Generation.... ...03/04/18 Maximum Physical Record..65535 File Type................LO t'revious !:'ile Name.......S'l'SLl!:L002 ) C0!1Un(2nt Reco.rd FILE HEADER FIl,E NUMBER: RAW ¡V¡WD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: II FILE SUMMARY V8N~)k 100L COOS GR ROP $ 3 ) header data for each bit run in separate files. 2 .5000 S'l'Ak'l' UEI:''l'H 10757.5 10785.5 S'1'OI:' DEP'I'H 12071.~) 12099.5 Ii LOG HEADER DATA DATE LOGGED: SOFTWARE SURfACE SOFT\iifARE VERSION: DOWNHOLE SOF'TWARE VERSION: DATA TYPE (MEMORY OR RE1\L-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM AN G.LE : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ II BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): IJRILLE:.R'S CASING DEP'I'H (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: HUD CHLORIDES (PPM): F'LU.lD LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: II NEUTRON TOOL MATRIX: JvlATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REHARKS: $ II Data Format Specification Record D:1ta Record Type..................O Data Specification Block Type.....O Logging Direction...._____________Down Optical log depth units_..........Feet Data Reference Point.. ...... .... ..Undefined Frame Spacing..................... 60 .1IN tv!ax frame::; per re'~~')rd............ .!)'Y:!'õ:fine,j Absent value..................... .-999 Depth Uni ts. _ _ _ _ . . _ . . . . . . _ _ . . . _ . . . Datum Specification Block sub-type...O 15-JAN-03 Insite 4.3 Mernory 79.7 96.2 TOOL NUMBE.R t327 [)8 3.750 10584.0 Flo Pro 8.60 65.0 9.0 21000 9.6 .000 .000 .000 .000 .0 152.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel ) ) MWD020 MWD020 FT FT/H API 1. 1. 1. 68 68 68 o 4 8 1 DEPT ROP GR ,.., 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT F'I' 10757.5 12099.5 11428.5 26f-35 1075'7.5 12099.5 ROP MWD020 FT/I-! 1..3 1051.. 89 102.402 2629 10785.5 12099.5 GR MWD020 API 20.74 207.26 52.3812 2629 10757.5 12071.5 Fil.-st Reading For Entire Fi.le..........10757.5 Last Reading For Entire File...........12099.5 File Trailer Service name.......... ...8'1'31.,18.003 Service Sub Level Name... Version Number.......... .1..0.0 Date of Generation.......03/04/1.8 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLI8.004 Physical EOE' File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/04/18 Maxirrmm Physical Record..65535 File Type................ 1.,0 J:'revious I:':Lle Name....... S'l'SJ...lLb. 003 Comment Record FILE ¡-!EADER FILE NUfv1BER: RAW MWD Curves and l09 BIT RUN NUMBER: DE PT I-I INCF;ZSJvIE:NT: # FILE SUMMARY VENDOR TOOL CODE GR ROP header data for each bit run in separate files. 3 .5000 START DEPTH 12072.0 12100.0 STOP DEPTH 1255'7.0 12585.0 .$ # LOG HEADER DATA UA'l't: LOC.JGEU: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (F'T): TOP LOG INTERVAL (F'T): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM }\NGLE: MAXI¡V¡UM ANGLE: 17 - ,J AN - 0 3 Insite 4.3 Memory 89.5 94.5 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE Gr-I $ Dual GR TOOL NUMBER 7801.2 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 10584.0 ) ) BOREHOLE CONDI'I'IONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (OEGF) .MUD AT MEASURED TEMPEP.ATURE (1'41'): MUD AT Ml\X CIRCULATING TERM PERATURE : MUD FILTRATE AT I'4T: MUD CAKE AT MT: Flo Prc, 8.60 65.0 9.0 21000 9.6 .000 .000 .000 .000 .0 159.1 .0 .0 # NEUTRON TOOL MATRIX: MA'1'RIX DENSI'ry: HOLE CORRECTION (IN): # '1'OOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: <' -? # Data Format Specification Record Uata H.ecord 'l'ype.................. (1 Data Speci f:i.cat.:ion Block. Type..... 0 Logging Direction......... ...... ..Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .lIN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specificati.on Block sub-type...O Name Service Order Units S.i.ze Nsam Rep Cod.e Offset Channel DEFT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 6~3 8 3 First Last Name Service Unit. Min Max Mean N,sam Reading Reading DEPT FT 12072 12585 12328.5 1027 12072 12585 ROP MWD030 FTIH 7.98 1142.04 110.822 971 12100 12::)85 GR MWD030 API 15.39 192.69 32.3929 971 12072 12557 First Reading For Entire File....... ...12072 Last Reading For Entire File. '" ... ... .12585 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1. 0.0 Date af Generatian.......03/04/18 Maximum Physical Record..65535 File Type............... .LO Next File Name...... ... ..STSLIB.005 Physical EOF Tape Trailer Service name... ....... ...LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 0::', / (I!¡ / 1 c: () 1:.- i í;j iLl... .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. ST S Ta~e Name.......... .... ..UNKNOWN Continuation Number..... .01 Next Tape Name...........UNKNOWN \, ) '\ ) Comments.................STS LIS Writinq Library. Scientific Technical Services Reel 'l'railer Service name.............LISTPE Dat.e.................... .03/04/18 Od.gin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .1JNKNOWN Continuation Number......Ol Next. Reel Name........... UNKNOWN Comments. . . . . . . . . . . . . . . . . S'I'S LIS Writing L.:i..brary. Scientific 'I'echn.ical Services Physical EOF Physical EOF End Of 1,18 File