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198-127
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, November 24, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC R-06A PRUDHOE BAY UNIT R-06A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 11/24/2023 R-06A 50-029-20388-01-00 198-127-0 W SPT 7752 1981270 1938 1315 1310 1300 1291 74 74 74 76 4YRTST P Guy Cook 10/12/2023 Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT R-06A Inspection Date: Tubing OA Packer Depth 501 2151 2115 2105IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC231011124406 BBL Pumped:3.4 BBL Returned:3.4 Friday, November 24, 2023 Page 1 of 1 MEMORANDUM State of Alaska Permit Number: 198-127-0 Alaska Oil and Gas Conservation Commission TO:JimReggI�I1 1` DATE: Thursday, October 17, 2019 P.I. Supervisor ( (. `� R SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. Packer R -06A FROM: Jeff Jones PRUDHOE BAY UNIT R -06A Petroleum Inspector Inj Sre: Inspector Reviewed By: P.I. Supry Tlea— NON-CONFIDENTIA Comm Well Name PRUDHOE BAY UNIT R -06A API Well Number 50-029-20388-01-00 Inspector Name: Jeff Jones Permit Number: 198-127-0 Inspection Date: 10/6/2019 - Insp Num: mi[JJ191009085I44 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min R -06A 'Type Inj w TVD 7752 Tubing 1460 1467 - 1467 - 1470 JWell PTD 1981270 ' Type Test SPT Test psi 1938 - IA 2 2400 2372 2364 - BBL Pumped: 5.3 BBL Returned: 5.2 OA 300 346 , 363 369 , Interval 4YRTST P/F P Notes: I well inspected, no exceptions noted. Mr—t�-T- acre 6(zotq � 1" Gc--Z "Yun�xlY/hG� Thursday, October 17, 2019 Page 1 of 1 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeIISiteEnginee@bp.com> Sent: Sunday, September 1, 2019 8:08 AM To: Wallace, Chris D (CED) Cc: AK, GWO Projects Well Integrity; AK, GWO Well Integrity Well Information Subject: GC2 Injectors overdue for AOGCC MIT -IA Mr. Wallace, Injectors W-207 (PTD # 2030490), W-221 (PTD #2110290), W-220 (PTD #210260), W-223 (PTD #211060), R-06 (PTD #1981270), and W-219 (PTD #2101050) were due for 4 year AOGCC MIT-IAs at the end of August 2019. Due to the GC2 TAR the wells have been shut in and were not tested before the end of the month. GC2 is expected to be back up to full rate by the end of next week so BP is requesting to leave the above mentioned wells in Operable status and track them on the monthly compliance report until they are brought back online and pressure tested. Please advise if this is not acceptable, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 • • STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations El Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: C/,9P 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 198-127 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-20388-01-00 7. Property Designation(Lease Number): ADL 0028278 8. Well Name and Number: PRUDHOE BAY UNIT R-06A 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: r i.�r I V ED Total Depth: measured 12308 feet Plugs measured 11615 feet �, true vertical 8976 feet JunkP R 0 5 017 measured feet Effective Depth: measured 11615 feet Packer measured See Attachment feet true vertical 8964 feet Packer true vertical See Attachment feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 38-118 38-118 Surface 2624 13-3/8"72#L-80 37-2661 37-2661 4930 2670 Intermediate 9705 9-5/8"47#L-80 35-9740 35-8671 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9880-9910 feet feet 11296-11360 feet 11410-11442 feet 11442-11474 feet 11474-11506 feet 12038-12308 feet True vertical depth: 8795-8820 feet feet 8957-8960 feet 8963-8965 feet 8965-8967 feet 8967-8969 feet 8967-8976 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12Sttreated o(ceasur squeeze summary: SCANNED 1 )01, Intervals treated measured: MAYLU Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 5056 100 764 Subsequent to operation: Shut-In 0 700 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development 0 Service RI 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 I3 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: 316-603 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature xiJ24411, c ePhone +1 907 564 4424 Date 4/4/17 Form 10-404 Revised 5/2015 e_v• 71. 5-/J0/`7 RBDMS '✓APR - 6 2017 Submit Original Only • • Packers and SSV's Attachment PRUDHOE BAY UNIT R-06A SW Name Type MD TVD Depscription R-06A TBG PACKER 8673.56 7754.29 4-1/2" HES TNT Perm Packer R-06A PACKER 8882 7930.08 Baker 47B-2 Liner Top Packer R-06A TBG PACKER 9135.18 8147.53 5-1/2"TIW Packer • m a O O o 0 0 0 0 r 6- O 0 O 1 N N O .- 00 N- O C N V I- N- Cn Cfl U N O o 0 0 0 0 0 i CO I"-- CC) CO Vt 3 O M O x N I� Ca V CO CO CO r-- co -co c-- O O Ln CO O ti N- O N CO C) CA I-- co r N 00 CO CO I,- CO CO 0 1 1 1 1 1 1 1 1 H f� CO C)) CC) CO I� LO M N CO CO O CO CO CO CA N CO 0) I� CO I- CO Q G) CD Co � OC CV CD CS) O O (fl CO N CO I-- N co co O N N CT O co 0) CA O 1_ 0 ~ E i i i i I I I i Z Q M Cfl CO I- Ln N CO CA CO M M M COCO MCO 0) C CO Ja • W F- O O O O O M C O 2 oo_IIJ w ' co"J OD C 0 y M N �# M Jco ( J *k 0 CLM N ti O M Ln t LO CO CO CAO N Vtr) M C CO CO I- r M (` (A d N 6) M (c) 00 W W' aa O = F- W o • U0 W U o LL W W W Z_ Z Z_ Z Et W W W m ODHZZJDJ CnZJJH � � Packers and SSV's Attachment PRUDHOE BAY UNIT R-06A SW Name Type MD TVD Depscription R-06A TBG PACKER 8673.56 7754.29 4-1/2" HES TNT Perm Packer R-06A PACKER 8882 7930.08 Baker 47B-2 Liner Top Packer R-06A TBG PACKER 9135.18 8147.53 5-1/2"TIW Packer • • ca O- Oi iii 2 O U H (a rn a) W C N O �C C p p m .O L W co Och o — o C as CU o ❑ 0 O O V U) E (6 in in CT H O * Q , 0 * W =c13 `o ' c c v a * m U in Co CO .u) o J ,- m O -p 0) 2 O).�a) r c- D CO O -Co Q N c— as - C o O .- -o N V — N O O (0 f0 a) Q X O C CA O N � U) O 0 O 'C CUay a_ d H N _0 (0 CO CO co �\ C O � C D a) L0 C v O OCY) -2 O o CV r U U X O p co (0 ti O cc 0) Q) a)O 0 7 `� ❑ Eo D ❑ tf) N O •Ul cn O N E H C @ C = co. 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OPEN HOLE 12038-12289 C 01/07/99 3-1/2"LNR,9.3#,L-80 STL, ---j 12038' .0087 bpf,D=2.992' 7"LNR,29#,L-80,.0371 bpf,D=6.184" — 10681' FBTD(TAGGED 01/07/99) — 12289' DATE REV BY COM ENTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 10/04/79 PN-1 ORIGINAL COMPLETION 07/08/15 SMfJMD FINAL ODE APPROVAL WELL R 06A 01/19/89 D-16 R1NO 03/21/17 MSS/JNC SET CBP&ADFStFS(03/14-15/17) FERMT Nb:'1981270 01/07/99 CTD SIDETRACK(R-06A) AR No: 50-029-20388-01 06/26/15 D-14 RWO SEC 32,T12N, R13E,728'FSL&1399'FWL 06/29/15 ,IND DREG HO CORRECTIONS 07/08/15 JMD TALLY DEPTH SHFT-CORRECTED BP Exploration(Alaska) V�� Titt r 6)0'Iyy, � THE STATE Alaska Oil and Gas ofLASI�;A Conservation Commission A . t = 333 West Seventh Avenue t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 rh Main: 907.279.1433 �F q ,5' Fax: 907.276.7542 www.aogcc.alaska.gov Matthew Bergene Production Engineer Challenger BP Exploration(Alaska), Inc. P.O. Box 196612 SCANNED MAR 2 2201Z Anchorage, AK 9951976612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU R-06A Permit to Drill Number: 198-127 Sundry Number: 316-603 Dear Mr. Bergene: 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, Cathy P. oerster �./�� Chair DATED this 41 " day of January, 2017. RDD IS t.., _1' D OF 0 A L A S K A OIL AND G E ST CONSERVATION COMMION NOV 2 8 2016 APPLICATION FOR SUNDRY APPROVALS IDTS i t i 20 MC 25.280 AOCC 1. Type of Request: Abandon ❑ Plug Perforations m • Fracture Stimulate 0 Repair Well 0 Opera ions shutdown 0 Suspend 0 Perforate ® - Other Stimulate 0 Pull Tubing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 1D o2C _ 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 198-127 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic 0 Service I I. 6 API Number: 50-029-20388-01-00 • 7, If perforating: 3141` 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 12I PBU R-06A 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028278/ ✓ti'k o 'y'Z7Q' /$ i(,30-l6 PRUDHOE BAY,PRUDHOE OIL' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 12308 ' 8976 ' 12289 8976 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 38-118 38-118 Surface 2624 13-3/8"72#L-80 37-2661 37-2661 4930 2670 Intermediate 9705 9-5/8"47#L-80 35-9740 35-8671 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic Q 13.Well Class after proposed work: • Detailed Operations Program Fe BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service IZI 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG I - GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Bergene,Matthew be deviated from without prior written approval. Email Matthew.Bergene@bp.com Printed Name �,Berggene,Matthew Title Production Engineer Challenger Signature ✓ellA ;) Phone +19075644849 Date `I J �Q/ I/ ar,Vl /•••(/ COMMISSION USE ONLY / W! `s Conditions of approval:Notify Commission so that a representative may witness Sundry Number: ‘(f2 — t.t.0 3 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: j41-)V— I 14114 Post Initial Injection MIT Req'd? Yes 0 No f—/' Spacing Exception Required? Yes 0 No URI' Subsequent Form Required: /0 4 D 4- APPROVED BYTHE Approved by /3.-2044/, COMMISSIONER COMMISSION Date:/ cZ_q vr4- //3//7- 0RIGINAL RBD SLJ,`l22.Ot-7- 7 '//tea ubmit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate /::;' , D • bp Nov 2 8 2016 0 22 November 2016 Michael Quick BP Exploration(Alaska)Inc. Sr. Petroleum Engineer 900 East Benson Boulevard 612 Alaska Oil and Gas Conservation Commission ABoa Ann choragee,,19AK AK 99519-6612 333 West 7th Avenue usA Anchorage, AK 99501 Main 907 564 5111 Re: Prudhoe Bay Unit R-06A Profile Modification Sundry Application Dear Michael Quick: Your technical approval is requested to set a plug and add additional perforations in the Ivishak injector R- 06Ai. R-06Ai is a CTD ST drilled in January 1999. It was designed for line drive Zone 4 injection support in the central R Pad area with future opportunity to open up Sag injection. The CTD liner sat down high at 12,038', leaving 270' of open hole, and was cemented and cleaned out. Initial injection in R-06Ai was WAG into the OH Ivishak section. The Sag interval was perforated in March 2001. To date the well has injected 8.2 bcf MI and 12.6 mmbw. A RWO wasorm -edw6/20-1- -which pulled the collapsed 7" tbg and replaced it with 4.5' tbg. The well was 0l in 8/201 ?nd SI in 1/2016br drilling at R-16A. The well has been SI since then due to the lack of injection water. } The objective of this job is to establish injection to the south of a non-conductive fault at —12,000' MD and establish MI connections to the producers in that direction. In order to achieve this, the current OH interval will be isolated with a CIBP and 160' of perforations will be added in the Ivishak up hole. Recent Integrity Highlights: 06/24/15: PPPOT-IC Passed to 3500 psi 06/26/15: MIT-T and MIT-IA Bil oth Passed to 4000 psi `/ 08/16/15: AOGCC MIT-IA passed to 2500 psi Theseloressure tests have proved competent tubing_down to 8,756' MD, competent casing down to the packer, and a competent packer. The CIBP will be set at 11600' and perforations added from 11,296' — 11,350' MD and 11,410' — 11,506' MD. Attached is a complete procedure with well bore schematic. Additional details on this wellwork procedure are available from Matthew Bergene at 564-4849 or Josh Allely at 564-5732. Respectfully, ..//.474---e.,,,vj,f. ......L.,---- Matthew Bergene Production Engineer Alaska Reservoir Development, BPXA 0 • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: R-06A Well Type: WAG Injection Well API Number: 50-029-20388-01 Well Activity Classification: Conventional 4 Activity Description: Plug and Perf Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Add Perf+ Prof Mod Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory None requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Matt Bergene Contact numbers: (907)564-4849 (307)630-9653 Well Intervention Engineer: Josh Allely Contact numbers: (907)564-5732 (907)350-7362 Lead Engineer: Ryan Rupert Contact numbers: (907)564-4238 (907)301-1736 Date Created: October 19,2016 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 Injection Date Choke Setting Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) Cut(%) (Mscf/Day) (psi) 1/13/2016 4,500 800 Current Status: Operable Shut In Inclination>70°at Depth(ft) 10,071' MD Recent H2S (date,ppm) NA 0 ppm Maximum Deviation(Angle and Depth) 95° 11,217' MD _ Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 37° 10,003' MD Reservoir pressure(date, psig) ananlog 3,250 psi Minimum ID and Depth 2.958" 8,882' MD Reservoir Temp,F 200°F Shut-in Wellhead Pressure 200 psi Known mech.integrity problems(specifics) None-RWO in 2015 to replace collapsed tubing Last downhole operation(date, operation) 6/26/2015 RWO: Pulled 7"tbg. Replaced with 4.5". MIT-T and MIT-IA to 4000 psi pass Most recent TD tag(date,depth, RIH W/KJT, 2.25"CENT., 1-1/2"S-BAILER, S/D LINER TOP toolstring OD) 8/2/2012 10,170' MD Q 8,872' SLM AND WORK THROIUGH, DRIFT TO DEV.Q 10,170' SLM, POOH 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. S • Comments,well history, Background: R-06Ai is a CTD ST drilled in January 1999. It was designed for line drive Zone 4 injection background information, support in the central R Pad area with future opportunity to open up Sag injection. It was completed with a etc: 3 1/2" liner across both the Sag interval and Ivishak.The CTD liner sat down high at 12,038'and was stuck there leaving 270'of open hole section in the Ivishak at the toe of the well. The liner was cemented and cleaned out.The cleanout reached TD at 12,308'and found no cement in the OH section. Initial injection in R-06Ai was WAG into the OH Ivishak section. Four WAG cycles put away 2.8 bcf of MI and 3.7 mmbw through February 2001. The Sag interval was perforated in March 2001. R-06ai came back on injection with PWI then MI in 2001 followed by PW through the end of 2005.An IPROF was run in 2002 while on PWI. It . showed 2% injection into the Saq. It went back on MI in 2006/2007 and showed production responses in R- 16 and R-18B. To date the well has injected 8.2 bcf MI and 12.6 mmbw. R-06Ai was shut in 2007 for flowline corrosion.The flowline repair work was finally completed in May 2012.An MIT-IA for regulatory compliance was done in August 2012 in preparation for bringing the well back on MI injection.The IA was pressured up to 4000 psi and experienced a sudden rapid pressure loss. Subsequent diagnostics indicated that the 7'tubing had collapsed. A RWO was performed in 6/2015 which pulled the 7'tbg and replaced it with 4.5"tbg. The well was P01 in 8/2016 and SI in 1/2016 for drilling at R- 16A. The well has been SI since then due to the lack of injection water. The well has a strong history of MI connections to the North of a fault that was encountered at 12000' MD while drilling. This is very similar to the depth that the liner was landed at(12038' MD). Since strong MI connections exist to the North,and injection rates appear to be typical for the Ivishak in the area,it is assumed that the fault is not conductive. Due to this,the prefrence is to establish injection to the south of this fault and hopefully establish MI connections to the producers in that direction. Additionally,since the well was completed R-16 has been ST outside of the pattern, leaving only R-18B as the sole producer with • an established MI connection. Benefits: IOR is being calculated for this well assuming that MI will be injected in March. It is based on the past response in R-18B,and this discounted by 80%,since MI will not be contacting truely un-swept• rock. Plan:In order to modify the stream lines and better sweep an area south of a non-conductive fault,the - current OH interval will be isolated and 160'of perforations will be added up hole. Once the CIBP is set, coil will tag the plug for depth control on the perforations. Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20% Suspected Well Problem: Poor pattern comformance Specific Intervention or Well Objectives: 1 Modify the injection streamlines by setting a plug and perforating up hole 2 3 • • Key risks,critical issues: Mitigation plan: CIBP will be set 144'deeper than the lowest shot. The 1 Damaging the CIBP while perforating CIBP is robust enough to handle the expected pressure pulse,plug is rated to 10000 psi dP The performance of this well was reviewed and an injectivity index per foot was calculated. Using this information,160'of perforations will be added. With 2 Not being able to meet injection targets this lengh of open reservoir,we expect to be able to get 3600 bwpd away at 800 psi WHIP. This leaves plenty of unused injection pressure if we need more rate. • While drilling this well there were no major losses. During cementing returns were maintained througout. After WOC,the well had a good liner lap test,loosing 3 Cement isolation 95 psi during the 30 min test. CT RIH to mill the dart, float and landing collars,and any cement in the OH section of the well. During milling full returns were maintained,and it wasnt untill we were in the OH section that losses of 0.5 bpm were established. Summary Service Line Activity Step# 1 CT Set plug and perforate 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1)MU memory GR/CCL in carrier and a JSN. Drift to 11700', log from 11700'to 8500'. Flag pipe for CIBP set. Contingint: If while drifting and tag high,jet diesel with the choke closed as needed to reach 11700'. 1 CT There is no need to use hot diesel if jetting is required. *** Note: Liner ends at 12038',and is open hole below, do not drift past 12000' *** *** Note: 2.5"guns swell to 2.676"in liquid. *** 2)Set CIBP with the top at_11FO11. 3)Add perforations according to attached sheet,Tagging the CIBP for depth control 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: POI at 3500 bwpd(a separate program will be submitted when ready for MI injection. Expect MI inj in 3/2017) 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 • I TREE= OW 4-1/16' WELLHEAD- MCEVOY R-06A SAFETY NOTES:WBL>70°#10071' QS READINGS _ ACTUATOR BAK1T2 G AVERAGE 125 ppm WREN ON MI""WELL REQUIRES A OKB ELT/= SS 99' I I SSSV WI-031 ON NI"'MAX DOGLEG'24.5*e 10680'"" titV= 21.31 1 KOP- 3200' I •f]OPDL)CI'OR —--�.. I 2156' a 411t2"9-ES X NP,13=3.813"j Max Angle= 95'/81 1121 T' � ------------------------ ' , Datum MD= 9960' Datum TVD= 88017 SS 'i0 2683' I-19-518'DVPKRI 266 ' 7 ' 6641' --{4.1/2'HES X NP,o.3.813" Minimum ID=2.968"@ 8882' BKR 4782 LTP > -I 8672' —9-5/8"X41/2" TNTPKR,D=3.903" ' 1 { 8708' l--I4•1/2"HES XMP,D=3.813"I 8779' H4-112"PE XNNIP,D=3.125' I I r TBG STUB(06122115)I4--8724'_J-.tip 8810' H..1/2-HALF MULE SHOE,13=3.958 4-1/2'TBC 12.64.L.-80 TCI 0152 bpf 13=3 058' 8810' •---- 8882'-1--118-KR47132 LTP,D=2.958' 4 GS 8890' -3.75'BKR DEPLOY SLY, D-4.00"-3.00' .. 88�-I4 375"-3.75"XO 3-1/2".D=2.99" I 7"TBG,24W,L-80,.0383 bpf,D=6.276 H 9066' N I 9086' I-17'X5-1/2"X0,D=4.892'I - [ 9098' IH5-12"OTISXAOLD SLV,D=4.562' g 1 9135' H9-5/8"X 5-12"TAN PKR D=4.75- I 9187' ]—5-112"PARKER X NP,U=4.5(2" BEHIND CT LNR ' -L 9209' H5-1/2"PARKER XNNIP,D=4.56" 1 15-12'TBG,171<,L-110,..0228 bpi,D=4.692" H—!. 1' I iI I.....„--1— 9226 -19-58"X r INV 71�K SLV,D=_• --_ 9229' H5-1/2"SEAL ASSY.WO SA♦'.,,$ 19-5/8"CSG,47*,L-80 BUTT,13=8.681" 9740' ( 9236' -9-5/8'X 7"TW HCR,o= " 1 Ir WHIPSTOCK wi RA TAG e#9870' I-. 9862 ' r Ml 10111 WINDOW IR-06A) 9682'-9879' PFRFORATIONSUIuNAARY o 0 RFFIOG 031 I AR I OG ON 03/15/01 �" ' ��1v(J _Co) - ANGLEATTOP FERE 31" • 9880 " .. ` \,,3J0� ? D Ibte Refer to Production DB far historical pert data t♦4�11►14111 �r.ray 0/' o SILL SF1- NIF3lVAL Gpn/Sgt'. SWI SUL 14444441 �� �N� 2-1/2" 2 9880-9910 0 03/16/01 1411114414111 1 !#11114 ( 11111141 10 12306' �"`-- -. OPEN HOLE 12038-12289 0 01107/99 1444444 1441114444411 r h 4 615 3-1)2 LNR,9 Sit,1-80 STI., 12038' 4P4 I1 IA LI 4 .0087 bpf,ID=2.992" I I r LNR,298,1-80,.0371 bpi,13=8.184' H 10681' 11417(TAGGED 01/07/99)I 12285' DATE REV BY ODAINENTS DATE I REV BY COMMENTS PRLIJIiOEBAY LINT 10110475 PR-1 OWGINWL COMPLETION O7/08/15I 398J0/13 FINAL 00EAPPPRQVAL WE.L.R-00A 01/19/89 D-16 RWO I FRAU No 1981270 01107199 CTO SIDETRACK(R-08A) API ND:50-029-20388-01 06/26115 D-14 RWO i SW 32,TI2N, R13E,723'FSL 8 1399'FNA 06/29'15 JMD DRLG HO CORRECTIONS 07/08/15 JMD TALLY DEPTH SI-1FT-CORRECTED BP Exploration(Alaska) - • • jilt PENDING PERFORATING PROCEDURE RDW Well: R-06A API 9:50-029-20388-01 Date: 10/19/2016 Prod Engr Matt _- Office Ph: (907)564-4849 HTS Level: Home Ph: _. _......_.. .......__._.. 0 ppm Cell/Pager: (307)630.9653 CC or AFE: APBINJEC WBL Entries IOR Type Work Description i I See Procedure I i I I I II Well Objectives and Perforating Notes: See Procedure. Attachment: Le , „pe annotated ,. rosed per„aotated Reference Loge Tie In Log Add 0 feet Log: Dual GR MWD I Dual GR MWD to the tie-in log to be on Date: 12/26/98-01/04/9i 12/26/98-01/04/99 depth with the reference log. Company: Spry-Sun S S _..._._.___._ un Depths(from-to) Depths(from-to) Feet SPF Orient. Phasing Zone Ad/Rellperf 11,296' 11360' 11296' -_,.. 11360_._. ...__64 6..._...__ Rand 60 Z4B Ad 11410' ._.._11,506'._.- 11,410'_ 11,506' 96 6 Rand 60° Z4B Ad Requested Gun Size: 2.5" Charge: Millennium II HMX Is Drawdown Necessary/Desired/Unnecessary During Perforating N/A Preferred Amount of Drawdown/Suggestions to Achieve Drawdown None Last Drift: 10,170 ft MD on .8/2/2012_ Est Res.Pres.@ 6,800'TVDss MD Is 3250 psi Perforation Summary summary Dist Well: ___—_R 6A _, Town: Date: API 9: 50-029-20388-01 Prod Engr. Anch Prod Engr P.D.Center PBTD e General Comments: Depths • Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf 0/B/U 0/B/U - 0/B/U .-.—...__._.,..._... _....�._._..__ ..___.—_..__ 0/B/U - 0/B/U - 0/B/U _.__._.. 0/B/U _ ...._...._._..... .---.T........_ 0/B/U _...._._... .._...__._._..._...... 0/B/U _._.__._..._......_ ...._......_...._. .__.___..__...._ • I FINAL MD ON sperry-sun 1:600 i 1:240 MD DRILLING SERVICES DGIt Di 11. 6 ‘1111 1, It ‘1 1 H Allia \GI) N VII It 11 C t NM 1 1)R01i-1 040 ( ompai„ : 1;1> I A1>Fok ‘TRys,, 1 \IL i‘sk .". ..,„ ..-? •f :.e - kit; : \OR1)1( I 1)0Wkl I ( II 4 _ - WO ,- : 1,t-116 1 D -i n) 2 , Lr' '4 — 11( 1(1 : 110-1)1101-. fl '' 1 \1 1 5 6 cc 0 - - ._ T, 4 .c -, -. ( minty% : I `N I, Z ?• C.' 43. .::: ' D 4. 2. MW .-e , ,. .. '"' N- /0 :,'11 11. 268 ..)11-117R SERVICL_.; , W., 148: 54. 13.566 ,-.• ',-:. 1-. ,, i- .1_ 3 X-635049 Y,597720!-, 4. 4 1100UWL ' 3/ ; 1/E W,2E — 4 -1-mannt Oatum : MEAN SLA LEVEL fLov. : 0.00 ft Elev. KB 0.00 Loy MeAs. From : MEAN SEA LEVEL 0.00 ft Ab.Perm.Oat. OF 0.00 ()rig. Meas. From: MEAN SEA LEVEL Job N AK MW 90046 GL 0.00 API Ntimh .- : SO-029-20388 UI WO 0. 00 - H.--, Ai d La!,trig 16.., (1,-(1 i rrIm 1-0 1-0d 0, 571-L',7- V4.ioht FP )m io ;r tft MO 1 . NI, ,J-,4 : ' ' ' : ' 10 -ft ) (ft MU, kft MU) 9871 12106 : 1/5 72.0 /661 4 625 4/.0 9740 7.000 29.0 9227 9871 0 • T r.l. ;r1 i., rtoy .4,Ji I :i#, t t y 'y,i, r ,..,1 .1.;‘,.0.,,,E, I...A Ailty ddefila gt- 1...t4.1 tifh xil 4:ufri-illti...0t.i 61 filt04,3,gfavtt, r4,5*.eit iffy f, ,,,,,,, t fl, ,,,,,,:.- -f ,f, r f,,1,.1. .. ,- -01 et pe et pr ov a aia,,ra by Sprav r y Sur nr a 1 a a rag Soar v 3 cora ___..... SGRC WELLBORE __ api SSTVD-FT ... ._ SROP PROFILE . _-------_-__-----__ feet rr hr SSIVD-FT ..... T I I T i 1 4 i 1 if . . , if ' i, . 1 I 1 1 11200 . , • i . '. • 1 , 't } • ,., i , 't # - ,..„..„, , e• 1 4 i 7 4 t i ' 1 1 I i . , 0 t 4 i 4 X t e , 4 c, fr. 4, , ,.. ,. tita.4 . _ ., . orirl t. Toi..,,,t 300 * .4 t 1 • • ' '(_ tae s $1l a tios t ' 4,1 / I �T.t 1ki. , '43i0' I. 8'tOb Tjy ix r. v t 1 0 t1 q t .. S.i T... 11400 p ., . i ....i f LT tEi-1t :..kmbt'' -how ,.;. i i Jr 1 I i l ! 1. I1. .' ,,f ti `. 4 `a tr 2,11 X 44 z 1, j 4 $800 i1 X ► f ''''' ttp` Z Qq t:` Tit- 1 t • I , . •, , El 1 w) iii Mii ,.., ___. II .I 11.1 4 t8 e_•--._. X y `-- - CIBP Top at 11600' 111011....44111 1 k _ f r" 4 r' ♦ I,, tr11 . +, ._ .., It * f 4 I j ` 4t ,. 4 , 4 1 3 • • ...... -_..., LINER/CEMENTING SUMMARY (. 13P) , DATE 1/3/99 . ,.. .i WELLS R-06c4 LINER SIZE/GRADE/THREAD 1500 1,80 STI UNER WT/FT 9,30 BOTTOM Of LINER AT 12,038.00 TOP OF UNER AT 8.890,43 ' M Description Includes: SUE,TYPE,CONNECTION NO ITEM OD ID LENGTH TOP BOTTOM Ai Guide Shoe 3 50 Ni' I.59 12,036,41 12,031.00 1ort 3-1/7 Tubing 31 /6 121104.65 I 2,036,41 1,.W Fk)cat Collor 3 50 NA 1.I/ 11003.43 12,02465 Joint 3-1/7 Tub*n9 3 50 31,78 11,97I 70 12,00348 Baker Latch Collar 3.50 N/A 0,64 11,971,06 11,971.70 BP Integral Turbo 4 40 2 99 79 (3 11,691.56 11,97106 95 3 1/2"9 34ift L-90,STL Tubing 3 50 2 99 2990,70 1901.16 189)86 BPX XO to 51! 150 2 99 0,92 8,900.24 3.931 16 Baker XO to F L4S 3 50 2 99 1.10 3.899,14 3.900,24 Baker Deployment Sub with 4'Tie Back Sleeve 4 375-3 75' 1"-3" 8,71 ,1 5,890,43 18994 8„:• ,43 1890,43 8,890 4.3 8,890,43 8,890,43 8,890,43 M899&3 1:• 43 8,890 43 3.'-• 43 2 3tEr CT PLAIN-rig Equipment(Le CTC,,)CV) Et'• .43 EL i• .43 BHA Total Length - 3147.57 .........„ CEMENT&DISKACME NT SUMMARY JP Fluid Type used In displaced Flo-Pro Iwo, Used bhl Cir.Rale while Displacing Flo-pro BPM Displacement Press. .psi Return Circulate rate BPM Loss Cir". CTLRT Release:,-, I Size ,n Cat Vol to shear CTLRT 57.95 obi Calculated CTLRT Shear Releasep.-,t Act.Vol to Shear CTLRT bbl Actual CTLRT Shear Release ot,i (_:-• Vol to Release CTLRT -5795 bbl Cr rate(Bpni)and press lest)while mixing cementIMMIII. Data Calculated Cement Vcairne Required=MEM bbl Stan Job hh:rnen Water Spacer Ahead MEM.bbl Cement at Density hh:rren Cement Volume through Micro Motion MM.bbl Finished Job httrrun Dropped CT Liner Wipe Plug(YesiNotIMIMI Yesitlo F119 Rep. Water Spacer Behind(bbl)111111.11111111bbi Baker Service Rep, Type at Displacement Fluid 11111111MMI DS Cementer Displacement Ratei Beni)and Pre56,(psi)IMP Bumped If Plug didn't B . liner wiper Plug Bump Yes/No Vol cement Leh in Liner MEIN etal Calculated Vol to bump LWP 84 65 Obi Estimated cement Top.1.1111111Min Actual Volume to burp LWP bet Pressure Applied to Plug After BurnOwie Psi Floats Heyde :,. AO COMMENTS Therotical Volumes Calculated Displacement Actural Vol Dello Vol Coiled Tubing Volume* 57 95 ,otol Actual Disp/ (Bbl.).„ Wiper Plug to Latch Collar Displ: 26 70 bet Actual Dtspi (lit)J): Total Deal. 84 65 hbl Act.Total awl(Bbl), 3 CO • • ....kbp Lac gm" Baker Thru-Tubing Ilaiwr t w 1.4.8. Well: R-06 Date: Co. Man: Description OD ID Length ty CTLRT 2000 Release 3.63" 1.25" 3.96' I Ball seat below set to shear @ 2780 PSI 0 mi Deployment Sleeve w/ 5.75" OD Scoop Guide 5.75— 3,00" 2.10' 4"GS Profile 11111111 am - - ______ 47B-2 Special Clearance Liner Top Packer . 1080 PSI To Start Setting 6.925' 3.04" 6.45' - e" 1 20K Shear Ring , I 4""GS"Retrieving Profile .._ Seal Nipple Pack Off 3'A"STL P 80.40 Locator 4.19" 2.958" .58' 3 'A" STL B 4" Seal Unit w/ 2.958" Indexing Mule Shoe 4.25" 4.00" TOTAL3'00" 1.15' 5 00' 19.24' 1 m a 0 0 0 0 0 0 c (No- rocO � NOCA) NT N C N V O tiO 1U h LO CO U N 0 0 0 0 0 0 0 I.- CO I— CO CO V' 7 CA co n V N I� m N CO s_ CO 00 r-- co -Co N C)) O LC) CO O N- O N- N O N CO (fl 6) t-- co N N 00 co c0 r` co co H N CO CO U) CO I- U) CO N CO O O CO CO CO CA N CO CO I.- co cc CD co com cs)C (.0 "Sr CO 000 N O N CO 00 O N C\IN C) CS) CO CO C) C.) 0 CI II I � Q < (0 O N- U) CO 0 co N- Lr) C)) N c7 co 00 co co co cc N co N- O _ CO C) 00 C)) • • a 0 o 0o CO O J CO __J CO CO = a) co c,4 —J p J *k •N N. ) X (A ,- c C O 0O OO N _(NI co N N tor) v U) s CO �O N O V U') M C co CO N- — N- L d) N C) co CO CO M J W � Q C 0 W U o Ctn c Z Z Z Z c[ W W W m m m O DI- ZZDDD U U) ZJJI- F- H • f6 CO C) O. v- O m � r p co rn cc co a 0 Ln co .c N Q Ln 1� A) O CO p I— 6) OO CO H N N CO L O O }1 Q O ��11= 0 a) N t6 2 ✓ a CC CO Qoa LL O c _c c0 W O N ca LL. co L m O 2 t a, a a O U c o L� m d = < D a O t d a m O 0 0 rn O N R CO � \ p, M 0 E z• Q Q co co cn 0 0 Packers and SSV's Attachment PBU R-06A SW Name Type MD TVD Depscription R-06A TBG PACKER 8673.56 7754.29 4-1/2" HES TNT Perm Packer R-06A TBG PACKER 9135.18 8147.53 5-1/2"TIW Packer • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re ( / DATE: Thursday,September 10,2015 P.I.Supervisor el I ` `�� SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC R-06A FROM: Jeff Jones PRUDHOE BAY UNIT R-06A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry L./>C- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT R-06A API Well Number 50-029-20388-01-00 Inspector Name: Jeff Jones Permit Number: 198-127-0 Inspection Date: 8/16/2015 Insp Num: mitJJ150906072442 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min j R 06A W . 7752 734 -� 736 736 - 737 Well� Type Inj TVD Tubing - ----------- PTD 1981270 •, ,IType Test SPT Test psi 1938 " L IA 363 2502 - 2478 - 2472 • -- - -------- -- Interval 14YRTST — P/F I P `-i- OA 823 709_ 709 - 736 - Notes: 4.2 BBLS methanol pumped. 1 well inspected,no exceptions noted. Thursday,September 10,2015 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIlIntegrityCoordinator@bp.com> Sent: Sunday, August 16, 2015 6:39 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad RJ; Peru, Cale; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Regg,James B (DOA) Subject: OPERABLE:Injector R-06A (PTD #1981270) AOGCC MIT-IA Passed All, Injector R-06A (PTD#1981270) passed an AOGCC witnessed MIT-IA to 2500 psi on August 16, 2015 reconfirming two competent barriers in the wellbore. The well is reclassified as Operable. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) Sc& V AUG 2 4 2015 BP Alaska-Well Integrity Coordinator GY Y Orga. /Ni to!, WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com From: AIC;D&C Well Integrity Coordinator Sent: Sunday, Au2t,02, 2015 11:02 AM To: AK, OPS GC2 OSM; AK, P GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad RJ; Peru, Cale; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DPI&.WeII Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) (jim.reag@alaska.gov) Subject: UNDER EVALUATION: Injector R-06A (PTD #1981270) Rig Workover Complete MIT-IA Passed All, Injector R -06A (PTD #1981270) underwent a rig Workover that was completed Oh-Q6/26/2015. The rig Workover replaced the tubing and packer. The well passed a MIT-IA on 06/26/2015. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Under Evaluation and ma e put on injection. • Well status is Under Evaluation i • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM N ` REPORT OF SUNDRY WELL OPERATIvr1S 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing Il Operations shutdown ❑ Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Rednll ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Convert to WAG 0 2 Operator Name BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 198-127 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service p 6. API Number: 50-029-20388-01-00 7 Property Designation(Lease Number): ADL 028279&028278 8 Well Name and Number: PBU R-06A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools' PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary. Total Depth: measured 12308 feet Plugs measured None feet RECEIVED true vertical 8976 feet Junk measured None feet JULI 2 3 2015 0 i Effective Depth: measured 12289 feet Packer measured 8672,9135 feet I true vertical 8976 feet Packer true vertical 7753,8147 feet AOGCC Casing: Length: Size: MD: TVD• Burst: Collapse: Structural Conductor 109' 20"x 30" 36'-145' 36'-145' Surface 2626' 13-3/8"72#L-80 35'-2661' 35'-2661' 4930 2670 Intermediate 9721' 9-5/8"47#L-80 34'-9755' 34'-8685' 6870 4760 Liner 635' 7"26#L-80 9227'-9862' 8226'-8779' 8160 7020 Liner 3156' 3-1/2"9 3#L-80 8882'-12038' 7930'-8967' 10160 10530 Perforation Depth: Measured depth: 9880 9910 feet 01-1.12038-12308 feet True vertical depth: 8795-8820 feet OH.8967-8976 feet Tubing(size,grade,measured and true vertical depth) 7",26#x 5-1/2",17#x 4-1/2",12 6#L-80 31'-9229' 31'-8228' Packers and SSSV(type,measured and 4-1/2"HES TNT Packer 8672' 7753' true vertical depth) -- 5-1/2"TIW Packer 9135' 8147' 12 Stimulation or cement squeeze summary: Intervals treated(measured): SatilkIED Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Infection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 340 0 - Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25 070 25 071,&25 2831 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service Q 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 ❑ GSTOR 0 WINJ 0 WAG I1 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: 314-386 Contact Warren,Abigail M Email Abigail.Warren@bp.com Printed Name Joe Lastu a Title Drilling Technologist 1 Signature • Phone +1 907-564-4091 Date i/23/1 5 �M .� VT) III 4/7 / l/i q//._/- - - .._ _ . R-06A, Well History (Pre-Rig Workover) DATE ( SUMMARY T/I/O = SSV/250/20, Temp: SI, PPPOT-T(PASS), PPPOT-IC (Incomplete) Pre RWO/Re-energize secondary seal. PPPOT-T: Stung into test void, (100 psi) bled void to 0 psi. Functioned LDS, all moved freely. Torqued to 500 ft/lbs. Pressured test void to 5,000 psi for 30 minute test. Lost 100 psi in 15 minutes, lost 50 psi in second 15 minutes. (PASS) Bled void to 0 psi. PPPOT-IC: Stung into test void, (100 psi) bled void to 0 psi. Opened SBS on test void to verify 0 psi in void. Functioned LDS, 1 had a hard time going back in, left out and flagged. The rest moved freely. Torqued to 500 12/3/2014 ft/lbs. DHD bled OAP to 0 psi. Was unable to bleed IAP to 0 psi. T/I/O = SSV/250/20. Temp = SI. Assist Cameron w/ LPE (Pre Rig). No AL. IA FL @ 390' (10 bbls). Bled OAP from 20 to 0 psi in 1 min. OAP increased 5 psi in 30 min. Bled IAP from 250 psi to 80 psi in 5 hrs 45 min (7 bbls). IAP increased 8 psi in 30 min. Unable to bleed IAP to 0 psi. RD per WIE. 12/3/2014 FWHPs = 70/88/10. SV, WV, SSV= C. MV= 0. IA, OA= OTG. NOVP. 1800. T/I/O = 81/91/4. Temp=SI. Bleed IAP& OAP to 0 psi. No AL. TBG & IA FLs near surface. Heater in well house is working properly. Bled TP to 66 psi & IAP to 81 psi in 4 hrs w/2 bbls of returns. During TBG & IA bleeds, OAP increased 1 psi. Monitor for 50 min. TP increased 9 psi & IAP 12/4/2014 increased 8 psi. Final WHPs=75/89/5. SV,WV,SSV=Closed. MV=Open. IA,OA=OTG. (0500 hrs). 72/94/17. Temp = SI. Assist Cameron w/LPE (Pre RWO). No AL. IA&OA FL's near surface. Bled IAP to slop trailer from 94 psi to 75 psi in 15 hrs, w/ 18 bbls returned. During IA bleed, TP decreased 12/5/2014 13 psi and OAP increased 3 psi. 59/75/20. Temp= SI. Assist Cameron w/LPE (Pre RWO). No AL. IA&OA FL's near surface. Maintained open bleed on IA for 14 hrs, w/6 bbls returned. Bled TP to 20 psi (FTS). Final 12/6/2014 WHPs=57/80/21. SV, WV=C. SSV, MV=O. IA&OA=OTG. 1630. T/I/O = 55/70/20, Temp: SI. PPPOT-IC (Incomplete) Re-energize secondary Y seal. PPPOT-IC: Stung into test void, (0+ psi) void bled to 0 psi. Standby while DHD bleeds WHP's to 0 psi. Unable to 12/6/2014 bleed WHP's to 0 psi. T/I/O=60/80/22. Temp=SI. Assist Cameron w/LPE (Pre RWO). No AL. IA, OA, &TBG FLs near surface. Bled IAP, through hardline, from 80 psi to 119 in 1 hr. During IA bleed TP decreased 7 psi 12/6/2014 and OAP decreased 9 psi. 1/1/0=60/79/17. Temp = SI. Bleed IAP & OAP to 0 psi, Assist Cameron w/ LPE. (Pre-RWO). Bled IAP during shift, shutting in to build gas cap 7 times with 10 bbls of returns, IAP increased 63 psi during bleeds due to fluid weight on top of gas bubble is decreasing. Called Vac truck to empty AP 12/7/2014 tank. Final WHP's= 60/142/12. SV&WV= C. MV& SSV= 0. IA& OA= OTG. NOVP. 16:30. T/I/O= 53/119/12. Temp=SI. Assist Cameron w/ LPE (Pre RWO). No AL. IA, OA, &TBG FLs near surface. Bled IAP, through hardline, from 119 psi to 77 psi in 5 hr, w/6 bbls of returns. During IA bleed TP increased 4 psi psi and OAP increased 8 psi. Final WHPs=57/77/20. 12/7/2014 SV,WV=Closed. SSV,MV=Open. IA,OA=OTG. (0530 hrs). T/I/O = 60/164/20. Temp=Sl. Assist Cameron w/ LPE (Pre RWO). No AL. Bled IAP from 164 psi to 105 psi in 1 min, gas, then fluid to surface. IAP continued to climb during bleed, from 105 psi to 280 12/7/2014 psi w/26 bbls of returns. WHPs= 85/280/15. T/I/O = 85/280/15. Temp=SI. Assist Cameron w/ LPE (Pre RWO). No AL. Continued w/ IA bleed from 280 psi to 330 psi in 15 min (fluid), w/4 bbls of returns, for a total return of 30 bbls evacuated from IA. During bleed, TP increased 35 psi, IAP increased 50 psi &OAP unchanged. Monitor for 2 hrs. TP increased 50 psi, IAP increased 53 psi, OAP unchanged. IA FL depressed to 850', 22 bbls. Tank was Vac'ced out and hardline blown down. Final WHPs= 170/383/15. Final 12/8/2014 WHPs=170/383/15. (0300 hrs). T/I/O = 180/398/21. Temp = SI. Assist Cameron w/ LPE (Pre RWO). No AL. T FL @ 486' (18 bbls). IA FL @ 1320' (34 bbls). IA FL dropped out 470' (12 bbls) in 8 hours. TP increased 10 psi, IAP increased 15 psi, OAP increased 6 psi in 8 hours. SV, WV= C. SSV, MV= 0. IA, OA= OTG. 12/8/2014 NOVP. 1100. R-06A, Well History (Pre-Rig Workover) T/I/O = SSV/400/20. Temp = SI. IA FL (Pre PPOT). IA FL @ 1200'. SV, WV, SSV= C. MV= 0. 12/9/2014 IA, OA= OTG. 11:15. T/I/O = SSV/403/15. Temp=Sl. Assist Cameron w/ LPE (Pre RWO). No AL. Unable to open SSV due to plumbing disconnect(Only fitting on barrel was Swagelok). IA FL @ 1230', 32 bbls. Bled IAP 12/10/2014 from 403 psi to 160 psi in 4 hrs, fluid to surface. T/I/O= SSV/160/15. Temp=SI. Assist Cameron w/ LPE (Pre RWO). No AL. IA FL @ surface. Bled IAP from 140 psi to 66 psi in 4 1/2 hrs, gas. Monitor for 30 min. IAP increased 13 psi. Final 12/11/2014 WHPs=SSV/79/15. (0530 hrs). T/I/O=SSV/80/11. Temp=Sl. Assist Cameron w/LPE (Pre RWO). No AL. IA FL ©210'. Bled IAP from 80 psi to 22 psi in 15 hrs. Bled TP from 200 psi to 100 psi, fluid to surface on both TBG & IA, in 1 hr. IAP increased 40 psi during TBG bleed. SI TBG bleed and monitor for duration of IA bled. SI 12/11/2014,IA bleed to stack out for 45 min. Bled IAP from 92 psi to 82 psi in 45 min, gas. T/I/O = 140/82/4. Temp=Sl. Assist Cameron w/LPE (Pre RWO). No AL. Continued IA bleed from 82 psi to 22 psi in 4 1/2 hrs. Instructed by WIE to depart and day crew will monitor later today. Final 12/12/2014 WHPs=140/22/4. SV,WV=Closed. SSV,MV=Open. IA,OA=OTG. (0500 hrs). T/I/O = 133/47/4. Temp = SI. WHPs (clean AP tank). Cleaned AP tank. Heater in well house, 12/13/2014 doors open and tree cap bled to 0 psi. SV, WV= C. SSV, MV= 0. IA, OA= OTG. 16:45. T/I/0=140/73/6, Temp=SI. LPE-IC (post failed PPPOT-IC), pre RWO. Stung into IC test void (0+ psi), bled to 0 psi. DHD pressured OAP with N2 to 1000 psi, no change in test void pressure. 12/18/2014 Monitored for 30 min. IC test void showed no increase in pressure, indicating primary seal is holding. T/I/O = 140/73/6. Temp = SI. LPE. (Assist Cameron). No AL. OA FL near surface. Increased OAP incrementally using N2 from 8 psi to 1000 psi for Cameron. OAP decreased 35 psi in 30 min. Bled OAP from 965 psi to 0+ psi in 7 min. Monitor during rig down. No change in WHPs. Final 12/18/2014 WHPs = 140/76/0+. SV= C. WV= LOTO. SSV, MV= 0. IA & OA = OTG. 19:45. T/I/O = 150/100/10. Temp = SI. IA FL (pre RWO). Integral installed on IA=inspection not current. 12/26/2014 IA FL @ 410' (11 bbls). SV, WV= C. SSV, MV= 0. IA, OA= OTG. 2300. T/I/O = SSV/320/0, Temp: SI, PPPOT-T (PASS), PPPOT-IC (PASS) Pre RWO. PPPOT-T: Stung into test void, (0+ psi) bled void to 0 psi. Monitored test void for 10 minutes, void stayed at 0 psi. Functioned LDS, all moved freely. Torqued to 500 ft/lbs. Pumped through void, good returns. Pressured test void to 5,000 psi for 30 minute test. Lost 50 psi in 15 minutes, lost 0 psi in second 15 minutes. (PASS) Bled void to 0 psi. PPPOT-IC: Stung into test void, (300 psi) bled void to 0 psi. Monitored test void for 10 minutes, void stayed at 0 psi. Functioned LDS, 1 stuck out and flagged, (will be changed out on the rig) the rest moved freely. Torqued to 600 ft/lbs. Pumped through void, good returns. Pressured test void to 3,500 psi for 30 minute test. Lost 100 psi in 15 minutes, lost 50 5/3/2015 psi in second 15 minutes. (PASS) Bled void to 0 psi. T/I/O = SSV/337/26. Temp = SI. MIT-OA**PASSED**to 1200 psi (pre RWO). No flowline, wellhouse, or scaffold. OA FL near surface. Used <1 bbl of AMB DSL to pressure up OA from 26 psi to 1200 psi. OAP lost 66 psi in the first 15 minutes & 8 psi in the second 15 minutes, for a total loss of 74 psi in 30 minutes. Bled OAP to 0+ psi (<1 bbl). Hung tags &AFE sign. 5/15/2015 Final WHP's = SSV/337/0+. SV= ?. SSV, = Closed. MV= Open. IA& OA= OTG. NOVP. 23:59. T/I/O = SSV/350/40. Temp = SI. PT balance & control lines to 2500 psi (Pre RWO). Pressure test control line to 2620 psi using -1 qt HYD fluid. Monitored for 5 min, lost 26 psi. Pressure test balance line to 2570 psi using -3 gal HYD fluid. Monitored for 5 min, lost 28 psi. Bled balance and control lines to 0 psi. Hung tags. Final WHPs = SSV/350/40. SV, WV, SSV, MV= C. IA, OA= 5/25/2015 OTG. 23:30. T/I/O= SI/360/40. N/U 3-1/8" O/A temp valve#67 & I/A temp valve#18 (Pre-Rig). Torqued & 5/31/2015 tested. T/I/O = 200/360/40. Set 6" CIW"J"TWC#408 @ 135", set good. N/D 6-3/8" x 7-1/16" CIW upper tree w/BB Otis actuator. N/U 6-3-8" x 7-1/16" temp valve#22 (Pre Doyon 16), torqued &tested. 6/1/2015 RDMO. FWHP's = TWC/360/40. R-06A, Well History (Pre-Rig Workover) T/I/O=BPV/380/20. Temp=SI. Bleed WHPs to 0 psi (Pre RIG). Well disconnected from system. IA FL near surface. OA FL @ surface. Bleed IAP to bleed tank from 380 psi to 285 psi in 3 hr. Monitor 30 min, IAP increased 30 psi. Final WHPs=BPV/315/20. SV=C. MV=O. IA&OA=OTG. NOVP. 6/16/2015 1350. North America-ALASKA-BP Page 1 of 10 Operation Summary Report — — . Common Well Name:R-06 AFE No Event Type:WORKOVER(WO) Start Date:6/17/2015 End Date:6/26/2015 X4-0100M-E:(2,940.000.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/11/1979 12:00:OOAM Rig Release:6/18/2015 Rig Contractor:DOYON DRILLING INC. 'UWI:500292038800 Active datum:R-06 @55.09usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth 1 Phase Description of Operations (hr) - (usft) 6/17/2015 18:00 - 00:00 6.00 MOB P I PRE MOVE RIG OVER WELL R-06 -TAKE ON 8.5PPG KWF,SPOT CIRCULATION TANK INTO PLACE,R/U AND TEST HARDLINE. '-PREP CELLAR F/WELL KILL.CREATE TASK HAZARD ASSESSMENT F/PLANNED CIRCULATION. 1 -COMPLETE RIG EVACUATION W/AAR 1 FOLLOWED BY PRE-SPUD MEETING W/A I CREW(HAUG). 1 -LOAD DUTCH RISER SETUP. SEND IN BOPE TEST NOTIFICATION T/ _ _ 1 AOGCC F/18:00 06/18/2015 6/18/2015 100:00 - 02:30 2.50 MOB P PRE 1 CONTINUE T/R/U LINES IN CELLAR AND TAKE jION 8.5PPG KWF INTO PITS. ' I I ACCEPT RIG T/WELL R-06•@ 00:01 06/18/2015 102:30 - 04:30 2.00 RIGU P PRE 1 TEST SURFACE LINES T7 250PSI/4000PSI F/5 MINS EACH.SPOT AND R/U MP#2 04:30 - 06:00 1.50 RIGU P � PRE MOBILIZE LUBRICATOR AND TOOLS T/RIG FLOOR,TEST LUBRICATOR. 06:00 - 07:00 1.00 RIGU P 1 PRE I WIRE IN MP#2 AND PRESSURE TEST LINES. 07:00 - 08:00 1.00 1 RIGU P PRE !DSM PULL TWO,AND R/D FROM TREE _' ' 320PSI SEEN ON THE TUBING. 08:00 - 08:30 0.50 . RIGU- P � PRE R/U KILL MANIFOLD ON THE TUBING AND I TEST/T 250PSI LOW,4000PSI HIGH. 08:30 - 11:30 3.00 CONDHL " P PRE R/U T/BULLHEAD DOWN THE TUBING AND IA 1 SIMULTANEOUSLY W/8.5PPG KWF,PUMP 1 I 875BBLS AS PER WELL PLAN -IA=400PSI,TBG=225PSI,BLEED IA T/ 260PSI,(TBG=170P51). I CIRCULATE W/MP#1,4BPM DOWN TBG, 1 ICP=1590PSI,FCP=1300PSI MP#2,6BPM DOWN IA,ICP=1620PSI,FCP=1400PSI. 11:30 - 12:00 0.50 RIGU P PRE MONITOR WELL F/30MINS 1200 - 13:30 1.50 RIGU P PRE CONTINUE T/MONITOR WELLBORE PRESSURE 1 -TBG ON A VAC,IA BUILDING PRESSURE T/ 1 1 I 1180PSI. 1 1 1 I -TBG BEGAN T/SWAP AND BUILD PRESSURE — .— i --- T/60PSI 1310 - 14:30 1.00 RIGU P ; PRE PUMP 150BBLS OF 8.5PPG DOWN THE TBG TAKING RETURNS UP THE IA T/THE FLOW BACK TANK -CIRCULATE @ 3BPM,ICP TBG=100PSI,IA= 200PSI,FCP TBG=125PSI,IA=OPSI 14:30 - 18:00 i 3.50 RIGU P W PRE MONITOR HP PRESSURES INCREASING:@14:30 TBG= 100PSI,IA=360PSI,@ 17:30 TBG=240PSI,IA =500PSI 18.00 - 19:00 1.00 i RIGU P 1 ' PRE 'BLEED OFF IA PRESSURE T/350PSI,TBG= 1 1 260PSI -CONTACT ODE,DECISION T/CIRCULATE 1 WELLBORE DUE T/DIESEL ON THE TBG AND . 1 IA _— Printed 7/14/2015 11:45:59AM • North America-ALASKA-BP Page 2 of 10 Operation Summary Report Common Well Name:R-06 AFE No Event Type:WORKOVER(WO) Start Date:6/17/2015 End Date 6/26/2015 X4-0100M-E:(2,940,000.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/11/1979 12:00:00AM Rig Release:6/18/2015 Rig Contractor.DOYON DRILLING INC. UWI:500292038800 Active datum:R-06 @55.09usft(above Mean Sea Level) Date From-To 1 Hrs Task Code NPT NPT Depth Phase ! Description of Operations ' (hr) (usft) i 19:00 - 20:30 i 1.50 RIGU P PRE 'CIRCULATE 110BBLS DOWN THE IA©2BPM, TAKING RETURNS F/THE TBG T/THE I FLOWBACK TANK ' -TBG BLEED BACK GAS F/INITIAL 5 BBLS, I SWAPPED T/DIESEL UNTIL-50BBLS AWAY AND GAS SEEN AGAIN F/5 BBLS,THEN 'WARM 8.5KWF AFTER 8OBBLS '-8.5 KWF SEEN FOR THE FINAL 3OBBLS W/A TRACE OF DIESEL.-80BBLS OF DIESEL RECOVERED I ICP IA=225PSI,TBG=100BBLS,FCP IA= I OPSI,TBG=125PSI 20:30 - 21:00 0.50 RIGU P PRE MONITOR WHP'S i L-TBG=60PSI,IA=OPSI(VAC) 21:00 - 21:30 I 0.50 RIGU P PRE I ATTEMPT T/BLEED OFF PRESSURE F/TBG 1 I- PUMP 2OBBLS DOWN IA @ 1 BPM,ICP IA= OPSI,TBG=50PSI,FCP IA=90PSI,TBG= 20PSI 21-30 - 22-30 1.00 RIGU P ` PRE MONITOR WHP'S -TBG=20PSI,IA=75PSI i -CONTACT ODE,DECISION T/BULLHEAD KILL 'WELL W/875BBLS OF 8.5KWF. 22:30 - 00:00 1.50 RIGU P PRE BULLHEAD FULL WELLBORE VOLUME t875BBLS SIMULTANEOUSLY DOWN IA AND TBG W/8.5PPG KWF -1§5BPM,IA=1350PSI,@5BPM TBG-1300PSI (COMBINED 10BPM INTO WELLBORE) 6/19/2015 100:00 - 00:30 0.50 RIGU P j PRE MONITOR WHP'S -TBG AND IA ON VAC 00:30 - 02:00 1.50 RIGU P PRE !FILL TUBING T/TAKE A STATIC LOSS RATE '-WELL LOSING 12BPH x02:00 - 04:00 2.00 RIGU P PRE B/D AND RID CIRCULATION LINES IN CELLAR, R/U TO FILL IA W/SECONDARY KILL 04:00 - 06:00 ' 2.00 RIGU P PRE !R/U DSM LUBRICATOR AND SET TWC -PERFORM ROLLING TEST ON TWC F/ I BELOW(GOOD TEST),PERFORM PRESSURE !TEST ON TWC F/ABOVE T/250PSI LOW, i 4000PSI HIGH,F/5MINS. 06:00 - 08:30 2.50 i RIGU P PRE I R/D DSM LUBRICATOR AND UD T/SHED, CAMERON BLEED OFF CONTROL LINE/HGR VOID,BREAK ALL BOLTS ON TREE/ADAPTER FLANGE 08:30 - 09:00 0.50 RIGU P PRE I BP WTL RICH BURNETT AND SUPERINTENDENT ALAN MADSEN VISI W/ CREWS 09:00 - 11:00 2.00 RIGU P PRE STEAM AND PULL TREE/ADAPTER AND t 'CLEAN WELLHEAD -6.5 TURNS T/MAKE UP T'IJ4S LANDING JNT CROSSOVER T/TBG HANGER,FUNCTION UPPER LDS. 11:00 - 12:00 1.00 BOPSUR P PRE N/U BOPE TURNBUCKLES,RISER,MOUSE HOLE,HOLE FILL -FILLING IA W/8.5PPG KWF @ 12BPH. LOSSES @ NOON=138BBLS OA PRESSURE=180PSI Printed 7/14/2015 11:45:59AM • North America-ALASKA-BP Page 3 of 10 Operation Summary Report Common Well Name:R-06 AFE No Event Type:WORKOVER(WO) Start Date:6/17/2015 End Date:6/26/2015 X4-0100M-E:(2,940,000.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/11/1979 12:00:00AM Rig Release:6/18/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292038800 Active datum:R-06 @55.09usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 15:00 i 3.00 BOPSUR P PRE CONTINUE T/N/U BOPE,RAM CONFIGURATION=3-1/2"VBR'S LOWER,7" SOLID BODY UPPER -R/U BOPE TEST EQUIPMENT -CONTINUE FILLING IA @ 12BPH 115:00 - 19:30 4.50 BOPSUR P PRE TEST BOPE T/250PSI LOW,4000PSI HIGH F/5 CHARTED MINS,W/4",4.5",AND 7"TEST EQUIPMENT AOGCC REP MATHEW HERRERA WAIVED WITNESS T/TESTING 19:30 - 23:00 3.50 RIGU P DECOMP R/U DUTCH RISER SYSTEM W/NEW D16 QUICK TEST SUB AND ASSOCIATED TEST PLUG,M/U DSM LUBRICATOR AND PRESSURE TEST SYSTEM T/250PSI LOW, I 4000PSI HIGH Ff 5 MINS EACH.(GOOD TEST) -PULL TEST PLUG F/DUTCH RISER BODY, TEST CONNECTION ON D16 QUICK TEST SUB (GOOD TEST)AND LUBRICATE OUT TWC. 23:00 - 00:00 1.00 RIGU P DECOMP CLEAN AND CLEAR RIG FLOOR,MOBILIZE BOT SWEDGE BHA T/RIG FLOOR,BLOW DOWN SURFACE LINES,M/U 4"SAFETY JOINT LOSSES @ MIDNIGHT=137BBLS OA=160PSI 1 FILLING IA W/8.5PPG KWF 6/20/2015 00:00 - 00:30 0.50 RIGU P DECOMP LUBRICATE RIG FLOOR EQUIPMENT 00:30 - 06:00 5.50 RIGU P DECOMP ,M/U BAKER FISHING SWEDGE BHA#1 AS PER 1 BOT REP(RICK),RIH T/OBSTRUCTION @ '1606'MD -VERIFY OD AND ID OF BHA,(SWEDGE=1.7" NOSE,3.875"BARREL). PJSM FOR JARRING,PERFORM PRE-JAR I j DERRICK INSPECTION. 06:00 - 10:00 j 4.00 CLEAN P DECOMP SWEDGE ON COLLAPSED T 26#TBG AS PER BOT REP -DAILEY JARS FIRING W/20K SET DOWN WEIGHT. -MARK BASELINE ON DP W/50K STRING WEIGHT AND PROGRESSIVELY INCREASE SET DOWN WEIGHT ON JARS. -WORK UP T/SETTING DOWN TOTAL STRING WEIGHT WITH 15'OF TRAVEL ONTO THE JARS TO INCRESE IMPACT LOAD. (ESTIMATED 11"MADE BASED ON MARKS ON SWEDGE) - AROUND 100 LICKS 10:00 - 10:30 0.50 CLEAN P DECOMP B/D TOP DRIVE,MONITOR WELL F/10MINS, WELL ON A VAC W/8.5PPG KWF 10:30 - 12:00 1.50 CLEAN P DECOMP POOH F/1609'MD,STANDING BACK DRILL PIPE AND COLLARS LOSSES T/THE WELLBORE=140BBLS @ NOON. OA PRESSURE=140PSI KWF=8.5PPG INTO THE WELLBORE Printed 7/14/2015 11:45:59AM • North America-ALASKA-BP Page 4 of 10 Operation Summary Report Common Well Name R-06 AFE No Event Type:WORKOVER(WO) Start Date:6/17/2015 End Date:6/26/2015 X4-0100M-E:(2,940 000.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/11/1979 12:00:00AM Rig Release:6/18/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292038800 Active datum:R-06 @55.09usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (u ) 12:00 - 14:00 2.00 CLEAN P DECOMP l CONTINUE T/STAND BACK DRILL COLLARS IN DERRICK,UD BAKER FISHING BHA#1 I(SWEDGE HAD SCRAPES ON THE NOSE I CONE UP T/THE GAUGE BARREL OF THE I SWEDGE) 14:00 - 15:00 1.00 CLEAN P DECOMP P/U AND M/U BAKER FISHING BHA#2 W/3-7/8" SWEDGE AND HANDLING EQUIPMENT 15:00 - 19:00 4.00 CLEAN P DECOMP 'RN W/BAKER FISHING BHA#2,TAGGING UP ON COLLAPSE©1607'MD PUW=90KLBS,SOW=94KLBS 19:00 - 23:00 4.00 CLEAN P DECOMP 'SWEDGE ON COLLAPSED 7"CSG @ 1607'MD AS PER BAKER FISHING HAND -START BY SETTING 40KLBS DOWN ON HYDRAULIC JARS AND WORK OUR WAY UP T/ SETTING FULL STRING WEIGHT. -GIVE OURSELVES'15-20'OF TRAVEL AND DROP STRING WEIGHT ONTO JARS, (ESTIMATED 1.5'OF HOLE SWEDGED BASED ON MARKS ON SWEDGE) -COOL JARS AFTER EACH SET OF 20-25 LICKS.(140 LICKS TOTAL) i 23:00 - 00:00 1.00 CLEAN P DECOMP COMPLETE DERRICK INSPECTION,UD SINGLE AND POOH W/STANDS OF 4"DP, }BLOW DOWN TOP DRIVE. I LOSSES @ MIDNIGHT=136BBLS OA PRESSURE=180PSI — l KWF=8.5PPG INTO THE WELLBORE 6/21/2015 100:00 - 00:30 0.50 CLEAN P DECOMP LUBRICATE RIG FLOOR EQUIPMENT 100:30 - 03:00 2.50 CLEAN P DECOMP POOH W/BAKER FISHING SWEDGE BHA#2 -UD DRILL COLLARS T/PIPE SHED. -SWEDGE MARKED FROM NOSE CONE I I THROUGH GAUGE OF THE BARREL. -MONITOR WELL,WELL ON A VAC @ 12BPH, i8.5PPG KWF. 03:00 - 03:30 0.50 FISH P DECOMP 1 CLEAN AND CLEAR RIG FLOOR,LOAD BAKER FISHING ITCO SPEAR,MN SPEAR BHA#3. 1 MONITOR WELL F/10 MINS,ON A VAC i 1 12BPH 8 5PPG KWF 03:30 - 04:30 1.00 FISH P DECOMP ENGAUGE 7"TBG HANGER,CAMERON BOLDS,CLOSE ANNULAR,OPEN HCR KILL T/ MONITOR FOR PRESSURE,PULL HANGER T/ FLOOR W/120KLBS HOOKLOAD. -SIGNS OF 10-20KLBS DRAG WHEN PULLING T/FLOOR. '04:30 - 05:30 1.00 FISH P DECOMP LOAD AND R/U 7'CSG EQUIPMENT AND CAMCO SPOOLING UNIT 05:30 - 06:00 0.50 FISH P DECOMP UD 7"TBG SPOOL AND B/D 7"26#IJ4S CSG FROM BAKER ITCO SPEAR Printed 7/14/2015 11:45:59AM North America-ALASKA-BP Page 5 of 10 Operation Summary Report Common Well Name.R-06 AFE No Event Type:WORKOVER(WO) Start Date:6/17/2015 End Date.6/26/2015 X4-0100M-E:(21940.000.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/11/1979 12:00:00AM Rig Release:6/18/2015 Rig Contractor DOYON DRILLING INC. UWI:500292038800 Active datum:R-06 @55.09usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations • (hr) (usft) 06:00 - 12:00 6.00 FISH P DECOMP POH AND UD 7"26#IJ4S L-80 TBG -10-20KLBS DRAG ALL THE WAY OUT OF THE HOLE. -RECOVERED 20'PUP,40 FULL JOINTS AND 1 FULL COLLAPSED JOINT. -PIN ON COLLAPSED JOINT WAS PARTIALLY COLLAPSED INDICATING THE TUBING STUB •LOOKING UP SHOULDN'T NEED TO BE DRESSED OFF. RECOVERED 23 S/S CONTROL LINE BANDS. LOSSES T/WELLBORE©NOON=114BBLS OA PRESSURE=150PSI MW=8,5PPG KWF 12:00 - 15:00 3.00 FISH P DECOMP CLEAR RIG FLOOR OF 7'HANDLING EQUIPMENT,R/D CAMCO SPOOLER AND EQUIPMENT,LOAD AND STRAP 4"DP 15:00 - 18:00 3.00 FISH N WSEQ DECOMP P/U AND M/U 5.5"BOT INSIDE CUTTER BHA# 4 AND RIH T/2014'MD -SLOW THROUGH 7"STUB AT 1646'MD(NO j 1 TROUBLE ENTERING STUB) -TAG UP ON SSSV @ 2014'MD,PUW= I 68KLBS,SOW=69KLBS 118:00 - 19:00 1.00 FISH- - N WSEQ DECOMP POOH F/2014'MD T/SURFACE W/BOT INSIDE CUTTER BHA#4 19:00 - 23:00 4.00 FISH P DECOMP P/U 3.5"BOT INSIDE CUTTER BHA#5 AND RIH T/2083'MD. -PUW=68KLBS,SOW=71 KLBS,RWT= 71 KLBS C 80RPM FREE TQ=1-2KFT-LBS 23:00 - 00:00 1.00 FISH P DECOMP CUT 7"LNR @2055'MD W/8ORPM,2-3K FT-LBS TQ,4-5BPM,1000PSI -DROP IN PIPE NOTICED ON FLOOR FOLLOWED BY BHA TORQUING UP. (INDICATION THE PIPE WAS CUT) !-MONITOR WELL POST CUT,OBSERVE SMALL BUBBLING IN THE STACK,NO FLOW CHANGE,CLOSE ANNULAR AND CHECK FOR PRESSURE,(NO PRESSURE),CIRCULATE SURFACE T/SURFACE VOLUME @ 4BPM i 450PSI THROUGH MGS. j OA PRESSURE=OPSI LOSSES T/WELLBORE @ MIDNIGHT= 67BBLS MW=8.5PPG KWF 6/22/2015 0000 - 00.30 0.50 FISH P DECOMP CONTINUET/CIRCULATEWELLBORE THROUGH MGS W/A SURFACE T/SURFACE VOLUME. 00:30 - 01 00 0.50 FISH P DECOMP MONITOR WELLBORE F/10 MINS,WELL ON A VAC @ 6BPH W/8.5KWF,BLOW DOWN GAS BUSTER 01:00 - 02:00 1.00 FISH P DECOMP POOH W/BOT CUTTER BHA#5,GAINED 10KLBS OVER PULL ON THE WAY OUT, INDICATING WE MAY HAVE CUT PORTION OF FISH AS WELL. Printed 7/14/2015 11:45:59AM North America-ALASKA-BP Page 6 of 10 Operation Summary Report Common Well Name:R-06 AFE No Event Type:WORKOVER(WO) Start Date:6/17/2015 End Date:6/26/2015 X4-0100M-E:(2,940,000.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/11/1979 12:00:00AM Rig Release:6/18/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292038800 Active datum:R-06 @55.09usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 04:00 2.00 FISH P DECOMP CONTINUE T/POOH W/BOT MECHANICAL CUTTER BHA#5 F/2055'MD T/SURFACE, (FISH RIDING ON MECHANICAL CUTTER) -SECURE 7"TBG ON THE FLOOR AND PULL 4"DP OUT FROM THE TBG. -L/D BOT FISHING BHA#5,CLEAN AND CLEAR RIG FLOOR. 04:00 - 05:00 1.00 FISH P DECOMP R/U 7"TBG HANDLING EQUPMENT AND UD 7" 26#L-80 TBG. 05:00 - 07:00 2.00 FISH P DECOMP UD 7"26#L-80 TBG -9 FULL JNTS(38.97'AVERAGE),SSSVLN, CUT JT=21.32'W/7.5"OD FLAIR !-RECOVERED 5 S/S BANDS AND CONTROL LINE(HARD T/DETERMINE FULL LENGTH OF CONTROL LINE SINCE IT WAS BALLED UP) 07:00 - 07:30 0.50 FISH P DECOMP 'R/D 7"TBG EQUIPMENT,CLEAN AND CLEAR RIG FLOOR 07:30 - 12:00 4.50 FISH P DECOMP M/U BOT MECHANICAL CUTTER BHA#6,RIH T/TOP OF 7"©2055'MD SET DOWN 2KLBS ;AND ROTATE,SLIDE THROUGH T/4553'MD PUW=tO1KLBS,SOW=103KLBS 1 LOSSES T/WELL @ NOON=64BBLS OA PRESSURE=0 PSI 8.5PPG KWF PUMPED INTO WELL(6-8BBL LOSSES/HR) 12:00 - 12-30 0.50 FISH P DECOMP ,SERVICE AND INSPECT RIG FLOOR EQUIPMENT/PIPE SKATE EQUIPMENT 12:30 - 18:00 5.50 FISH P DECOMP CONTINUE T/RIH W/BOT 5.5"LNR CUTTER F/ • 4553'MD T/8891'MD(TOP OF LNR CONFIRMED W/TAG) -PUW=162KLBS,SOW=145KLBS,RWT= 153KLBS @ 80RPM -PULL CUTTER UP 140'T/8751'MD(BACK CALCULATED AS MID JNT OF 7"TBG) 18:00 - 18:30 0.50 FISH P f DECOMP CUT 7"LNR @ 8751'MD W/4BPM,570PSI, 80RPM,4-5K FT-LBS TQ -NOTICE PUMP PRESSURE REDUCE AS CUTTERS EXPAND IN CASING,SEE JUMP IN WEIGHT INDICATOR AND MARK ON DP I INDICATING THE CSG HAD FALLEN,SEE SUBSTANTIAL REDUCTION IN TORQUE 1 INDICATING THE CUTER BLADES WERE PUSHED OUT AS THE TBG CUT AND FELL 18:30 - 21:00 2.50 FISH P DECOMP CIRCULATE BU THROUGH MGS @ 5BPM 770PSI 21:00 - 21:30 0.50 FISH P DECOMP MONITOR WELLBORE F/10MINS,WELLONA VAC @ 8BPH W/8.5PPG KWF -BLOW DOWN TD AND CHOKE _ 21:30 - 00:00 2.50 FISH P DECOMP POOH F/8751'MD T/3795'MD -PUW=162KLBS,SOW=145KLBS I LOSSES T/WELLBORE=86BBLS OA PRESSURE=OPSI 8.5PPG KWF PUMPED INTO WELL(6-8BBL • LOSSES/HR) 6/23/2015 00:00 - 00:30 0.50 FISH P DECOMP SERVICE AND INSPECT RIG FLOOR EQUIPMENT/PIPE SKATE EQUIPMENT. 00:30 - 02:00 1.50 FISH P DECOMP CONTINUE T/POOH W/BOT MECHANICAL CUTTER BHA#6 F/3795'MD,STANDING BACK DP IN DERRICK Printed 7/14/2015 11:45:59AM • North America-ALASKA-BP Page 7 of 10 Operation Summary Report Common Well Name:R-06 AFE No Event Type:WORKOVER(WO) Start Date:6/17/2015 End Date:6/26/2015 X4-0100M-E:(2,940,000.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:DOYON 16 I Spud Date/Time:10/11/1979 12:00:00AM Rig Release:6/18/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292038800 Active datum:R-06 @55.09usft(above Mean Sea Level) Date From-To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 02:30 0.50 FISH P � DECOMP LID BOT MECHANICAL CUTTER BHA#6. -MONITOR WELL,WELL ON A VAC 6-8BPH, 8.5PPG KWF. 02:30 - 04:30 2.00 FISH P DECOMP RIH T/TOF @ 2055'MD AND ESTABLISH PARAMETERS. -PUW=74KLBS,SOW=77KLBS. 04:30 - 07:30 3.00 FISH P DECOMP ENGAGE FISH AS PER BOT REP. -ACQUIRE SLOW CIRCULATING RATES. PUW WITH FISH=130 KLBS. MONITOR WELL FOR(10)MINUTES.LOSS RATE=6 BPH,8.5 PPG BRINE. 07:30 - 09:00 1.50 FISH P i DECOMP L/D BOT SPEAR BHA#7. 09:00 - 09:30 0.50 FISH P DECOMP R/U 7"EQUIPMENT ON RIG FLOOR. 09:30 - 12:00 2.50 FISH P DECOMP POOH AND UD 7"26#L-80 IJ4S TUBING. -1.../D 45 JOINTS.PUW=150 KLBS,SOW=145 KLBS. • I LOSSES TO WELL PAST(12)HOURS=65 BBLS,8.5 PPG BRINE. OA=OPSI. 12:00 - 12:30 0.50 FISH P DECOMP PTSM.SPCC AND EQUIPMENT CHECKS [.AROUND THE RIG. CROWN-O-MATIC AND SPCC CHECKS. GOOD. 12:30 - 17:30 5.00 FISH P DECOMP POOH AND L/D 7"26#L-80 IJ4S TUBING. -UD TOTAL OF(171)JOINTS TO PIPE SHED, UD(1)CUT JOINT=19.08'. 17:30 - 19:00 '1.50 FISH R DECOMP R/D 7"HANDLING EQUIPMENT. -CLEAR AND CLEAN RIG FLOOR. 19:00 - 23:30 4.50 DHB P i DECOMP PJSM.P/U AND RIH WITH 9-5/8"HES RBP. I-RIH FROM SURFACE TO 8,665'MD.PUW= 165 KLBS,SOW=140 KLBS. -SET RBP AT 8,665'MD,CENTER OF i ELEMENT. 23:30 - 00:00 0.50 DHB P DECOMP POOH AND STAND BACK DP IN DERRICK -POOH FROM 8,665 MD TO 8,263'MD. LOSSES TO WELL PAST(24)HOURS=129 BBLS,8.5 PPG BRINE. OA=0 PSI. _ I NO SLOW CIRCULATING RATES THIS TOUR. 6/24/2015 00:00 - 01:00 1.00 DHB P DECOMP •PTSM.SPCC AND EQUIPMENT CHECKS AROUND THE RIG. -CROWN-O-MATIC AND SPCC CHECKS. GOOD. I CONTINUE STAND BACK DP IN DERRICK -POOH FROM 8,263'MD TO 7,979'MD.PUW= •155 KLBS,SOW=130 KLBS. 01:00 - 02:30 1.50 DHB P DECOMP PJSM.PRESSURE TEST CASING AGAINST RBP. • R/U TEST EQUIPMENT ON RIG FLOOR. -PRESSURE TEST TO 250 PSI LOW,4,000 PSI HIGH FOR(30)CHARTED MINUTES.PASSES BP TESTING CRITERIA,0 PSI LOSS OVER 30 MINUTE TEST. 02:30 - 03:00 0.50 DHB P I DECOMP PJSM.P/U HES STORM PACKER. -RIH ON(1)STAND AND SET STORM PACKER AS PER HES REPRESENTATIVE. Printed 7/14/2015 11:45:59AM North America-ALASKA-BP Page 8 of 10 Operation Summary Report Common Well Name:R-06 AFE No Event Type:WORKOVER(WO) Start Date:6/17/2015 End Date:6/26/2015 X4-0100M-E.(2,940,000.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/11/1979 12:00:00AM Rig Release:6/18/2015 Rig Contractor.DOYON DRILLING INC. UWI:500292038800 Active datum:R-06 @55.09usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth • Phase Description of Operations — ..._ (hr) (usft) 03:00 - 03:30 0.50 DHB P DECOMP PJSM PRESSURE TEST STORM PACKER. -PRESSURE TEST TO 250 PSI LOW,2,500 PSI �;HIGH FOR(5)CHARTED MINUTES.GOOD 1 TEST. --- i 03:30 - 04:30 1.00 WHSUR P DECOMP I BLOW DOWN ALL LINES. -DRAIN BOPE STACK. -PULL WEAR RING. 04:30 - 06:30 2.00 WHSUR P DECOMP PJSM.ND BOPE AND TUBING SPOOL I -REMOVE TUBING SPOOL FROM CELLAR. 06:30 - 08:00 1.50 WHSUR P DECOMP CAMERON REPAIR CASING SPOOL LDS. -CHANGE OUT PACKOFF. 08:00 - 09:00 1.00 WHSUR P DECOMP PJSM.N/U NEW TUBING SPOOL. -INSTALL TEST PLUG AND SECONDARY IA VALVE. 09:00 - 10:30 I 1.50 WHSUR P DECOMP PRESSURE TEST PACKOFF TO 250 PSI LOW, 3,500 PSI HIGH FOR(30)CHARTED MINUTES. GOOD TEST. 10:30 - 12.00 1.50 BOPSUR P DECOMP PJSM.N/U BOPE. -PREPARE CELLAR TO CHANGE OUT UPPER ' •RAMS. i ! I ' . I i LOSSES TO WELL PAST(12)HOURS=0 BELS, !8.5 PPG BRINE. OA=0 PSI. NO SLOW CIRCULATING RATES ACQUIRED. 12:00 - 14:00 2.00 BOPSUR P DECOMP PTSM.SPCC AND EQUIPMENT CHECKS 1 i !AROUND THE RIG. '-CROWN-O-MATIC AND SPCC CHECKS. GOOD. •i I -REMOVE 7"UPPER PIPE RAMS. ' -INSTALL 3-1/2"X 6"VBR RAMS. I-TEST NEW TUBING SPOOL BREAKS AND UPPER RAMS/DOOR SEALS TO 250 PSI LOW, _ 4,000 PSI HIGH FOR(5)MINUTES. 14:00 - 15:00 1.00 BOPSUR P DECOMP 1 R/D TEST EQUIPMENT. -BLOW DOWN SURFACE LINES. 15:00 - 16:00 1.00 DHB P DECOMP RIH AND RETRIEVE HES STORM PACKER. RELEASE STORM PACKER. __ __ -POOH AND UD STORM PACKER. 16:00 - 18:00 2.00 DHB P DECOMP I RIH AND RETRIEVE HES RBP. 1-ENGAGE AND RELEASE RBP AS PER HES REPRESENTATIVE. BULLHEAD 110 BBLS AT 10 BPM=1,440 PSI. I -SHUT DOWN AND MONITOR WELL FOR(10) MINUTES.LOSS RATE=10 BPH,8.5 PPG -- I BRINE. '18 :00 - 19:30 1.50 DHB P i , DECOMP 1 PJSM SLIP AND CUT 60'DRILLING LINE. 119:30 00:00 4.50 T DHB i P DECOMP I PJSM.POOH WITH HES RBP. -L/D DP TO SHED 1X1. -POOH FROM 8,605'MD TO 3,746'MD.PUW= 1 93 KLBS. LOSSES TO WELL PAST(12)HOURS=49 BBLS,8.5 PPG BRINE. 'BULLHEAD LOSS TO WELL=110 BBLS,8.5 'PPG BRINE. j OA=O PSI. NO SLOW CIRCULATING RATES ACQUIRED. I Printed 7/14/2015 11:45:59AM • North America-ALASKA-BP Page 9 of 10 Operation Summary Report Common Well Name:R-06 AFE No Event Type:WORKOVER(WO) Start Date:6/17/2015 End Date:6/26/2015 X4-0100M-E:(2,940.000.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/11/1979 12:00:00AM Rig Release:6/18/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292038800 Active datum:R-06©55.09usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) I (usft) 6/25/2015 00:00 - 00:30 0.50 DHB P DECOMP PTSM.SPCC AND EQUIPMENT CHECKS AROUND THE RIG. -CROWN-O-MATIC AND SPCC CHECKS. I GOOD. 00:30 - 04:00 3.50 DHB i P DECOMP PJSM.POOH WITH HES RBP. -L/D DP TO SHED 1 X 1. -POOH FROM 3,746'MD TO SURFACE. 04:00 - 05:30 1.50 DHB P ' DECOMP PJSM.UD HES 9-5/8"RBP. 05:30 - 07:00 1.50 DHB P DECOMP 'r CLEAR AND CLEAN RIG FLOOR. '-PULL WEAR RING. -R/U 4-1/2"COMPLETION EQUIPMENT ON RIG FLOOR. 07:00 - 12:00 5.00 RUNCOM P RUNCMP PJSM.RIH WITH 4-1/2"12.6#L-80 TC-II INCOMPLETION. ;-BAKER LOC ALL CONNECTIONS BELOW 9-5/8"PACKER. I-USE JET LUBE SEAL GUARD THREAD ICOMPOUND. -USE TORQUE TURN SERVICES TORQUING 'EACH CONNECTION TO 3,850 FT-LBS. -RIH FROM SURFACE TO 1,895'MD.PUW=60 KLBS,SOW=63 KLBS. -LOSSES TO WELL PAST(12)HOURS=102 BELS,8.5 PPG BRINE. OA=0 PSI. NO SLOW CIRCULATING RATES ACQUIRED. 12-00 - 12:30 0.50 RUNCOM P RUNCMP PTSM.SPCC AND EQUIPMENT CHECKS AROUND THE RIG. -CROWN-O-MATIC AND SPCC CHECKS. GOOD. 12.30 - 14 00 1.50 RUNCOM . P RUNCMP PJSM.RIH WITH 4-1/2"12.6#L-80 TC-II COMPLETION. -USE JET LUBE SEAL GUARD THREAD COMPOUND. -USE TORQUE TURN SERVICES TORQUING EACH CONNECTION TO 3,850 FT-LBS. -RIH FROM 1,895'MD TO 3,206'MD.PUW=74 KLBS,SOW=74 KLBS. 14:00 - 14:30 0.50 RUNCOM N RREP 3,206.00 RUNCMP REPAIR PIPE SKATE EJECTOR. 14:30 - 23:00 8.50 RUNCOM P RUNCMP RIH WITH 4-1/2"12.6#L-80 TC-II COMPLETION. -USE JET LUBE SEAL GUARD THREAD COMPOUND. USE TORQUE TURN SERVICES TORQUING EACH CONNECTION TO 3,850 FT-LBS. -RIH FROM TO 3,206'MD 8,749'MD,TAG TOP OF 7"STUB.PUW=131 KLBS,SOW=120 KLBS. -ROTATE 1/2 TURN AT SURFACE AND WORK PIPE,WORK INTO 7"STUB. } -RIH FROM 8,749'MD TO 8,756'MD. 23:00 - 00:00 1.00 RUNCOM P RUNCMP PJSM.P/U AND M/U TUBING HANGER AS PER CAMERON REPRESENTATIVE. -RIH AND LAND HANGER AT 8,779'MD. -CAMERON RILDS. I LOSSES TO WELL PAST(24)HOURS=195 BBLS,8.5 PPG BRINE. OA=OPSI. j NO SLOW CIRCULATING RATES ACQUIRED. Printed 7/14/2015 11:45:59AM • North America-ALASKA-BP Page 10 of 10 Operation Summary Report Common Well Name:R-06 AFE No Event Type:WORKOVER(WO) Start Date:6/17/2015 End Date:6/26/2015 X4-0100M-E.(2,940,000.00) Project:Prudhoe Bay Site:PB R Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/11/1979 12:00:00AM Rig Release:6/18/2015 Rig Contractor.DOYON DRILLING INC. UWI:500292038800 Active datum:R-06 @55.09usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations r) 6/26/2015 00:00 01:00 1.00 RUNCOM P (u ) - - RUNCMP �PTSM.SPCC AND EQUIPMENT CHECKS 'AROUND THE RIG. CROWN-O-MATIC AND SPCC CHECKS. GOOD. PJSM.PRESSURE TEST LINES.REVIEW PRESSURE CROSSCHECK LIST WITH CREW. ALL CHALLENGE QUESTIONS ANSWERED. -PRESSURE TEST LRS LINES TO 4,000 PSI. GOOD TEST. -PRESSURE TEST RIG SURFACE LINES TO 4.000 PSI.GOOD TEST. 01:00 - 03:30 2.50 RUNCOM ! P RUNCMP PJSM.BULLHEAD CORROSION INHIBITED 8.5 PPG BRINE. -BULLHEAD 470 BBLS DOWN IAAT 5 BPM= 1.050 PSI. 03:30 - 05:00 1.50 RUNCOM P RUNCMP PJSM.BULLHEAD FREEZE PROTECT DIESEL WITH LRS. -BULLHEAD 120 BBLS DIESEL DOWN IAAT 5 BPM=975 PSI. -SWAP OVER TO TUBING AND BULLHEAD 35 BBLS DIESEL DOWN TUBING AT 5 BPM=1,260 PSI. 05.00 - 10:00 5.00 RUNCOM P RUNCMP PJSM.DROP BALL AND ROD AND SET PACKER AS PER HES REPRESENTATIVE. -PRESSURE TEST TUBING TO 250 PSI LOW, 4.000 PSI HIGH FOR(30)CHARTED MINUTES. GOOD TEST. -BLEED TUBING PRESSURE DOWN TO 1,500 PSI AND HOLD. PRESSURE TEST IA TO 250 PSI LOW,4,000 PSI HIGH FOR(30)CHARTED MINUTES. GOOD TEST. -WTLAPPROVAL TO PROCEED. 10:00 10:30 0.50 RUNCOM P RUNCMP BLOW DOWN LINES,RIG DOWN LRS. 110:30 - 11:30 1.00 RUNCOM P RUNCMP CAMERON SET TWC. -PRESSURE TEST FROM ABOVE TO 250 PSI LOW,4,000 PSI HIGH FOR(5)MINUTES. GOOD TEST. 11:30 - 12:00 0.50 RUNCOM P RUNCMP BLOW DOWN LINES,DRAIN BOPE STACK. 12:00 - 13:30 1.50 BOPSUR P RUNCMP PJSM.N/D BOPE. -RIG DOWN FLOOR EQUIPMENT. 13:30 - 15:00 1.50 WHSUR P RUNCMP PJSM.N/U CAMERON 13-5/8"X 4-1/16" ADAPTER FLANGE AND 4-1/16"TREE. 15:00 - 16:00 1.00 WHSUR P RUNCMP CAMERON PRESSURE TEST HANGER VOID AND SEALS. -PRESSURE TEST TO 250 PSI LOW,5,000 PSI HIGH FOR(30)MINUTES.GOOD TEST. 16:00 17:00 1.00 WHSUR P RUNCMP PJSM.PRESSURE TEST 4-1/2"TREE TO 250 PSI LOW,5,000 PSI HIGH FOR(5)MINUTES. GOOD TEST. 17:00 - 18:00 1.00 RIGD P RUNCMP PJSM.MOVE RIG OFF WELL R-06A. -PAD OPERATOR NOTIFIED. -WSL PRESENT FOR PULLING RIG OFF WELL R-06A. RIG RELEASE AT 18:00 HRS ON 06/26/2015. Printed 7/14/2015 11:45:59AM TREE= 0W4-1/16' ,-.43LFEAD= BAKER Y R-06A SA S READINGS AVERAGE ppmWHEN ONMI**WELL�REQUIRES A ACTUATOR= BAKER C OKB aEV= 5509' I 1 SSSV WHIN ON MI""MAX DOGLEG-24.5"@ 10680'""' BF.BEV=-- —21.31' KOP= 3200. ___,"CONDUCTOR, ? I ' 2156' H4-1/2"l X NP,D=3.813' l x Angie= 95"@ 1121T #, Datum MD= 9960' D= 1_._.. 2583' H 9-5/8'DV FKR Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,D=12.347' -{ 2661' II8641' 4-1/2" " Minimum ID =2.968" @ 8882' BKR 47B2 LTP g 8672' --{9-5/8'X 4-1/2'I-ES TNT FKR D=3.903" I 1 8708' --14-112"FES X NP.D=3.813" ' v 8779' H4-1/2"HES XN NIP,U=3.725' 7"TBG STUB(06/22/15) H 8724' - 8810 H4-1/2"HALF M1r E SHOE D=3.958" 4-1/2"TBG,12.6#,L-80 TCI.0152 bpf,D=3.958' -I 8810' 1 888T 1-{BKR 4782 LTP,D=2.958"(4'GS PROFLE) 8890' -4.375'-3.75'BKR DEPLOY SLV, D=400` 300" 8899' -14.375"-3.75"XO 3-1/2",D=2.99" 7"TBG,26#,L-80,.0383 bpf,D=6.276" H 9086' \ 9086' H7"X 5-112"XO,D=4.892" L 9098' -15-1/2"OTIS XA SLD SLV,D=4.562' IP. 9135' -19-5/8'X 5-1/2"TIW PKR,D=4.75' I 9187' -I5-1/2"PARKER X NP,ID=4.56T BEHIND CT LNR ' 9209' H5-1/2"PARKER XN NP,D=4.56" 5-1/2"TBG,17#,L-80, 0228 bpf,ID=4.892" H 9221' r 922T H9-5/9"X 7"TIW 11 K SLV,D= " nJJJ --" 9229' H5-112"SEAL ASSY.W/O SEALS 9-5/8'CSG,47#,L-80 BUTT,D=8.681" H 9740' 9235' -19-5/8"X 7"TM/HGR D= 7'W-IPSTOCK vi/RA TAG @ 9870' --1 9862' L. 7"MLLOUT WINDOW (R-06A) 9862'-9870' PERFORATION SUMMARY FEF LOG: COLLAR LOG ON 03/15/01 ANGLE AT TOP PERE 31"@9880' Note:Refer to Roduction DB for historical pert data /�1�444..4f1 SIZE SPF INTERVAL Opn/Sqz SHOT SCZ (►•9�4�*�*�*�*�1 94.1..4 2-1/2"+ 2 9880-9910 0 03/16/01 19.0.491 99.99 1 TD 12308' OPEN HOLE 12038-12289 0 01/07/99 �•�•�•�•�•�•�1� 3-1/2"LNR,9.3#,L-80 STL, -{ 12038' .0087 bpf.D=2.992' 491 7'LNR,29#,L-80,.0371 bpf,D=6.184" - 10681' PBTD(TAGGED 01/07/99) H 12289' DATE REV BY CONVENTS DATE REV BY COtilMENTS PRIAHOE BAY UNIT 1 10/04/79 PN-1 ORIGINAL COMPLETION 07/08/15 SMYJMD FINAL ODEAPPROVAL WELL: R-06A 01/19189 D-16 RWO PERMIT No:1981270 01/07/99 CTD SIDETRACK(R-06A) AR No: 50-029-20388-01 06/26115 D-14 RWO SEC 32,T12N, R13E 728'FSL&1399'FWL 06/29/15 JMD DREG HO CORRECTIONS 07/08/15 JMD TALLY DEPTH SI-*T-CORRECTED BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday, August 02, 2015 11:02 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Superintendent;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad RJ; Peru, Cale;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: UNDER EVALUATION:Injector R-06A (PTD#1981270) Rig Workover Complete MIT-IA Passed All, Injector R -06A (PTD #1981270) underwent a rig Workover that was completed on 06/26/2015. The rig Workover replaced the tubing and packer. The well passed a MIT-IA on 06/26/2015. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Under Evaluation and may be put on injection. • Well status is Under Evaluation • Annuli are fluid packed • A SSSV is not required Please use caution while placing the well on injection due to fluid packed annuli and the possibility for annular fluid expansion. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator GWGlobal Wells Organization SCANNED AUG 0 32015 Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com Fro . < D&C Well Integrity Coordinator Sent: Thurs ugust 16, 2012 10:33 AM To: 'Regg, James B Chris Wallace (chris.wallace@alaska.gov) Subject: NOT OPERABLE: Inj R-06A (PTD #1981270) MIT-IA Failed Jim/Chris, WAG Injector R-06A(PTD#1981270) has been a LTSI injector. In pr tion for returning the well to MI service, a pre- injection MIT-IA was performed on 08/16/2012 that failed. The failing tesisiiitti a lack of two competent barriers in the wellbore. The well will remain shut in and continue to be reported on the AOGCC rly Injection Report. 1 \\ • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 , ~~ 20C~ ~ ~ ~ ~~i.f~~'~~ ~ i.. .~ July 10, 2009 ~IU~ 1 ~ ~9A~ Mr. Tom Maunder (~ ~ 1 ~'~ Alaska Oil and Gas Conservation Commission "t~ 333 West 7th Avenue _ ~ -~ ~ ~ ~ ~ ~ Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB R-Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB R- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Torin Roschinger, at 659-5102. Sincerely, Anna Dube, P.E. 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) R-pad Date Revised 7/10/2009 Well Name API # PTD # 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 R-02 50029203540000 1781000 1.25 NA 1.25 NA 6.8 5/11/2009 R-03A 50029203640100 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 50029203740000 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 50029203800100 1972500 0 NA 0 NA 3 5/13/2009 R-06A 50029203880100 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 50029205230100 2000100 2.25 NA 2.25 NA 43 5/11/2009 R-08 50029205480000 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 50029206090100 1982330 3.25 NA 325 NA 17.85 5/14/2009 R-10 50029206180000 1810930 2 NA 2 NA 14.5 6/22/2009 R-11A 50029208930100 1982060 0.25 NA 0.25 NA 1.7 6/11/2009 R-12 50029209210000 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 50029209290000 1830440 24 NA 24 NA 96.9 6/23/2009 R-14 50029209090100 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 50029209170100 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 50029206860000 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 50029206770100 1981380 4 NA 4 NA 272 5/15/2009 R-18B 50029206330200 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 50029206370100 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 50029209970000 1831200 0.25 NA 0.25 NA 3.4 6/13/2009 R-22 50029210050000 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 50029210130100 1972020 2.25 NA 2.25 NA 16.2 6/12/2009 R-24 50029212320000 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 50029222780100 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 50029215470000 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 50029215570000 1860510 0.25 NA 0.25 NA 1.7 6/11/2009 R-29 50029222750100 1971070 20 3.9 1.25 NA 11.05 5/14l2009 R-31 A 50029222770100 2021500 1.5 NA 1.5 NA 8.5 5l11 /2009 R-32A 50029224130100 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 50029224080000 1931530 0 NA 0 NA 2.5 5/18l2009 R-35 50029224240000 1931810 0.25 NA 0.25 NA 1.7 5/11/2009 R-36 50029225220000 1941440 3.25 NA 3.25 NA 44.2 5/14/2009 R-39A 50029225260100 1960840 2 NA 2 NA 22.1 5/11/2009 R-40 50029229260000 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 50029233990000 2081530 3.25 NA 3.25 NA 22.1 5/12/2009 • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 26, 2009 ~ ~ I~„~ l`~ ~, . b~ Mr. Tom Maunder ~, Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of R-Pad Dear Mr. Maunder, • ~~ ~ . ~ ~UL A 1 2009 ~~~~k~ ~i~ ~ Ga~ ~on~. ~or~~~~~i~~ Anchor~~ Enclosed ptease find a spreadsheet with a list of wells from R-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, 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, ~ a`~~J'~3~~ '~rt~ ~ ._ ~~~~ Torin Roschinger BPXA, Well Integrity Coordinator s • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date R-pad 6/25/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitoN sealant date ft bbls ft na al R-02 1781000 1.25 NA 1.25 NA 6.8 5/11/2009 R-03A 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 1972500 0 NA 0 NA 3 5/13/2009 R-06A 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 2000100 2.25 NA 2.25 NA 43 5/11/2009 R-08 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 1810930 2 NA 2 NA 14.5 6/22/2009 R-f 1 A 1982060 0.25 NA 0.25 NA 1.7 6/11 /2009 R-12 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 1830440 3.75 NA 3.75 NA 76.5 6/22/2009 R-14 2021560 0 NA 0 NA 0.04 5/1 S/2009 R-15A 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 1981380 4 NA 4 NA 27.2 5/15/2009 R-18B 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 1831200 0.25 NA 0.25 NA 3.4 6/13/2009 R-22 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 1972020 2.25 NA 2.25 NA 16.2 6/12/2009 R-24 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 1860510 0.25 NA 0.25 NA 1.7 6/11/2009 R-29 1971070 20 3.9 1.25 NA 11.05 5/14/2009 R-31A 2021500 1.5 NA 1.5 NA 8.5 5/11/2009 R-32A 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 1931810 025 NA 0.25 NA 1.7 5/11/2009 R-36 1941440 3.25 NA 3.25 NA 44.2 5/14/2009 R-39A 1960840 2 NA 2 NA 22.1 5/11 /2009 R-40 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 2081530 3.25 NA 3.25 NA 22.1 5/12/2009 H-09 (PTD#1800640), M-14 (P~#1801090), R-02 (PTD#1781000), R~ (PTD#19812... Page 1 of 1 P.~u ~- ~A Regg, James B (DOA) ~ C~ `~-- ~ 27 From: Regg, James B (DOA) ~~ ~~~~ /0~ Sent: Tuesday, June 16, 2009 11:24 AM ~ 1 To: 'Roschinger, Torin T.'; Maunder, Thomas E (DOA); Engel, Harry R Cc: NSU, ADW Well Integrity Engineer; Schwartz, Guy (DOA sponsored) Subject: RE: H-09 (PTD#1800640), M-14 (PTD#1801090), R-02 (PTD#1781000) R-06 (PTD#1981270) - Year Compliance Testing ~/ Postponing MITs until completion of GC2 turnaround and wells H-09, M-14, R-02, and R-06 are put back on injection (and stabilized) is acceptable. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Roschinger, Torin T. [mailto:Torin.Roschinger@bp.com] Sent: Monday, June 15, 2009 3:47 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSU, ADW Well Integrity Engineer ~~.;~, A Subject: H-09 (PTD#1800640), M-14 (PTD#1801090), R-02 (PTD#1781000), 6~0f (PTD#1981270) 4-Year Compliance Testing Jim, ~'-~A The following water injectors H-09 (PTD#1800640), M-14 (PTD#1801090), R-02 (PTD#1781000), and R..Ag (PTD#1981270) are due for their 4-year regulatory compliance testing this month. However, because the GC2 turn-around will continue until July 7th the injectors will remain shut-in. Preferably, we would like to wait until GC2 is operating and the injectors are back online and stabilized rather than testing them shut-in. Please let us know if postponing the 4-year tests until after GC2 turn-around is acceptable. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 6/16/2009 ) ) BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 RECEIVED AUG I 2 2005 August 11 , 2005 A'aska Oil & Gas Cons. Commission Anchorage Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 ~,,-(.. {\ k"n,¡¡¡::.r' nUG "'~ íl ?OO¡¡:: t,;)~J1¡ð~h:!~;;~..) H 1. Jl. L· ~) Subject: R-06A (PTD 1981270) Application for Cancellation of Sundry #303-353 Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 303-353. The sundry was for continued water injection with rapid TxlA communication. The well has been repaired and passed an AOGCC witnessed MIT -IA to 4000 psi. The well has been reclassified as a normal well on WAG injection. With the cancellation of the sundry, the well will be removed from the Monthly Injection Report. If you require any additional information, please contact Anna Dube or Joe Anders at (907) 659-5102. Sincer~y, "/ í Î d I'vv.Þ...l, 0vJ1'e- Anna Dube Well Integrity Coordinator Attachments Application for Sundry Cancellation form 10-404 ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. Repair WellD Plug PerforationsD Pull Tubing 0 Perforate New PoolD Operation Shutdown 0 Perforate 0 4. Current Well Class: Development 0 Stimulate D WaiverD OtherŒ) CANCEL Time Extension D SUNDRY Re-enter Suspended WellD 5. Permit to Drill Number: 198-1270 6. API Number 50-029-20388-01-00 ExploratoryD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.09 8. Property Designation: ADL-028278 11. Present Well Condition Summary: StratigraphicD 9. Well Name and Number: R-06A 10. Field/Pool( s): Prudhoe Bay Field / Prudhoe Oil Pool Service Œ1 Total Depth measured 12308 feet true vertical 8976.1 feet Plugs (measured) None Effective Depth measured 12289 feet Junk (measured) None true vertical 8975.7 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 20" 91.5# H-40 34 144 34.0 144.0 1490 470 SURFACE 2627 13-3/8" 72# L-80 34 - 2661 34.0 - 2660.6 4930 2670 PRODUCTION 9706 9-5/8" 47# L-80 34 - 9740 34.0 - 8671.3 6870 4760 LINER 635 7" 29# L-80 9227 - 9862 8226.1 - 8779.4 8160 7020 LINER 3146 3-1/2" 9.3# L-80 8892 - 12038 7938.6 - 8967.3 10160 10530 Measured depth: 12038 - 12308 True vertical depth: 8967.28 - 8976.09 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 7" 26# L-80 @ 31 5-112" 17# L-80 @ 9086 9-5/8" DV Packer @ 2583 4" Bocat 47 B-2 LNR Top PKR @ 8882 5-1/2" TIW Packer @ 9135 7" Top Packer @ 9235 9086 9221 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Oil-Bbl Representative Daily Averaqe Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 8365 9468 Tubing Pressure 965 1019 Prior to well operation: Subsequent to operation: 14. Attachments: ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD DevelopmentD Service Œ] Copies of Logs and Surveys run _ Daily Report of Well Operations_ WAG D GINJD WINJŒ WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: 303-353 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Anna Dube Printed Name A~na ~.na be r:' n J1 Signature --0( /\.A_..(. Å cU { ! ~ Phone Well Integrity Coordinator 659-5102 Date 8/11/05 Title RBDMS BFL AUG 1 S 2005 RECEIVE[) AUG 1 2 Z005 Form 10-404 Revised 4/2004 Alaska Oil & Gas Cons. Commì~;s<Hl Anchorage R-06A (PTD #1981270) Internal Waiver Cancellation ) ) S·u.~j.e·~~.:..·.~.~8·~;A-.·..(prJl)...#1.~.·~..1.·2.7.0)· Int~rn~l..·Y¡~iv.er.··.C·.$1SellåtiOn· F~~ltlf"9\lþy,~aT~" ~~na.I?ube(~13P .çQl11? :o~te :llhµ,· JL~ug2.005 .lO:10:28.;().&OO· Winton and Jim, The internal BP waiver for rapid TxlA communication on well R-06A (PTO #1981270) has been cancelled. The well has been repaired and passed an AOGCC witnessed MIT-IA on 06/19/05. It has been reclassified as a normal well available for WAG injection. The application for cancellation of sundry #303-353 has also been sent by mail. Please let us know if it is not received in the next couple of days. Well R-06A will also be removed from the Monthly Injection Report given the cancelled sundry and waiver. Please let me know if you have any questions. Thank you, }lnna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659..5102 Pager: (907) 659-5100 x1154 ;SClJt~~ ~~ tE [,I (~F 11) :;~ 1] 2. 0 (P; ",'¡J _..1 "-.' .~. . ,,'-.)J 1 of 1 8/11/2005 12:53 PM ) ') 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 OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay I PBU I Pad R 06/19/05 Rob Mielke Packer Depth Pretest Initial 15 Min. Well R-06A Type Inj. F TVD 8,147' Tubing 1,000 1,000 1,000 I P.T.D. 1981270 Type test P Test psi 2,037 Casing 10 4,020 3,980 Notes: MIT-IA to 4000 psi. Evaluate TxlA communication for MI injection. AOGCC Declined to Witness Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Test Details: SCANNED JUt () C'.\ 20 n ,;:: (,; Z u;::¡ TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 2005-0619_MIT _PBU_R-06A.xls \qcn' / I v-1 30 Min. 1,000 Interval 0 3,960 P/F P Interval P/F Interval P/F Interval P/F Interval P/F INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) f>TD J:Ì , qfJ-I~7 Notice of Waive red Well , ,,' '" ~,,' J "'" ì"~'--=~"'.>3 WELL TYPE: Water Injeçtor DATË: WELL~ R-oaA 12"'25-03 b\ioCUonData; œKI9l03:'tOOO, B'NPD(Ö' 1200 psi. PièsstJre.~ , JnJ~~ng, 51 T~b¡ng 122Q þ~ eac 'Pst 9--518 ~1' ANN 1600 psi" 1OQ þ..~i '13~ S/8£'AN N æ:t~f 240 (>Št ..' ..',' REAS.ONFOR,NOTIGE; , '.. ..' Rt:bpjg "1r,.)CIA,Ç()rnrnLu~iç~tIQn ' TUBING BY 9..5/811 COMMUNICATION? ...... ., n IL 11' ~..., ......,..".:.....-:".-..- YES xx NO '_.- ,~'~'ftrIAFåÜed':O1}Ö1¡Ó3~'l[R:::l.25BP~'@ ¿3oòpsi. " '" , "',, , ,,' '...., ' , ,;...:" . : 9..5I8'~ BY 13..:J81i COMMUNICATION? ."yes " ' .....,-..-....._v..'" , . NO XX , .' CMfl-f~ }\Pä6$e<~ tÖ25óâ psi.. 02126.:03. ",' ,..111 -CA. Pa.:;~Ad tL") 2000 þ.-"¡ - ú5l11/CI3. ,c¡, ..:¡ir"":~ .. 2 Levüls nrÞrot~,-;1¡L'm ~~r~ pt,nd1.H:!luH and $urface casings have been tested to at least 1.:2 times the operating pr~ssure ;i::ni!s. II AOGCC issvød Sundry j 3:3~353 dated '12/02/03 for continl.;'ed w3ier injaction on:y. :.. This v,tai\'gr su~rc6edE tha wÇlJver dated 0:5/17;'03. " .. " .,.., ~..............._mlllll"""""" "1J.nrc:~" , PLAN Of ACTION: Any de1JîaHon from this waIver must be pre..approved by the Wells GrmJ~)' and tha Operati.ans Managør. G Altow ?W¡ Ihjocti:on - he Ml inJection allowcd. .. Tubing and IA prE;:..r;SL2iA~ rfJ?Y l~q~,t;\¡¡(1'.P'. .¡. Monitor vJ!?1! I'~ë,ad pressuniH:i i-ind 109 d~H¡, . Perform the following waiver comptlance testing: . Submi1 a monthly mpa:rt of ir.jec1ion rate: and \'IIHP's t:. the AOGCC. .. Anouai 'LNFT*T or CITOA. ... CM1T-TIdA tv 2500 p.9¡ eycr" 2 yoars. . NoUy tho AOGCC and r..'1ncei WQiVG'f if 1airng MIT's ¡nd:~1.te ~w1h:€:r proolerr3. OperiÍiltin 9 Limtts Max lAP ~ :roO'D pat Max OAP ':;: 1000 pst 'I. .. ',., ,", ",,~~~.:_~, ".".7.,....._,:,".._~.._.__._.- .....,~.. -. -... ::,,:' "'Z:' ':""'::Z:<i,' /2'" i.... "ó,", 'bate /zJrk itåte Distr;bution: W): J Pa~ <Jper.slm 'a.o;;; t' ?,':J!;tE.r-aìr.':)(!f' )~'Q;; . '."'",'" ::::0 t --.,.......- """"--~--- tj(Ç;ANNEi) JAN 1 4 2004 ~P Exploration (Alaska) Inc. Post Office Box 196612 PRB-24 Anchorage, Alaska 99519-6612 bp November 24, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: R-06A (PTD 198-1270) Application for Sundry Approval Dear Mr. Aubert: Attached is the Application for Sundry form 10-403 for well R-06A. This request is to align sundry requirements with the current AOGCC approved sundry matrix. Included with this application are a Form 10-404 to cancel sundry #303-072, a Form 10-403 requesting approval to continue PWl injection only into a well with Rapid T x IA communication, a description summary of proposal, and a wellbore schematic. If you require any additional information or clarification, please contact either Joe Anders or myself at (907) 659-5102. Well Integrity Engineer Attachments 1) Application for Sundry form 10-403 2) Application for Sundry Cancellation form 10-404 3) Description Summary of Proposal 4) Wellbore Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. O~erations Performed: AbandonE~ Suspendr--I Operation ShutdownE~ PerforateF~ varianceE] Annular Disposal['-~ Alter CasingE~ RepairWellr--~ Plug PerforationsE] StimulateO Time ExtensionE~ Other[~] Change Approved ProgramE~ Pull Tubing[---1 Perforate New PeelE] Re-enter Suspended Wellr-'~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development E] Exploratory[~ 198-1270 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphicrl ServicerX-] 50-029-20388-01-00 7. KB Elevation (ft): 9. Well Name and Number: 55.09 R-06A 8. Property Designation: 10. Field/Pool(s): ADL-0028278 Prudhoe / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 12308 feet true vertical 8976 feet Plugs (measured) Effective Depth measured 12289 feet Junk (measured) true vertical 8866 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface ' 2627 13-3/8" 72# L-80 34 2661 34 - 2660.58 4930 2670 : Intermediate i 9706 9-5/8" 47# L-80 34 9740 34 - 8671.32 6870 4760 Production I 3146 3-1/2" 9.3# L-80 8892 12038 7938.58 - 8967.28 10160 10530 Liner 643 7" 29# L-80 9227 9870 8226.08 - 8786.45 8160 7020 Perforation depth: Measured depth: 9880' - 9910' True vertical depth: ~ 8795.15' - 8819.71' Tubing: ( size, grade, and measured depth) 7" 26# L-80 @ 31' - 9086' MD/5-1/2" 17# L-80 @ 9086' - 9229' MD Packers & SSSV (type & measured depth) 9-5/8" DV Packer @ 2583' MD / 5-1/2" TIW Packer @ 9135' MD 7" Liner Top Packer @ 9235' MD / NO SSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: ExploratoryE-~ Development r-1 Service Copies of Logs and Surveys run _ 16. Well Status after proposed work: Operational Shutdown oi l-I Sasl--I WAG r--1 G NJr-I W NJ[] WDSPLF1 Daily Report of Well Operations __ Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.C. Exempt: ContactI 303-072 John Cubbon / Joe ~Aj;~ders Printed Name Johry~u~. ~'/f/ TitleWell Integrity Coordinator Signature ...... ~¢//,~,/~~ Phone 659-5102 Date 11/24/03 2627 13-3/8" 72# L-80 34 2661 34 - 2660.58 4930 2670 9706 9-5/8" 47# L-80 34 9740 34 - 8671.32 6870 4760 3146 3-1/2" 9.3# L-80 8892 12038 7938.58 - 8967.28 10160 10530 643 7" 29# L-80 9227 9870 8226.08 - 8786.45 8160 7020 Form 10-404 Revised 4/2003 ., `STATE OF ALA,SKA ALA,SKA OIL AND GAS CONSERVATION OOMMI,S,SION APPLICATION FOR SUNDRY APPROVAL 2O AAC 25.28O 1. Type of Request: Abandon I-I Suspend r-1 Operation Shutdown E] PerforateE] Variancer~ AnnuarDisposalr--I Alter Casing [--I Repair Well [--I Plu.q PeRorations r-1 Stimulate[--I Time Extension [--I Other[--I Change Approved Program r"l Pull Tubing r-1 Perforate New Pool [-1 Re-enter Suspended Well 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development [--] Exploratoryr'-~ 198-1270 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic r~ Service [~ 50-029-20388-01-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 55.09 R-06A 8. Property Designation: 10. Field/Pool(s): ADL-028278 Prudhoe Bay ! PRUDHOE 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft):12308 IT°ta' Depth TVD (ft):8976.09 IEffective Depth MD (ft): IEffective Depth TVD (ft): IPlugs (measured): I Junk (measured):12289 8865.55 Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor Surface 2627 13-3/8" 72# L-80 34 - 2661 34.0 2660.6 4930 2670 Intermediate 9706 9-5/8" 47# L-80 34 - 9740 34.0 8671.3 6870 4760 Production 3146 3-1/2"9.3#L-80 8892 - 12038 7938.6 - 8967.3 10160 10530 Liner 643 7" 29# L-80 9227 - 9870 8226.1 8786.5 8160 7020 PeRoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9880' - 9910' 8795.15' - 8819.71' 7" 26# L-80 31' - 9086' 12038' - 12308' 8967.28' - 8976.09' 5.5" 17# L-80 9086' - 9229' Packers and SSSV Type: Packers and SSSV MD (ft): 9-5/8" DV Packer / 5-1/2" TIW Packer 2583' MD / 9135' MD 7" Liner Top Packer / NO SSV 9235' MD 12. Attachments: Description Summary of Proposal r-'] 13. Well Class after proposed work: Detailed Operations Program Fl BOP Sketch Fl ExploratoryFI DevelopmentFI service[~ /,r' 14. Estimated Date for 11/25/2003 15. Well Status after proposed work: Commenci%l Operation: Oil I'-I Gasr'] Plugged[-] Abandoned [-I 16. Verbal Approval: Date: WAGE] GINJFI WINJI~! WDSPLE] Commission Representative: Perpared by S. Copeland 564-4424 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Cubbon Printed Name ,~,o~~on Title Well Integrity Coordinator Signature /i ~/~ ( ~ Phone 659-5102 Date 11/24/03 ¢ ' - Commission Use Only I '~)u~_~)ber. Sund ~,~ Conditions of approval: Notify Commission so that a representative may witness . Plug Integrity B BOP TestB Mechancial Integrity TestB Location ClearanceU ther: ,,., ,~ ,~ ~ ' Subsequent Form Required: :~¢ ;~ '~[~i~). Orlgir~al Signe¢115~' BY ORDER OF Appr°ved bY:_~¢,¢-,/,~,,~.~l;,.,,~,Sarah Pall~ ........ ~'"'Ji-r'~i~'" ; i:...,..,+. ~! [ ::l i, I; !l'~.~li'i ,,,¢, :.. L~,,? "i'¢"COMMISIONER! THE COMMISSION Date: ti.,~ '~'.,~ 0/~ Form 10-403 Revised 2/2003~., ,~, ,_, u,, ,j SUBMIT IN DUPLI ~AT-- R-06A Description Summary of Proposal 11/21/03 Problem' Injector with Rapid TxlA Communication Well History and Status Well R-06A (PTD 1981270) is an injector that failed an MIT-IA on 01/01/03. A LLR of 1.25 BPM @ 2300 psi was established. Recent events: > 01/01/03: MITIA failed. LLR=1.25 BPM @ 2300 psi. > 02/24/03: Set IBP @ 9349'. > 02/26/03: CMIT TxlA to 2500 psi PASSED. > 02/28/03: LDL shows temp anomaly at 9050'. This sundry request is to allow for continued injection of water. The, following supports the request: · A CMIT-TxlA passed on 02/26/03 to 2500 psi against an IBP, demonstrating/.. competent production casing. · Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. · A CMIT-TxlA will be conducted every 2 years to confirm production casing integrity. Proposed Action Plan 1. Allow well to continue water-only injection. 2. Record wellhead pressures and injection rates daily. 3. Submit a monthly report of daily pressures and injection rate. 4. Perform combination MIT Tubing x IA every 2 years. ~ .... 5. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. TRE = 6" MCEVOY WELl'HEAD = MCEVOY R 06A SAFETY NOTES: WELL > 70 DEC @ 10075' AND GOES '/~{JTUA'¥0'R'~ ...................... ~TI~' ~ HORIZONTAL @ 10650'. ***RAPID TxlA COMM. ; KB. ELEV = 55.09; OPERATING LIMITS: MAX lAP = 2000 PSI, MAX CAP = BF. ELEV = 21.31' - = ~~~ ~ - 1000 PSI (05/17/03 WAIVER)*** KOP = 3200' / DatumMaXAngle=MD= 95@11217'100~ ~ ,'I 2017' I-I~"o.,~s~w.,~=~.~"l Datum TVD = 8800' SS , :: ::-~1 2583' I4o-~,~"~v ~'1 I~-~,, c~, ~.,-~o,,~=~.~4~,, H 2~' ~ ~ 8892' Id4-3/8"TIEBACK (ENTRY GUIDE), ID=4.00" I IT°P°F 3-112" L'NER"D = 2'992" I--I 8901' I I~".~,~,.-~o..o~.,,.~=~.~"1-I 9086' [ ,, ~ 9087' I-I~"x~-~,:"~xo,.o=4..o~"(.~,.~..~) I '1'~'2--~_ 9098' I-I~-~,~"o*,~ XA SLIDINGSLV, ID : 4.562" (BEHIND LNR) Minimum ID = 2.992" @ 8901' TOP OF 3-1/2" LINER ~ ~ ~ 9135' i-io-~,~,,x.-~,~,,.,w~...,~=4.~.,,(...,.~...) I ! I~"--'q 9187' H~-~,,~^~×~.~..~=4.~,.(~.,~.~) I I I------~ 92o9' I--I5-1/2"PAR~ERXNN,P.D=4.S6"(em,NDLNR)I -- TOPOF7"TIWLNR/HGRTIEBACKSLV Id 9227' ~ ~,o~: oo,~^~,o~ o~ o~o~ ANGLE AT TOP PERF: 31 @ 9880' XXXXXXX(~ Note: Refer to Production DB for historical perf data ~¢ ~ ~ ~-f.. ~22~0' I SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 2 9880-9910 C 03/16/01 OPEN HOLE 12038-12308 O 01/07/99 ~X~ I7'' LNR' 29#' L'80, ID = 6.184'' Id 10681 ~_~~k / 7 ~-~,~,,,~, ~.~, ,-~o ~,, .oo~ ~¢, ,D= ~'~"1-1 ~20~' I / I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/04/79 ORIGINAL COMPLETION 01/11/03 DACFFLH :DRAWING CORRECTIONS WELL: R-06A 01/19/89 RWO 02~24~03 PWE/KK SET 2-1/8" BKR IBP PERMIT No: 1981270 : 01/07/99 CTD SIDETRACK (R-O6A) 04/28/03 JM/TP PULL IBP@ 9349' APl No: 50-029-20388-01 03/14/01 SlS-SLT CONVERTEDTO CANVAS 05123103 ATD/TLH WA IV ER SA FETY NOTE SEC32, T12N, R13E. 729' NSL& 1400' EWL 03/30/01 RN/CH/TP CORRECTIONS 10/02/03 PJP/TLH OPEN HOLE PERF CORRECTIONS 07/31/01 CH/KAK CORRECTIONS BP Exploration (Alaska) ,,, , , ,,,, ............................................................................................ PERFORATION SUMMARY REF LOG: COLLAR LOG ON 03/15/01 ANGLE AT TOP PERF: 31 @ 9880' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 2 9880 - 9910 C 03/16/01 OPEN HOLE 12038- 12308 O 01/07/99 DATE REV BY COMMENTS DATE REV BY COMMENTS 10/04/79 ORIGINAL COMPLETION 01/11/03 DACFFLH DRAWING CORRECTIONS 01/19/89 RWO 02/24/03 PVVE/KK SET 2-1/8" BKR IBP 01107199 CTD SIDETRACK (R-06A) 04/28/03 JM/TP PULL IBP@ 9349' 03/14/01 SIS-SLT CONVERTEDTO CANVAS 05/23/03 ATD/TLH WA IV ER SA FETY NOTE 03/30/01 RN/CH/TP CORRECTIONS 10/02/03 PJP/TLH OPEN HOLE PERF CORRECTIONS 07/31/01 CH/KAK CORRECTIONS 04~02~03 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2728 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott, Milne Pt. Well Job # Log Description Date Blueline Color Prints CD lA-07 / 'Tr~'~)~ L PRODUCTION PROFILE 02/04103 iNK-22A ~,q~/-,.~,-.~ ~ PROD PROFILE/DEFT 02/26'03 PWDW2-1-7' ~~7 ~-(,~ ~ LDL 03/01103 PWDW2-1 ,~, TEMPERATURE LOG 02/15103 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~i~ ~ .~% ~,~'~ ~' ~_~_'.~ ~-~-' Date Delivered: :, ANNEU SE? t $ 20D3 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'Cr'N: Beth STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Continue water / injection Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X / Perforate _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development _ Exploratory __ Stratigraphic __ Service__X 4. Location of well at surface 4551' FNL, 3880' FEL, Sec. 32, T12N, R13E, UM At top of productive interval 1917' FNL, 1471' FEL, SEC 32, T12N, R13E, UM At effective depth 858' FNL, 4960' FEL, Sec. 33, T12N, R13E, UM At total depth 734' FNL, 4818' FEL, Sec 33 T12N, R13E, UM (asp's 635049, 5977205) (asp's 637402, 5979882) (asp's 639169, 5980974) (asp's 639309, 5981100) 6. Datum elevation (DF or KB feet) RKB 55.0 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well numbe..[,,... R-06A 9. Permitnumber/approvalnumber 198-127 10. APInumber 50-029-20388-01 11. Field / Pool Prudhoe Bay Field / Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 110' 20" Surface 2627' 13-3/8" Intermediate 9606' 9-5/8" Tieback Stinger 636' 7" Liner 3148' 3-1/2" 12310 feet Plugs (measured) 8976 feet 12122 feet Junk (measured) 8972 feet Cemented 605 c.f. 3863 c.f. 1514 c.f. 336 c.f. 190 c.f. 2-1/8" BKR IBP set @ 9349' (02/24/2003). Could not get below 12122' after liner was stuck @ 12038'. Measured Depth True vertical Depth 144' 144' 2661' 2661' 9640' 8584' 9227'-9863' 8226'-8780' 8890'- 12038' 7937'-8967' Perforation depth: measured Open Hole Completion 12038'-12308'. Add Peris 9880'-9910'. true vertical Open Hole Completion 8967'-8976', Add Peris 8795'-8820'. Tubing (size, grade, and measured depth 7" 27# L-80 TBG @ 9086' MD. 7" x 5-1/2" XO @ 9086'. 5-1/2" 17# L-80 TBG @ 9221'. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" TIW Packer @ 9135'. 7" Otis SSSVN @ 2017'. 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch _ 14. Estimated date for commencing operation March, 2003 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil _ Gas Service WATER INJECTOR--/' Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: t(,~ &&'~/7 Title: Well Integrity Engineer FOR COMMISSION USE ONLY Questions? Call Joe Anders (907) 659-5102.. Date: Prepared by DeWayne R. Schnorr 564.5174 Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity BOP Test Location clearance ' ~ p Mechanical Inte-'-grity Test__ , --~ , Subsequent form req--~ired 10- Approved by order of the C~mmi*s~pn e~_..a. ,~,~,~/~ ~ ~ Commissioner Date ~/g~_/O J ........ ,, Form 10-403 Rev 06/15/88 * SUBMIT IN TRIPLICATE BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-24 Anchorage, Alaska 99519-6612 bp March 6, 2003 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: R-06A (PTD 1981270) Application for Sundry Approval Dear Mr. Maunder: Attached is the Application for Sundry form 10-403 for well R-06A. This reqpest is for approval to continue injection into a well with Tubing by IA communication.'A description summary of proposal and wellbore schematic is included. If you require any additional information or clarification, please contact either John Cubbon or me at (907) 659-5102. Sincerely, Joe Anders, ~.E. Well Integrity ~ngineer Attachments SCANNED MAR 1 3 2003 R-06A Description Summary of Proposal O3/O5/O3 Problem: Injector with Rapid TxlA Communication Well History and Status Well R-06,~,'(PTD 1981270) is an injector that failed an MIT-IA on 01/01/03. A LLR of 1.25 BPM @ 2300 psi was established. Recent events: > 01/01/03: MITIA failed. LLR=1.25 BPM @ 2300 psi. > 02/24/03: Set IBP @ 9349'. ,/- > 02/26/03: CMIT TxlA to 2500 psi PASSED.' > 02/28/03: LDL shows temp anomaly at 9050'. '/ This sundry request is to allow for continued injection of water. The following supports the request: · A CMIT-TxlA passed on 02/26/03 to 2500 psi against an IBP, demonstrating competent production caSing. · Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. · A CMIT-TxlA will be conducted every 2 years to confirm production casing integrity. Proposed Action Plan 1. Allow well to continue water-only injection. 2. Record wellhead pressures and injection rates daily. 3. Submit a monthly report of daily pressures and injection rate. 4. Perform combination MIT Tubing x IA every 2 years. 5. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. SCANNED MAR i 3 2003 TREE = 6" MCEVOY AWELLHEAD'cTUATOR = MCEVOYoTiS, R== 06A SAFETY NOTES: WELL > 70 BEG @ 10075' AI~D GOES HORIZONTAL @ 10650'. , KB. ELEV = 55.09' --~'- BF. ELEV = 21.31' ' KOP = 3200' Max Angle = 95 @ 11217' ~--., II 2o47' H DatumaD= 10046' DatumTVD = 8800' SS -'-' -'-'-~J 2583' HO-5/8"DVPKRI 113-3/8" CSG' 72#' L'80"D: 1'2'34r' I--[ 2881' I.__~ -- '~l , 8892' H4-3/8'' IIEBACK {ENTRY GUII~), D =4.00" ITc~ o~ 3-1/z' UNE~ ~D = 2.99Z' ~ 8901' Minimum ID = 2.~2" @ 8001' tr'~"~ TOP OF a-1/2" LI~ ER ~ [~----I 9135' HO-S/8"XS-1/2"TIWPK~D-4.?S"(eEUNDLNR)I I Im--~ 9187' H 5-1/2" PARKER X NIP, D=4.562"(BEHINDLNR) ] ITOPOF7"TrWLNR/HGRT'E~ACK,sLv H 922'r 1 9.s/8,, CSG, 47#, C.80, ,D = 8.C~1,, ~ 10~ OF Wl-iPSlOC~ @ 9862' Rill= lOG: CCS. LAR LOG ON 03/15/01 ANGLEAT TOPPERF: 31 @ 9880' Note: Refer to Production IDB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 2 9880 ~ 9910 C 03/16/01 89' I H'" I · . 3-1/2' L~R, 9.3#, k-80 STL, .0087 bp[, ID = 2.992" DATE REV BY COMMENTS DATE REV BY I COMMENTS I PRUDHOE BAY UNIT 10/04/79 ORIGINAL COIVPLE]'ION 01/11/03 DAC/tlh DRAWING CORRECTIONS WELL: R-06A 01/19/89! RWO 02124103 PWE/KK SET2-1/8" BKRIBP PERIVIT No: 1981270 01/07/99 ~5'TD SIDETRACK ' APl No: 50-029-20388-01 03/14/01 SIS-SLT CONVERTED TO CANVAS SEC32, T12N, R13E, 729' NSL & 1400' EWL 03/30/01 RNICHITI: CORRECTIONS 07/31/01 CH/KAK CORRECTIONS BP Exploration (Alaska) PERFORATION SUMMA RY REF LOG: COLLAR LOG ON 03/15/01 ANGLEAT TOPPERF: 31 @ 9880' Note: Refer to Production IDB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 2 9880 ~ 9910 C 03/16/01 DATE REV BY COMMENTS DATE REV BY COMMENTS 10/04/79 ORIGINAL COIVPLE]'ION 01/11/03 DAC/tlh DRAWING CORRECTIONS 01/19/89! RWO 02124103 PWE/KK SET 2-1/8" BKR IBP 01/07/99 ~'TD SIDETRACK 03/14/01 SIS-SLT CONVERTEDTOCANVAS 03/30/01 RNICHI'rI: CORRECTIONS 07/31/01 CH/KAK CORRECTIONS SCANNED MAE i 3 2003 Wavier Check List Well Name: I~ - O (a/~- Operator: ~ ~ Date: PTD: I ~ '~ ° I 7.. 7 Sundry #: ~ 69 5 ' 6~ 7 2- Order(s): Item Y/N Comments 1. Notified of p~-essure communication or leakage? _._._ ,,, 2. Diagnostics planned/run? Method? '3'. Fo~m 10403 submitted requesting waiver? ~. .4. Alternate MIT passed? Method? AOGCC witnessed? 5. MIT Part II verified? How? ' 6. Area or Review examined? Definition of Terms T IA OA MIT CMIT LLRT Tubing Inner Annulus (tbg x csg) Outer Annulus (csg x csg) Mechanical Integrity Test Combined test of annular spaces Leak Loss Rate Test Integrity # Barriers Condition AOGCC Notification Enhanced Operational Restrictions Category Affected Requirements Monitoring Requirements~ Normal 0 Full wellbore integrity MIT - 4 years Water, slurry, gas, MI upon approval TxlA communication (tubing ~ Next business day if 200 psig Annual MITiA/LLRT 3 1 leak; packer leak quantifiable) change in annulus pressure CMIT TxlA - 2 yrs Water only IAxOA communication Annual MrlIA & CMIT IAxOA Water only; annulus PSV w/alarms & set points 2 1 Production casing leak MIT Tubing - 2 yrs for ESD < MIYP of next oUter casing TxlAxOA communication Kill well; submit Sundry (10403) outlining 1 >1 Release beyond wellbore Next business day Daily reports until well secured repairs Y t perating ers; Annulus Pressure Monitonng Matrix applies to the following well configuration: 1. Conventional completion per regulations; monobore on case by case basis 2. Production casing designed for shut-in tubing pressure 3. USDW exemption or finding of no aquifer Reviewing Engineer: Recommended Action: Integrity Category: 5 waiver, chklst, doc:8/2/2002 ~J{~/.~NED ~A~ i 3 2003 STATE OF ALASKA ALASKA OIL AND GAS .CONSERVATION COMMISSION REPORT OF,SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Add Perfs Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 728' FSL, 1399' FWL, Sec. 32, T12N, R13E, UM At top of productive interval n/a --- water injection well At effective depth 857' FNL, 319' FWL, Sec. 33, T12N, R13E, UM At total depth 734' FNL, 461' FWL, Sec. 33, T12N, R13E, UM 5. Type of Well: Development __ Exploratory__ Stratigraphic__ Service__X (asp's 635049, 5977205) (asp's n/a) (asp's 639169, 5980974) (asp's 639309, 5981100) 6. Datum elevation (DF or KB feet) RKB 55 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number R-O6A 9. Permit number / approval number 198-127 10. APl number 50-029-20388-01 11. Field / Pool Prudhoe Bay Field/Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2627' Intermediate 9606' Liner 636' Sidetrack Liner 3148' Perforation depth: 12310 feet Plugs (measured) 8976 feet 12122 feet Junk (measured) 8972 feet Could not get below 12122' after liner was stuck @ 12038'. Size Cemented Measured Depth True Vertical Depth 20" x 30" 605 c.f. 144' 144' 13-3/8" 3863 c.f. 2661' 2661' 9-5/8" 1514 c.f. 9640' 8584' 7" 336 c.f. 9227' - 9863' 8226' ~ 8780' 3-1/2" 190 c.f. 8890' - 12038' 7937' - 8967' measured Open Hole Completion 12038' - 12308'. Add Perfs 9880' - 9910'. RECEIVED JUL 27 2001 true vertical Open Hole Completion 8967' - 8976', Add Perfs 8795' - 882A~mka 0il & Gas Cons. C0rnmissJ0n Anchorage Tubing (size, grade, and measured depth) 7" x 5-1/2" XO @ 9086', 5-1/2" 17#, L-80 TBG @ 9135' MD. 5-1/2" Tubing Tail @ 9221'. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" TIW PKR @ 9135'. 7" Otis SSSV Landing Nipple @ 2017' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Oil~Bbl Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended __ Service __ Water Irfi~ction 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~/~~ ~~.~¢~~.~ Title: Technical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · Date July 23, 2001 Prepared by DeWayne R. Schnorr 564-5174 01/24/2001 02/06/2001 03/16/2001 05/16/2001 01/24/01 R-06A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PERF(ADD-PERF): AC EvA-E~BLEED CA PERF(ADD-PERF): PULL ISSSV / D&T W/2.5 DUMMY GUN PERF(ADD-PERF): PERFORATING 2.5" HSD 2 SPF SCHMOO B GONE: SBG TREATMENT EVENT SUMMARY RECEIVED ,JUL 27 2001 Alaska Oil & ~as Cons, Commission Anchorage BLED IA FROM 730 PSI TO 20 PSI, BLEED CA FROM180 PSI TO 0 PSI. T/I/O = 1380/730/180 Temp = 128, (2" WATER IN CELLAR, SMALL BUBBLES AROUND TREE). BLED CATO 0 PSI IN 20 MIN. GETTING ARCTIC PACK. BUBBLES IN CELLAR WATER DID NOT CHANGE. PRESSURE CA UP WITH DIESEL FROM FLUID PACKED IA TO 400 PSI, LET SOAK 30 MIN. BLED CA TO 0 PSI, IA @ 440 PSI. PRESSURED CA UP WITH IA DIESEL TO 220 PSI AND LET SOAK FOR 30 MIN. BLED CA TO 0 PSI AGAIN, ARCTIC PACK COMING IN SLUGS. BLED IA TO 20 PSI. SI BLEEDS AND MONITOR FOR 20 MIN. STILL GETTING A FEW BUBBLES. FINAL WHP'S 1250/20/0. 02/06/01 PULLED MCX-INJECTION VALVE ( SER.# M-35 ) AND D&T W/2.50 DUMMY GUN TO 9982' SLM. ***NOTE: FLAPPER MISSING FROM VALVE*** 03/16/01 PERFORATED 9880-9910 USING 2.5" HSD 2 SPF POWER JET CHARGES ORIENTED TO SHOOT HIGH SIDE. 05/16/01 SBG TREATMENT Fluids Pumped 2 PRESSURE TEST LUBRICATOR W/DIESEL (2 TESTS). 389 SCHMOO B GONE 292 FLUSH W/ WATER 683 TOTAL 03/16/2001 ADD-PERFS SUMMARY THE FOLLOWING INTERVAL WAS PERFORATED USING 2.5" HSD POWER JET CHARGES, 2 SPF, ZERO PHASING, ORIENTED TO SHOOT HIGH SIDE. 9880' - 9910' MD Page I FW: R-06Ai Zonal Isolation Subject: FW: R-06Ai Zonal Isolation Date: Fri, 9 Mar 2001 20:52:36 -0000 From: "McLellan, Bryan J" <McLellBJ~BP.com> To: "'steve_davies~admin.state.ak.us'" <steve_davies~admin.state.ak.us> Steve, Here is a copy of the R-06Ai zonal isolation correspondence between Tom Maunder and I. ..... Original Message From: Tom Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Saturday, February 24, 2001 1:02 PM To: McLellan, Bryan J Subject: Re: R-06Ai Zonal Isolation Brian, I concur with your summary of our meeting. We examined the bond logs and operational summary of the CT sidetrack. Bond isolation is indicated as you discuss and the GR signature shows the casing set in the base of the Kingak. I am satisfied that the examined information indicates competent zonal isolation Tom Maunder, PE Petroleum Engineer AOGCC "McLellan, Bryan J" wrote: > Tom, > As we discussed in our meeting today: > > The injection well R-O6Ai in Prudhoe Bay was sidetracked from its original > location in December 1998. No cement bond log was run in the 3-1/2" liner > to prove zonal isolation after the sidetrack was drilled. However, a cement > bond log from the original wellbore indicated good quality cement outside > the 9-5/8" casing from 9000' (top of the logging interval) to 9227' (top of > 7" liner lap). It might be inferred that there is good cement behind the > 9-5/8" casing down to the shoe at 9740' The cement bond log over the liner > lap portion (9227-9740' md) indicated poor cement behind the 7" liner, but > can not say anything about the quality of the cement job behind the 9-5/8" > casing. The entire reservoir interval from 9000' down to the top of the Sag > River at 9865' md is Kingak shale. The Kingak along with the 227' of good > cement outside the 9-5/8" liner could suggest that we have zonal isolation > uphole from the Sag River. > Further, after the sidetrack was drilled and the 3-1/2" liner was run, 34 > bbls of 15.8 ppg class G cement were pumped and passed a 30 min liner lap > pressure test to 2300 psi. > BP requests the AOGCC's confirmation of competant zonal isolation in R- 06Ai. > > Thank you, > Bryan McLellan > 1 of 2 3/12/01 7:16 AM FW: R-06Ai Zonal Isolation > Bryan McLellan > BP Exploration, Alaska > Production Engineer > (907) 564-5516 Tom Maunder <tom maunder~admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 3/12/01 7:16 AM ~ALASKA~ eare. d rvloes rilling BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: March 31, 1999 From: Terrie Hubble Technical Assistant Subject: Revised Surveys Enclosed, in duplicate, are updated directional surveys for the following wells: G-14A, Permit #98-53 S-31 A, Permit #98-220 G-09A, Permit fl98-263 R-06A, Permit #98-127 Baker Hughes INTEQ has submitted these revised surveys to us correcting the grid coordinates. These surveys do not require changes to the Completion Reports which were previously submitted by Theresa Mills, and are being provided to you simply for your records. However, I have also attached a revised Completion Report for R-06A as I have found a few errors in the previously submitted form and have chosen to revise it at this time. These changes are primarily minor (corrected TD was 12308', open hole completion was from 12038' to 12308'), but felt that it was important to make the corrections. The well histories and logs have previously been filed with the Commission and there are no changes. Thank you. /tlh STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Revised: 03/31/99 (CT ST) WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas []Suspended []Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-127 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20388-01 4. Location of well at surface ~ 9. Unit or Lease Name 729' NSL, 1400' EWL, SEC. 32, T12N, R13E, UM"'""" "'"""'.~r~ ' ........ PrUd.hoe Bay Unit .......... At top of productive interval ~~ 10. Well Number N/A - Water Injection Well . R-06Ai At total depth 11 Field and Pool 4547' NSL, 449' EWL, SEC. 33, T12N, R13E, UM Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBD = 55.09 AMSLI ADL 028278 12. Date Spudded12/26/98 110' Date T' D' Reached I 14' Date C°mp" Susp" °r AbanO'115' Water depth' if °ffsh°r'"'"i"i'~'i'"~i 0f C°mpleti°nsl/5/99 1/7/99 N/A MSLI One 1~: TotaI Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) [19. Directional Survey 120. Depth where SSSV setl21. Thickness of Permafrost 12308 8921 FTI 12308 8921 FTI []Yes []No (Nipple) 2017' MD 1900' (Approx.) 22. Type Electric or Other Logs Run GR 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20"X 30" L-80 Surface 144' 36" 505 cu ft 13-3/8" 72# L-80 Surface 2661' 17-1/2" 3863 cuft 9-5/8" 47# L-80 Surface 9740' 12-1/4" 1514 cu ft ........ 7" . ~29# L-80 9227' 9862' 8-1/2" 336 ca ft 0 D J G! I~ ' 3-1/2" 9.3# L-80 9890' 12038' 4-1/2" 190 cu ft 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD .... Bottom and interval, size and number) SiZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Open Hole Completion 7", L-80 9085' MD TVD MD TVD 5:1/2.I i,80 9085, , 9221, 9134' 12038' - 12308' 8869' - 8921' . ............................. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) January 9, 1999 ! Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SiZE IGAs-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITy-APl (CORR) 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. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Shublik 9910' 8764' Sadlerochit 10038' 8839' 31. List of Attachments Revised Survey ~2. I hereby certify that the foregoing is true and correct to the best of my knoWledge Signed Terrie Hubble Title Technical Assistant III Date R-06Ai 98-127 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. iNSTRUCTIONS GEN£R,~,: 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 B.P. Exploration (True) Structure : Pad R Field : Prudhoe Bay Well : R-O6A, APl 50-029-20388-01 Location : North Slope, Alaska East (feet) -> 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 .3600 3800 4000 4200 4400 4600 4800 5000 I I I I I I I I I I I I I I I I I I I I I t I I I I I I I I I I I 8000 8200 84OO 8600 8800 9000 I V s2oo '4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2200 Oete plotted : 24-Mar--g9 Pie{ Reference ;z R-O6A Cox ,301. Coocdinete~ ere In feet reference R--06. me Vert~al Oeptrm are reference rk~ - MSt. = 55.2ft. i i i i i i i i i i i i i i i i i i i i i I i I i I i i i i i i i I i ........ I 400 200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 --- ~km' Nughe~ INT[G --- Vertical Section (feet) -> · Azimufh 57,54 wifh reference 2620.74 N, 2366.57 E from R-06 ,2400 B.P. Exploration (True) Pad R R-O6A R-06 Prudhoe Bay North Slope, Alaska SURVEY L I ST I NG by Baker Hughes INTEQ Your ref : R-O6A Our ref : svy79 License :API 50-029-20388-01 Date printed : 24-Mar-99 Date created : 1-Mar-99 Last revised : 24-Mar-99 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 633665.590,5976451.290,999.00000,N Slot location is nTO 20 44.268,w148 54 13.567 Slot Grid coordinates are N 5977204.986, E 635048.990 Slot local coordinates are 728.97 N 1396.73 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North B.P. Exploration (True) Pad R,R-O6A Prudhoe Bay, North Slope, ALaska Neasured Inc[in Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R O I N A T E S 9800.00 28.02 68.00 8668.99 2620.74N 2366.57E 9862.00 26.48 69.02 8724.10 2631.14N 2392.98E 9889.06 33.28 62.37 8747.56 2636.75N 2405.21E 9919.08 40.99 55.03 8771.49 2646.23N 2420.60E 9955.74 50.66 46.16 8797.03 2663~00N 2440.75E 9980.96 55.68 40.00 8812.15 2677.75N 2454.50E 10002.71 61.98 34.36 8823.41 2692.58N 2465.71E 10037.81 65.45 29.61 8838.96 2719.27N 2482.35E 10069.06 69.02 28.52 8851.05 2744.45N 2496.34E 10106.99 78.72 29.20 8861.57 2776.32N 2513.91E 10124.76 84.44 31.01 8864.17 2791.52N 2522.73E 10149.46 88.09 29.40 8865.78 2812.82N 2535.13E 10191.91 86.82 28.69 8867.67 2849.89N 2555.71E 10235.21 87.56 28.36 8869.79 2887.89N 2576.37E 10275.96 88.62 26.51 8871.15 2924.04N 2595.13E 10311.71 87.50 21.69 8872.36 2956.64N 2609.72E 10345.08 86.50 24.80 8874.11 2987.26N 2622.87E 10378.21 87.05 31.57 8875.97 3016.40N 2638.48E 10417.24 87.84 35.63 8877.71 3048.86N 2660.05E 10450.29 87.31 38.62 8879.11 3075.19N 2679.98E 10497.71 86.08 45.36 8881.85 3110.36N 10566.64 85.95 49.72 8886.64 3156.77N 10619.29 88.53 58.82 8889.18 3187.44N 10650.21 90.40 61.70 8889.47 3202.77N 10680.29 90.00 69.07 8889.37 3215.29N SURVEY LISTING Page 1 Your ref : R-O6A Last revised : 24-Mar-99 10725.99 90.65 73.88 8889.11 3229.81N 10759.86 89.34 75.80 8889.11 3238.66N 10792.54 88.02 74.04 8889.86 3247.16N 10826.39 89.25 71.22 8890.67 3257.27N 10875.89 89.16 67.17 8891.36 3274.84N 10909.29 89.88 66.33 8891.64 3288.03N 10937.64 90.22 67.52 8891.61 3299.14N 10965.19 89.43 64.00 8891.70 3310.45N 11007.66 85.29 62.59 8893.65 3329.51N 11055.16 84.41 59.24 8897.92 3352.50N 11122.51 85.08 60.14 8904.08 3386.35N 11156.57 86.45 59.60 8906.60 3403.40N 11181.48 88.43 55.35 8907.71 3416.77N 11216.98 94.93 53.11 8906.67 3437.50N 11251.56 94.49 53.39 8903.83 3458.12N 11297.73 89.51 54.22 8902.22 3485.36N 11328.93 86.89 59.69 8903.20 3502.36N 11362.58 86.94 61.47 8905.01 3518.86N 11394.06 87.28 64.16 8906.60 3533.22N 11425.43 86.50 68.87 8908.30 3545.70N 11458.48 85.49 71.77 8910.61 3556.81N 11492.01 86.05 74.54 8913.09 3566.50N 11527.58 91.17 76.87 8913.95 3575.27N 11555.16 94.14 79.57 8912.67 3580.90N 11591.91 93.63 86.82 8910.18 3585.24N Dogleg Vert G R I D C 0 0 R D S Deg/lOOft Sect Easting Northing 2.59 0.00 637368.27 5979867.29 2.60 27.87 637394.49 5979878.16 27.92 41.20 637406.61 5979883.99 29.58 59.28 637421.84 5979893.75 31.53 85.28 637441.68 5979910.87 27.89 104.79 637455.16 5979925.86 36.47 122.21 637466.10 5979940.89 15.65 150.58 637482.26 5979967.87 11.87 175.90 637495.80 5979993.29 25.63 207.83 637512.80 5980025.47 33.73 223.43 637521.34 5980040.82 16.15 245.32 637533.36 5980062.34 3.43 282.59 637553.28 5980099.77 1.87 320.41 637573.25 5980138.12 5.23 355.64 637591.37 5980174.60 13.83 385.44 637605.37 5980207.45 9.78 412.97 637617.97 5980238.29 20.47 441.78 637633.06 5980267.70 10.59 477.41 637654.05 5980300.55 9.18 508.36 637673.50 5980327.22 2711.63E 14.42 553.94 637704.52 5980362.95 2762.35E 6.31 621.64 637754.40 5980410.25 2804.99E 17.94 674.08 637796.48 5980441.67 2831.84E 11.10 704.96 637823.05 5980457.48 2859.16E 24.54 734.74 637850.14 5980470.49 2902.48E 10.62 779.08 637893.19 5980485.77 2935.17E 6.86 811.42 637925.72 5980495.21 2966.71E 6.73 842.59 637957.10 5980504.27 2999.01E 9.09 875.26 637989.21 5980514.95 3045.27E 8.18 923.73 638035.14 5980533.34 3075.95E 3.31 956.69 638065.58 5980547.07 3102.03E 4.37 984.66 638091.46 5980558.64 3127.15E 13.09 1011.93 638116.37 5980570.40 3165.04E 10.30 1054.13 638153.91 5980590.13 3206.38E 7.26 1101.35 638194.83 5980613.85 3264.28E 1.66 1168.37 638252.11 5980648.72 3293.65E 4.32 1202.30 638281.18 5980666.29 3314.63E 18.81 1227.18 638301.91 5980680.04 3343.40E 19.36 1262.59 638330.31 5980701.28 3371.02E 1.51 1296.95 638357.55 5980722.38 3408.24E 10.93 1342.98 638394.28 5980750.28 3434.37E 19.43 1374.15 638420.09 5980767.74 3463.64E 5.28 1407.70 638449.06 5980784.76 3491.60E 8.60 1439.01 638476.76 5980799.62 3520.32E 15.20 1469.94 638505.25 5980812.61 3551.36E 9.27 1502.09 638536.09 5980824.26 3583.36E 8.41 1534.29 638567.91 5980834.52 3617.81E 15.81 1568.06 638602.19 5980843.91 3644.77E 14.55 1593.83 638629.05 5980850.01 3681.15E 19.73 1626.86 638665.34 5980855.00 ALt data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from R-06 and TVD from rkb - MSL = 55.2ft. Bottom hole distance is 5772.20 on azimuth 48.59 degrees from wellhead. Vertical section is from tie at N 2620.74 E 2366.57 on azimuth 57.54 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad R,R-O6A Prudhoe Bay, North SLope, Alaska SURVEY LISTING Page 2 Your ref : R-O6A Last revised : 24-Hat-99 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R ! D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D [ N A T E S Deg/lOOft Sect Easting Northing 11620.33 93.57 91.02 8908.39 3585.771t 3709.51E 14.7'5 1651.07 638693.68 5980856.04 11662.29 93.74 93.56 8905.72 3584.10N 3751.34E 6.05 1685.47 638735.54 5980855.11 11701.04 93.20 91.27 8903.37 3582.47N 3789.99E 6.06 1717.20 638774.20 5980854.17 11737.42 92.87 89.09 8901.45 3582.35N 3826.31E 6.05 1747.79 638810.52 5980854.71 11781.82 92.28 85.64 8899.45 3584:39N 3870.61E 7.88 1786.27 638854.77 5980857.53 11811.04 89.75 82.67 8898.93 3587.3711 3899.67E 13.35 1812.38 638883.77 5980861.03 11846.04 87.38 81.28 8899.81 3592.25N 3934.31E 7.85 1844.23 638918.32 5980866.53 11874.97 87.13 78.76 8901.20 3597.26N 3962.77E 8.74 1870.93 638946.68 5980872.04 11908.46 86.10 73.76 8903.17 3605.20N 3995.24E 15.22 1902.58 638978.99 5980880.56 11936.85 85.98 72.94 8905.13 3613.31N 4022.37E 2.91 1929.8/, 639005.98 5980889.15 11964.45 85.86 69.90 8907.10 3622.08N 4048.46E 11.00 1956.56 639031.91 5980898.39 11994.29 86.80 65.67 8909.01 3633.34N 4076.02E 14.49 1985.86 639059.26 5980910.13 12037.67 85.15 63.19 8912.05 3652.01N 4115.06E 6.85 2028.81 639097.95 5980929.50 12077.77 85.81 60.70 8915.22 3670.81N 4150.33E 6.41 2068.66 639132.88 5980948.92 12106.40 88.67 56.42 8916.59 3685.73N 4174.72E 17.96 2097.25 639157.00 5980964.26 12135.67 88.92 53.56 8917.21 3702.51N 4198.69E 9.81 2126.48 639180.66 5980981.48 12174.20 89.78 48.38 8917.65 3726.7TN 4228.60E 13.63 2164.74 639210.14 5981006.26 12221.52 87.71 49.18 8918.68 3757.94N 4264.19E 4.69 2211.49 639245.16 5981038.06 12259.34 88.58 46.90 8919.91 3783.21N 4292.29E 6.45 2248.77 639272.81 5981063.82 12279.50 88.92 46.57 8920.35 3797.02N 4306.97E 2.35 2268.57 639287.23 5981077.90 12310.00 88.92 46.57 8920.92 3817.99N 4329.12E 0.00 2298.51 639309.00 5981099.25 Att data in feet un[ess otherwise stated. CaLcuLation uses minimum curvature method. Coordinates from R-06 and TVO from rkb - MSL = 55.2ft. Bottom hole distance is 5772.20 on azimuth 48.59 degrees from weLLhead. Vertical section is from tie at N 2620.74 E 2366.57 on azimuth 57.54 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the CLarke - 1866 spheroid Presented by Baker Hughes INTEQ STATE OF ALASKA ° ALASK,~?'-'~_ AND GAS CONSERVATION COMMIr'-~"3N CT Sidetrack well WELL COMF,-~=TION OR RECOMPLETION REPORT ,~',,,,D LOG ii status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-127 3. Address 8. APl Number P.O. Box196612, Anchorage, Alaska 99519-6612 50-029-20388-01 · 4. Location of well at surface ~e~¢,~ .tOl~.~ 9. Unit or Lease Name 729' NSL, 1400' EWE, SEC. 32, T12N, R13E, UPM '!'~.'·~: : ": ",~~' '~ ! Prudhoe Bay Unit At top of productive interval ! !/~/~" !!i~i 10. WellNumber N/A - water injection well . R-06Ai At total depth ! ~i.:,:~' ~:~] ! 11, Field and Pool 4547' NSL, 449' EWE, Sec 33, T12N, R13E! ....../~.~ i' Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Design~fi'~i¥~i~'E"S~e~rial N°. Pool KBD - 55.09 AMSLI ADL 028278 12. Date Spudded12/26/98 113' Date T'D' Reached t 14' Date C°mp" Susp" °r Aband'115' Water depth' if OffshOre 116' NO' Of COmpletiOns1/5/99 1/7/99 N/A MSL I One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional SurveyI 20. Depth where SSSV set~l. Thickness of Permafrost 2017 MD 1900' (Approx.) 12310 8921 FTI 12310 8921,, F~I .............. OYes []No, ,,! .................. | ........................... 22. Type Electric or Other Logs Run GR 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP DO'I-rOM SIZE CEMENTING RECORD AMOUNT PULLED 20x30 L-80 Surface 144 36" S05 c.f. 13-3/8" 72# L-80 Surface 2661 17 1/2" 3863 c.f. 9-5/8" 47# L-80 Surface 9640 12-1/4" 1514 c.f. , 7" 29# L-80 9227 10681 8-1/2" 336 c.f. 3-1/2" 9.3# L-80 9890 12038 4-1/2" 190 c.f. 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Open hole completion Shoe @ 12038, TD @ 12308 7" L-80 9085' MD TVD 5 1/2" L-80 9085' to top of 7" 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL, !MD) AMOUNT & KIND OF MATE~,IAL USED ........ , .................... 27. PRODUCT,ON TEST ~D I lkl ^ I Date First Production IMethod of Operation (Flowing, gas lift, etc.) ~*J I \ i U I I ",! ~ L 1/9/99 ] Water Injection Date of Test Hours Tested PRODUCTION OIL-aBE GAS-MCF WATER-aBE CHOKE SIZE I GAS-OIL RATI~ I FOR TEST Flow Tubing Casing Pressure .~ALCULATED OIL-aBE GAS-MCF WATER-aBE OIL GRAWTY-API (CORR) · Press. _~4-HOuR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. ormation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. TSHU 9910 8765 TSAD 10038 8846 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby ce~fy that the foregoing is true and co';~t'"i~"'i'he b~st of my knowledge ........ Signed ~re~~. ~ Title CoiledTubin~lDrillin~lTA Date c~/~ j~(~[ Prepared By Name/Number: Theresa M/Ifs 564-5894 ~NSTRUCTIONS 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 ir.,, 06Al TREE: 6" McEvoy ~' ' WELLHEAD: McEvoy Conventional m KB. ELEV = 55.09' BF. ELEV = 21.31' ACTUATOR: Otis ~ I 13-3/8",72#/ft, --' NIPPLE L-80, BTRS FOC-- I~ I ~ ! ( Otis )( 5.96" ID) 13 3/8" Shoe [ 2661 ] --------~" J i~' I j 7",26~/ft, L-SO, TUBING i' i TUBING ID: 6.276" I i CAPACITY: .0382 BBL/FT HORIZONTAL SIDETRACK 'LINER: m .~,.. I , ~ ."~ 7"x51/2" = CROSSOVER Baker Entry Guide Top at 9890 Ft. I SLIDING SLEEVE i Baker Enty Guide ID: 4.00" ~1 -- Otis XA I 9098 Shoe at 12,038 ft. i ( 4.562" MIN. ID) I I CAPACITY: 0.0087 BBL/FT 9-5/8" PACKER 191341 i, ( TIW )(4.75"1D) i: , , ~ ~ 5 1/2" "×" NIPPLE 9187 I (Parker) (4.63" ID) ~ ~ 5 1/2" "XN" NIPPLE 9209 (Parker)(4.63" ID) I '' ' '~I ~ 5 1/21'NSoeal AssemblySeal) I Top 7" Liner Hanger I 9227' I 9 s/o" 47# L-80 BTRS I 9740' I ~1 shoe [ I i i~. i "~ ![ Original 7", 29#, L-80, BTRS liner was PERFORATION SUMMARY abandonded with cement plug from REF: LOG: None ~ 9870-10072 ft. cement Plug was SIZE ~PF INTERVAL (~PEN/SQZ,D'~ pressure tested with 2200 psi. . Odginal 7" Shoe at 10681 ft. i No Perfs, ~ i Open hole , Baker 7" Whipstock Top set at 9862 ft. i I ~ RA Tag at 9870 ft. i 4.56" window milled from 9862-9870 ft i I I I I I 3 1/2", 9.3#, L-80, Shoe I 12,038' I__~ ,i CTD HORIZONTAL $1BETR~CK rD of 4 1/2" Open Hole I 12308' } ~ DATE REV. BY COMMENTS PRUDHOE BAY UNIT 3/25/80 INITIAL RIG COMPLETION WELL: R-06ai (32-32-12-13) , , 11/15/89 HF EWe APl NO: 50-029-20388-01 1/7/99 cJs CTD Horizontal SidetraCk SEC 32i TN, 12Ni RGE 13E ,, BP Exploration (^laska) II SIZE 3PF, INTERVAL ~PEN/SQZ'D No Perfs, Open hole Well: R-06A Accept: 12/20/98 Field' Prudhoe Bay Spud: 12/26/98 APl' 50-029-20388-01 Release: 1/7/99 Permit: 98-127 CTD Unit: Nordic #1 Date Day Depth 12/20/98 1 12/20/98 Accepted Rig 17:00 hrs.. NU BOP, run lines, set tanks. Finish RU rig. PT BOP witness by Larry Wade with AOGCC. Installed Baker CTC, Pulled tested to 35k, Loaded CT and PT to 3500 psi. PU Milling BHA. TIH. 2/22/98 2 TIH and tagged at 9575. Drilled through quickly, WR to bottom at 9884' (Top of Whipstock). Flagged pipe at 9793' EOP. PT squeeze to 2200 psi, lost 125 psi in 15 min. POOH and ran WL. WL tagged at 9575'. POOH and RD. TIH with UR. Tagged at 9582' UR twice from 9582' to 9880'. POOH and PU Window milling BHA. RIH & mill XN at 9,223'. RIH & mill window 9,863'. 12/23/98 3 Milling on window. Not making progress. POOH atfter6.5 hrs. Changed out Motor and HDC. RIH. Tagged at 9862' after-28' correction. Starting window mill. Made ~1-1/2', motor quit stalling & progress stopped. Either motor gave up or spinning on junk, POOH for new motor & DCs. Tally DCs & P/U same. 12/24/98 4 RIH with mill. Tagged @ 9893' Corrected back to 9863.3'. Starting Mill.. Tried for 2.5 hrs, unable to make progress. POOH to run WL LIB. OOH and stand collars back in derrick. RU WL and run 4.4" LIB and tagged at 9863' POOH looks good). RIH with 2.625"* 1" Tapered lB and tagged WS. POOH and no marks on TIB. PU new BHA and install CTC. RIH, corrected back to 9863.3'. Milled 3' in 2-3/4" hours, no progress last 45 min. Big bite & stall, require 78k# to pull free. Lost 6' of hole, unable to get back to whipstock. Wiper trip to tbg tail & verify clean BHA. Work mill at 9860', unable to get back to whipstock. POOH for LIB on slickline. Run 4.4" LIB, some ragged marks along one side, nothing in the middle. 12/25/98 5 RIH with 2.625'1" Tapered LIB. Tagged 2' lower than yesterday. POOH and seen signs of symmetrical circle with tit in the middle of circle. Ran 3.625" LIB and seen the same picture. Ordered out tapered mill and hydraulic jars. PU Dimple mill and hydraulic jars and remaining BHA, TIH. Tagged at 9866.4' PU clean. Working on window. 1st motorwork at 9865..6' Drilling what looks like formation at 9866' 1st stall at 98681. PUH and Milled and stalled 9867' Broke free. Milled back to 9868.1. Clean. Milling ahead. Milled to 9869' and dry tagged at 9870.7. Milled to 9870.2. Backed ream at 9870.1'to 9863' at 0.4 FPM. Milled to 9870.4, reamed window interval again, worked stall spot 9869'. Dry tag & flag, POOH. Slip & cut drlg line. M/U & RIH w/milling BHA. Dress window 9866'-9869' 12/26/98 6 10024 Milling window with string reamer from 9860' to 9871.5. Conducted back reamed twice. Clean. Mud swap while milling window. Dry tagged at 9871'. POOH during mud swap. OOH and LD Milling BHA. Load out milling tools. Held safety meeting. Made up drilling BHA#1 & RIH, no problem wi 2.8 deg motor in SS, tagged up at 9901', corrected to 9871'. Drilled build section 9871 '-10,000'. Short tripped to window 40k up, 24k dn, drilled 10,000'-10,024'. Motor failed to recover from a stall. POOH for motor. '12/27'/98 7 '10'1 $0 OOH and changed out motor. RIH and at 9828' corrected back to 9800'. Orient TF prior to going in window. Went thro window at 37L. TIH. Tagged bottom at 10020' Orient TF Drilling at 37L. Drilling and unable to get survey on the fly. Pump up survey, drilling. Pump up survey at 10094' Unable to receive reliable survys. POOH to troubleshoot MWD. NPT time started at 1400 hrs 12-26-98 OOH and changed probe. TIH and shallow hole tested. OK. Tag at 10,126' correct to 10,094', survey 10,074', 10,038' & 10,003'. Back on clock at 22:30hr, drill high side 10,094'-10,145', landed well. POOH for motor, L/D 2 deg motor, P/U 3-1/2" 1.15 deg motor & DS 49. RIH, tag 10,175', correct to 10,145'. Attempt to drill ahead - no progress - motor stall too easy - POOH 2128198 8 10339 Changed out motor, PT tool string. RIH with 2 7/8" Tandem motor. Tie-in at RA Marker at 9871' Corrected -25' RIH and tagged bottom. Orient TF 80R. Drilling orient and drilling. Drilled from 10150' to 10282'. Pulled 80k at 10282' (Stacking Problem). Wiper trip to 9930'(window) at 10282' Clean. Drilling and surveys. Pumped up survey at 10300' and took 65k to pull free. Orient around for dir. Control (10300'). Drilling and survey at 10339' Running survey at 0.4 FPM and got stuck at 10320' Worked CT at 80k to 0. NOTE:. Its required to spend 15min per 30' to pump up survey. Sperry tools unable to read survey data on the fly. While pumping up survey, lose TF orientation and have to orient around to achieve correct TF. Called for crude. Spotted two 10 bbl crude pills in open hole, worked pipe & had no movement. Circulated crude pills from hole. Pulled 80k# & moved pipe up hole 50' - no further movement. Dropped 15/16" ball & disconnected at 5500 psi - coil still stuck. Circulated & waited on more crude. Spotted 25 bbl pill on bottom, pumping crude past open hole as needed to prevent freeze-up on surface, work pipe with crude on bottom - no pipe movement. 12/29/98 9 10400 Working CT while spotting crude. Pulling at 82,000# and down to negative wt. With 11 bbl crude out, CT top section came free. Cir at 2.5 bpm and POOH. Trip out of OH, clean. POOH. LD BHA and cut 200' coiled tubing off. PU fishing BHA and RIH. Tagged a little at 10228' Pushed fish down to 10324'. POOH with 2000# extra string wt. OOH and LD Fishing tools. M/U drilling BHA #6, RIH, tag up at 10,369', correct to 10,339'. Drill to 10,347', sperry tool quit, unable to revive it. POOH for MWD. Change out MWD & RIH. Tag up at 10,377', correct to 10,347'. Drill to 10,400', sperry tool quit one time but did come back. Sperry tool appears sluggish after orienting, unable to survey on the fly - still requires 15min/30' of hole for survey. 2/30/98 10 1 '1086 Drilling and getting surveys on the fly. Drilled from 10347' to 10490'. Short tripped to window (clean). Orient TF. Drilling. Drilled 10490' to 10650', pumped up survey and made wiper trip to window. Orient TF to hold angle at 88 deg. Drilled 10650' to 10758' wiper trip prior to orient TF to R-Side. Drill from 10758-868' and had stacking problems. Short trip to window. Tie-in at 9910', add 4.0'. Drill from 10868-11000' (8892' TVD). Short trip to window. Drill from 11000- 11086' (8900' TVD). 2/31/98 '11 1112~ Drilling. Orient TF. POOH due to Hr. LD tools and conduct weekly BOP Test. Witness by John Spaulding AOGCC. (Installed Rig Communications). PU Drilling BHA. Installed DS CTC. RIH with BHA #8. Shallow hole test. Tagged bottom at 11090' CTD. Orient TF. 90 reactive Torque. Possible fault encountered at ~ 11,000' MD(8893.1' TVDss). No fluid loss while drilling. Drill to 11114'. PUH to 10970 and log well to check GR values. GR tool failed. POOH. NPT starts at 1800 hrs. Change out MWD probe. RIH with BHA #9 to TD. Log GR of last 30' of drilled hole. Drill from 11114-121' and GR quit. POOH for MWD. Lay down 3" Sperry tools. MU 3.5" Sperry tools. RIH with BHA #10. 1/1/98 12 11488 RIH and corrected 28' at 9828' RIH and at 10600', the Dir Probe started sending high count to surface. Tagged bottom and TF erratic and counts are high. Worked at getting tools to work. POOH to change out MWD probe OOH and PU Solar tool programmed for long survey with TF. PU Tandem motor and Less aggressive bit (DS74). RIH w/BHA #11. Tagged bottom at 11121 '. Orient TF. Drill from 11121-225' building angle to get back to TVD prior to fault and MWD problems. Shod trip to window. Tie-in, add 3.0'. Drill from 11225-347'. Shod trip to window. Displace to new FIo Pro mud. Drill from 11347-488'. Backream to 11340' (8902' TVD) to check survey. Looks like MWD has failed. 1/2/99 13 11660 POOH. Changed out Motor (PU Sperry 3-1/8 slow speed motor) and PU Different Solar Tool. RIH with BHA #12 and corrected -28' at window. RIH and logged 11224' to TD to confirm GR and Directional values from last motor run. Survey and GR data correct. Drilling and getting survey on fly Trouble sliding, made 300' wiper trip at 11551 '. Drill to 11617'. Shod trip to window. Tie-in, add 1.0'. Drill from 11617-630'. Orient to left. Drill from 11630-660' and had problems making hole. POOH for motor. Found stator rubber in bit nozzles. Change bit and motor. RIH with BHA #13 (Sperry Drill motor, DS49 rr bit). Tie-in to GR at 9110'. Precautionary ream to TD. 1/3/99 14 12090 RIH and tagged bottom. Orient TF and Drilling. Drilled 10660' to 11700' and pumped up survey. Drilled 11700' to 11740 and pumped up survey. Drilling. String stuck while drilling at 11753' Work differential stuck pipe. Came free. Shod trip to window. Drilling Pump up survey at 11781 '.Drilling, taking lots WOB to get to drill. Drilled 11753' to 11845' and shod trip to window. Drilling from 11845-923' and plugged jets. Backream to window and unplugged jets. Tie-in, add 1.0'. Drill from 11923-12026' with two 100' backreams. Shod trip to window. Drill from 12026-12090'. 1/4/99 15 12260 Drilled 12026' to 12101' Stacking problem. Wiper trip to window (9825'). Tagged bottom and orient TF around. Drilling with stacking problems. Working bit several times to get the required WOB & Pp to drill. (sticky) Drilled 12101' to 12178'.(77') Wiper trip to window. (Clean). Orient TF around. Drilled 20' at good wt to bit transfer. Then started having problem sliding and sticky. Drilling with negative string wt. POOH to check BHA. Log pass 11000' to 11100' PUH and tie-in. Corrected (-3'). POOH. Change bit (3-3-1), chk MWD probe. Rehead CTC, change packoff. PT @ 3500 psi, 35K. RIH with BHA#14 (DS 74 rr bit, 1.04 deg motor). Relog 10800- 11100' for geo (found some difference in prior GR). Drill from 12230-12260'. Backream to window. Park at window. Conduct Safety Stand Down Meeting. 1/5/98 16 12308 PUH to casing. Held Field Wide Safety Stand down with CTD Project Personnel.(1 hrs) RIH. Tagged bottom. Orient TF, pump up survey. Drilling. 300' wiper trip at 12301'. Drilling to TD at 12308'. POOH and tie-in. Corrected -4', TD after correction = 12308'. Painted flag at 6470' EOP. POOH to run liner. LD and load out 3.5" drilling tools. Held Safety and Operational meeting. (both crews). MU 97 its 3-1/2" 9.3# L-80 STL liner. Install Baker CTLRT. RIH w/liner on 2-3/8" CT. RIH clean to 11021' and started seeing wt loss as turbos went thru window. Gradually lost weight until set down at 11525'. Work shoe to 11796' and couldn't push any further. POOH for drill collars. At surface with top of liner. Load collars in pipeshed. 1/6/99 17 Load Pipe shed with 16 3-1/8" drill collars. RIH with liner and collars on 2-3/8" CT. Correct -32' at window. RIH and set down at 12038' and stuck liner. Worked between 84k and -5k with out movement. Pump 26 bbls dead crude, let soak-still no movement. Discuss. Displace mud to 2% KCL water. Drop 5/8" ball. Release from liner with 40K. Pump 34 bbls 15.8 ppg Class G cement with latex. Load wiper dart. Displace dart with KCI water to liner wiper plug. Displace wiper plug to latch collar with full returns. PT @ 2000 psi. Unsting, floats held. Jet TOL, then POOH. LD DC's. Load out handling tools. Prep CT to install weld-on CTC. 117199 18 Weld on DS CTC. Press test and pull test. Wait on Cement 2 hours. Pressure test liner lap at 2300 psi for 30 min with 2% KCI water. Good liner lap test. RIH with 2.70" Baker mill and 2 1/8" motor to mill out float equipment. Tag top of liner and correct depth to 8891 ft. RIH reaming 3.5" liner. No cement to Baker landing collar. Mill thru landing collar in 1 hour 20 min. Mill thru float collar in 20 min. Mill thru float shoe in 1 hour 10 min. Pump 30 bbl FIoPro sweep. Backream and ream float equipment and dress to 2.70". RIH in open hole with a few setdowns to TD (full returns after displaced to 2% KCI water). Backream open hole from TD to 3-1/2" shoe with 4 ppb Lithium Hypochlorite water (bleach) and leave in open hole. Losing 0.5 BPM after open hole displaced. POOH with milling assy. Install nozzle. RIH w/CT and displace top 2000' of wellbore to MeOH. Displace CT to N2. Vac and clean pits. General RD, prep to move. 18199 19 ND BOPE. Lift BOP stack to rig floor. Replace annular element. Nipple up tree cap and pressure test with 3000 psi. Close master and swab valves. Move green tank. Move rig off of well. RELEASED RIG AT 09:30 HRS, 01/07/99. TOTAL TIME ON WELL WAS 17 DAYS, 16.5 HRS. Move rig off of R pad. Derrick up rig move. R-06Ai tubing is freeze protected to 2000 ft. BP Exploration, Inc. Well: R-06A Prudhoe Bay North Slope, Alaska Rig: Nord ic #1/CTU #7 End of Well Survey Report Provided in: True- Grid - ASP Job Number: AFE Number: 103O49 4P1168 Reviewed by' ~/~'~¢~,-,- BAKER HUGHES INTEQ 8000 - - 8200- 8400- B.P. Exploration Structure : Pad R Field : Prudhoe Bay Slot : R-06 Location : North Slope, Alaska East (feet) -> GRID 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 I I I t II 1 I II II II I I I I I I II I I II II II I I II I 4400 4200 4O0O 3800 3600 z 3400 0 3200 3000 v 2800 KOP - 9862 MD, 8724,10 TVDss Tie en - 8668.99 Tvd, 2662.45 N, 2519.54 E 2600 2400 Tie on - 28.02 Inc, 9800,00 Md, 8668.99 Tvd, 0.00 Vs . 9862 MD, 8724.10 TVDss 2200 J ~'~ol. lld by plurmer V g200 ~e ~tted; 2O-J~-Sa ~ ~f~m i~ R-0~ V~r~ ~1. I I I J 1 I I I I J I I I I I I I J I I I t i i i i i i i i i 1 i i i i i coo~n~t~ ~re ~ f~t ~emnce R-O~. 400 200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 r.. V~a~ ~pms ~. ~.n~ U~ - ~ - ( Vertical Section fee -> --- ..,~ ..,- ,~. --- Azimuth 57.54 with reference 2662.45 N, 2319.54 E from R-06 8600 8800 :3 9000 B.P. Exptoration Pad R R-06 Prudhoe Bay North Stope, Alaska SURVEY L [ ST [NG by Baker Hughes [NTEQ Your ref : R-O6A Our ref : svy400 License : Date printed : 20-Jan-99 Date created : 20-Jan-99 Last revised : 20-Jan-99 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 633665.590,5976451.290,999.00000,N Slot location is nTO 20 44.268,w148 54 13.567 Slot Grid coordinates are N 5977204.986, E 635048.990 Slot local coordinates are 753.70 N 1383.40 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is Grid North B.P. ExpLoration Pad R,R-06 Prudhoe Bay, North Slope, Alaska SURVEY LISTXNG Page 1 Your ref : R-O6A Last revised : 20-Jan-99 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R ! D C 0 0 R D S Depth Oegrees Oegrees Oepth C 0 0 R D ! N A T E S Deg/lOOft Sect Easting Northing 9800.00 28.02 66.98 8668.99 2662.45N 2319.54E 2.59 0.00 637368.53 5979867.43 9862.00 26.48 68.00 8724.10 2673.32N 2345.76E 2.60 27.96 637394.75 5979878.31 9889.06 33.28 61.35 8747.56 2679.15N 2357.89E 27.92 41.32 637406.88 5979884.14 9919.08 40.99 54.01 8771.49 2688.90N 2373.11E 29.58 59.40 637422.10 5979893.89 9955.74 50.66 45.14 8797.03 2706.03N 2392.96E 31.53 85.34 637441.95 5979911.01 9980.96 55.68 38.98 8812.15 2721.02N 2406.44E 27.89 104.76 637455.43 5979926.01 10002.71 61.98 ]3.34 8823.41 2736.05N 2417.38E 36.47 122.06 637466.37 5979941.03 10037.81 65.45 28.59 88~8.96 2763.03N 2433.55E 15.65 150.18 637482.54 5979968.01 10069.06 69.02 27.50 8851.05 2788.46N 2447.09E 11.87 175.25 637496.08 5979993.44 10106.99 78.72 28.18 8861.57 2820.64N 2464.09E 25.63 206.87 637513.08 5980025.62 10124.76 84.44 29.99 8864.17 2835.99N 2472.64E 33.73 222.32 637521.63 5980040.98 10149.46 88.09 28.38 8865.78 2857.50N 2484.65E 16.15 244.00 637533.64 5980062.49 10191.91 86.82 27.67 8867.67 2894.94N 2504.58E 3.43 280.91 637553.57 5980099.92 10235.21 87.56 27.34 8869.79 2933.30N 2524.55E 1.87 318.35 637573.54 5980138.28 10275.96 88.62 25.49 8871.15 2969.77N 2542.67E 5.23 353.21 637591.66 5980174.76 10311.71 87.50 20.67 8872.36 3002.63N 2556.67E 13.83 382.66 637605.66 5980207.62 10345.08 86.50 23.78 8874.11 3033.47N 2569.27E 9.78 409.85 637618.26 5980238.46 10378.21 87.05 30.55 8875.97 3062.89N 2584.37E 20.47 438.37 637633.36 5980267.87 10417.24 87.84 34.61 8877.71 3095.73N 2605.36E 10.59 473.71 637654.35 5980300.72 10450.29 87.31 37.60 8879.11 3122.41N 2624.81E 9.18 504.44 637673.80 5980327.40 10497.71 86.08 44.34 8881.85 3158.13N 2655.83E 14.42 549.79 637704.82 5980363.12 10566.64 85.95 48.70 8886.64 3205.44N 2705.72E 6.31 617.27 637754.71 5980410.43 10619.29 88.53 57.80 8889.18 3236.87N 2747.81E 17.94 669.65 637796.80 5980441.85 10650.21 90.40 60.68 8889.47 3252.68N 2774.37E 11.10 700.55 637823.36 5980457.66 10680.29 90.00 68.05 8889.37 3265.68N 2801.47E 24.54 730.40 637850.46 5980470.67 10725.99 90.65 72.86 8889.11 3280.96N 2844.53E 10.62 774.93 637893.52 5980485.95 10759.86 89.34 74.78 8889.11 3290.40N 2877.05E 6.86 807.44 637926.04 5980495.39 10792.54 88.02 73.02 8889.86 3299.46N 2908.44E 6.73 838.78 637957.43 5980504.45 10826.39 89.25 70.20 8890.67 3310.14N 2940.55E 9.09 871.61 637989.54 5980515.12 10875.89 89.16 66.15 8891.36 3328.53N 2986.49E 8.18 920.24 638035.48 5980533.52 10909.29 89.88 65.31 8891.64 3342.26N 3016.93E 3.31 953.30 638065.92 5980547.25 10937.64 90.22 66.50 8891.61 3353.84N 3042.81E 4.37 981.35 638091.80 5980558.82 10965.19 89.43 62.98 8891.70 3365.59N 3067.72E 13.09 1008.67 638116.71 5980570.58 11007.66 85.29 61.57 8893.65 3385.32N 3105.27E 10.30 1050.94 638154.26 5980590.31 11055.16 84.41 58.22 8897.92 3409.05N 3146.19E 7.26 1098.20 638195.18 5980614.03 11122.51 85.08 59.12 8904.08 3443.92N 3203.48E 1.66 1165.26 638252.47 5980648.90 11156.57 86.45 58.58 8906.60 3461.49N 3232.55E 4.32 1199.21 638281.54 5980666.47 11181.48 88.43 54.33 8907.71 3475.24N 3253.28E 18.81 1224.09 638302.27 5980680.22 11216.98 94.93 52.09 8906.67 3496.47N 3281.68E 19.36 1259.45 638330.67 5980701.46 11251.56 94.49' 52.37 8903.83 3517.58N 3308.92E 1.51 1293.77 638357.91 5980722.57 11297.73 89.51 53.20 8902.22 3545.48N 3345.66E 10.93 1339.73 638394.65 5980750.47 11328.93 86.89 58.67 8903.20 3562.94N 3371.48E 19.43 1370.89 638420.47 5980767.93 11362.58 86.94 60.45 8905.01 3579.96N 3400.45E 5.28 1404.47 638449.44 5980784.95 11394.06 87.28 .63.14 8906.60 3594.82N 3428.15E 8.60 1435.82 638477.14 5980799.81 11425.43 86.50 67.85 8908.30 3607.81N 3456.65E 15.20 1466.83 638505.64 5980812.80 11458.48 85.49 70.75 8910.61 3619.46N 3487.48E 9.27 1499.11 638536.47 5980824.45 11492.01 86.05 73.52 8913.09 3629.72N 3519.31E 8.41 1531.46 638568.30 5980834.70 11527.58 91.17 75.85 8913.95 3639.11N 3553.59E 15.81 1565.43 638602.58 5980844.09 11555.16 94.14 78.55 8912.67 3645.21N 3580.45E 14.55 1591.37 638629.44 5980850.20 11591.91 93.63 85.80 8910.18 3650.20N 3616.75E 19.73 1624.67 638665.74 5980855.18 ALL data in feet unless otherwise stated. CalcuLation uses minimum curvature method. Coordinates from R-06 and TVD from MSL - rkb = 55.2 ft. Bottom hole distance is 5772.20 on azimuth 47.57 degrees from weLLhead. Vertical section is from tie at N 2662.45 E 2319.54 on azimuth 57.54 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the CLarke - 1866 spheroid Presented by Baker Hughes [NTEQ B.P. Exploration Pad R,R-06 Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 2 Your ref : R-O6A Last revised : 20-Jan-99 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Oegrees Depth C 0 0 R D I N A T E S Oeg/lOOft Sect Easting Northing 11620.33 93.57 90.00 8908.39 3651.24N 3645.09E 14.75 1649.14 638694.08 5980856.22 11662.29 93.74 92.54 8905.72 3650.31N 3686.95E 6.05 1683.97 638735.94 5980855.29 11701.04 93.20 90.25 8903.37 3649.3711 3725.61E 6.06 1716.08 638774.60 5980854.35 11737.42 92.87 88.07 8901.45 3649.90N 3761.94E 6.05 1747.02 638810.93 5980854.89 11781.82 92.28 84.62 8899.45 3652.73N 3806.19E 7.88 1785.88 638855.18 5980857.71 11811.04 89.75 81.65 8898.93 3656.22N 3835.19E 13.35 1812.22 638884.18 5980861.21 11846.04 87.38 80.26 8899.81 3661.72N 3869.74E 7.85 18~4.33 638918.73 5980866.71 11874.97 87.13 77.74 8901.20 3667.23N 3898.11E 8.74 1871.22 638947.10 5980872.22 11908.46 86.10 72.74 8903.17 3675.75N 3930.43E 15.22 1903.06 638979.42 5980880.73 11936.85 85.98 71.92 8905.13 3684.34N 3957.41E 2.91 1930.44 639006.40 5980889.33 11964.45 85.86 68.88 8907.10 3693.58N 3983.34E 11.00 1957.28 639032.33 5980898.56 11994.29 86.80 64.65 8909.01 3705.32N 4010.70E 14.49 1986.66 639059.69 5980910.31 12037.67 85.15 62.17 8912.05 3724.69N 4049.39E 6.85 2029.70 639098.38 5980929.67 12077'.77 85.81 59.68 8915.22 3744.11N 4084.33E 6.41 2069.61 639133.32 5980949.10 12106.40 88.67 55.40 8916.59 3759.46N 4108.45E 17.96 2098.19 639157.44 5980964.44 12135.67 88.92 52.54 8917.21 3776.67N 4132.11E 9.81 2127.40 639181.10 5980981.65 12174.20 89.78 47.36 8917.65 3801.45N 4161.59E 13.63 2165.57 639210.58 5981006.44 12221.52 87.71 48.16 8918.68 3833.25N 4196.61E 4.69 2212.19 639245.60 5981038.24 12259.34 88.58 45.88 8919.91 3859.02N 4224.27E 6.45 2249.35 639273.26 5981064.01 12279.50 88.92 45.55 8920.35 3873.09N 4238.69E 2.35 2269.08 639287.68 5981078.08 12310.00 88.92 45.55 8920.92 3894.45N 4260.46E 0.00 2298.91 639309.45 5981099.43 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from R-06 and TVD from MSL - rkb = 55.2 ft. Bottom hole distance is 5772.20 on azimuth 47.57 degrees from wet[head. Vertical section is from tie at N 2662.45 E 2319.54 on azimuth 57.54 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes [NTEQ BAKER HUGHES INTEQ EOW Survey Calculations Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLAN Company: B.P. Exploration Well: R-06A Calculation Method: Minimum Curvature Vertical Sect. Plane: 57.540 TRUE Vertical Sect. Plane: 58.560 (;RID Measured Depth from: RKB True Vertical Depth: Sea level Rig: Nordic #1/CTU #7 Job No: 103049 Field: Prudhoe Bay? Alaska AFE No: 4P-1168 Mag. Declination: 27.970 BHI Rep: H. Wal~oner, M. Miller Grid Correction: 1.020 Job Start Date: 23-Dec-98 Total Correction: 26.950 Job End Date: 03-Jan-99 RKB Height: 55.200 Meas. Depth 9800.00 9862.00 9889.06 9919.08 9955.74 9980.96 lncl. Angle (de#) 28.02 26.48 33.28 40.99 50.66 55.68 10002.7 i 61.98 10037.81 65.45 10069.06 10106.99 10124.76 10149.46 10191.91 10235.21 10275.96 TRUE Azi. (deg) 68.00 69.02 62.37, 55.03 Subsea TVD (ft) 8668.99 Vertical Section !o,o) 0.00 8724.11 28.04 8747.56 41.43 8771.49 59.51 46.16 8797.03 85.37 40.00 8812.15 104.69 34.36 8823.41 121.87 Dogleg Severity °/100ft. 0.00 2.60 27.92 29.58 31.53 27.89 36.47 29.61 8838.96 149.73 15.65 69.02 28.52 8851.05 174.55 !1.8' 78.72 29.20 8861.58 205.84 25.63 8864.18 31.01 84.4z 88.09 86.82 87.56 88.62 221.14 242.61 29.40 10311.71 87.50 10345.08 86.50 10378.21 87.05 8865.79 28.69 8867.67 279.14 28.36 8869.79 316.19 26.51 8871.15 350.67 8872.36 8874.11 379.75 406.60 21.69 24.80 31.57 8875.98 434.81 10417.24 87.84 35.63 8877.72 469.86 10450.29 87.3 38.62 8879.12 500.37 86.08 45.36 85.95 49.72 58.82 61,70 69.07 73.88 75.80 74.04 10497.71 10566.64 1(B19.29 10650.2 ! ! 0680.29 i 0725.99 10759.86 10792.54 88.53 90.40 90.00 90.65 89.34 88.02 545.47 612.71 665.01 695.92 725.83 770.53 803.20 834.71 8881.85 8886.65 8889.19 8889.47 8889.37 8889.11 8889.11 8889.87! 33.73 16.15 3.43 1.87 5.23 13.83 9.78 20.47 10.59 9.18 14.42 6.3 17.94 11.10 Coords.-TRuE N(+)/S(-) Lat. (Y) 2620.74 2631.15 2636.76 2646.24 2663.01 2677.76 2692.59 2719.27 2744.46 2776.33 2791.53 2812.83 2849.90 2887.90 2924.04 E(+)/W(-) Dept (X) 2366.57 2392.98 2405.21 2420.60 GRID Azi. (deg) 66.98 68.00 61.35 54.01 Coords. - GRID N(+)/S(-) Lat. (Y) 2662.45 2673.32 2679.15 2688.91 2440.75 45.14 2706.03 2454.50 38.98 2721.02 2465.71 33.34 2736.05 2482.35 28.59 2763.03 2496.34 2513.91 2522.73 27.50 28.18 29.99 28.38 27.67 27.34 25.49 2535. i 3 2555.71 2576.37 2595.13 2788.46 2820.64 2835.99 2857.51 2894.94 2933.30 2969.77 2956.65 2609.72 20.67 3002.63 2987.26 2622.87 23.78 3033.48 3016.40 2638.48 30.55 3062.89 2660.05 3048.87 34.61 37.60 44.34 48.70 57.80 60.68 68.05 72.86 74.78 73.02 3075.19 2679.98 3110.36 2711.63 3156.77 3187.44 3202.78 24.54 3215.30 10.62 3229.81 6.86 3238.67 6.73 2762.35 2804.99 2831.84 2859.16 2~)2.48 2935.17 2966.71 3247.17 3095.74 3122.41 3158.14 3205.44 3236.87 3252.68 3265.68 3280.97 3290.40 3299.46 E(+)/W(-) Dep, (X) 2319.54 2345.76 2357.89 2373.11 Coords. - ASP N(+)/S(-) Lat. (Y) 5979867.45 5979878.32 5979884.15 5979893.91 E(+VW(-) Dep.(X) 637368.54 637394.76 637406.89 637422.11 2392.96 5979911.03 637441.96 2406.44 5979926.02 637455.44 2417.38 5979941.05 637466.38 2433.55 5979968.(/3 637482.55 2447.09 5979993.46 637496.09 2464.09 5980025.64 637513.09 2472.63 2484.65 2504.57 2524.55 2542.66 5980040.99 637521.63 5980062.51 637533.65 5980099.94 637553.57 598t)!38.30 637573.55 5980174.77 5980207.63 5980238.48 598{)267.89 5980300.74 5980327.41 598(1363.14 2556.67 2569.27 2584.36 26O5.35 2624.81 2655.83 2705.71 5980410.44 2747.81 598tN41.87 598{N57.68 2774.37 2801.47 2844.52 2877.05 2908.44 5980470.68 5980485.97 5980495.40 5980504.46 637591.6x 637605.67 637618.27 637633.36 637654.35 637673.81 6377{N.83 637754.71 637796.81 637823.37 637850.47 637893.52 637926.05 637957.44 i Meas. Incl. TRUE Subsea Vertical Dogleg Coords. - TRU. E ........ GRID Coords. - GRID Coords. - ASP ~ Depth Angle Azi. TVD Section Severity 'N(+)/S(-) E(+)/W(-) Azi. N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+VW(-) .. (de[~) !de~) (ft) (0,0) °/lOOft. Lat. (Y) Dep. (X) (de[~) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) i 0826.39 89.25 71.22 8890.67 867.67 9.09 3257.27 2999.01 70.20 3310.14 2940.55 5980515.14 637989.55 , 10875.89 89.16 67.17 8891.36 916.46 8.18 3274.85 3045.27 66.15 3328.54 2986.48 5980533.54 638035.48 10909.29 89.88 66.33 8891.64 949.60 3.31 3288.03 3075.95 65.31 3342.26 3016.93 598¢}547.26 638065.93 ,,, ! 0937.64 90.22 67.52 8891.61 977.72 4.37 3299.14 3102.03 66.50 3353.84 3042.81 5980558.84 638091.8 i 10965.19 89.43 64.00 8891.70 1005.10 13.09 3310.45 3127.15 62.98 ....3365.59 " ~067.72 ..... 5t)80570.59 638116.72 11007.66 85.29 62.59 8893.65 1 047.43 10.30 3329.51 3 ! 65.04 61.57 3385.32 3105.27 598(}590.32 638 i 54.27 11055,16 84.41 59.24 8897.92 1094.71 7.26 3352.50 3206.38 58.22 3409.05 3146.19 5980614.05 638195.19 ...... 11122.51 85.08 60.14 !' " 8904.09 1161.78 1.66 3386.35 3264.28 59.12 ' 3443.92 3203.47 598(}648.92 638252.47 11156.57 86.45 59.60 8906.60 1195.75 4.32 3403.4{) 3293.65 58.58 3461.49 3232.54 5981}666.49 63828 i.54 11181.48 88.43 55.35 8907.72 1220.61 18.81 3416.78 3314.63 54.33 3475.24 3253.28 5980680.24 638302.28 11216.98 94.93 53.11 8906.68 1255.92 19.36 3437.51 3343.40 52.09 3496.47 3281.68 5980701.47 638330.68 11251.56 9',:1.49' 53.39 8903.84 1290.17 1.51 3458.13 3371.02 52.37 3517.58 3308.92 5980722.58 638357.92 . . 11297.73 89.51 54.22 8902.23 1336.06 10.93 3485.36 3408.24 53.20 3545.48 ' 3345.66 5980750"'.'48 ....... 638394.(. 1 i 328.93 86.89 59.69 8903.21 1367.20 19.43 3502.36 3434.37 58.67 3562.94 337'1.48 5980767.94 638420.48 I 13'62.'58 86.94 61.47 8905.02 1400.79 5.28: 3518.87 3463.64 60.45 3579.96 3400.45 5980784.96 638449.45 11394.06 " 87.28 64.16 8906.60 . 1432.18 8.60 3533.23 3491.60 63.14 3594.82 3428.15 5980799.82 638477.15 11425.43 86.50 68.87 8908.31 1463.27 i 5.'~20 3545.71 3520.32 67.85 3607.81 3456.64 5980812.81 638505.64 ,, I 1458.48 85.49 71.77 8910.62 1495.65 9127 3556.81 3551.36 70.75 3619.46 3487.48 598{)824.46 638536.48 11492.{) 1 86.05 74,5,4 8913.09 1528.16 8.41 3566.50 3583.36 73.52 3629.72 i' 3519.30 5980834.72 638568.3(} ,,, 11527.58 91.17 76.87 8913.95 1562.30 15.81 3575128 3617.81 75.85 3639.11 3553.59 5980844.11 638602.59 11555.16 94.14 79.57 8912.68 1588.40 14.55 3580.90 3644.77 78.55 3645.21 3580.45 5980850.21 638629.45 11591.91 93.63 86.82 8910.18 1621.97 19.73 3585124 3681.15 85.80 3650.20 3616.75 5980855.20 638665.75 .. 1162{).33 93.57 91.02 8908.40 1 646.69 14.75 3585.78 3709.51 90.00 3651.24 3645.08 5980856.24 638694.08 , 11662.29 93.74 93.56 8905.72 1681.93 6.05 3584.10 375 ! .34 92.54 3650.31 3686.95 5980855.31 638735.95 1 i 701.04 93.20 91.27 8903.38 1714.42 6.06 3582.47 3789.99 ' 90.25' 3649.37 3725.61 598{}854.37 638774.6 i 11737.42 92.87 89.09 8901.45 ! 745.69 6.i)5 3582.36 3826.3 i 88.07 3649.90 3761.93 5981)854.91) 638810.93 11781.82 92.28 85.64 8899.45 1784.93 7.88 3584.40 3870.61 84.62 3652.73 3806.19 5981)857.73 638855.19 11811104 89.75 82.67 8898.94 1811.49 13.35 3587.37 3899.67 81.65 3656.22 3835.19 5980861.22 638884.19 11846.{)4 87.38 81.28 8899.81 1843.84 7.851 3592.26 3934.31 80.26 3661.72 3869.74 5980866.72 6~89 i 8.'74 11874.97 87.13 78.76 8901.20 1870.91 8.74 3597.26 3962.77 77.74 3667.23 3898. ! 1 5981)872.23 638947. I I I 1908.46 86.10 73.76 8903.181 1902.93 15.22 3605.20 3995.24 72.74 3675.75 3930.42 5980880.75 638979.4. 11936.85 85.98 72.94 8905.14 1930.43 2.91 3613.32 4022.37 71.92 3684.34 3957.41 5980889.34 6~9(J06.41 ! 11964.45 85.86 69.90 8907.10 1957.38 11.00 3622.09 4048.46 68.88 3693.58 3983.34 5981)898.58 6391)32.34 I 11994.29 86.80 65.67 8909.01 1986.84 14.49 36J3.34 4076.02 64.65 370~.32 4010.70 5980910.32 639059.70 , 12037.67 85. ! 5 63.19 8912.06 2029.96 6.85 3652.02 41 ! 5.06 62.17 3724.69 4049.39 5980929.69 639098.39 12077.77 85.8 60.70 8915.22 2069.89 6.41 3670.82 4150.33 59.68 3744.11 4084.32 5980949.11 639133.32 i 2106.40 88.67 56.42 8916.60 2098.48 17.96 3685.73 4174.72 55.40 3759.46 4108.44 5981.)964.46 639157.44 12135.67 88.92 53.56 8917.21 2127.64 9.81 3702.52 4198.69 52.54 3776.67 4132.11 5980981.67 639181.11 12174.20 89.78 48.~8' '8917.~5 2165.72 i3.63 3726.77 4228.60 47.36 3801.45 4161.59 5981006.45 639210.59 I 12221.52 87.71 49.18 8918.69 2212.19 4.69 3757.94 4264.19 48.16 3833.25 4196.61 5981038.25 639245.61 12259.34 88.58 46.90 8919.91 2249.22 6.45 3783.22 4292.29 45.88 3859.02 4224.26 5981064.02 639273.26 12279.50 88.92 46.57 8920.35 2268.87 2.35' 3797.03 ~.306.97 45.55 3873.09 4238.69 5981078.09 639287.69 12310.00 88.92 46.57 '8930.93 2298.59 0.00 38 i 7.99 4329.12 45.55' 3894.45 4260.46 5981099.45 639309.46 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Ch risten so rf,/,~,/',~ DATE' Chairman THRU' Blair Wondzeil, ~ FILE NO' P. I. Supervisor FROM' Larry Wade, I~',~,,.~/~ SUBJECT: Petroleum In~pect~ December 20, 1998 .DOC BOP Test Nordic/Dowell 1 PBU R-06 PTD 98-127 December 20,1998: I traveled to BPX R-Pad to witness a BOP test on Nordic/Dowells #1. The rig looked to be kept in a clean and orderly manner. The test went well except for a valve in the choke manifold which had to be serviced to pass the pressure test. SUMMARY: I witnessed a BOP test on Nordic/Dowell 1,4 hours,0 failures. Attachments: aiugltfe.xls cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report (For Coil Tubing Units) OPERATION: Drlg: X Thru tubing: Drlg Contractor: Nordic/Dowell Rig No. Operator: BPX Well Name: R-O6ai Casing Size: 7 Set @ 10,681 Test: Initial X Weekly Other 12/21/98 DATE: 1 PTD # 98-127 Rig Ph.# Rep.: Dave Hildreth Rig Rep.: Zane Montague Location: Sec. 32 T. 12N R. 13E Meridian Umiat Test Pressures 250/4000 Test MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok PTD On Location Standing Order Posted Well Sign X Unit Condition X Hazard Sec. X FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Quan. Pressure P/F BOP STACK: Annular Preventer Blind/Shear Rams Blind/Shear Rams Pipe Rams Pipe Slip Rams HCR Valves Kill Line Valves Check Valve Quan. 1 Test Press. P/F 0 P 250/4000 P 250/4000 P 250/4000 P 250/4000 P 250/4000 P 250/4000 MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X X H2S Gas Detector X X CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 15 250/4000 P 32 250/4000 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch covers: Master: Nitgn. Btl's: 3,000 I 2,150 minutes 23 minutes 24 x Remote: 1900-2300-2500 Psig. sec. sec. Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested '/a Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279.1433 REMARKS: Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YE5 X NO Waived By: Witnessed By: Larry Wade FI-021L (Rev.12/94) Aiugltfe.xls TONY KNOWLES, GOVERNOR ~kLASKA OIL AND GAS CONSERVATION COMMISSION ,.3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: -307) 276-7542 Jul,,' 7. 1998 Ted Stagg Coilcd Tubing Drilling Enginccr BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Prudhoc Bay Unit R-06Ai BP Exploration (Alaska) Inc. Permit No. o8-127 Sur. Loc. 729'NSL. 1400'EWL. Scc. 32. T12N. RI3E. UM Btmholc Loc. 1067'SNL. 4648'WEL. Scc. 33. TI2N. RI3E. UM Dear Mr. Stagg: Enclosed is thc approvcd application for pcrmit to rcdrill thc above rcfcrcnccd xvcll. The pcrmit to rcdrill docs not exempt you from obtaining additional pcrmits required by law from other governmental agcncies, and docs not authorize conducting drilling opcrations until all other required permitting determinations arc made. The blowout prcvcntion cquipmcnt (BOPE) must be tcstcd in accordance v~'ith 20 AAC 25.035: :md the mechanical integrity (MI) of thc in.jcction xvclls must bc dcmonstratcd under 20 AAC 25.412 and 20 25.030{g)(3). Sut'ficicnt notice (approximatcly 24 hours) of thc Nil test bcforc opcration, and of thc BOPE tcst pcrtbrmcd bcforc drilling bcloxv thc surfiqcc casing si~oc, must be given so that a representative o£ thc CommissioP, may xvitncss the tests. Notice nlax' be given by um ficld inspector on thc North Slopc pager at 659-3607. · Chairman '"~__..) BY ORDER OF TIlE COMMISSION dlffEnclosure CC' Dcpartmcnt of Fish &Gamc. Habitat Section xx'/o cncl. Departmcnt of Environmcntal Conscrvation w/o cncl. STATE OF ALASKA ~ ALASKA' L AND GAS CONSERVATION CO~w'MISSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork ~[]Drill []Redrill Ilb Typeofwell []Exploratory [] Stratigraphic Test I--I Development Oil Re-Entry [] Dee.p...~r!I ' []Service [] Development Gas []Single Zone []Multiple Zone ........ 2. Name of Operator "5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBD = 55.09 AMSL Prudhoe Bay Field / Prudhoe 3. Address i6. Property Designation Bay Pool P.O. Box196612, Anchorage, Alaska 99519-6612 ADL 028278 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 729' NSL, 1400' EWL, SEC. 32, T12N, R13E, UPM ................ Prudhoe Bay Unit ....... At top of productive interval 8. Well Number Number 2S100302630-277 N/^ - water injection well R-06Ai At total depth 9. Approximate spud date Amount $200,000.00 1067' SNL, 4648' WEL, Sec. 33, T12N, R13E 7/13/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15'." prOPosed depth (MD and TVD) ADL 028279 @ 630'I No Close Approach 2560 12,265; 8899'TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9940' Maximum Hole Angle 90° Maximum surface 3300 psig, At total depth (TVD) @8800' 3667 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 4-1/2" 3-1/2" 9.3# L-80 ST-L 3070' 9,195 8057 12,265 8,899 140 c.f. ..... I ............ '3 ~!'~'~ !19. To be completed for Redrill. Re-entry. and Deepen Operations. " i?~. Present well condition summary Total depth: measured 10688 feet Plugs (measured) J true vertical 9537 feet ~;~'"'~"~ Ui~ Effective depth: measured 10535 feet Junk (measured) fill at 10535' MD (11/89)''''~'~';~:'' true vertical 9396 feet Casing Length Size Cemented MD TVD Structural Conductor 110 20x30 605 c.f. 144 144 Surface 2627 13-3/8" 3863 c.f. 2661 2661 Intermediate 9706 9-5/8" 1514 c.f. 9740 8671 Production Liner 1454 7" 336 c.f. 9227-10681 8225-9530 Perforation depth: measured 9861'- 9935' Sqzd: 10076-85,10105-29 10000'-10028', 10038'-10066', 10085'-10105', 10129'-10136' Plug with Pkr@10072' true vertical subsea 8723'-8790' (Sag R.) 8849'-8973' (four Ivishak intervals) ...... , ....................................... , ......... 20. Ai'iachm'entS'l~ Filing Fee [] Drilling Fluid Program [] Property Plat [] Time vs Depth Pict [] BOP Sketch [] Refraction Analysis [] Diverter Sketch [] Seabed Rep Contact Engineer Name/Number: Ted Stagg 564-4694 Prepared By Name/Number: Theresa Mills 564-5894 ....... , .... 2i11 hei'eby c'ertify that tl~e foregoing is true and correct to the be;'t of my knowledge si,ned Ted Staaa Title Coiled Tubing Drilling Engineer Date Commission Use Only Per. Number I APl Number I Approval Dante.,.. I See cover lottor ~'~;:>' ,/'~-'7 50- ~.2. ~-- ~ ~3 .~ <~' ~'--' ~:~ ] ~' ~"/~'-' ~' ~ for other requirements Conditions of Approval: Samples Required [] ~es ~ , No Mud Log Required [] Yes...~ No .y rog n [] irectio. Survey.equi e [] Required Working Pressure forBOPE [] 2M; [] 3M; [] ~[] 10M; [] 15M Other: .~T IZ~-.~a-(r..Z3 p~..~ o~...'"¢'e l,u8.~¢...~ ,or, e,o, Oa e Approved By j:tq!RS~ Rigncd By Commissioner the commission Form 10-401 Rev. 12-01-85 ,')avid W. Johnston Submit In Triplicate BPX. R-06ai Sidetrack Summary of Operations: R-06i is being sidetracked to improve injection conformance in Zone 4. This sidetrack will be conducted in two phases. Phase 1: Set whipstock and downsqueeze abandonment cement: Planned for 6/29198. · An inner annulus pressure test has been performed. A Kinley caliper has been run over the tubing and liner. · A permanent whipstock will be set on ELine at approximately 9920' MD, between existing perforations. · Existing perforations will be abandoned with approx. 20 bbls cement by downsqueezing above and below the whipstock. Abandonment cement will be pressure tested to 1500 psi with AOGCC witness. Phase 2: Mill Window and Drill Directional Hole: Planned for 7113198. Directional drilling coil tubing equipment will be rigged up and utilized to mill the window and drill the 4 W'directional hole as per attached plan to planned TD of 12,265' MD (8,899' TVDss). Mud Program: - Phase 1: Seawater - Phase 2: FIo-Pro (8.8 - 8.9 ppg) Casing Program: - 3 %, L-80, ST-L liner will be run from TD to approx. 9195' MD and cemented with approx. 25 bbls. cement. The well will then be perforated with coil tubing conveyed guns. Well Control: - BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 9940' MD (8,795' TVD ss) - TD: 12,265' MD (8,899' TVD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · A CBL log will be run in the 3 %"liner as deep as possible with e-line conveyed logs. TREE: 6" McEvoy WELLHEAD: McEvoy ACTUATOR: Otis ,.. (, R( .6ai Proposed Compleuon KB. ELEV = 55.09' BF. ELEV = 21.31' 13-3/8",72#/ft, L-80, BTRS 13 3~8" Shoe 2661 FOC- m....._ SSSV LANDING NIPPLEI ( Otis )( 5.96" ID) 2017 7",26#/ft, L-80, TUBING TUBING ID: 6.276" CAPACITY: .0382 BBL/FT PERFORATION SUMMARY REF: LOG: BHCS 9-27-79 INTERVAL (:~PEN/SQZ'D 9861-9935 OPEN 9861-9905 OPEN 6-95 10000-10028 10038-10066 10085-10105 10129-10136 OPEN/11-89 OPEN/11-89 OPEN/11-89 OPEN/11-89 Top 7" Liner Hanger 9 5/8" 47# L-80 BTRS shoe MARKER JOINT 9227 9740 9933' Top Whipstock approx. 9920' MD Abandonment cement to be downsqueezed past whipstock 7" Otis WD PACKER 4" MIN ID 10072 4 1/2 .... X" NIPPLE (Otis) (3.813" ID) I 10078 J (Otis) (3.725" ID) 10081 4/12" WLEG 10083 (Otis) (4"ID) 7"x5 1/2" CROSSOVER SLIDING SLEEVE Otis XA ( 4.562" MIN. ID) 9085 9098 9134 9187 9209 9221 9-5/8" PACKER ( TIW )(4.75"1D) 5 1/2 .... X" NIPPLE (Parker) (4.562 X" ID) 5 1/2 .... XN" NIPPLE (Parker)(4.55" ID) 5 1/2" Seal Assembly / No Seal Could not get back down J 9210' ELMD in the liner top with the I Seal Assembly 4 1/2" open hole 3 1/2" cemented liner PBTD (Junk) 10630 7" ,29#/ft, L-80, BTRS 10681 R-06 VeAical Section o 500 8700 ~ ,,~,.,.,-,-TSAG. 8750 Path Distance (Feet) 1,000 1,500 2,000 2,500 3,000 3,500 {TSGR 8723ss, 9860'MD i J TSHU ~. J 8,860- J ~ -- 8800 8850 T 8900 [~- 8,965 9000 ~ 9050 - Tot Drld:2325 ft 12265 TD Marker Depths (~Orig Wellbore TSAG TSHU TSAD J 8,723Jrt TVD ! 8,76s1~ ~o s,ssol. Kick Off 8,7951ft -I'VD 9,9401ft MD Deprtr (~KO 3,599 ft JMD KO Pt 9,940J MD New Hole 2325J I Total MD 12,265J TVD TD 8,899J DLS degll00 Tool Face Length Curve 1 28 -10 251 Curve 2 6 90 339 Curve 3 6 -90 309 Curve 4 6 180 189 Curve $ 6 90 319 Curve 6 6 -90 294 Curve 7 6 0 224 Curve 8 6 -90 400 2,325 Drawn: 6/11/98 13:41 Plan Name: Case 102 4,000 3,500 3,000 2,500 2,000 R-06 2,500 3,000 3,500 4,000 X distance from Sfc Loc 4,500 5,000 JWell Name R-06 J CLOSURE JDistance 5,691 ft Az 51 deg NEW HOLE E/W (X) N/S (Y) Kick Off 2,378 2,682 TD 4,436 3,565 State Plane 639,485 5,980,770 Surface Loc 635,049 5,977,205 DLS degl100 Tool Face Length Curve 1 28 -10 251 Curve 2 6 90 339 Curve 3 6 -90 309 Curve 4 6 180 189 Curve 5 6 90 319 Curve 6 6 -90 294 Curve 7 6 0 224 Curve 8 6 -90 400 2,325 Drawn: 6/11/98 13:41 Plan Name: Case 102 R-06ai CT Drilling & Completion BOP 2 3/8" CT Pack-Off Lubricator~ 12" 36" z 22.5" · 18"I :38" 7 1116" Annular 7 1116" Pipe/Slip ~ 7 1116" ~ ~ 2 318" Pipe SWAB OR MASTER VALVE I 2 3~8" · WELL PERMIT CHECKLIST FIELD & POOL COMPANY INIT CLASS ADMINISTRATION ENGINEERING WELL NAMF_~'_ .~'6~./ PROGRAM: exp [] dev [] redr_,r~se~/~wellbore seg o ann. disposal para reqO GEOL AREA ..... ~;' ,,~ UNIT# //.~.._<:,,~ r ON/OFF SHORE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. 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 ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... N Y N ~Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N N 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. DATE GEOLOGY ~,PPR 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. HOPEs, do they meet regulation ................ 26. HOPE press rating appropriate; test to .5'Oc:~ G psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. 30. 31. 32. 33. 34. Is presence of H2S gas probable ................. tv~ ~,~.y~ Permit can be issued w/o hydrogen sulfide measures ..... Y ~ Data presented on potential overpressure zones ....... ~1 ---~ ! ~ Seismic analysis of shallow gas zones ............. /'Y N f/'_./,, ./"-/~ Seabed condition survey (if off-shore) ............. J Y N Con, tact, nam. e/phon,e.for weekly progress reports ...... -,¢/ Y N lexp;ora~ory on;yj ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: JDH UIC/Annular COMMISSION' co (.o t'l-/4, - Comments/Instructions: M:chekiist rev 05/29/98 dlf:C:\msoffice\wordian\diana\checklist Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information'of this nature is accumulated at the end of the file under APPENDIX. No special'effod has been made to chronologically organize this category of information., Sperry-Sun Drilling Services LIS Scan Utility Sun Feb 25 18:21:15 2001 Reel Header Service name ............. LISTPE Date ..................... 01/02/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/02/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-90046 B. JAHN HILDRETH/WHI R-06A 500292038801 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 25-FEB-01 MWD RUN 2 AK-MW-90046 B. JAHN HILDRETH/WHI MWD RUN 3 AK-MW-90046 B. JAiN HILDRETH/WHI JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW-90046 B. JAHN HILDRETH/WHI MWD RUN 5 AK-MW-90046 B. JAHN HILDRETH/WHI MWD RUN 6 AK-MW-90046 B. JAI{N HILDRETH/WHI JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 AK-MW-90046 B. JAI{N HILDRETH/WHI MWD RUN 8 AK-MW-90046 B. JAHN HILDRETH/WHI MWD RUN 9 AK-MW-90046 B. JA_HN HILDRETH/SEV JOB NUMBER: LOGGING ENGINEER: OPEP~ATOR WITNESS: MWD RUN 11 AK-MW-90046 B. JAI{N HILDRETH/SEV MWD RUN 12 AK-MW-90046 B. JAHN HILDRETH/SEV MWD RUN 13 AK-MW-90046 B. JAHN HILDRETH/SEV JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 14 AK-MW-90046 B. JAHN HILDRETH/SEV 32 12N 13E .00 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.375 2661.0 2ND STRING 9.625 9740.0 3RD STRING 7.000 9871.0 PRODUCTION STRING 4.500 12308.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUB-SEA TRUE VERTICAL DEPTHS (TVDSS). 3. MWD RUNS 1-5, 11-14 ARE DIRECTIONAL WITH DGR (DUAL GAMMA RAY) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 6-10 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. TOOL CHAGE FROM DGR TO NGP SENSOR OCCURS AT 10309'MD,8872'TVDSS, AND FROM NGP PROBE TO DGR DETECTORS AT ll091'MD, 8901'TVDSS. MWD RUN 10 MADE NO FOOTAGE AND IS NOT PRESENTED. 5. MEASUREMENT AFTER DRILLING (MAD) DATA FROM RUN 14 IS USED IN THE INTERVAL 10805'MD, 8890'TVDSS TO lll00'MD, 8903'TVDSS OWING TO GAMMA RAY TOOL FAILURE. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER THE E-MAIL FROM D. DOUGLAS FOR D. DICKEY OF BP EXPLORATION (ALASKA), INC. ON 02/10/01. TIE-IN CONFIRMED BY BP BY CORREALTION OF MWD GR TO PARENT WELL (R-06 OH GR) JUST BELOW ~OP OF WHIPSTOCK AT 9862'MD, AND REVIEW OF RA TAG PLACEMENT. 7. MWD RUNS 1-9 AND 11-14 REPERSENT WELL R-06A WITH API#: 50-029-20388-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12308'MD, 8921'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9850.0 12272.0 ROP 9874.0 12308.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD 1 MWD 2 MWD 3 MWD 4 MWD 5 MWD 6 MWD 7 MWD 8 MWD 9 MWD 11 MWD 12 MWD 13 MWD 14 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP 9871 0 10023 10094 10145 10154 10339 10347 11090 11112 11121 11488 11662 12230 MERGE BASE 10023 0 10094 0 10145 0 10154 0 10339 0 10347 0 11090 0 11112 0 11121 0 11488 0 11662 0 12230 0 12308 0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification 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 Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9850 12308 11079 4917 9850 ROP 13.18 397.98 60.5812 4869 9874 GR 22.83 563.65 47.8289 4845 9850 Last Reading 12308 12308 12272 First Reading For Entire File .......... 9850 Last Reading For Entire File ........... 12308 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 R3~W MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9850.0 ROP 9874.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10001.5 10024.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : 26-DEC-98 INSITE 4.0 SOLAR, PCD 3.01E, SPC 5.74 MEMORY 10023.0 9871.0 10023.0 33.3 60.9 TOOL NUMBER SOLAR GM 72829 4.500 4.5 FLO-PRO 8.80 .0 9.0 7.2 .000 .000 .000 .000 50.8 .3 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification 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 Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 1 FT/H 4 1 68 4 2 GR MWD 1 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9850 10024 9937 349 9850 ROP 13.18 64.9 32.7976 301 9874 GR 60.58 563.65 140.914 304 9850 Last Reading 10024 10024 10001.5 First Reading For Entire File .......... 9850 Last Reading For Entire File ........... 10024 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical ~Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10002.0 ROP 10024.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10068.0 10094.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 26-DEC-98 INSITE 4.0 SOLAR, PCD 3.01E, SPC 5.74 MEMORY 10094.0 10023.0 10094.0 60.9 65.1 TOOL NUMBER SOLAR GM 72829 4.500 4.5 FLO-PRO 8.80 ~0 9.0 7.2 .000 .000 .000 .000 50.8 .3 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification 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 Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10002 10094 10048 185 10002 ROP 16.08 59.9 32.8841 140 10024.5 GR 51.96 423.98 191.212 133 10002 Last Reading 10094 10094 10068 First Reading For Entire File .......... 10002 Last Reading For Entire File ........... 10094 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10071.0 ROP 10094.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10120.0 10145.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: 26-DEC-98 INSITE 4.0 SOLAR, PCD 3.01E, SPC 5.74 MEMORY 10145.0 10094.0 10145.0 65.4 80.4 TOOL NUMBER SOLAR GM 697002 4.500 4.5 FLO-PRO 8.80 .0 9.0 7~4 .000 .000 .000 .000 50.2 .3 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined At, sent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10071 10145 10108 149 10071 ROP 16.77 146.94 59.9231 102 10094.5 GR 22.83 63.18 37.2581 99 10071 Last Reading 10145 10145 10120 First Reading For Entire File .......... 10071 Last Reading For Entire File ........... 10145 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10120.5 ROP 10145.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10127.0 10154.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: 27-DEC-98 INSITE 4.0 SOLA_R, PCD 3.01E, SPC 5.74 MEMORY 10154.0 10145.0 10154.0 88.1 88.1 TOOL NUMBER SOLAR GM 697002 4.500 4.5 FLO-PRO 8.80 .0 9.0 7.4 .000 .000 ,000 .000 46.6 .3 Data Format Specification Record Data Record Type .................. 0 Data Specification 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 Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 4 FT/H 4 1 68 4 2 GR MWD 4 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10120.5 10154 10137.2 68 10120.5 ROP 23.33 205.51 84.7094 18 10145.5 GR 29.51 31.52 30.3521 14 10120.5 Last Reading 10154 10154 10127 First Reading For Entire File .......... 10120.5 Last Reading For Entire File ........... 10154 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10127.5 ROP 10155.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10308.5 10339.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS 27-DEC-98 INSITE 4.0 SOLAR, PCD 3.01E, SPC 5.74 MEMORY 10339.0 10154.0 10339.0 86.8 88~6 TOOL NUMBER SOLAR GM 697002 4.5O0 4.5 FLO-PRO 8.80 .0 9.0 7.4 .000 .000 .000 .000 54.9 .3 Data Format Specification Record Data Record Type .................. 0 Data Specification 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 Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 5 FT/H 4 1 68 4 2 GR MWD 5 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10127.5 10339.5 10233.5 425 10127.5 ROP 33.47 397.98 66.4047 370 10155 GR 26.95 70.52 36.3061 363 10127.5 Last Reading 10339.5 10339.5 10308.5 First Reading For Entire File .......... 10127.5 Last Reading For Entire File ........... 10339.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type.' ............... LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10309.0 ROP 10340.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record STOP DEPTH 10315.5 10347.0 28-DEC-98 INSITE 4.0 SOLAR, PCD 3.01E, SPC 5.74 MEMORY 10347.0 10339.0 10347.0 87.5 87.5 TOOL NUMBER NGP SPC 295 4.500 4.5 FLO-PRO 8.80 .0 8.3 7.4 .000 .000 .000 .000 56.3 .3 Data Record Type .................. 0 Data Specification 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 Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 6 FT/H 4 1 68 4 2 GR MWD 6 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10309 10347 10328 77 10309 ROP 54.13 120.71 79.5593 15 10340 GR 26.09 28.22 27.0986 14 10309 Last Reading 10347 10347 10315.5 First Reading For Entire File .......... 10309 Last Reading For Entire File ........... 10347 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10316.0 ROP 10347.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 STOP DEPTH 11059.0 11090.5 30-DEC-98 INSITE 4.0 SOLAR, PCD 3.01E, SPC 5.74 MEMORY 11090.0 10347.0 11090.0 84.4 90.7 TOOL NUMBER NGP SPC 52 4.500 4.5 FLO-PRO 8.90 .0 9.0 6.4 .000 .000 .000 .000 63 .3 .3 Data Specification 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 Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 7 FT/H 4 1 68 4 2 GR MWD 7 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10316 11090.5 10703.2 1550 10316 ROP 32.06 229.98 62.6377 1487 10347.5 GR 23.93 127.12 39.6626 1487 10316 Last Reading 11090.5 11090.5 11059 First Reading For Entire File .......... 10316 Last Reading For Entire File ........... 11090.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... 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BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11061.0 ROP 11091.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11082.5 111112.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 30-DEC-98 INSITE 4.0 SOLAR, PCD 3.01E, SPC 5.74 MEMORY 11112.0 11090.0 11112.0 84.4 84.4 TOOL NUMBER NGP SPC 59 4.500 4.5 FLO-PRO 8.90 .0 9.0 6.4 .000 .000 .000 .000 63 .3 .3 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 Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 8 FT/H 4 1 68 4 2 GR MWD 8 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11061 11112.5 11086.8 104 11061 ROP 26.21 50.65 38.0445 44 11091 GR 24.92 43.15 33.1402 44 11061 Last Reading 11112.5 11112.5 11082.5 First Reading For Entire File .......... 11061 Last Reading For Entire File ........... 11112.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ............ STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11083.0 ROP 11115.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWkRE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11090.0 11121.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 31-DEC-98 INSITE 4.0 SOLAR, PCD 3.01E, SPC 5.74 MEMORY 11121.0 11112.0 11121.0 .0 .0 TOOL NUMBER NGP SPC 217 4.500 4.5 FLO-PRO 8.90 .0 9.1 6.0 .000 .000 .000 .000 63 .3 .3 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 9 FT/H 4 1 68 4 2 GR MWD 9 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11083 11121 11102 77 11083 ROP 46.15 55.62 52.8854 13 11115 GR 26.7 37.7 33.1067 15 11083 Last Reading 11121 11121 11090 First Reading For Entire File .......... 11083 Last Reading For Entire File ........... 11121 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11091.0 ROP 11121.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11451.0 11488.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet 01-JAN-99 INSITE 4.0 SOLAR, PCD 3.01E, SPC 5.74 MEMORY 11488.0 11121.0 11488.0 85.1 95.5 TOOL NUMBER SOLAR GM 69702 .500 4.5 FLO PRO 8.90 .0 9.0 5.8 .000 .000 .000 .000 60.8 .3 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined At, sent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 11 FT/H 4 1 68 4 2 GR MWD 11 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11091 11488 11289.5 795 11091 ROP 22.79 226.97 70.1736 734 11121.5 GR 28.42 109.85 43.5626 721 11091 Last Reading 11488 11488 11451 First Reading For Entire File .......... 11091 Last Reading For Entire File ........... 11488 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... 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BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11451.5 ROP 11488.5 $ LOG HE~DER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 11622.0 11661.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 01-JAN-99 INSITE 4.0 SOLAR, PCD 3.01E, SPC 5.74 MEMORY 11662.0 11488.0 11662.0 85.5 94.1 TOOL NUMBER SOLAR GM 72829 4.500 4.5 FLO PRO 8.80 .0 9.4 6.4 .000 .000 .000 .000 58.9 .3 Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 12 FT/H 4 1 68 4 2 GR MWD 12 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11451.5 11661.5 11556.5 421 11451.5 ROP 42.82 233.8 75.634 347 11488.5 GR 24.89 35.75 30.1232 342 11451.5 Last Reading 11661.5 11661.5 11622 First Reading For Entire File .......... 11451.5 Last Reading For Entire File ........... 11661.5 File Trailer Service name ............. STSLIB.012 Service Sub Level Name... 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BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11622.5 12190.0 ROP 11662.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 12230.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN 03 -JAN- 99 INSITE 4.0 SOLAR, PCD 3.01E, SPC 5.74 MEMORY 12230.0 11662.0 12230.0 85.2 93.7 TOOL NUMBER SOLAR GM 72829 4.500 4.5 FLO PRO 8.80 .0 9.4 6.8 .000 .000 .000 .000 65.6 .3 Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 13 FT/H 4 1 68 4 2 GR MWD 13 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11622.5 12230 11926.2 1216 11622.5 ROP 19.41 304.36 57.3204 1137 11662 GR 25.36 84.28 33.3882 1136 11622.5 Last Reading 12230 12230 12190 First Reading For Entire File .......... 11622.5 Last Reading For Entire File ........... 12230 File Trailer Service name ............. STSLIB.013 Service Sub Level Name... 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BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12190.5 12272.0 ROP 12230.5 12308.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined 04 -JAN- 99 INSITE 4.0 SOLAR, PCD 3.01E, SPC 5.74 MEMORY 12308.0 12230.0 12308.0 87.7 88.9 TOOL NUMBER SOLAR GM 69702 4.500 4.5 FLO PRO 8.90 .0 9.4 6.0 .000 .000 .000 .000 65.6 .3 Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 14 FT/H 4 1 68 4 2 GR MWD 14 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12190.5 12308 12249.2 236 12190.5 ROP 28.03 78.37 52.4653 156 12230.5 GR 26.1 37.35 29.6017 164 12190.5 Last Reading 12308 12308 12272 First Reading For Entire File .......... 12190.5 Last Reading For Entire File ........... 12308 File Trailer Service name ............. STSLIB.014 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.015 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/02/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/02/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
