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210-056
Originated: Delivered to:30-Jan-25 Alaska Oil & Gas Conservation Commiss 30Jan25-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED MT7-89 50-103-20889-00-00 224-089 Greater Mooses Tooth WL TTiX-PPROF FINAL FIELD 5-Jan-25 1R-06A 50-029-21331-01-00 210-056 Kuparuk River WL Plug Setting FINAL FIELD 13-Jan-25 3T-612 50-103-20896-00-00 224-128 Kuparuk River WL TTiX-SCMT FINAL FIELD 17-Jan-25 3S-610 50-103-20875-00-00 223-126 Kuparuk River WL TTiX-PPROF FINAL FIELD 23-Jan-25 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T40040 T40041 T40042 T40043 1R-06A 50-029-21331-01-00 210-056 Kuparuk River WL Plug Setting FINAL FIELD 13-Jan-25 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.31 08:15:00 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1R-06A KUPARUK RIV UNIT 1R-06A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 1R-06A 50-029-21331-01-00 210-056-0 W SPT 6266 2100560 1566 2240 2240 2240 2240 430 560 560 560 4YRTST P Austin McLeod 5/5/2023 MITIA 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:KUPARUK RIV UNIT 1R-06A Inspection Date: Tubing OA Packer Depth 660 3000 2940 2920IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230506181827 BBL Pumped:2.6 BBL Returned:2.5 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9James B. Regg Digitally signed by James B. Regg Date: 2023.06.02 10:50:40 -08'00' MEMORANDUM State of Alaska Initial Alaska Oil and Gas Conservation Commission TO: Jim Regg (\Cef I Z�I I� DATE: Monday, May 20, 2019 P.I. Supervisor � SUBJECT: Mechanical Integrity Tests 2100 CONOCOPHILLIPS ALASKA, INC. IA IR -06A FROM: Adam Earl KUPARUK RIV UNIT IR -06A Petroleum Inspector OA 550 Ste; Inspector 600 Reviewed By: i P.I. Supry Jljp. NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IR -06A Insp Num: mitAGE190510084852 Rel Insp Num: API Well Number 50-029-21331-01-00 Permit Number: 210-056-0 Packer Depth Well IR -06A Type Inj w -TVD 6266 PTD 2100560 Type Test SPT Test psi 1566 BBL Pumped: 0.9 ' BBL Returned: 06 ' Interval! 4YRTST P/F P Notes: MIT 1A Inspector Name: Adam Earl Inspection Date: 5/8/2019 Monday, May 20, 2019 Page I of I Pretest Initial 15 Min 30 Min 45 Min 60 Min ubing 2100 2400 2100 1100 IA 150 1850 Isis 1900 OA 550 600 _ 600 600' Monday, May 20, 2019 Page I of I STATE OF D AL OIL AND GAS CONSERVATION COMMI SION 'VE REPORT OF SUNDRY WELL OPERATIONS NOV 21 2017 • 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ AC i ) Ihtdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Appro dWrogram ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ACID STIMULATE 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 210-056 3.Address: P. 0. Box 100360,Anchorage,Alaska Stratigraphic❑ Service D 6.API Number: 99510 50-029-21331-01 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1 R-06A ADL 25635,ADL 25640 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10,940 feet Plugs measured None feet true vertical 6,639 feet Junk measured None feet Effective Depth measured 10,245 feet Packer measured 8,435 feet true vertical 6,708 feet true vertical 6,266 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 feet 16 " 110'MD 110 TVD SURFACE 4,622 feet 9 5/8" 4,659' MD 3693 TVD PRODUCTION 8,835 feet 7 " 8,870' MD 6604 TVD "A"LINER 785 feet 2 3/8" 10,245' MD 6708 TVD Tubing(size,grade,measured and true vertical depth) 3.5" J-55 8,862'MD 6,599'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER'FHL' PACKER 8,435'MD 6,266'TVD SAFETY VLV-CAMCO TRDP-1A SSS\ 1,908'MD 1,850'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED DEC 1 9 2017, Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 470 550 2128 Subsequent to operation: 0 0 900 1010 2277 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG D GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-259 Contact Name: Jason Burke Authorized Name: Jason Burke Contact Email: Jason.Burke@cop.com Authorized Title: Staff Engineer • O /� Contact Phone: (907)265-6097 Authorized Signature: ---"" Date: 4110 - vrv ' -/7/t7- RE : s L' Ee.; I at, Form 10-404 Revised 4/2017iZ /T/7 Submit Original Only • • IR-06A ACID STIMULATE DTTM JOBTYP SUMMARYOPS START 10/23/17 ACID RIH WITH NOZZLE, TAG AT 9272' CTMD, CLEAN OUT DOWN TO HARD TAG AT 9331' CTMD, LAY IN ACID FROM 9331' CTMD TO 8800' CTMD. TURN WELL OVER TO DSO, (JOB COMPLETE) KUP " 1R-06A Coiocoiilhips �+ Well Attribu Max Angle&MD TD Alaska,Inc Wellbore API/UWI Field Name Wellbore Status Ind(°) MD(ftKB) Act Btm(ftKB) Corloca4hillips 500292133101 KUPARUK RIVER UNIT INJ 99.25 10,360.89 10,940.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date '.� IR-06A,11/1520179.3727 AM SSSV:TRDP Last WO: 37.61 5/15/1985 Verocal schema=(actual) Annotation Depth(ftKB) End Date Annotator Last Mod By End Date Last Tag:SLM 8,770.0 12/14/2015 Rev Reason:TAG pproven 12/21/2015 11,7 4 HANGER;33.1 ■t irj. li_ Casing Strings )1 m M'�` Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread l U CONDUCTOR 16 15.062 38.0 110.0 110.0 65.00 H-40 WELDED 4 � Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len II...Grade Top Thread CONDUCTOR,38.0-110.0 ^SURFACE 9 5/8 8.921 37.0 4,658.7 3,693.4 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread WINDOW AL2 8 6.000 8,802.0 8,814.0 6,563.1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread • WINDOW A 8 6.000_ 8,820.0 8,832.0 6,577.5 SAFETY VLV;1,907.7 n T" Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)...Wt/Len p...Grade Top Thread it PRODUCTION Post S/T 7 6.276 34.8 8,870.0_ 6,604.3 26.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread GAS LIFT;2,040.8 al "A"LINER 23/8 1.995 9,460.0 10,245.1 6,708.4 4.70 L-80 STL al Liner Details GAS LIFT;4,325.9Ill Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 9,460.0 6,726.9 93.43 Anchor-billet ANCHORED ALUMINUM BILLET 1.000 SURFACE;37.01,858.7• - Tubing Strings GAS LIFT;5,6308 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection It TUBING Post S/T 31/2 2.992 33.1 8,862.0 6,599.0 9.30 J-55 EUE8rd GAS LIFT;6,285.1 114 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS BFT;8,782.1 33.1 33.1 0.00 HANGER FMC TUBING HANGER w/PUP 3.500 II 1,907.7 1,850.0 29.47 SAFETY VLV CAMCO TRDP-1A SSSV 2.812 GAS LIFT;7,198.1al 8,421.1 6,255.5 41.75 PBR BAKER PBR 3.000 8,434.8 6,265.8' 41.46 PACKER BAKER'FHL'PACKER 3.000 GAS LIFT;7,615.2 8,584.4 6,380.3 38.77 BLAST RING BLAST RING(1) 2.867 111 8.727.9 6,493.5 36.93 BLAST RING BLAST RING(1) 2.867 GAS LIFT;8,080.8 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;8,381.0 at Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 8,800.5 6,552.1 35.66 WHIPSTOCK BOT 3.5"monobore WS w/retrieval tang/4-deg ramp 7/5/2010 1.000 PBR;8,421.1 I I removed PACKER;8,434.8 : 8,819.0 6,567.2 35.11 WHIPSTOCK BOT 3.5"monobore WS w/retrieval tang/4-deg ramp 6/14/2010 1.000 III removed GAS LIFT;8,473.4 Perforations&Slots II Shot GAS LIFT;8,514.5 DensTop(ND) Btm(TVD) (shots/ Top(DKR) Btm(ftKB) (ftKB) (ftKB) Zone Date k) Type Com 9.4/1.0 10,244.0 6,726.3 6,708.4 A-3,1R-06A 6/22/2010 32.0 SLOTS Alternating solid/slotted pipe-0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends al Mandrel Inserts St ati N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(int Sery Type Type 9n) (psi) Run Date Com 1 2,040.8 1,963.8 CAMCO KBUG 1 GAS I IFT DMY BK 0.000 10/30/2010 10:00 1111 2 4,325.9 3,449.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 11:00 . t 'E 3 5,630.8 4,355.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 10:00 1 [ 4 6,285.1 4,787.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 2:30 r 5 6,762.1 5,103.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 12:30 WHIPSTOCK 8,800.5 '' 'I 6 7,198.1 5,396.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 5:00 SLOTS;8,7E2.0-8,848.0 - :i 1' 7 7,615.2 5,683.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 6:00 WINDOW AL2;8,802.0-8,814.0 8 8,060.8 5,995.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 8:00 t.111il 9 8,381.1 6,225.8 CAMCO KBUG 1 GAS LIFT DMY rdo20 0.000 0.0 10/31/2010 11:00 1 8,473.4 6,294.9 CAMCO MMG-2 11/2 INJ OPEN 0.000 0.0 11/21/1993 2:00 WHIPSTOCK;8,819.0 '.' ' 0 ', -' 1 8,544.5 6,349.4 CAMCO MMG-2 11/2 INJ DMY RK 0.000 0.0 5/21/2010 2:00 WINDOW A,8,820.0-8,832.0 a f Notes:General&Safety End Date Annotation 7/19/2010 NOTE:WELL SIDETRACK 1R-06A,AL1,AL1-01,AL2,AL2-01 11 i 7/19/2010 NOTE:WELL IS INJECTOR THAT WAS PRE-PRODUCED UNTIL 11/27/2010 PRODUCTION Post 8;70.0 7/21/2010 NOTE:View Schematic w/Alaska Schematic9.0(2 pages) SLOTS;9,150.0-10,822.0 SLOTS;9,100.010,209.0 AL2-01 LINER;8,781.2-10,823.0 I AL1-01 LINER;8,815.4-11,805.0 SLOTS;9,471.010,24.0 _i i_ "A"LINER,9,460.010,245.1 I • OF 1.1" • Iyyy�s� THE STATE Alaska Oil and Gas of TT Ae c KA Conservation Commission 'wet__ 333 West Seventh Avenue 41-1617*-- GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke Staff Wells Engineer 6 Z01 , ConocoPhillips Alaska, Inc. }U\- P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1R-06A Permit to Drill Number: 210-056 Sundry Number: 317-259 Dear Mr. Burke: 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 . Foerster Chair DATED this-749 day of June, 2017. RBDMS JUN L 6 2017 • � RECEIVED EIVEI STATE OF ALASKA JUN 1 j 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION Od—C c,'Zcl/"7 APPLICATION FOR SUNDRY APPROVALS / 20 AAC 25.280 1.Type of Request: Abandon El Plug Perforations El Fracture Stimulate ❑ Repair Well El Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Acid Stimulate 0' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory 0 Development ❑ 210-056 • 3.Address: Stratigraphic IDService 0 , 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-21331-01 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes CINo CI i KRU 1R-06A ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25635,ADL 25640 • Kuparuk River Field/Kuparuk River Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,940' • 6,639' , 10245 . 6708 . 1286psi NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 72' 16" 110' 110' Surface 4,622' 9 5/8 4,659' 3,693' Production 8,870' 7" 8,870' 6,604' Liner 785' 2 3/8 10,245' 6,708' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9471-10244 . 6726-6708 3.500" J-55 8,862' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER'FHL'PACKER . MD=8435 TVD=6266 SAFETY VLV-CAMCO TRDP-1A SSSV - MD=1908 TVD=1850 12.Attachments: Proposal Summary E Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service CI ' 14.Estimated Date for 7/1/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG [ • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: T}} f)},> ' (, i' Contact Name: Jason Burke Authorized Title: ,C-A,1 /,iFFX___ Contact Email: Jason.Burke@cop.com Contact Phone: (907)265-6097 Authorized Signatur ---" . Date: '14-1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 i -7- 2-5 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test El Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No L7 Spacing Exception Required? Yes ❑ No z' Subsequent Form Required: /0 "— 4-0 RBDMS L - J V N 2 6 2017 APPROVED BY Approved by: I atLe--4.-14*--- COMMISSIONER THE COMMISSION Date:6 , 20' /7 O RIG I NSubsin Form ane Form 10-403 Rev'ed 4/2017 p r valid for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips Alaska,Inc. �r Drilling&Wells ConocoPhillips Well Intervention Alaska 1R-06A Acid Treatment (TBD) Engineer: Jason Burke Wells Engineer 907-231-4568 DAD, dynamic acid dispersion, is an acid outside-phase emulsion prepared and stabilized with dispersing agent F103. The purpose of the dispersion is to simultaneously dissolve acid-soluble minerals and remove oil paraffinic deposits. Target areas can be tubulars,perforations or the critical matrix. Objectives: Spot Dynamic Acid Dispersion (DAD) treatment with CT into perforations to increase injectivity • Coiled Tubing: Spot 100 bbl of DAD into formation 1. MIRU 1.5" CT,MU 5 port wash nozzle BHA 2. Begin RIH, enter slotted liner completion at 8781' MD. 3. Continue RIH until TD 10823' MD is reached or until CT locks up 4. When CT has reached ultimate depth begin pumping DAD treatment. When treatment is exiting the CT (depending on CT volume) shut in the choke and begin POOH at a rate that will allow treatment to be spotted from final depth to 8800' MD (At 10823' MD 100 bbl/1 BPM=100 min & 2023 ft/ 100 min=20 fpm). Chase the DAD treatment out of the CT with produced water or diesel. a. Do not exceed 4500 psi surface pressure 5. After an additional 5 bbl of fluid has been injected behind the treatment POOH 6. RDMO CT. Return well to injection. Function SLB Code Concentration Quantity Acid corrosion inhibitor A264 4 gpt 15 gal HC1 H036 221.4 gpt 934 gal Emulsifier F103 15 gpt 63 gal Iron Control L058 20 ppt 76 lbs Non-emulsifier W054 2 gpt 19 gal Xylene A026 100 gpt 420 gal June 7, 2017 1R-06A Well Work Procedure Page 1 of 1 KUP 1 R-06A ConocoPhillipsr Well Attribu Max Angl MD TD Ala ,. -Inc, - Wellbore APUUWI Field Name Wellbore Status ncl F.) MO(ftKB) Act Btm(ftKB) canoaPhai, 500292133101 KUPARUK RIVER UNIT INJ 99.25 10,360.89 10,940.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) "Rig Release Date 1. 16-06A,6(8/20178.04.17 AM SSSV:TRDP Last WO. 37.61 5/15/1985 11 Vertical scnemaec(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Virg Last Tag:SLM 8,770.0 12/14/2015 Rev Reason:TAG pproven 12/21/2015 HANGER,-33.1 .. , Casing Strings yurrrr,.,,.,,u»n,»uununirn"'�7 tN Casing Description OD(in) ID(in) Top(ftKB( Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I..Grade Top Thread CONDUCTOR 16 15.062 38.0 110.0 110.0 65.00 H-40 WELDED Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread CONDUCTOR;38.0-110.0 SURFACE 9 5/8 8.921 37.0 4,658.7 3,693.4 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(1...Grade Top Thread WINDOW AL2 8 6.000 8,802.0 8,814.0 6,563.1 Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread WINDOW A 8 6.000 8,820.0 "8,832.0 6,577.5 SAFETY VLV;1,907.7 /!77',. Casing Description OD(in) 10(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread II PRODUCTION Post S/T 7 6.276 34.8 8,870.0 6,604.3 26.00 J-55 BTC ar Casing Description 0D(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread GAS LIFT;2,040.8 "A"LINER 2 3/8 1.995 9,460.0 10,245.1 6,708.4 4.70 L-80 STL E. Liner Details GAS LIFT;4,325.9 Nominal ID I Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) 9,460.0 6.726.9 93.43 Anchor-billet ANCHORED ALUMINUM BILLET 1.000 SURFACE 370-4.6587 Tubing Strings GAS LIFT,5,630.8 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING Post SR 31/2 2.992 33.1 8,862.0 6,599.0 9.30 J-55 EUE8rd GAS LIFT;6,285.1 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inoi(') Item Des Com (in) GAS LIFT;6,762.1 33.1 33.1 0.00 HANGER FMC TUBING HANGER w/PUP 3.500 at 1,907.7 1,850.0 29.47 SAFETY VLV CAMCO TRDP-1A SSSV 2.812 GAS LIFT;7,198.1 a 8,421.1 6,255.5' 41.75 PBR BAKER PBR 3.000 8,434.8 6,265.81 41.46'PACKER BAKER'FHL'PACKER 3.000 GAS LIFT;7,815.2 la 8,584.4 6,380.3 38.77 BLAST RING BLAST RING(1) 2.867 8,727.9 6,493.5 36.93 BLAST RING BLAST RING(1) I 2.867 GAS LIFT;8,0608 It Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;8,381.0 Top(ND) Top Incl Top(ftKB) (ftKB) C) Des Com Run Date ID(in) 8,800.5 6,552.1 35.66 WHIPSTOCK BOT 3.5"monobore WS w/retrieval tang/4-deg ramp 7/5/2010 1.000 PBR.8,421.1 S l removed PACKER.8,434.8- il8,819.0 6,567.2 35.11 WHIPSTOCK-BOT 3.5"monobore WS w/retrieval tang/4-deg ramp 6/14/2010 1.000 Iremoved GAS LIFT;8,473.4 i Perforations&Slots Shot GAS LIFT;8,544.5 i, 11 Top(ND) Btm(ND) Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 9,471.0 10,244.0 6,726.3 6,708.4 A-3,1R-06A 6/22/2010 32.0 SLOTS Alternating solid/slotted pipe-0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends Mandrel Inserts se ati ---iev- on Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sent Type Type (in) (psi) Run Date Com 1 2,040.8 1,963.8 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 10/30/2010 10:00 2 I 4,325.9 3,449.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 11:00 Igg. 3 5,630.8 4,355.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 10:00 31 4 6,285.1 4,787.6 CAMCO -KBUG 1 GAS LIFT DMY 'BK 0.000 0.0 10/30/2010 2:30 5 6,762.1 5,103.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 12:30 ii I WHIPSTOCK;8,800.5 , 1 6 7,198.1 5,396.4 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 5:00 ' 7 7,6152 5,683.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 6:00 SLOTS.8782.0-8,848.0 WINDOW AL2;8,802.0.8,814.0 8 8,060.8 5,995.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 8:00 9 8,381.1 6,225.8 CAMEO KBUG 1 GAS LIFT DMY 'rdo20 0.000 0.0 10/31/2010 11:00 I' lB 1 8,473.4 6,2949 CAMCO MMG-2 11/2 INJ OPEN ' 0.000 0.0 11/21/1993 2:00 . WHIPSTOCK;8,819.0 '^\g 0 1 8,544.5 6.349.4 CAMCO MMG-2 11/2 INJ DMY RK 0.000 0.0 5/21/2010 2-00 : 1 I WINDOW A.8820.0-8,832.0 Notes:General&Safety i End Date Annotation a 7/19/2010 NOTE:WELL SIDETRACK 1R-06A,AL1,AL1-01,AL2,AL2-01 7/19/2010 NOTE:WELL IS INJECTOR THAT WAS PRE-PRODUCED UNTIL 11/27/2010 PRODUCTION Poet SR,34.8- 8,870.0 7/21/2010 NOTE:View Schematic w/Alaska Schematic9.0(2 pages) ) SLOTS;6150.0-18822.0 SLOTS;9,180.0-10,209.0 AL2-01 LINER;8,781.2-10,823.0 I I AL1-01 LINER;8.815.4-11,805.0 4- SLOTS;9,471.0-10244.0 _I I "A"LINER,9,460.0-10,245.1_____j L WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 8, 2016 Attn.: Makana Bender ° w 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 DATA LOGGED / t /2016 i't K. BENDER RE: Multi Finger Caliper(MFC)/Static Bottom Hole Pressure Survey: 1R-06A Run Date: 12/5/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1R-06A Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21331-01 Static Bottom Hole Pressure Survey 1 Color Log 50-029-21331-01 SCONE PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: /49.4112.-ftec..d,4edceat MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1-?21/ DATE: Wednesday,May 20,2015 P.I.Supervisor ' ,21/ 61 SI( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1R-06A FROM: Bob Noble KUPARUK RIV UNIT 1R-06A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1R-06A API Well Number 50-029-21331-01-00 Inspector Name: Bob Noble Permit Number: 210-056-0 Inspection Date: 5/14/2015 Insp Num: mitRCN150516102028 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IR-06A • Type Inj W-TVD 6266 Tubing 2140 • 2140 2170 - 2190- PTD 2100560 Type Test SPT Test psi 1566 • IA 525 2860 - 2780 - 2780 - Interval 4YRTST P/F P ✓ OA 280 500 • 490 490 - Notes: satitiE© !UL i 3 ?1315 Wednesday,May 20,2015 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c= 10 - 0 5‘40 Well History File Identifier Organizing (done) Two-sided III 111111 1 III ❑ Rescan Needed I I IIIIE III III CAN DIGITAL DATA OVERSIZED (Scannable) /7eyscale for Items: ❑ Di kettes, No. '� ❑ Maps: Items: Other, No/Type:G O • Other Items Scannable by a Large Scanner Poor Quality Originals:l kr VER (Non-Scannable) O IZED S ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: mf BY: Maria Date: � a / �� /s/ Project Proofing I 1E11 IIIII BY: Date: (ViP 1/7191/ /s/ Scanning Preparation 3 x 30 = qo + I = TOTAL PAGES 7 4 10(Count does not include cover sheet) BY: (Marii) Date: 1 cl. ° /s/ Production Scanning I Stage 1 Page Count from Scanned File: 9 ----(Count does include cover sheet) Page Count Matches Number in Scanning Preparation: 1 .YES NO BY: MP Date: 11,g,g1r 4 lsl f Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /5/ Scanning is complete at this point unless rescanning is required. I ReScanned I I BY: Maria Date: /s/ Comments about this file: Quality Checked 111111111111111 4.]/7ninn4 A 1A/-II LJ:-•--.f-:1-.in-.-fl-J-- 0 c 1 9 Fs i co c ! e--as N >- Iii = 0 d O 6-in E cc- o v a g c a) g O a 2 2 0 z o w 0) 2 2 a CO c Q To o d c r > 0 o 0 0 0 0 j N N N N Z o N N aV • 0 O O O 01 Q U J co C z co co co co - N O - al ici m c C C C C C E y c = = a 0. O. O. O. o. `" a c) ;� O U 0 0 0 0 0 0 E co et a c U y o 0 0 0 0 0 O N a a co o 0 0 0 sr 0 0 N — m z,c; 1 I CL J 0 j N 0 0 0 0 0 0 no£ W J t6 Ce us d U C t M• cocN N N 0 O V co co c co co co -o W Z > J N U 0 0 a Z c_ o cc a as 1-Q o cc o c J co O . CL IN m c >. E o ZI a)'175 13 U U y 76 8 O a� co y a a) O N 0 E co J u) N LO CD CO J a H9 CC 0. • O I z o f O N C N c p rn1 > d CO n c a o Y ZI u) T T T w T a o z �'o Ce > > t o d 0 00 N y y N i6 -J 0 N N N a) C)) V) z o 0 cc ceccccrorn I C C C C C C as w O O O O D o • CD I 7 is o = 7 7 ` 4-z. 2 LO y z c c c c o 6 '6 z m co w F=- p O a z 1ilv as O y O 0 c4 y:, Q O d z -o d F. \ \ o o z . _N % ca o z a p rn p re 7: O) J-. i v v 0 O U Ta I E a a o _ o _ p _ a o a) 0 w Q a m °�2 a 0 0 0 0 0 a y 0 o a c m o 0 CL a p I 3 -9 oI->' w J J J w Ce a 0 ¢Q t) 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday,December 29,2010 TO: Jim Regg P.I.Supervisor �� ��Z�`/ (0 SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1R-06A FROM: Bob Noble KUPARUK RIV UNIT 1R-06A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry i NON-CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1R-06A API Well Number: 50-029-21331-01-00 Inspector Name: Bob Noble Insp Num: mitRCN101212160729 Permit Number: 210-056-0 Inspection Date: 12/12/2010 • Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. well ' IR-06A1Type Inj. 1 W • TVD 6266 • IA 900 2200 " 2190 2180 2180 ' P.T.D 2100560 'TypeTest 1 SPT I Test psi 1 1566 • OA 550 690 690 690 690 Interval INITAL • P/F P Tubing 1240 1240 ( 1240 1220 1220 Notes: Held test for an extra 15 min. - Wednesday,December 29,2010 Page 1 of 1 Page 1 of 2 Maunder, Thomas E (DOA) From: CPF1 Prod Engr[n1269 @conocophillips.com] Sent: Sunday, December 05, 2010 9:10 AM To: Maunder, Thomas E (DOA) Cc: CPF1 DS Lead Techs; Bommarito, Forest; Glessner, Dana; CPF1 Ops Supv Subject: RE: 1R-06A LPP/SSV is back in service as of 12-03-2010 k0 — OS (o Tom, I had a typo in the e-mail below. The injection pressure was 800 psi when the LLP/SSV was placed back in service. The pressure is now above 1000 psi. David Lagerlef/Dan Bearden CPF1 Production Engineers n1269 @conocophillips.com 659-7493 pager 659-7000 765 From: CPF1 Prod Engr Sent: Saturday,December 04,2010 3:54 PM To: 'Maunder,Thomas E(DOA)' Cc: CPF1 DS Lead Techs; Bommarito,Forest;Glessner,Dana;CPF1 Ops Supv Subject: re: 1R-06A LPP/SSV is back in service as of 12-03-2010 Tom, The LPP/SSV for 1 R-06A is no longer defeated as of 12-03-2010. The well is currently injecting at a rate of about 2500 bwpd at over 600 psi wellhead pressure. Let me know if you have any questions. David Lagerlef/Dan Bearden CPF1 Production Engineers n1269 @conocophillips.com 659-7493 pager 659-7000 765 From: CPF1 Prod Engr Sent: Thursday,November 18,2010 6:31 PM To: 'Maunder,Thomas E(DOA)' Cc: CPF1 DS Lead Techs; NSK Prod Engr&Optimization Supv; Bommarito, Forest;Glessner,Dana;CPF1 Ops Supv Subject: Request for temporary waiver to defeat LPP/SSV for 1R-06A on 11-18-2010 Tom, ConocoPhillips requests administrative approval under CO 432D to operate 1 R-06A, a Kuparuk water injection well, with a defeated safety valve system. This request is similar to CO 406B administrative approval granted to the West Sak Pool. The LPP for injection well 1 R-06A will most likely need to be defeated due to low injection pressure. The well was pre-produced, following a CTD multilateral sidetrack, from July, 25, 2010 until October 23, 2010 when it was shut in to convert to injection. The work to convert the well to injection should be completed in the next few days and we would like to put the well on water injection shortly thereafter. We expect injection pressure to increase sufficiently in the next few weeks as the reservoir pressure increases. This will allow us to re-engage the SVS system and return the well to normal operations. vc- 1/21/2011 c-°( c) ......_..._.._____.... .._. Page 2 of 2 It is anticipated the well will begin injecting 2000 bwpd at pressures below the minimum LPP set point, perhaps initially on a vacuum. A MITIA was performed on 05/09/07 with the outcome listed below. Thanks in advance for your time on this matter and call or email me with any questions. Regards, David Lagerlef 05/09/07 State witnessed MITIA (Robert Noble) (passed). T/I/O= 1190/530/20. Pressured up IA to 1950 psi with 2.3 bbls diesel. 15 min reading= T/I/0= 1190/1910/20 . 30 min reading =T/I/O= 1190/1900/20. Bled IA. T/I/O= 1190/560/20. David Lagerlef/Dan Bearden CPF1 Production Engineers n1269 @conocophillips.com 659-7493 pager 659-7000 765 1/21/2011 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSL.m REPORT OF SUNDRY WELL OPERATIONS . 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate r Other pi PROD to WINJ Alter Casing r Rill Tubing r Fbrf orate New Fbol r Waiver r Time Extension r Change Approved Program r Operat.Shutdow n r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Current Well Status: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r -- 210-056 - 3.Address: 6.API Number: Stratigraphic r Service r P.O. Box 100360,Anchorage,Alaska 99510 - 50-029-21331-01 00 7.Property Designation: 8.Well Name and Number: ADL 25635,25640 - 1R-06A 9.Field/Pool(s): Kuparuk River Field/Kuparuk Oil Pool 10.Present Well Condition Summary: Total Depth measured 10940 feet Plugs(measured) None true vertical 6639 feet Junk(measured) None Effective Depth measured 10245 feet Packer(measured) 8435,8909 true vertical 6708 feet (true vertucal) 6266,6628 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110 110 0 0 SURFACE 4622 12 4659 3694 0 0 WINDOW"A" 12 8 8832 8832 0 0 PRODUCTION 9244 7 9279 6729 0 0 "A"LINER 785 2.625 10245 6708 0 0 0 0 0 Perforation depth: Measured depth: Slots:9471-10244 True Vertical Depth: 6726-6708 RECEIVED Tubing(size,grade,MD,and ND DEC 0 1 2010 9 ) 3.5,J-55,8931 MD,6640 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER'FHL'PACKER @ 8435 MD and 6266 TVD Alaska Oil &Gas Cons. Commission PACKER-BAKER'FB-1'PACKER @ 8909 MD and 6628 ND Anchorage SAFETY VLV-CAMCO TRDP-1A SSSV @ 1908 MD and 1850 ND 11.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 429 1195 109 1500 159 Subsequent to operation 1089 700 1864 13.Attachments 14.Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development r Service r 15.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations_ - GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 16.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 310-329 Contact Bob Christensen/Darrell Humphrey Printed Name o--ert D. Chris e -1 __ Title Production Engineering Specialist • Signature / .� . .:659-7535 Date r .4 yr fo IJA2 Vie Form 10-404 Revised 10/2010 RBDMS DEC 0'11010 h_.,... b y/-Nub i nal 049 1R-08A DESCRIPTION OF WORK COMPLETED SUMMARY • • Date Event Summary Pre Produced Injector turned to Water Injection service 10/28/10 TAG LINER TOP©8781' RKB. PERFORMED 30 MINS SBHPS @ 8500'RKB=1943 PSI, 145 DEG F. 15 MIN GRADIENT STOP @= 1938 PSI. 10/29/10 SET 3.5"WEATHERFORD WRP@ 8455'USING 1-11/16"SHORTY LONGSTROKE - SETTING TOOL. CCL-ME=15.7'CCL STOP DEPTH-8439.3' 10/30/10 DEPLOYED 2.75 AVA CATCHER SUB ONTOP OF WRP @ 8455'RKB. PULLED GLVS @ 2043',4326',6285', 7615' RKB AND SET DV'S. PULLED OV @ 8381'RKB AND LEFT POCKET OPEN FOR CIRC OUT. 10/31/10 CIRC OUT TBG X IA. SET DV @ 8381' RKB. MIT TBG TO 2500 PSI. PASSED. MIT-IA TO 3000 PSI-PASS. IN PROGRESS. 11/01/10 PULLED CATCHER SUB AND WRP @ 8455' RKB. 11/27/10 Commenced Water Injection service • v„- KUP 1R-06A ConocoPhilli Well Attributes Angle&MD TD Alaska,'I, ya+ Wellbore API/UWI Field Name Well Statue Intl(°) MD(SKS) Act Sire(ftKB) t.mocoHamps 500292133101 KUPARUK RIVER UNIT INJ 99.25 10,360.89 10,940.0 Comment '125(ppm) Date Annotation End Dab KB-Ord(ft) Rig Release Date ••• Well Conte:-1R-06A,11280108'.34.22 AM SSSV:TRDP Last WO: 37.61 5/15/1985 Schematic-Actual Annotation Depth(NKB) End Date Annotation Last Mod...End Data Last Tag: Rev Reason:GLV C/O,SET PLUG/CATCHER Imosbor 10/31/2010 Casing Strings HANGER,33 - Casing Description String 0... String ID..Top(ftKB) Set Depth(I...Set Depth(TVD)...String Wt...String... String Top Thrd r 1 CONDUCTOR 16 15.062 38.0 110.0 110.0 65.00 H-40 WELDED Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd ' I WINDOW cri In S 8 6. ID 8(1168) 8,832.0 th( 6,577.5 36.00 J-55 BTC CONDUCTOR, Casing Description String 0... String ID...Top(18(8) Set Depth(f...Set Depth(TVD)...String Wt...String...S41ng Top Thrd 3&710 PROgON Description String ..• 46.gID...Top(KKB) Set Depth(f...'Set Depth(TVD)...String Wt...String...String Top Thrd 9 34.8 9,279.2 l 6,728.9 26.00 J-55 BTC SAFETY VLV, .____I Caning Descrlptlon String 0... String ID...Top MKS) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 1,908 ° "A"LINER 23/8 1.995 9,460.0 10,245.1 6,708.2 4.70 L-80 STL GAS 111.11. { Liner Details Za, Top Depth (TVD) Top Inc! Noon... OAS LIFT, Top(19(8) (KKB) (°) Item Oescription Comment ID(In) 4,326 9,460.0 6,726.9 93.43 Anchor-billet -Anchored Aluminum Billit 1.000 SURFACE, Tubing Strings 37.4,858 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd GAS LIFT. TUBING 31/2 2.992 33.1 8,932.1 6,640.2 9.30 J-55 EUE8rd Ss" r Completion Details GAS LIFT, Top Depth 6,285 (ND) Top Intl Nomi... Top(SKS) PM 1"1 Item Description Comment 10(In) GAS LIFT. 33.1 33.1 -0.70 HANGER FMC TUBING HANGER w/PUP 3.500 8,762 1,907.8 1,848.6 28.88 SAFETY VLV CAMCO TRDP-1A SSSV 2.812 GAS,1 LIFT,98 1 8,421.1 6,255.9 41.30 PBR BAKER PBR 3.000 8,434.9 6,266.0 41.09 PACKER BAKER'FHL'PACKER 3.000 GAS LIFT, 7.ets 8,862.0 6,598.8 48.02 BLAST 2.992 L GAS LIFT, j 8,908.4' 6,627.7 55.19 LOCATOR BAKER LOCATOR SUB w/5'SEAL 4.000 8061 1 8,909.4 6,628.2 55.33 PACKER BAKER'FB-1'PACKER 4.000 OAS LIFT, irrii,. 8,912.7 6,630.0 55.76 SBE BAKER SEAL BORE EXTENSION 4.000 8,381 8,923.8 6,636.2 57.24 NIPPLE CAMCO'Cr NIPPLE NO GO 2.750 PBR,8,421 - r L I 8,931.3 6,639.8 58.80 SOS CAMCO SHEAR OUT SUB 2.992 PACKER,8,438 Other in Hole(Wireline retrievable plugs,valves,pun ps,fish,etc.) CATCHER. Top Depth 8,454 II,9,_wI (TVD) Top loci PLUG,8455 -- Top 11158) (KKB) (') Description Comment Run Elate ID(In) 11. 8,454.0 6,280.3 40.79 CATCHER CATCHER SET ON TOP OF PLUG 10/30/2010 0.000 GAS LIFT, 8,455.0 6,281.1 40.78 PLUG WRP 10/29/2010 0.000 8,473 r 8,819.0 6,567.2 35.11 WHIPSTOCK BOT 3.5"morobore WS w/retrieval tang/4-deg ramp 6/14/2010 1.000 GAS LIFT, j removed 8.545 1 8,920.5 6,634.4 56.80 CIBP 2.69"CIBP 5/26/2010 0.000 9,145.0 6,710.1 79.26 FISH 1 1/2"GLV Valve Dropped;Could Still be in Tubing String 3/15/1986 Perforations&Slots Shot Top(TVD) Fite)(TVD) Dens Top(ftKB) 8tm(fh8) (MB) 15K8) Zone Date (eh..• Type Comment 9,471.0. 10,244.0 6,726.0 6,708.2 '6/22/2010 32.0-SLOT Alternating solid/slotted pipe- 0.125"12.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non-slotted ends Notes:General&Safety L End Date Annotation 7/19/2010 NOTE:WELL SIDETRACK 1R-06A,AL1,AL1-01,AL2,AL2-01 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED �, 7/21/2010 NOTE:View Schematic w/Alaska Schernatic9.0(2 pages) - WHIPSTOCK, I 8,819 WINDOW'A' 8,820-8,832 C i GAS LIFT MMG,8,890 '�� LOCATOR,_ _� L 8,908 7 PACKER,8,909 SBE,8913 - --( CIBP,8921 NIPPLE,8,924- Mandrel Details Top Depth Top Port 505,8,931 - lr. (TVD) Inc! OD Valve Latch Size TRO Run Ste Top(Po(B) ((MB) (°1 Make Model (In) Sery Type Type (in) (pm) Run Date Corn... 1 2,040.8 1,963.6 33.06 CAMCO-KBUG 1 GAS LIFT DMY BK 10/30/2010 Q 2 4,326.0 3,449.3 43.06 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 FISH,9,145 3 5,630.9 4,355.6 49.21 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 4 6,285.1 4,787.6 48.27 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 5 6,762.2 5,103.9 48.28 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 PRODUCTION, _ 6 7,198.2 5,396.4 47.03 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 35-9,279 7. 7,615.3 5,683.7 46.14 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 SLOT. 8 8,060.9 5,995.7 44.90 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 9,471-10.244 9' 8,381,1 6,225.9 42.60 CAMCO KBUG 1 1/2 PROD DMY rdo20 0.000 0.0 10/31/2010 'A'LINER, - 9,48018245'\ 10 8,473.5 6,294.9 40.49 CAMCO MMG-2 1 1/2 PROD OPEN 0.000 0.0 11/21/1993 TD(1R-06A), 10,940 • KUP 1R-06A • ConocoPhillips s Alaska,Inc KB-God(K) -Rlp Release Date 37.61 5/15/1985 Well Conaa.-1R-06A,110201013 34-22 AM T Schematic-Actual HANGER.33 CONDU&10 SAFETY VLV, 1 1,908 1 OAS LIFT, 2041 OAS LIFT, 4.326 SURFACE, __•� 37-4,669 OAS LIFT. 5,631 OAS LIFT, 6,285 OAS LIFT, 8782 OAS LIFT, 7,196 GAS LIFT, 7,615 OAS LIFT, 8,181 FF l GAS LIFT_ J 8,381 l r L PBR,8,421- PACKER,8,435 CATCHER, 8,451 PLUG.8.455 •V/% GAS LIFT, 8,473 L GAS LIFT, 8,545 WHIPSTOCK. 8,819 WINDOW"A", 8,8208,832 OAS LIFT HMO,LIFT LOCA8 O PACKER,8,909 ` /S SBE,8.913 ) CIBP.8.921 NIPPLE.8.924 I �. Mandrel Details Top Depth Top Port SOS.8.931 - (TVD) Inc! 00 Valve Latch Sloe TRO Run Stn Top MKS) (1B) P) Make Model (in) Sem Type Type (In) )psl) Run Data Corn... 11 8,544.5 6,349.5 39.15 CAMCO MMG-2 1 1/2 PROD DMY RK 0.000 0.0 5/21/2010 12 8,890.3 6,616.8 52.78 CAMCO MMG-2 1 1/2 PROD OPEN 0.000 0.0 5/21/2010 FISH,9,145-- PRODUCTION, 35-9,279 SLOT, • 9,47140,244 "A"LINER, 9,48010,245 TD(1R0,940 108A), Page 1 of, r Maunder, Thomas E (DOA) From: CPF1 Prod Engr[n1269 @conocophillips.com] Sent: Saturday, November 27, 2010 4:46 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr&Optimization Supv; NSK Prod Engr Specialist; Seitz, Brian; CPF1&2 Ops Supt; Glessner, Dana; Braden, John C Subject: LPP/SSV defeated on 1R-06A- 11-27-10 Tom/Jim, The low pressure pilot(LPP) on multi-lateral injector 1R-06A (210-056, 210-057, 210-058, 210-059, 210-083)was defeated on 11/27/2010 when the well was returned to injection service after being shut since 10/23/10 (after a 90-day pre-production period). Current wellhead pressure (as of 16:41 11/17/10) is 150 psi at an injection rate of 600 bwpd. The LPP and SSV have been tagged and their status is recorded in the"Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 700 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Daniel Bearden/David Lloyd Lagerlef CPF1 Production Engineers n1269 @conocophillips.com 659-7493 pager 659-7000 765 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, November 19, 2010 2:10 PM To: CPF1 Prod Engr Subject: RE: Request for temporary waiver to defeat LPP/SSV for 1R-06Ai (210-056) on 11-18-2010 Dave, Following up on your request, the correct well reference is 1 R-06A. 1 R-06 is P&A. No need to list all the laterals that were subsequently drilled. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Friday, November 19, 2010 1:08 PM To: 'CPF1 Prod Engr' Subject: RE: Request for temporary waiver to defeat LPP/SSV for 1R-06i on 11-18-2010 Hi Dave, Here is the AA that was issued to cover these cases. When you need to defeat the SVS for Kuparuk wells, you should handle it the same as WS. Give us an email that you did defeat the SVS and give us notice when you put the SVS back in to service. Does this answer your question? 11/29/2010 Page 2 of Tom Maunder, PE AOGCC From: CPF1 Prod Engr [mailto:n1269 @conocophillips.com] Sent: Friday, November 19, 2010 11:41 AM To: Maunder,Thomas E (DOA) Subject: FW: Request for temporary waiver to defeat LPP/SSV for 1R-06i on 11-18-2010 Tom, I think the e-mail address I used below didn't get through to you, so I'll try it again. Best regards, David Lagerlef/Dan Bearden CPF1 Production Engineers n1269 @conocophillips.com 659-7493 pager 659-7000 765 ngr rember 18,2010 6:31 PM nas E(DOA)' Techs;NSK Prod Engr&Optimization Supv;Bommarito,Forest;Wu,Jianbing;CPF1 Ops Supv t for temporary waiver to defeat LPP/SSV for 1R-06i on 11-18-2010 Tom, ConocoPhillips requests administrative approval under CO 432D to operate 1 r-06i, a Kuparuk water injection well, with a defeated safety valve system. This request is similar to CO 406B administrative approval granted to the West Sak Pool. The LPP for injection well 1R-06 will most likely need to be defeated due to low injection pressure. The well was pre-produced, following a CTD multilateral sidetrack, from July, 25, 2010 until October 23, 2010 when it was shut in to convert to injection. The work to convert the well to injection should be completed in the next few days and we would like to put the well on water injection shortly thereafter. We expect injection pressure to increase sufficiently in the next few weeks as the reservoir pressure increases. This will allow us to re-engage the SVS system and return the well to normal operations. It is anticipated the well will begin injecting 2000 bwpd at pressures below the minimum LPP set point, perhaps initially on a vacuum. A MITIA was performed on 05/09/07 with the outcome listed below. Thanks in advance for your time on this matter and call or email me with any questions. Regards, David Lagerlef 05/09/07 State witnessed MITIA(Robert Noble) (passed). T/I/0= 1190/530/20. Pressured up IA to 1950 psi with 2.3 bbls diesel. 15 min reading= T/I/0= 1190/1910/20 . 30 min reading=T/I/0= 1190/1900/20. Bled IA. T/I/0= 1190/560/20. David Lagerlef/Dan Bearden CPF1 Production Engineers n1269@conocophillips.com 659-7493 pager 659-7000 765 11/29/2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.r egD alaska. o ; d a.ao cc. r dho .ba v alaska.q ov hoeb e b r ook s alaska.gov tom.maunder alaska.pov OPERATOR: ConocoPhillips Alaska,Inc I 040 FIELD/UNIT/PAD: Kuparuk/KRU/1R-06A l-, DATE: 10/31/10 OPERATOR REP: Jim Phillips AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1R-06A ' Type lnj. N TVD 6,266' Tubing 425 2500 2400 2390 Interval p / P.T.D. 2100560 " Type test_ P Test psi '1566.5 Casing 400 400 400 400 _ P/F P Notes: converting producer to Injection well OA 300 280 280 260 Well 1R-06A Type In). N TVD 6,266' Tubing 1,100 1,390 1,375 1,400 Interval p P.T.D. 2100560 Type test P Test psi 1566.5 Casing 400 1 3,000 3,000 "2,975 P/F F Notes: 54 OA 260 475 460 440 Well 1R-06A _ Type In). N TVD 6,266' Tubing 1,400 1,400 1,400 1,400 Interval 0 P.T.D. 2100560 Type test P Test psi 1566.5 Casing 2,900 3,000 3,000 ' 3,000 P/F P Notes: re-test T l . OA 425 425 420 415 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi_ Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle 1=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey T=Test during Workover W=Water D=Differential Temperature Test 0=Other(describe in notes) Form 10-426(Revised 06/2010) 2010-1 031_MIT KRU_1R-06A_3tests.xls Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, November 19, 2010 2:10 PM To: 'CPF1 Prod Engr' Subject: RE: Request for temporary waiver to defeat LPP/SSV for 1 R-06Ai (210-056)on 11-18-2010 Dave, Following up on your request, the correct well reference is 1 R-06A. 1 R-06 is P&A. No need to list all the laterals that were subsequently drilled. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Friday, November 19, 2010 1:08 PM To: 'CPF1 Prod Engr' Subject: RE: Request for temporary waiver to defeat LPP/SSV for 1R-06i on 11-18-2010 Hi Dave, Here is the AA that was issued to cover these cases. When you need to defeat the SVS for Kuparuk wells, you should handle it the same as WS. Give us an email that you did defeat the SVS and give us notice when you put the SVS back in to service. Does this answer your question? Tom Maunder, PE AOGCC From: CPF1 Prod Engr [mailto:n1269 @conocophillips.com] Sent: Friday, November 19, 2010 11:41 AM To: Maunder, Thomas E (DOA) Subject: FW: Request for temporary waiver to defeat LPP/SSV for 1R-06i on 11-18-2010 Tom, I think the e-mail address I used below didn't get through to you, so I'll try it again. Best regards, David Lagerlef/Dan Bearden CPF1 Production Engineers n1269 @conocophillips.com 659-7493 pager 659-7000 765 ngr ✓ember 18,2010 6:31 PM .nas E(DOA)' Techs; NSK Prod Engr&Optimization Supv;Bommarito,Forest;Wu,Jianbing;CPF1 Ops Supv t for temporary waiver to defeat LPP/SSV for 1R-06i on 11-18-2010 Tom, ConocoPhillips requests administrative approval under CO 432D to operate 1r-06i, a Kuparuk water injection well, with a defeated safety valve system. This request is similar to CO 406B administrative approval granted to the West Sak Pool. 11/19/2010 Page 2 of 2 The LPP for injection well 1R-06 will most likely need to be defeated due to low injection pressure. The well was pre-produced, following a CTD multilateral sidetrack, from July, 25, 2010 until October 23, 2010 when it was shut in to convert to injection. The work to convert the well to injection should be completed in the next few days and we would like to put the well on water injection shortly thereafter. We expect injection pressure to increase sufficiently in the next few weeks as the reservoir pressure increases. This will allow us to re-engage the SVS system and return the well to normal operations. It is anticipated the well will begin injecting 2000 bwpd at pressures below the minimum LPP set point, perhaps initially on a vacuum. A MITIA was performed on 05/09/07 with the outcome listed below. Thanks in advance for your time on this matter and call or email me with any questions. Regards, David Lagerlef 05/09/07 State witnessed MITIA(Robert Noble) (passed). T/I/O= 1190/530/20. Pressured up IA to 1950 psi with 2.3 bbls diesel. 15 min reading=T/I/O= 1190/1910/20 . 30 min reading=T/I/O= 1190/1900/20. Bled IA. T/I/0= 1190/560/20. David Lagerlef/Dan Bearden CPF1 Production Engineers n1269 @conocophillips.com 659-7493 pager 659-7000 765 11/19/2010 SEAN PARNELL,GOVERNOR O � `fit ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 / FAX (907)276-7542 ADMINISTRATIVE APPROVAL NO. CO 432D.009 Mr. Gary Targac Kuparuk Production Engineering& Optimization Supervisor ConocoPhillips Alaska P.O. Box 100360 Anchorage, AK 99510-0360 RE: Conservation Order 432D Kuparuk River Field Kuparuk River Unit Kuparuk River Oil Pool Defeating Low Pressure Pilots on Water Injection Wells with Low Tubing Pressure Dear Mr. Targac: By electronic message dated October 12, 2010, ConocoPhillips Alaska ("CPA") requested approval to disable automatic shut-in equipment on Kuparuk River Unit(KRU) water injection well 1E-09 (1820280) due to surface pressure below the automatic shut-in equipment activation set point. Due to similar low surface pressure situations experienced with water injection wells in the shallower West Sak Oil Pool, on June 14, 2005 the Commission issued CO 406B.001 allowing relief similar to this request. While CPA specifically requested this approval for 1E-09, this is the second Kuparuk Pool water injection well that has experienced low surface pressure when placed in service. Since it is probable that additional wells may also need this relief, it is appropriate to consider your request as an Administrative Approval under Rule 12 of CO 432D. CO 432D Rule 5 (a) prescribes that "Each well shall be equipped with a Commission approved fail-safe automatic surface safety valve system (SVS)..." Rule 5 (b) requires that "The safety valve system (SVS) shall not be deactivated except during repairs, while engaged in active well work, or if the pad is manned." CPA recently initiated injection in newly completed multi-lateral well 1E-15A (2100130) that had been producing for a few months as well as 1E-09 which had not been active since February 2001. In both situations, the reservoir bottomhole pressure (BHP) had become reduced in the vicinity of the wellbore. With locally reduced BHP, when injection is started the surface pressure can be insufficient for the pressure sensor CO 432D.009 November ,2010 Page 2 of,3'a- controlling the SSV to function properly. To prevent the SVS from repeatedly functioning and shutting in the well, the pressure sensor (low-pressure pilot) must be defeated (prevented from functioning). CPA is requesting approval to defeat a given water injection well's low pressure pilot until the operating injection surface pressure reaches 700 psi. A localized reduction in BHP resultin g from production from a specific well or from P P eci adjacent wells in the reservoir is not unusual. After water injection has been in operation for a while, the local BHP should increase giving sufficient surface pressure to allow the low-pressure pilot to operate properly. A check valve remains functional at all times to prevent flow from the well if the flowline were to be damaged. Granting CPA's request will not increase the risk to any fresh water since all aquifers have been exempted by EPA per 40 CFR 147.102 (b)(3). Now therefore, as provided by Rule 12 of CO No. 432D, it is ORDERED that Rule 5 (b) be amended to read as follows: b. The safety valve system (SVS) shall not be deactivated except during repairs, while engaged in active well work, or if the pad is manned. However, the Low Pressure Pilot may be defeated on Kuparuk Pool water injection wells when the surface injection pressure is less than 700 psi. Low J P P pressure pilots on Kuparuk Pool water injection wells must be operable when the surface pressure exceeds 700 psi. The operator will notify the Commission via electronic mail when a specific well's Low Pressure Pilot is defeated and again when the pilot function is returned to normal. If the SVS on a development well cannot be returned to service within 24 hours, the well must be shut in at the wellhead and at the manifold building. (Source CO 348 and C0432D.009) 1) Wells with a deactivated SVS shall be identified by a sign on the wellhead stating that the SVS has been deactivated and the date it was deactivated. (Source CO 348) 2) A list of wells with the SVS deactivated, the dates and reasons for deactivating, and the estimated re-activation dates must be maintained current and available for Commission inspection on request. (Sour CO 348) At ''ti- ',, Ar DONE at Anchorage,Alaska an• .. _: o mber 2 2010. J � ,i s v. ‘ .;t s . o q ;,fit ,c w \'''' '''-1 ‘611 VI ' ir*el, J• • Cathy p. Foerster aniel T. S-•I ount � T Chair, C s issioner Co toner Commissioner Page 1 of 3 Regg, James B (DOA) P zl0- asp From: Brooks, Phoebe L (DOA) tlI3110 Sent: Wednesday, November 03, 2010 10:33 AM To: Phillips, Jim (ASRC Energy Services) Cc: Regg, James B (DOA) Subject: RE: 1R-06 MIT results Attachments: MIT KRU 1R-06A 10-31-10 Revised.xls Thanks for getting back to me. I've revised the report to include a Packer TVD of 6266' and a Test psi of 1566.5. Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: Phillips, Jim (ASRC Energy Services) [mailto:Jim.Phillips @contractor.conocophillips.com] Sent: Wednesday, November 03, 2010 9:56 AM To: Brooks, Phoebe L (DOA) Subject: RE: 1R-06 MIT results Phoebe, The packer depth is 6266' I must have been looking at the wrong line while typing in the numbers, sorry and thanks for catching that. I also agree on the test psi. If you have any more questions let me or Martin know, he will be back in the office in the morning. Thanks Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659-7224 From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks @alaska.gov] Sent: Tuesday, November 02, 2010 11:33 AM To: Phillips, Jim (ASRC Energy Services) Subject: RE: 1R-06 MIT results Jim, There also seems to be a slight difference in the Packer TVD reported (6255) and what we have in our database (6266); can you please confirm the Packer TVD?The test psi field seems to have had the formula overwritten so the figure should be 1563.75 (based on a Packer TVD of 6255) or 1566.5 (based on a Packer TVD of 6266). Thanks for your help, Phoebe 11/3/2010 Page 2 of 3 Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-7934242 Fax: 907-276-7542 From: Brooks, Phoebe L(DOA) Sent: Tuesday, November 02, 2010 10:51 AM To: 'Phillips, Jim (ASRC Energy Services)' Cc: Regg, James B (DOA) Subject: RE: 1R-06 MIT results Jim, Attached is a revised report for MIT KRU 1R-06A 10-31-10.The well name was changed to 1R-06A based on the PTD#, the verbiage was removed from the AOGCC Rep field (this field should include an inspector's name or be left blank), and the Operator Rep field now includes your name. If you disagree please let me know. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: Regg, James B (DOA) Sent: Tuesday, November 02, 2010 9:52 AM To: Brooks, Phoebe L (DOA) Subject: FW: 1R-06 MIT results Jim Regg AOGCC 333 W.7th Avenue,Suite 100 Anchorage,AK 99501 907-793-1236 From: Phillips, Jim (ASRC Energy Services) [mailto:Jim.Phillips @contractor.conocophillips.com] Sent: Tuesday, November 02, 2010 9:49 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: 1R-06 MIT results Tom, Attached is a copy of 1 R-06 MITT and MITIA results for Injection conversion. When the well has had time to stabilize we will schedule a State witnessed test. If you have any questions let me know. 11/3/2010 Page 3 of 3 Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659-7224 11/3/2010 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaq(ctalaska.gov; doa.aoacc.prudhoe.bayt alaska.govi phoebe.brooks(aDalaska.00v; tom.maunder @alaska.gov OPERATOR: ConocoPhillips Alaska,Inc 2� / 1(13 \(0 FIELD/UNIT/PAD: Kuparuk/KRU/1R-06A DATE: 10/31/10 OPERATOR REP: Jim Phillips AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1R-06A " Typelnj. N TVD 6,266' Tubing 425 '2500 2400 J2390 Interval ID P.T.D. 2100560 l Type test P Test psi '1566.5 Casing 400 400 400 400 P/F P '/ Notes: converting producer to Injection well OA 300 280 280_ 260 /?ZL-T-"1- Well 1R-06A Type Inj. N TVD 6,266' Tubing 1,100 1,390 1,375 1,400 Interval 0 P.T.D. 2100560 Type test P Test psi 1566.5 Casing 400 ''3,000 3,000 2,975 ' P/F F .✓ Notes: )„lam j-It 1 OA 260 475 460 440 Well 1R-06A Type Inj. N TVD 6,266' Tubing 1,400 1,400 1,400 1,400 Interval 0 P.T.D. 2100560 Type test P Test psi 1566.5 Casing '2,900 3,000 3,000 ,/3,000 P/F P Notes: re-test kil�.7..lT t,x'_ OA 425 425 420_ 415 Well Type Inj. rTVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey T=Test during Workover W=Water D=Differential Temperature Test 0=Other(describe in notes) Form 10-426(Revised 06/2010) MIT KRU 1R-06A 10-31-10 Revised(2).xls SETE o ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Robert D. Christensen Production Engineering Specialist �� ConocoPhillips Alaska, Inc. , P.O. Box 100360 �, Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 1R-06A Sundry Number: 310-329 Dear Mr. Christensen: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Daniel T. Seamount, Jr. Chair DATED this pJ- day of October, 2010. Encl. Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit,NSK-69 PO Box 196105 ConocoPh i I I i ps Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 September 27,2010 Dan Seamount RECENIE3 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission SE P 2 9 2010 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 gam aGO '�ni " Aiderage Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk Wells 1R-06A, 06AL 1, 06AL 1-01, 06AL2, and 06AL2-01 from Oil Production service to Water Injection service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. for 1R-06A (PTD 210-056), 1 R-06AL 1 (PTD 210-057), 1 R-06AL 1-01 (PTD 210-083), 1R-06AL2 (PTD 210-058), and 1R-06AL2-01 (PTD 210-059) If you have any questions regarding this matter,please contact myself or Darrell R. Humphrey at 659-7535. Sincerely, Robert D. Christensen Attachments i STATE OF ALASKA V i1D ,, Y ,t ALAS. .)IL AND GAS CONSERVATION COMMISS. 4 -Up'� ' 'APPLICATION FOR SUNDRY APPROVALS ROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Rug Ferforations r Perforate r Rill Tubing r Time Extension E Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: PROD to WINJ r • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r . Exploratory r 210-056 • 3.Address: 6.API Number: Stratigraphic r Service r P.O. Box 100360,Anchorage,Alaska 99510 50-029-21331-01 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 1R-06A • 9.Property Designation: 10.Field/Pool(s): ADL 25635,25640 Kuparuk River Field/Kuparuk Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10940 • 6639 • 10245' 6708' C ClE asing Length Size MD ND Burstf� 's � ` CONDUCTOR 110' 72 16 110' S; P 2 q 2010 SURFACE 4622 12 4659' 3694' WINDOW"A" 12 8 8832' 8832' AlnkaQll+ v',' r ,.,ti ;" ii PRODUCTION 9244 7 9279' 6729' Anclosnege "A"LINER 785 2.625 10245' 6708' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots:9471-10244 6726-6708 3.5 J-55 8931 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER'FHL'PACKER MD=8435 TVD=6266 PACKER-BAKER'FB-1'PACKER MD=8909 TVD=6628 SAFETY VLV-CAMCO TRDP-1A SSSV MD=1908 TVD=1850 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/15/2010 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r • GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG I- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen/Darrell Humphrey Printed Name Robert D. Christensen Title: Production Engineering Specialist Signature �� Phone:659-7535 Date 0 tp... ,/i D Commission Use Only nn Sundry Number: 3/O�p(-1 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test Liz Location Clearance r Other: Subsequent Form Required: /b .4/0 ii 40 APPROVED BY /C4 //1 I ' U Approved by: + ..,� COMMISSION THE COMMISSION Date: `T` RBDMS 'CT 04 20� $ RIGI A L ,-f �' .. Form 10-403 Revised 1/2010 /O.y./O Submit in D plicate 1R-06A DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert KRU Well 1R-06A(PTD 210-056)from Oil Production service to Water Injection service. Well 1R-06A(CTD Sidetrack)was completed in the Kuparuk formation on July 19, 2010 as a pre- roducing injector with initial production commencing on July 25, 2010. Conversion to Injection service is require fd p ential reservoir depletion. The 16" Conductor was cemented with 215sx of CS II. The 9-5/8" Surface casing (4659' and/3694'tvd)was cemented with 1390sx Permafrost E and 425sx PF C. The 7" Production casing (9279' and/6729'tvd)was cemented with 510 sx Class"G"and 250sx PFC. The top of the Kuparuk B sand was found at 8820' and/6568' tvd. The top of the Kuparuk A4 sand was found at 9029' and/6681'tvd. The injection tubing/casing annulus is isolated via Baker FHL Packer located @ 8435' and/6266'tvd. KUP 1R-06A Conoc illips o Well Attributes Max Anifile&MD TD Inc Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ft/(B) LOr,oc„Ri4ep1 500292133101 KUPARUK RIVER UNIT INJ 10,940.0 Comment 112S(ppm) Date Annotation End Date KB-Ord(R) Rig Release Date ••• Well Confi9.-1R-06A,721201012'.47:18 PM 1SSSV:TRDP Last WO: 37.61 5/15/1985 Schemste-Actual IAnnotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:SIDETRACKS,GLV C/O Imosbor 7/21/2010 Casing Strings HANGER 33 Casing Description String 0... String ID...Top(ftKB) Set Depth(/...Set Depth(TVD)...String Wt...String... String Top Thrd I CONDUCTOR 16 15.062 38.0 110.0 65.00 H-40 WELDED Casing Description String 0... String ID...Top(61(9) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.765 37.0 4,658.7 36.00 J-55 BTC CONDUC70ft, Casing Description String 0... String ID...Top(11Kg) Set Depth(f...Set Depth(TVO)...String Wt...String...String Top Thrd 31-110 WINDOW"A" 8 6.000 8,820.0 8,832.0 Casing Description String 0... String ID...Top(1669) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd PRODUCTION 7 6.151 34.8 9,279.2 26.00 J-55 BTC 4 Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String . String Top Thrd SAFETY t,aoa VL17 -I1, "A"LINER 23/8 1.995 9,460.0 10,245.1 4.70 L-80 STL IIII Liner Details G/18 LIFT, Top Depth 2,011 (TVD) Top Inc' Noml... Top(RKB) 1RK8) (°) Item Description Comment ID tin) GAS LIFT. 9,460.0 Anchor-billet Anchored Aluminum Billit 1.000 4.326 Tubing Strings SURFACE. . i Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 37-4.559 TUBING I 31/2 ( 2.992 I 33.1 I 8,932.1 I I 9.30 I J-55 I EUEBM GAS LIFT, Completion Details 5.831 p . Top Depth GAS LIFT. ( ) Top Incl Noml... g, Top MB/ 1 8) I"1 Item Description Comment ID(in) 33.1 HANGER FMC TUBING HANGER w/PUP 3. GAS LIFT, 1,907.8 SAFETY VLV CAMCO TRDP-1A SSSV 2.81500 2 6,762 8,421.1 PBR BAKER PBR 3.000 3.000 GAS LIFT, 7.798 8,434.9 PACKER BAKER'FHL'PACKER OAS LIFT, 8,862.0 BLAST JT 2.992 7.115 8,908.4 LOCATOR BAKER LOCATOR SUB w/5'SEAL 4.000 OM • GAS LIFT, 8,909.4 PACKER BAKER'FB-1'PACKER 4.000 11351 8,912.7 SBE BAKER SEAL BORE EXTENSION 4.000 GAS LIFT, :_ 8,923.8 NIPPLE CAMCO'D'NIPPLE NO GO 2.750 8,381 8,931.3 SOS CAMCO SHEAR OUT SUB 2.992 PBR,6,421 {.,iii. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PACKER.8,435 , Top Depth (TVD) Top Incl GAS LIFT. gr� Top(RKB) InKB) l") Description Comment Run Date ID(In)1111 6.473 L 8,819 WHIPSTOCK BOT 3.5"monobore WS w/retrieval tang/4-deg ramp 6/14/2010 1.000 removed GAS LIFT, pp 1545 L 8,921 CIBP 2.69"CIBP 5/26/2010 0.000 9,145 FISH 1 1/2"GLV Valve Dropped;Could Still be in Tubing Stling 3/15/1986 Perforations&Slots Shot Top(TVD) Blom(TVD) Dens Top(RKB) Btm MKS)) (RKB) (R813) Zone Date (eh... Type Comment 9,471 10,244 6/22/2010 32.0 SLOT Alternating solid/slotted pipe- 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non-slotted ends Notes:General&Safety End Dab Annotation r 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED 7/21/2010 NOTE:View Schematic w/Alaska Schematic9.0(2 pages) WHIPSTOCK, I 8.819 WINDOW NV, " 8,8208.832 _ I GAS LIFT MMG.6.890 LOCATOR. __ 8,908 PACKER.8,909- S8E,8,913- CIBP,8,921 // NIPPLE.5,924 - - ° Mandrel Details SOS,8,931 -- '.Top Depth Top I Port - (TVD) Intl OD Valve Latch Sloe TRO Run Stn Top MKS) IRKB) I') Make Model (In) Sery Type Type tin) (psi) Run Date Com... 1 2,040.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,317.0 7/21/2010 FISH,9,145 - 4 2 4,326.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,333.0 7/21/2010 3 5,630.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 4 6,285.1 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,319.0 7212010 5 6,762.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 PRODUCTION. 6 7,198.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 359,279 7 7,615.3 CAMCO KBUG 1 GAS LIFT 'GLV BK 0.188 1,342.0 7212010 sl.or. 8 8,060.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 9.471-10.244 9 8,381.1 CAMCO KBUG 1 12 PROD OV rdo20 0.188 0.0 7/21/2010 'A-LINER. 9.460-lD.245\ 10 8,473.5 CAMCO MMG-2 11/2 PROD OPEN 0.000 0.0 11/21/1993 TD(1RA6/), \ 10,940 111 ail 1111miZ Mule WM. le ..,*.-1 ..'7.,.-.1i 104, lot-.....-144,P ,r,,,,,..z.„,,,p,,. . ,;),„D, -0 2 3.,,,,74., 2 j• ,— , - - -^-' , ' 4 i ''A--4 ''. — •c.--:(0 fli174 :' ‘-iiLL[i..'-':-.4: itl-:7-f,-:`n I..',..1...;;O1,,iL.,..,..,-;„ - ---' .1-- --- ;' , , ,- - = , c „,,, c• ,./ ...--.. .— ..._ ' .. M a - CI 0 * * 0 a) - -,-) . ? = - . ...., .... m < . - E 0 ,•:-. E 2 cr) a II --- -- _-_ o (i) co ,- ..-. - - -.1 o rr-, r) 7.1 o , 0 ■.. i '5, '-' L.Ti a) 0 a) . ,..= • - =.. * - , . * 4..... CD co 8 to 'E' 0) -•,...- 4.) C13 u_ C & _SI Li- 0: 0) a u_ 0_ E : 1-1- m 0 - '-• E cu E '' E '- 'I.: . -._. o_ - 0 g ..,, ,. us oot oc.) 02 . _ 2 crs 0 C.) i oc _ cps _ 0 R (a us mi 1 0. = c• V) o. c,, o = 0 44 co •— co o W co C.) •- o 0 _ o -0 c 0 V) lc CC r, .0 : r) .... ..... -.... =O• 5 0 E m c., 2 ,-• O L° 0 co .... c? c 0 0 c I.: (”? 0, L3 ..0.1 •.1, fli 0 03 CD 0 2 c.„ 0 0 C T- 03 Ts 0 P.- 0 C 01 0 c 0 .-- W . - . c E cy) a_ CE1 CO al ._ cf, Cl) oo os 1.1.I ,., m z •= CO LJ- 4.a _. Ci Z al a = - 0 C ctI 1,7; e rx co _ E — 0 00 :*6. • a) ‘- 03 (i) molcci •_ _ u) _. -- z t) a) a>. o .1c > _us C) c.,2 le, = , ....i.- La '13 C0 03 C13 C 03 0 Tli 7g 4- *c g T 0 < -,-.9 ' .rt ' c c .rc xe 73 0 cc• -- ce 0 N 4( 75 -- > ""4 '..... C = 73 ...L. 0 Cn 4g •••.' Coll ct 6 ii)- ..... - = al;1.7_0 cy :....- 'CS , 1-• a 2! ,_ m cl_ ZZ i__ 11 7r, :E t,„5 E 9L5 ci_j , ,,, c.) .- a) 8 , _01:00 > cco ., -.• ,, .0w I__ -E ILI CD 4...., 0 s) .. 00 4 k •C2 ° 11) = 2 .- • -c al = . ,..) ..1 r0 0 c' 0 0 as EL- .cgeiguEg' 0 za .co ^ -- CD .cr, 0 4-, > 02il' Oc - .4 '4 = 0 1__ = 5 15 :: 15 g ,,, == c I- c) 2 g 0 , 6.C) .c 0, c 0- c 0 • ,c c) (.9 cl: cc m 0 in c4 4 4C c.) 4-1 4i CO ct. CI 0. ` STATE OF ALASKA 4. ALASK, . .JIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well E Rug Perforations r Stimulate r Other r Pre-Prod Inj Alter Casing r Pull Tubing r Perforate New Pool Waiver <30 days r r Time Extension r Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r \ 210-056 3.Address: NN API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service p- 50-029-21331-01 7.Property Designation\ 8.Well Name and Numer: ADL 25635,25640 1 R-06A 9.Field/Pool(s): Kuparuk River Field/Kuparuk Oil Pool 10.Present Well Condition Summary: Total Depth measured 10940 feet Plugs(measured) None true vertical 6639 feet Junk(measured) None Effective Depth measured 10245 feet Packer(measured) 8435, 8909, 8921 true vertical 6708 feet (true vertucal) 6266,6628,6634 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110 110 0 0 SURFACE 4622 9.625 4659 3694 0 0 PRODUCTION 9244 7 9279 6729 0 0 WINDOW"A" 12 8 8832 6578 0 0 Perforation depth: Measured depth: 9471-10244 RECEIVED True Vertical Depth: 6726-6708 p 2010 Tubing(size,grade,MD,and TVD i13 y.'.d 03„ 9( 9 ) 3.5,J-55,8931 MD,6640 ND px,2 � •G1ISSIOf1 Packers&SSSV(type,MD,and ND) PACKER-BAKER'FHL'PACKER @ 8435 nd 6266 ND PACKER-BAKER'FB-1'PACKER @ 8909 MD and 6628 ND CIBP-2.69"CIBP @ 8921 MD and 6634 ND SAFETY VLV-CAMCO TRDP-1A SSSV @ 1908 MD and 1850 ND 11.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 781 3029 760 1267 164 13.Attachments 14.Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development r' Servic p- 15.Well Status after work: Oil r Gas\ r WDSPL r Daily Report of Well Operations X GSTOR r WAG r GASINJ r WIND r SPLUG r 16.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Bob Christensen/Darrell Humphrey Printed Name A R• ie ,O. Christensen Title Production Engineering Specialist Signature AV Allr X _ _ Phone:659-7535 Date ,tip Form 10-404 Revised 7/2009 RBDMS AUG i se* , j),_/, Submit Original Only 1R-06A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/20/10 MEASURED BHP @ 8500' MD: 3154 PSI. SET CATCHER. PULLED DV @ 8381' RKB, SET 3/16"OV @ SAME. PULLED DVs @ 7615' &6285' RKB, SET GLVs @ SAME. IN PROGRESS 07/21/10 PULLED DVs @ 4326' &2041' RKB. SET GLVs @ SAME. BLED IA TO CONFIRM GLVs SET. PULLED CATCHER. COMPLETE. 07/25/10 OPEN WELL- RETURN TO SERVICE " . X0,1, KUP 1R-06A ConocoPhillips 0,1 Well Attributes Max Angle&MD TD Alaska,Inc Welibore APIIUWI Field Name Well Status Inc'(°) MD(MB) Act Btm(ttKB) innocaFwapa 500292133101 KUPARUK RIVER UNIT INJ 10,940.0 Comment H2S(ppm) Date Annotation 'End Date KB-Ord(ft) Rig Release Date ••• Well Config.-1R-06A,7/21201012:41.15 PM 1SSSV:TRDP Last WO: _ 37.61 5/15/1985 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...'End Date Last Tag: Rev Reason:SIDETRACKS,GLV C/O Imosbor 7/21/2010 Casing Strings HANGER,33 Casing Description String 0... String ID...Top(Po(8) Set Depth(f...Set Depth(TVD)...String Wt_.String...IString Top Thrd - - CONDUCTOR 16 15.062 38.0 110.0 65.00 H-00 WELDED Casing Description String 0... String ID...Top(fIKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.765 37.0 4,658.7 36.00 J-55 BTC CONDUCTOR, I Casing Description String 0... String ID...Top OMB) Set Depth(f...Set Depth(TVD)...String Wt...String_.String Top Thrd 38.1W WINDOW"A" 8 6.000 8,820.0 8,832.0 Casing Description String 0... String ID...Top(RKB) Set Depth(L..Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.151 34.8 9,279.2 26.00 J-55 BTC Casing Description String 0... String ID...Top(Po(B) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SAFETY vLV, "A"LINER 2 3/8 1.995 9,460.0 10,245.1 4.70 L-80 STL 1,908 Liner Details _ OAS LIFT, ' Top Depth 2.041 ' (TVD) Top Inc! Nom'... Top MKS) (MB) ("I Item Description Comment ID('n) OAS LIFT, _ 9,460.0 Anchor-billet Anchored Aluminum Billit 1.000 4.328 Tubing Strings SURFACE, Tubing Description String D... String 10 Top(1t1(91 Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd 37-1.658 TUBING 31/2 2.992 33.1 8,932.1 9.30 J-55 EUE8rd OAS 51 , Completion Details Top Depth GAS LIFT, (TVO) Top Incl Nomi... 8,285 "' Top(RKB) (RKS) (°) Item Description Comment ID(In) 33.1 HANGER FMC TUBING HANGER w/PUP 3.500 GAS LIFT. 1,907.6 SAFETY VLV CAMCO TRDP-1A SSSV 2.812 6,762 0 8,421.1 PBR BAKER PBR 3.000 GAS LIFT, 7,198 8,434.9 PACKER BAKER'FHL'PACKER 3.000 OAS LIFT, 6,662.0 BLAST JT 2.992 7,615 8,908.4 LOCATOR BAKER LOCATOR SUB w/5'SEAL 4.000 . GASUFT, r 8,909.4 PACKER BAKER'FB-1'PACKER 4.000 8.081 T lT - 8,912.7 - SBE BAKER SEAL BORE EXTENSION 4.000 OAS LIFT, , _ 8,923.8 NIPPLE CAMCO'0'NIPPLE NO GO 2.750 8381 8,931.3 SOS CAMCO SHEAR OUT SUB 2.992 POR.9,421 - t I Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PACKER.8,436 Top Depth an (TVD) Top Inc' GAS LIFT, Top MB) (RKB) (")_ Description Comment Run Date ID(In) 8.473 8,819 WHIPSTOCK BOT 3.5"monobore WS w/retrieval tang/4-deg ramp 6/14/2010 1.000 removed GAS 8,921 CIBP 2.69"CIBP 5/26/2010 0.000 9,145 FISH 1 1/2"GLV Valve Dropped;Could Still be in Tubing String 3/15/1986 Perforations&Slots Shot Top(TVD) Btm(TVD) Den. Top(FMB) Btm(MB) (MB) (11KB) _ _Zen. Date (oh--- Type Comment IN 9,471 10,244 6/22/2010 32.0 SLOT Alternating solid/siotted pipe- 0.125"u2.5"@ 4 drcumferential adjacent rows,3"centers staggered 18 deg,3'non-slotted ends Notes:General&Safety End Date Annotation 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED 7/21/2010 NOTE:View Schematic w/Alaska Schemalic9.0(2 pages) WHIPSTOCK, ', 8,819 WINDOW"A°, 8,820-8.832 1 i_ OAS LIFT r_4• MAW,8,890 LOCATOR, 0908 PACKER,8,909 _ SBE,8,913 F I CIBP,8,921 NIPPLE.8.924 Mandrel Details SOS,8031 Top Depth Top Port (TVD) 1001 OD Valve Latch Size TRO Run Ste Top(MB) ( B) (") Make Model (in) Sery Type Type (In) (psi) Run Date Com... 1 2,040.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,317.0 7/21/2010 FISH,9,145-- 4 2 4,326.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,333.0 7212010 3 5,630.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 4 6,285.1 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,319.0 7212010 , 5 6,762.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 PRODUCTION, 6 7,198.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 59,279 Ce 7 7,615.3 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,342.0 7212010 SLOT, 8 8,060.9 CAMCO KBUG GAS LIFT DMY BK 0.000 0.0 11/10/1987 9,47110,24/ 9 8,381.1 CAMCO KBUG 1 12 PROD OV rdo20 0.188 0.0 7212010 °A°LINER. 9,460.10.245 10 8,473.5 CAMCO MMG-2 1 12 PROD OPEN 0.000 0.0 11/21/1993 TD(1R-08A), 10,940 • KUP 1 R-06A • ConocoPhillips III Lonocoihllips KB-Ord(N) Rig Release Date Well Conbo.-18-08A,7/21/2010 12.41.15 PM 37.61 5/15/1985 Schemsto-Actual et�y HANGER,33 I 1 CONDUCTOR,—I I 3&110 0 � SAFETY YL 1,9013 OAS LIFT, .041 2.041 I [ OAS LIFT, 4,328 SURFACE, J 37-4.659 OAS LIFT, 5,631 L GAS LIFT. 1 6,235 GAS LIFT. 8,762 T. j[ OAS 7LIFT, ,198 OAS LIFT5, 7,61 T GAS LIFT, j' 6,061 T CGAS LIFT, 6,381 P66,8,421 PACKER,8,435 GAS LIFT, 8,473 GAS 6,LIFT, jl 545 L L. WHIPSTOCK,_ _�\ I 8,819 WINDOW'A', 8,8208,632 GAS LIFT HMG,SIFT LOCATOR _ f 6,908 1 PACKER.6,909 `�•`� J S8E,8,913 -/ CIBP.8,921— 11110.–. NIPPLE,8,924 Mandrel Details SOS,8,931 Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top(FMB) MKS) (`) Make Model (in) Sery Type Type (in) (pei) Run Date Com... 11 8,544.5 CAMCO MMG-2 1 1/2 PROD DMY RK 0.000 0.0 5/21/2010 FISH,9,145 4 12 8,890.3 CAMCO MMG-2 1 1/2 PROD OPEN 0.000 0.0 5/21/2010 PRODUCTION, 59,279 T, 9,471-10SLO,244 A'LINER, D 860,25 10,940 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil IO Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ lb.Well Class ' 20AAC 25.105 20AAC 25.110 Development � • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ._, Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: July 19,2010 " 210-0560/ ' 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 June 17,2010 50-029-21331-01- 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 272'FNL,222'FEL,Sec. 19,T12N,R10E,UM f _ June 21,2010 1R-06A Top of Productive Horizon: 8. KB(ft above MSL): 84'RKB • 15.Field/Pool(s): 868'FSL,924'FWL,Sec. 19,T12N,R10E,UM GL(ft above MSL): AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+ND): 240'FNL, 1659'FWL,Sec.30,T12N,R10E,UM 10245'MD/6708'ND Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-539470 ' y- 5990930• Zone-4 r 10940'MD/6639'TVD ADL 25635,25640' TPI: x-535817 y- 5986772 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-536557 y- 5985668 Zone-4 1908'MD/1850'TVD 2560 18.Directional Survey: Yes 0 No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1550'MD/1527'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 8820'MD/6568'ND 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# F1-40 Surf. 110' Surf. 110' 24" 215 sx CS II 9.625" 36# J-55 Surf. 4659' Surf. 3694' 12.25" 1390 sx Permafrost E,425 sx PF C 7" 26# J-55 Surf. 9278' Surf. 6975' 8.5" 510 sx Class G,250 sx PFC 2.375" 4.7# L-80 9460' 10245' 6727' 6708' 3" slotted liner 24.Open to production or injection? Yes 0 No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+ND of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5" 8932' 8435'MD/6266'ND slotted liner 9466-10238'MD 6726-6708'ND 8909'MD/6628'ND caliptE�ji { 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. r; j; DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ;none �4L& 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) July 25,2010 pre-produced injector-flowback in progress ✓ Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 7/31/2010 16 hours Test Period--> 389 2317 459 209% 5952 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 165 psi 1263 24-Hour Rate-> 584 3476 689 not available 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q , Sidewall Cores Acquired? Yes ❑ No Ell ' If Yes to either question,list formations and intervals cored(MD+ND of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RECEIVED NONE A.l_I ; U ' 2010 Alaska MI&Gas Core.Commission Anchorage Form 10-407 Revised 12/2009 RBDMS AUG 0'4 2Q ONTINUED ON REVERSE Submit original only 6'•/7 it, *LC, /S 6 28. GEOLOGIC MARKERS(List all formations and meikers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? El Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1550' 1527' needed,and submit detailed test information per 20 AAC 25.071. Top Kuparuk B Sand 8820' 6568' Top Kuparuk A Sand 9029' 6681' N/A Formation at total depth: Kuparuk A4 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: ‘try Eller©263-4172 Printed Na e V. awve Title: Alaska Wells Manager \\\\\\vvv�"`�+++n1\ / Signature Phone 265-6306 Date J(3 ZC'JIO Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 1 R-06 Pre and Post Rig Summary DATE SUMMARY 4/18/10 T-POT(PASSED), T-PPPOT(PASSED), IC-POT(PASSED), IC-PPPOT(PASSED), MITIA (PASSED), MITOA(PASSED) 4/20/10 JOB SUSPENDED FOR SAFETY STAND DOWN 4/21/10 DISPLACED TBG WITH 290 BBL SW FOLLOWED BY 20 BBL DSL. BRUSHED TBG TO 2.75" NIPPLE @ 8924' RKB WITH BLB AND 2.80" G/R. IN PROGRESS. 4/22/10 TAGGED @ 8986' SLM. SE 5" CA-2 PLUG &GAUGES IN D NIPPLE ( 8924' RKB. SET JUNK CATCHER ON PLUG. ATTEMPTED TEST TBG. PUMPED 50 BBL DSL, 1 BPM @ 1700 PSI. IN PROGRESS. 4/23/10 WITH HOLEFINDER IDENTIFIED APPARENT C SAND LEAK IN BLAST RINGS BETWEEN 8868' & 8572' RKB. RETURN IN 3 DAYS FOR C SAND BHP. 4/26/10 MEASURED C SAND BHP @ 8860' RKB: 2545 PSI. PULLED CATCHER @ 8891', PULLED CA-2 PLUG& DUAL PANEX GAUGES @ 8924' RKB. FINAL A SAND BHP: 2998 PSI. COMPLETE. 4/27/10 (PRE CTD) PT& DD TEST SV, MV, SSV, DD&SSSV. JOB IS ONGOING. 4/28/10 PRE CTD PT SV, MV,SSV( PASSED), DDT SV, MV, SSV( PASSED ), DDT SSSV( FAILED) 5/3/10 BRUSHED& FLUSHED SSSV; ATTEMPTED CLOSURE TEST, FAILED. DRIFTED TBG TO 2.77" TO D NIPPLE. IN PROGRESS. 5/4/10 RUN PDS CALIPER LOG FROM 8800'SLM TO SURFACE. SET F COLLAR STOP @ 1954' SLM, RUN FLAPPER CHECKER TO SSSV @ 1904' SLM. JOB IN PROGRESS. 5/5/10 LOCKOUT SSSV @ 1908' RKB. JOB IN PROGRESS 5/6/10 DRIFT TBG W/2 5/8"X 15MIPSTOCK DUMMY TO 8920' SLM. JOB COMPLETE 5/13/10 DRIFT TBG 2.76"TO 2.75" NIPPLE @ 8924' RKB. RE-LOGGED PDS MULTIFINGER CALIPER FROM TBG TAIL TO 7800'. DATA ACQUIRED. 5/21/10 VERIFIED FLAPPER OPEN ON SSSV @ 1908' RKB. PULLED DVs @ 8890' &8473' RKB. READY FOR CMT RETAINER. —�^�sok Ash 5/26/10 SET HALLIBURTON 2.69" CIBP PLUG AT A DEPTH 8920.5'. CCL STOP DEPTH RECORDED AT8907.5'. CCL TO MID ELEMENT OFFSET MEASURED AT 13'. 5/29/10 PERFORATED USING 2.5"X 12' GUNS WITH 60 DEG PHASING, 6 SPF, MILLENIUM DEEP PENETRATING CHARGES. PERFORATED AT 8819'-8831', AND 8791'-8803'. DEPTHS CORRELATED TO GAMMA RAY ON SCHLUMBERGER CBL DATED 6/8/85. 6/2/10 PUMPED 38 BBLS 15.8 CLASS G CEMENT, SQUEEZED APPROX 15 BBLS BEHIND PIPE, . .sc4veez c s�hV ACHIEVED 1200 PSI SQUEEZE PRESSURE, JETTED OUT TUBING TO TARGET TOC AT 8582 CTMD, FREEZE PROTECTED &TRAPPED 600 PSI ON WELLHEAD. 6/5/10 TESTED TBG TO 2500#30 MIN.PASS.BLED TBG TO ZERO. Note: Witness of P/T&tag waived by state inspector Bob Noble. 6/6/10 ASSIST ASRC REPLACE 7"TREE CAP AND 2' RISER WITH 3 1/2" BONNET ON FLOW CROSS.TAGGED TOC @ 8526' SLM WITH 2.5' BAILER,SAMPLE OF CEMENT OBTAINED.EST TOC @ 8554' RKB.BLED TBG TO NO FLOW.READY FOR COIL 6/7/10 MILLED CEMENT FROM TAG Al"8565 CTMD TO STALL(CIBP)AT 8913 CTMD WITH WEATHERFORD MOTOR &2.69 BI-CENTER MILL. PASSED PRESSURE TEST TO 1500 PSI. WELL IS FREEZE PROTECTED, READY FOR S/L. 6/8/10 PERFORM NO FLOW TEST, NO PRESSURE INCREASE/NO RETURNS. TAG STA.#11 AT 8523' ?tiac\c) SLM (8544' RKB)21' CORRECTION. DRIFT TBG W/ DMY WHIPSTOCK DRIFT, TAG @ 8584' is CORR RKB, UNABLE TO MAKE IT DEEPER. ASSIST CREW IN SETTING BPV. COMPLETE. 7/20/10 MEASURED BHP @ 8500' MD: 3154 PSI. SET CATCHER. PULLED DV @ 8381' RKB, SET 3/16" OV @ SAME. PULLED DVs @ 7615'&6285' RKB, SET GLVs @ SAME. IN PROGRESS. 7/21/10 PULLED DVs @ 4326' &2041' RKB. SET GLVs @ SAME. BLED IA TO CONFIRM GLVs SET. P©S c �C PULLED CATCHER. COMPLETE. ConocoPhillips Time Log & Summary Wel/view Web Reporting Report Well Name: 1R-06 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 6/13/2010 8:00:00 AM Rig Release: Time.Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 06/12/2010 24 hr Summary Move rig from 3K pad to 1R 10:00 20:00 10.00 0 0 MIRU MOVE MOB P Move from 3K pad 20:00 00:00 4.00 0 0 MIRU MOVE MOB P On location,start spotting up rig 06/13/2010 Continue to spot and Shim Rig/Test BOPE 00:00 08:00 8.00 0 0 MIRU MOVE MOB T Using a CAT to pull rig modules into position, rig matts and plywood to - level rig 08:00 20:00 12.00 0 0 MIRU WHDBO BOPE P Rig accept at 08:00. Start BOP test, witnessing waived by Jeff Jones. Nipple up BOP. Change out blind/shear rams. 20:00 23:00 3.00 0 0 MIRU WHDBO BOPE T Multiple attempts to get T-2 tree valve to pass test Change out valve T2(MP line valve) 23:00 00:00 1.00 0 0 MIRU WHDBO BOPE P Fill coil with seawater. Test stripper, reel valve,and T-2 valve. 06/14/2010 Complete Rig, Underream 8320 to 8870, run Dummy whipstock to 8870.Set whipstock 8828.5 TOW=8819 00:00 02:00 2.00 0 0 MIRU WHDBO BOPE T T-2 visable leak from stem. Call out grease crew. Inner reel valve& Packoff good, Pressure test PDLs 02:00 03:30 1.50 0 0 MIRU WHDBO BOPE T Service T-2 valve stem packing/ Pressure test. All BOPE components tested successfully. 03:30 05:00 1.50 0 0 MIRU WHDBO BOPE P PJSM, Rig Up FMC, Pull BPV, R/D FMC 05:00 06:00 1.00 0 0 SURPRI WELLPF UREM T PJSM, P/U Weatherford motor& under reamer and Inteq Coil track assembly 06:00 08:00 2.00 0 8,320 SURPRI WELLPF UREM T RIH,circulate out freeze protect diesel to tiger tank and swap well over to flo-pro 08:00 10:00 2.00 8,320 8,870 SURPRI WELLPF UREM T Tie in,+9'correction. Close EDC and start underreamng from 8560'- 8870'. No indication of motor work. 10:00 12:00 2.00 8,870 0 SURPRI WELLPF UREM T Open EDC and POOH 12:00 12:30 0.50 0 0 SURPRI WELLPF UREM T Lay down BHA. Under reamer in good shape. 12:30 13:00 0.50 0 0 PROD1 RPEQP1PULD P PU dummy whipstock BHA 13:00 15:00 2.00 0 8,870 PROD1 RPEQP1TRIP P RIH,circulating.4 bpm. No obstructions. 15:00 17:00 2.00 8,870 0 PROD1 RPEQP1TRIP P POOH 17:00 18:00 1.00 0 0 PROD1 RPEQP1PULD P Lay down Dummy WS Page 1 of 33 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 18:00 19:00 1.00 0 0 PROD1 RPEQP1PULD P PJSM, Install pip tags in Whipstock, M/U 3 1/2 Monobore whipstock, surface test 19:00 21:15 2.25 0 8,350 PROD1 RPEQP1TRIP P RIH 21:15 21:30 0.25 8,350 8,390 PROD1 RPEQP1 DLOG P 8350, Perform Gamma Tie in for a +8'correction Close EDC, PUW=26K, RIW=13K 21:30 21:36 0.10 8,390 8,700 PROD1 RPEQP1TRIP P Continue to trip in well 21:36 21:54 0.30 8,700 8,860 PROD1 RPEQP1 DLOG P 8700', run CCL Log, No Correction Pull up to setting depth,8828.5"bit depth",8819'TOWS. 21:54 22:00 0.10 8,860 8,829 PROD1 RPEQP1WPST P Pumps online @.5 BPM.Tool shifted @ 4000PSI Set Down 1.1K.Good set, POOH 22:00 00:00 2.00 8,829 200 PROD1 RPEQP1TRIP P POOH 06/15/2010 Completed first window mill run 8820 to 8826. POOH for second string exit BHA. 00:00 00:30 0.50 200 0 PROD1 RPEQP1 PULD P PJSM, Flo check well. Lay down BHA#3 00:30 01:30 1.00 0 0 PROD1 WHPST PULD P M/U BHA#4,0.6 degree motor,2.8" Window Mill and 2.79 string reamer 01:30 03:30 2.00 0 8,350 PROD1 WHPST TRIP P RIH with BHA#4 03:30 03:36 0.10 8,350 8,382 PROD1 WHPST DLOG P 8350',gamma tie in,+8'correction to 8390 PUW=25.5, RIW=7K 03:36 03:48 0.20 8,382 8,820 PROD1 WHPST TRIP P RIH to mill window 03:48 12:48 9.00 8,820 8,824 PROD1 WHPST MILL P Dry tag @ 8820'. PUH 10',orient to HS. Pumps on 1.35BPM @ 3970FS 8820,Motor work and WOB. Start time milling. 12:48 12:54 0.10 8,824 8,824 PROD1 WHPST MILL P Slow progress. Pull up hole and free spin at 3790, up wt 26k, 1.35 bpm, ann 4235, bh off 4633,wob 0.1k. 12:54 15:00 2.10 8,824 8,825 PROD1 WHPST MILL P Milling autodriller, 1.7k-2.8k WOB at 1 fph ROP. DP from 500-560 psi. pumping 1.34 bpm. Stopping for WOB as needed(not exceed 2.8k WOB). 15:00 19:30 4.50 8,825 8,825 PROD1 WHPST MILL P Seeing change in Differential Pressure up 70 PSI WOB Drilling off faster 8825.2' 19:30 21:15 1.75 8,825 8,826 PROD1 WHPST MILL P 8825.7',WOB @ 100Ibs.Went to 8826.0 without gaining WOB.Motor work minimal. At 8826 looks like 7 inch contact- 1001bs WOB with Motor work @ 100 PSI.Start reaming passes. Never saw any cement in returns. 21:15 22:45 1.50 8,826 8,800 PROD1 WHPST TRIP P Complete three reaming passes, PUH to 8800,Open EDC Trip out 22:45 00:00 1.25 8,800 3,020 PROD1 WHPST TRIP P Tripping Out Midnight depth 3020' Bleed down IA Page 2 of 33 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06/16/2010 24 hr Summary Completed 2nd mill run to exit casing and into formation to 8840'. RIH with caliper log. 00:00 00:45 0.75 3,020 0 PROD1 WHPST TRIP P Continue out of well 00:45 01:15 0.50 0 0 PROD1 WHPST PULD P PJSM,Lay down BHA#4, Window mill 2.79 No-Go 01:15 02:00 0.75 0 0 PROD1 WHPST PULD P P/U BHA#5 Fat radius mill 2.8 go 2.79 NoGo on WFT 2.0 degree motor. Verified Bit Box 2.125"OD and wear pad ground off. Stab on well and surface test tool string 02:00 04:30 2.50 0 8,389 PROD1 WHPST TRIP P Open EDC, RIH 04:30 04:50 0.34 8,389 8,827 PROD1 WHPST DLOG P Tie in+7ft correction.Close EDC,wt check 28K. RIH and dry tag 8827'(1' deeper than previous TD). PUH 30K,pump 1.25 bpm. RIH to 8827',WOB 0.1K, 111 psi motor work,milling window. 04:50 05:44 0.91 8,827 8,829 PROD1 WHPST MILL P Milling window using time schedule. Each 0.1'move is averaging 500# WOB and 100 psi motor work and then dropping off. 05:44 11:02 5.30 8,829 8,832 PROD1 WHPST MILL P Milling using autodriller at 1 fph. Calling BOW 8832.0'.Milling rat Hole down to 8840. Getting some cement and siltstones /shales in returns 11:02 12:32 1.50 8,832 8,840 PROD1 WHPST MILL P Millling formation 1.26BPM@ 3867 FS 1.9KWOB 12:32 14:32 2.00 8,840 8,840 PROD1 WHPST REAM P 8840,Start Back reaming window, made three passes.Surface weight indicator looked smooth DHWOB showed 400 lbs bobble @ 8817 above TOWS. RIH and slight overpull @ same area.TOW=8820 14:32 16:32 2.00 8,840 0 PROD1 WHPST TRIP P Trip out of well.Stop and check tie in 8370 to 8388',correction-2'. Continue out of well 16:32 17:29 0.95 0 0 PROD1 WHPST PULD P At Surface, PJSM-lay down BHA #5 Mill 2.80 Go,2.79 No Go 17:29 19:49 2.34 0 0 PROD1 WHPST PULD P Prep PDS tools-Crew Change Pram PDS call ep r tool Hold PJSM-MU BHA,stab on and surface test. 19:49 22:14 2.42 0 8,340 PROD1 WHPST TRIP P RIH w/PDS Caliper BHA#6. EDC close,circulating through XO ports. 22:14 22:48 0.58 8,340 8,380 PROD1 WHPST DLOG P Tie in+6.5ft correction.Wt check _25K. RIH 22:48 23:48 1.00 8,380 8,836 PROD1 WHPST TRIP P RIH @ 5 fpm through the window. Pipe wt dropped-1000#while BHA was moving through the window, no change to WOB.Wait for calipers to open with BHA 2'off bottom. Page 3 of 33 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 23:48 23:57 0.16 8,836 8,790 PROD1 WHPST DLOG P Log up hole at 20 fpm,28K up wt,to 8790',stop and wait for caliper to close. 06/17/2010 Caliper across window. Drilled"A"lateral to 9290'. 00:00 00:45 0.75 8,790 8,600 PROD1 WHPST DLOG P Waiting for calipers to close. RIH @ 5 fpm to 8836'. Pipe wt dropped-1000#while BHA was moving through the window, no change to WOB.Wait for calipers to open. Log up 2nd pass at 20 fpm,up wt 28K, to 8600'.Wait for caliper to close. 00:45 02:45 2.00 8,600 0 PROD1 WHPST TRIP P POOH pumping 0.5 bpm, up wt 29K at 80 fpm. 02:45 04:15 1.50 0 0 PROD1 WHPST PULD P At surface, PJSM. LD PDS caliper BHA#6. MU drilling BHA#7(2.7"x 3"RWD Hughes Bit). Stab on and surface test. 04:15 06:00 1.75 0 8,350 PROD1 DRILL TRIP P RIH with drilling assembly, BHA#7. EDC open circ 0.25 bpm 06:00 06:12 0.20 8,350 8,391 PROD1 DRILL DLOG P 8350'Gamma Tie In+9'correction 06:12 06:42 0.50 8,391 8,840 PROD1 DRILL TRIP P Close EDC, Drift through window, Looks good,Start mud swap and drill ahead 06:42 10:54 4.20 8,840 8,990 PROD1 DRILL DRLG P 8840', Drill ahead 1.3 BPM @ 3885 RIW=10.5K BHP=4250 10:54 11:36 0.70 8,990 8,990 PROD1 DRILL WPRT P 8990',Wiper trip to window. Pull up through window Log K-1 marker and Tie In RA marker on Whipstock -2.5 @ K-1, RA Marker @ 8826.3 TOW=8820.3 Trip in hole to drill 11:36 14:54 3.30 8,990 9,140 PROD1 DRILL DRLG P 8990', Drill ahead 1.37 BPM @ 3689 PSI FS BHP=4145 Slow drilling in A5-A6 14:54 15:18 0.40 9,140 9,140 PROD1 DRILL WPRT P 9140 Wiper to window PUW=31 K 15:18 22:20 7.04 9,140 9,227 PROD1 DRILL DRLG P 9140, Drill Ahead 1.44 BPM @ 4000PSi FS BHP=4165 22:20 23:59 1.66 9,227 9,290 PROD1 DRILL DRLG P Drilling through ankerite,turn down to drop 10'.At 9233'broke through. Drillign ahead 70 fph,600 psi motor work 06/18/2010 Drilled ahead to 10044'.Mud swap. 00:00 00:30 0.50 9,290 9,290 PROD1 DRILL WPRT P Wiper#2 to window. PU wt=29 K 00:30 01:00 0.50 9,290 9,327 PROD1 DRILL DRLG P Drilling ahead.WOB 1.8, ROP 80 fpm,motor work 200 psi. 01:00 03:40 2.67 9,327 9,440 PROD1 DRILL DRLG P PU off bottom to orient around the end stop. Up wt 29K. RIH,drilling ahead. Page 4 of 33 Time Logs Date From .To + Dur S.Depth E.Depth Phase Code Subcode T Comment 03:40 04:05 0.42 9,440 9,440 PROD1 DRILL WPRT P Tie in wiper. PUH to 8850'. Up wt 30K. Log GR tie-in,-3ft correction. 04:05 05:41 1.60 9,440 9,590 PROD1 DRILL DRLG P Drilling ahead. 1.46 bpm @ 4000 psi, BHP 4177 psi. 05:41 06:33 0.87 9,590 9,590 PROD1 DRILL WPRT P 9590',Wiper trip to window PUW=29k 06:33 08:04 1.53 9,590 9,740 PROD1 DRILL DRLG P 9590', Drill Ahead 1.45 BPM@ 3740FS RIW=9.6K WOB=1.4K BHP=4191 08:04 09:13 1.15 9,740 9,740 PROD1 DRILL WPRT P Wiper to window 09:13 11:10 1.96 9,740 9,890 PROD1 DRILL DRLG P 9740', Drill Ahead 1.45 BPM@ 3991 FS RIW=6.9K WOB=1.7K BHP=4202 11:10 12:42 1.54 9,890 9,887 PROD1 DRILL WPRT P 9890 Wiper to window with Tie in,-5' correction 12:42 13:57 1.26 9,890 9,999 PROD1 DRILL DRLG P 9887', Drill Ahead 1.45 BPM@ 4013FS RIW=8K WOB=1.3K BHP=4222 13:57 21:42 7.75 9,999 10,040 PROD1 DRILL DRLG P Back in Ankorite, confirmed in samples ROP<10 FPH 21:42 23:12 1.50 10,040 10,040 PROD1 DRILL WPRT P 10040',may have broken out of the ankorite just prior to wiper trip.Wiper trip to widow 8845'. PU wt 26K. Circulating in new mud during wiper trip. RIH 23:12 23:57 0.75 10,040 10,044 PROD1 DRILL DRLG P Drill ahead, 1.47 bpm @ 3427 FS WOB 2.7, ROP 25 fph, motor work 250 psi. 06/19/2010 Drilled ahead to 10585' 00:00 05:00 5.00 10,044 10,067 PROD1 DRILL DRLG P Drilling ahead.Still drilling in ankorite -5 fph. WOB 2.9,CT wt=4K, 1.46 bpm @ 3600 psi.Motor work 256 psi. 05:00 05:30 0.50 10,067 10,075 PROD1 DRILL DRLG P Drilling ahead at-5 fph,siderite with a small amount of ankorite in the returns. 05:30 06:30 1.00 10,075 10,190 PROD1 DRILL DRLG P Drilling Break. ROP=120-150FPH 06:30 08:12 1.70 10,190 10,190 PROD1 DRILL WPRT P Wiper trip to window PUW=27K BHP=4178 08:12 11:42 3.50 10,190 10,299 PROD1 DRILL DRLG P 10190', Drill Ahead 1.48 BPM @ 3590PSI FS RIW=12k BHP=4183 11:42 11:54 0.20 10,299 10,299 PROD1 DRILL WPRT P BHA Wiper PUW=28K 11:54 12:54 1.00 10,299 10,312 PROD1 DRILL DRLG P Drill ahead 1.49 BPM @ 3881 FS BHP=4232 12:54 15:09 2.25 10,312 10,313 PROD1 DRILL DRLG P 10312,Started losing fluid 1 BPM Healed up fairly quick. Pulled wt check up past area. Looked ok PUW=28K Continue to drill 15:09 16:09 1.00 10,340 8,775 PROD1 DRILL WPRT P Wipe to window with tie in PUW=29K, Losing.1 to.2 BPM Page 5 of 33 Time Logs Date From To " Dur S.Depth E.Depth Phase ,Code Subcode T Comment 16:09 16:30 0.35 8,720 8,720 PROD1 DRILL RGRP T Pull up through window,Open EDC, Position reel and install shims 16:30 16:36 0.10 8,720 8,850 PROD1 DRILL WPRT P Shut EDC, RIH to tie in 16:36 16:51 0.25 8,850 8,864 PROD1 DRILL DLOG P Tie into RA Marker-10.5'correction 16:51 17:30 0.65 8,864 10,340 PROD1 DRILL WPRT P Continue wiper trip, RIH 17:30 19:45 2.25 10,340 10,490 PROD1 DRILL DRLG P Drilling ahead. WOB 1.4,CT wt=6K 1.46 bpm @ 3811 psi 19:45 21:45 2.00 10,490 10,490 PROD1 DRILL WPRT P Wiper trip#1. PUW 28K, PUH to 8845'. RIW 8K,started taking weight at 10300',stacked out at 10420'. Slow rate to 1.15 bpm, RIW-5K to 10490' 21:45 00:00 2.25 10,490 10,585 PROD1 DRILL DRLG P Drilling ahead. WOB 2K,CT wt=-8K 1.44 bpm @ 3700 psi. 06/20/2010 Drilled ahead to 10790'. 00:00 05:00 5.00 10,585 10,602 PROD1 DRILL DRLG P Drilling ahead at<5 fph WOB 2.2,CT wt=-7K 1.47 bpm @ 3647 psi. 05:00 09:45 4.75 10,602 10,618 PROD1 DRILL DRLG P Drilling ahead at<5 fph WOB 2.5,Ct wt=-4K 1.45 bpm @ 3950 psi 09:45 12:51 3.10 10,618 10,629 PROD1 DRILL DRLG P Wt Check PUW=27K Drill Ahead 1.45 BPM @ 3862 PSI BHP=4263 12:51 12:57 0.10 10,629 10,629 PROD1 DRILL RGRP T Losing circ pressure. Pump 2 low charge pressure 12:57 14:33 1.60 10,629 10,635 PROD1 DRILL DRLG P 10629', Drill Ahead 1.41 BPM @ 3698 FS BHP=4185 ROP<5FPH 10635 Drilling Break ROP 70 FPH 14:33 14:39 0.10 10,635 10,637 PROD1 DRILL WPRT P 10637,Pull Mini Wiper 14:39 14:51 0.20 10,637 10,640 PROD1 DRILL DRLG P 10637 Drill Ahead 1.45 BPM @ 3847 PSI FS BHP=4298.3 to.4 BPM Losses 14:51 16:03 1.20 10,640 8,798 PROD1 DRILL WPRT P Wipe to window, Pull up through window to inspect gooseneck counter. Pump down MP line to maintain BHP 16:03 16:33 0.50 8,798 8,798 PROD1 DRILL RGRP T Clean counter wheel,check encoder coupler,good. Reposition spring on wheel for more pressure against coil. 16:33 16:42 0.15 8,798 8,843 PROD1 DRILL WPRT P RIH to log Gamma 16:42 16:54 0.20 8,843 8,860 PROD1 DRILL DLOG P Gamma tie in-10.5 correction 16:54 18:05 1.19 8,860 10,640 PROD1 DRILL WPRT P Continue trip in hole 18:05 19:24 1.33 10,640 10,674 PROD1 DRILL DRLG P Drill ahead 1.45 bph @ 3578 psi FS BHP=4181, ROP 22 fph Page 6 of 33 Time Logs. Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 19:24 19:43 0.33 10,674 10,674 PROD1 DRILL WPRT P Short wiper up to 10550'because return rate dropped to 0.10 bpm. Open choke to drop BHP from 4200 psi to 4100 psi. Return rate increased to 1.0 bpm 19:43 21:43 2.00 10,674 10,790 PROD1 DRILL DRLG P Drill ahead WOB 2.7K,CT wt=-3K 1.46 bpm, 1.2 bpm returns, BHP= 4137 psi. 21:43 23:58 2.25 10,790 10,650 PROD1 DRILL WPRT P Wiper trip#1 PUW 28K.Over pull at 10643'. PU to 8845', RIH 06/21/2010 Drilled to 10940'. Unable RIH pass 10650'during wiper trip. POOH,function test BOPs. RIH with"A"lateral liner. 00:00 00:40 0.67 10,650 10,790 PROD1 DRILL WPRT P Continue RIH wiper trip#1. 00:40 03:15 2.59 10,790 10,940 PROD1 DRILL DRLG P Drilling ahead WOB 2.5K,CT wt=-4K 1.45 bpm, BHP=4118 pis,returns 1.2 bpm 03:15 06:06 2.85 10,940 10,640 PROD1 DRILL WPRT P Wiper trip w/tie-in. Need to confirm accuracy of depth acquisition system. PUW 29K. Last 2 wiper trips pulled heavy at 10648'. RIH,-7 ft correction. 06:06 08:06 2.00 10,640 10,230 PROD1 DRILL WPRT T Started losing RIH weight @ 10280, Ratty from there down until hard setdown @ 10647 PUH to above 10280 @ 5FPM, backream 180 degrees out of as-drilled. 08:06 08:30 0.40 10,230 10,650 PROD1 DRILL WPRT T RBIH,Set down at 10494,Still Ratty. Reduce pump rate, made it down to 10650. PUH @ 90 degrees off of as drilled 08:30 10:00 1.50 10,650 10,650 PROD1 DRILL WPRT T Attempt multiple speeds and pump rates. Not getting motor work and minimal WOB at setdowns. Not able to set down and drill from here. Backream at different TF's 10:00 10:15 0.25 10,650 8,850 PROD1 DRILL WPRT T After working this area had heavy overpull @ 10630. Talk to town, decision made to TD hole and run _111 r. Wipe to Window PUW=32 10:15 10:30 0.25 8,850 8,865 PROD1 DRILL DLOG T Log gamma tie in for-4.5'correction 10:30 11:30 1.00 8,865 10,240 PROD1 DRILL WPRT T RBIH pump low and hi vis sweep 11:30 13:30 2.00 10,240 10,240 PROD1 DRILL WPRT P PUH to window chasing sweeps Log Gamma tie in for+3.5 RBIH to la Liner runnin• pill 13:30 16:00 2.50 10,240 0 PROD1 DRILL TRIP P POOH laying in beaded liner Pill followed with 11.8 ppg NaBr KWF Page 7 of 33 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 16:00 17:00 1.00 0 0 PROD1 DRILL PULD P At Surface, PJSM, Flo check well. Lay down BHA#7 Blow down tool, Bit looks good 2 plugged nozzles 17:00 17:15 0.25 0 0 PROD1 DRILL BOPE P Perform Bi-Weekly BOPE function test 17:15 20:40 3.42 0 850 COMPZ CASING PUTB P PJSM-P/U Liner.Crew change,cont to run liner. MU liner run BHA#8.On well surface test. 20:40 23:19 2.66 850 8,647 COMPZ CASING RUNL P Tag up,open EDC. RIH @ 60 fpm. Fluid losses—8 bbl/1000 ft. 23:19 23:58 0.66 8,647 9,900 COMPZ CASING RUNL P RIH to 8647'. EOP correction+9'. Close EDC,circulate aound the back side, RIH. 06/22/2010 RIH"A"liner with billet. Set liner at 9455'TOL, 10240'BOL. POOH laying in 9.4#FloPro. Performed injector head repairs: replaced chains,skates,and skate-bearings. Lined up to pump slack management. 00:00 00:15 0.25 9,900 11,245 COMPZ CASING RUNL P Continue RIH with"A"lateral liner 00:15 00:45 0.50 11,245 10,469 COMPZ CASING RUNL P Liner on depth(9460'to 10245'). Top slip of anchor orientated high side. Set anchor:press up 3600 psi,broke back.WOB went from 1.25K to 6K. CT wt went from 12.9K to 11.6K. 00:45 02:20 1.59 10,469 8,815 COMPZ CASING TRIP P PUH into casing. PUW=29K. Stop at 8815',tie-in Circulate out KWF with 9.4 ppg FloPro. Lost 145 bbl NaBr KWF total. 02:20 02:39 0.33 8,815 8,374 COMPZ CASING DLOG P PUH and RIH to tie,-5ft correction. TOL=9455, BOL=10240 02:39 04:51 2.20 8,374 0 COMPZ CASING TRIP P POOH at 70 fpm,20K.Circ 1.47 bpm w/1.2 bpm returns. 04:51 06:58 2.13 0 0 COMPZ CASING PULD P PJSM, Undeploy BHA#8 Liner running tool 06:58 22:58 16.00 0 0 PROD2 DRILL RGRP T Injector repairs,Unstab pipe. Remove injector chains and inspect skates/bearings. Find two cracked bearings in addition to known crack in chain. Reinstall new skates and new bearings. Re-install chains, gripper blocks,and guards. Install stripper and stab pipe. Holding MPD pressure at surface for 11.8 ppg EMW at window. Losses for entire time while OOH was 2 bbl. NAD Non-Billable Rig Repair time 16-hrs. (0700-2300 hours: 16-hrs cum nbh for 6/22/10) 22:58 23:58 1.00 0 0 PROD2 DRILL SLPC T Line up and begin to pump cable up CT for slack management. 06/23/2010 Completed slack management and pressure deployed BHA#9. Tagged billet at 9455'and sidetracked off billet for AL1 lateral. Drilled ahead AL1 to 9605'. Lost 2 BBL 9.4#Powervis to formation. Page 8of33 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 PROD2 DRILL SLPC T Continue slack management and cut 20'pipe to cable. 01:00 03:00 2.00 0 0 PROD2 DRILL RGRP T Re-head,pick up BHA#9 and prep to pressure deploy. NAD Non-Billable Rig Repair time 2-hrs. (0100-0300 hours:2-hrs cum nbh for 6/23/10) 03:00 03:30 0.50 0 0 PROD2 DRILL SLPC T Displace CT to FloPro. 03:30 03:42 0.20 0 0 PROD2 STK SFTY P PJSM for deployment 03:42 05:42 2.00 0 0 PROD2 STK PULD P Deploy BHA#9 05:42 07:42 2.00 0 8,350 PROD2 STK TRIP P RIH 07:42 08:06 0.40 8,350 8,380 PROD2 STK DLOG P tie in,+8' 08:06 08:54 0.80 8,380 9,455 PROD2 STK TRIP P Close EDC and RIH to billet 08:54 10:36 1.70 9,455 9,456 PROD2 STK KOST P Tag top of billet, PU and bring pump online at 1.4 BPM,3500 CTP,4190 BHP. PU and start time drill at 1 1 a.-bGj A L FPH from 9454.8'. Note:With EDC open,annular pressure sensor reading 100 psi higher than internal BHA pressure. Also causing dP to read 100 psi lower than normal,and ECD to calculate 0.3 ppg higher than actual. Actual BHP is 4090 psi, 150 WHP, FS dP is 375 psi. 10:36 11:06 0.50 9,456 9,457 PROD2 STK KOST P Time drill at 2 FPH 11:06 11:30 0.40 9,457 9,458 PROD2 STK KOST P Time drill at 3 FPH 11:30 12:00 0.50 9,458 9,463 PROD2 STK KOST P Time drill at 10 FPH 12:00 12:36 0.60 9,463 9,483 PROD2 DRILL DRLG P Drill ahead, 12:36 13:06 0.50 9,483 9,483 PROD2 DRILL WPRT P PU and backream past billet at full pump rate, RBIH with pump down, clean. 28K PUW, 12K RIW 13:06 22:45 9.65 9,483 9,576 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM,3200 CTP, 150 WHP,4160 BHP.good drilling until encountering ankerite at 9524', ROP down to-5 FPH 22:45 23:20 0.59 9,576 9,605 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM,3400 CTP, 100 WHP,4175 BHP. ROP increase to-50 FPH. 23:20 23:59 0.66 9,605 9,605 PROD2 DRILL WPRT P Wiper trip. PUH to 8854(30K#), RBIH(12K#). 06/24/2010 Drilled AL1 lateral 9605'to 10256'. 00:00 00:12 0.20 9,605 9,605 PROD2 DRILL WPRT P Complete wiper trip. Back on bottom. 00:12 03:36 3.40 9,605 9,755 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM,3420 CTP, 95 WHP,4175 BHP. ROP -44 FPH. 03:36 04:36 1.00 9,755 9,755 PROD2 DRILL WPRT P Wiper trip. PUH to 8847(31K#), RBIH(12K#). Page 9 of 33 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 04:36 09:12 4.60 9,755 9,905 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM,3420 CTP, 95 WHP,4175 BHP. ROP —50 FPH. 09:12 09:54 0.70 9,905 8,850 PROD2 DRILL WPRT P Wiper trip to window,30K PUW. Motor work and 3K overpull at 9025' 09:54 10:06 0.20 8,850 8,880 PROD2 DRILL DLOG P Tie in,-2' 10:06 10:36 0.50 8,880 9,905 PROD2 DRILL WPRT P Wiper in hole, 11K RIW,stacked weight at 9058', pumping.5 BPM and saw slight—100 psi motor work. reaminder of trip in hole was clean 10:36 14:24 3.80 9,905 10,055 PROD2 DRILL DRLG P Drilling ahead, 1.5 BPM,3600 CTP, 4100 BHP,90 WHP,2-3K WOB, 200-300 motor work 14:24 15:42 1.30 10,055 10,055 PROD2 DRILL WPRT P Wiper trip to window,31K PUW 15:42 20:10 4.48 10,055 10,205 PROD2 DRILL DRLG P Drilling ahead, 1.6 BPM,3800 CTP, 4150 BHP,90 WHP,2-3K WOB, 200-300 motor work. —33 FPH. 20:10 21:49 1.66 10,205 10,205 PROD2 DRILL WPRT P Wiper trip. 30.5K#PUW, 10K#RIW. Saw slight weight bobble pulling up through 9030',and then 1000#WOB and—100-psi motor work running back down throught 9058'. Pumped 1.4 BPM through trip. Remainder of trip was clean. 21:49 23:58 2.16 10,205 10,256 PROD2 DRILL DRLG P Drilling ahead, 1.34 BPM,3350 CTP, 4150 BHP,45 WHP,2-3K WOB, 100-200 motor work. ROP back down to—5 FPH 10215'approaching 'Fault#1'. Total losses to formation for today: 5-BBL Powervis. Current mud system(#2)has 1701'; LSRV 46K;0.6%solids 06/25/2010 Drilled AL1 lateral 10256'to 10655'. Lost 189 BBL 9.4#Powervis to formation over 24-hour period. 00:00 03:00 3.00 10,256 10,355 PROD2 DRILL DRLG P Drilling ahead, 1.38 BPM,3500 CTP, 4172 BHP,68 WHP,2-3K WOB, 100-200 motor work. ROP—10 FPH. Appear to have penetrated fault at 10,300'with ROP increasing to 55-60 FPH. 03:00 04:00 1.00 10,355 10,355 PROD2 DRILL WPRT P Wiper trip to 8845';31.5K#PUW. 04:00 04:15 0.25 10,355 10,355 PROD2 DRILL DLOG P Log down 2.5-fpm for tie in. Determine correction of-6.5'. 04:15 05:00 0.75 10,355 10,355 PROD2 DRILL WPRT P Wiper in hole,8K RIW. Stacked 8K#at 9058',pumping 0.5 BPM with no WOB nor motor work. Remainder of trip in hole was clean. 05:00 08:48 3.80 10,355 10,505 PROD2 DRILL DRLG P Drilling ahead, 1.42 BPM,3600 CTP, 4195 BHP,30 WHP,2-3K WOB, 100-200 motor work. ROP—50 FPH. Start Mud swap 08:48 10:12 1.40 10,505 10,505 PROD2 DRILL WPRT P New mud around bit,Wiper to 9150', 32K PUW,clean trip both ways Page 10 of 33 Time Logs Date From To Dur S.Depth;E.Depth Phase Code Subcode T Comment 10:12 22:30 12.30 10,505 10,632 PROD2 DRILL DRLG P Drilling ahead, 1.5 BPM,3600 CTP, 4200 BHP,250 WHP,2-3K WOB with 5-6K Surface weight, 100-200 motor work. 22:30 00:00 1.50 10,632 10,644 PROD2 DRILL DRLG P Appear to have broached thief zone at 10632'as returns fall to 0.3-0.4 BPM. ROP stays 4-7 FPH until seeing 40-50 FPH again around 10644'. All other parameters same. _Lost 189 BBL 9.4#Powervis to formation over 24-hourperiod. 06/26/2010 Drilled AL1 lateral 10655'to 11255'. Lost 411 BBL 9.4#Powervis to formation over 24-hour period. Losses now down to 7-bbl/hr. 00:00 00:50 0.84 10,644 10,644 PROD2 DRILL DRLG P Drilling ahead 1.34 BPM(-0.5 BPM returns),3300 CTP,4255 BHP,300 WHP,2-3K WOB,6-7K#Surface weight. Drilling 40-50 FPH. 00:50 02:44 1.91 10,644 10,644 PROD2 DRILL WPRT P Wiper trip 10656-9142'. 28.7K# PUW,9.5K#RIW. Clean through 9455'. 02:44 08:05 5.35 10,644 10,805 PROD2 DRILL DRLG P Drilling ahead 1.3 BPM(-0.6 BPM returns),3200 CTP,4250 BHP,330 WHP,3-4K WOB,Saw 70 FPH for brief interval then back down to drilling 4 FPH. Out of ankerite at 10670,drill ahead with improving return rate. Dropped BHP to 4100 psi,losing<0.1 BPM 08:05 09:29 1.40 10,805 8,845 PROD2 DRILL WPRT P Wiper to window,29K PUW, losing 0.1 BPM 09:29 09:41 0.20 8,845 8,870 PROD2 DRILL DLOG P Tie in,-6' 09:41 10:41 1.00 8,870 10,805 PROD2 DRILL WPRT P Wiper back in hole,9K RIW. Stacked weight at 9058', 10:41 13:29 2.80 10,805 10,955 PROD2 DRILL DRLG P Drilling ahead, 1.5 BPM, 1.3 returns, zero WHP,4100 BHP,3850 CTP. 2 -3K WOB with 3K Surface weight. 13:29 15:35 2.10 10,955 10,955 PROD2 DRILL WPRT P Wiper trip,29K PUW, 15:35 18:24 2.83 10,955 11,105 PROD2 DRILL DRLG P Drilling ahead, 1.5 BPM, 1.3 returns, zero WHP,4140 BHP,3850 CTP. 2 -3K WOB with 3K Surface weight. 18:24 20:48 2.41 11,105 11,105 PROD2 DRILL WPRT P Wiper trip to 9142'. 29K PUW. 20:48 23:33 2.75 11,105 11,255 PROD2 DRILL DRLG P Drilling ahead, 1.42 BPM, 1.2 returns,zero WHP,4160 BHP, 4190CTP. 2-3K WOB with-1K Surface weight. 23:33 23:57 0.41 11,255 11,255 PROD2 DRILL WPRT P Begin wiper to window,29K PUW, losing 0.2 BPM. Lost 411 BBL 9.4# Powervis to formation over 24-hour period. 06/27/2010 Drilled AL1 lateral to TD at 11585'. Displaced well to beaded liner running pill and 11.8#KWF. Prepared for BOPE testing. Lost 161 BBL 9.4#Powervis to formation over 24-hr period. 00:00 01:15 1.25 11,255 11,255 PROD2 DRILL WPRT P Continue wiper trip to window;29K PUW, losing 0.2 BPM. 01:15 01:30 0.25 11,255 11,255 PROD2 DRILL DLOG P Tie in:-7 Page 11 of 33 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T. Comment 01:30 02:36 1.10 11,255 11,255 PROD2 DRILL WPRT P Wiper in hole. Stacked about 4K# surface weight down through 9058'. 02:36 06:54 4.30 11,255 11,405 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, 1.2 returns, 22 WHP,4165 BHP,3900CTP. 2-3K WOB with-10K Surface weight. 06:54 09:42 2.80 11,405 11,405 PROD2 DRILL WPRT P Wiper trip,31K PUW, 11K RIW. Clean trip 09:42 11:06 1.40 11,405 11,472 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, 1.2 returns, 22 WHP,4200 BHP,3800 CTP. 2-3K WOB 11:06 11:42 0.60 11,472 11,472 PROD2 DRILL WPRT T Stacking weight, PUH and become differentially stuck,After attempting to pull free at up to 60K,shut down pump and pulled once more to 60K, no movement. RBIH to 10K surface, 1K WOB and started pumping again. Had 75 PSI motor work,pulled up to 35K then continued PUH at 32K, PUH while circulating in high vis pill. 11:42 14:36 2.90 11,472 11,585 PROD2 DRILL DRLG P High vis pill at bit drilling ahead at 1.4 BPM, 1.2 BPM returns,3800 CTP, WOChoke and 4215 BHP,-6K to -10K surface weight for 2-3K WOB 14:36 15:18 0.70 11,585 11,585 PROD2 DRILL CIRC P Called TD at 11585'after comino out of the top of the formation. Pump low/high vis sweeps Notified AOGCC of 10PM BOP test time Witness waived by Bob Noble (14:45-hrs). 15:18 17:06 1.80 11,585 8,845 PROD2 DRILL WPRT P Wiper to window, 17:06 18:35 1.49 8,845 9,100 PROD2 DRILL DLOG P Tie in,-6'. RBIH 18:35 19:53 1.30 9,100 11,585 PROD2 DRILL WPRT P RBIH pumping beads at 10325' 1.2 BPM, 35 FPM. Tag TD at 11585'. 19:53 21:59 2.11 11,585 0 PROD2 DRILL DISP P POOH laying in beaded liner pill 45 FPM,0.4 BPM,WHP 350. Beads out of BIT at 8850'. Swap to KWF and time out KWF to be at window. Stop at 8798'. Pump 10 BBL beads above BHA. POOH pumping KWF window to surface. Stay on KWF to surface and decrease pulling speeds due to intermitent losses of returns. , 21:59 22:24 0.42 0 0 PROD2 DRILL TRIP P At surface. Flow check well. Conduct PJSM regarding move off well, lay down of BHA. 22:24 22:54 0.50 0 0 PROD2 DRILL PULD P Lay down Drilling Assembly#2 (BHA#9). Bit grade out: 1/2/bt/n/x/i/wt/td. 22:54 23:58 1.08 0 0 PROD2 DRILL CIRC P Flush rig lines. Grease crew on location;grease tree valves. Prep for BOPE testing. 06/28/2010 Set AL1 liner at TD 11585';TOL is at 10116'. POOH and layed down liner running tools. P/U drilling assembly#3(BHA#11). Page 12 of 33 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:00 01:30 1.50 0 0 PROD2 DRILL CIRC P Circulate CT from KWF to water. BOPE test PJSM. 01:30 11:00 9.50 0 0 PROD2 DRILL BOPE P Perform BOPE test. Replace actuator on B5. 11:00 12:18 1.30 0 0 PROD2 DRILL DISP P Displace FW from coil with KWF, install checks in UQC,RU floor for liner ops,confirm hole is full,2.3 Bbls to fill 12:18 12:42 0.40 0 0 COMPZ CASING SFTY P PJSM for liner operations,discuss safety joint drill 12:42 15:00 2.30 0 1,468 COMPZ CASING PULD P Start running liner,safety joint drill after first joint in hole. Total of 45 ioints slotted liner 15:00 16:00 1.00 1,468 1,513 COMPZ CASING PULD P MU aluminum billet,GS and Inteq liner running BHA, MU injector 16:00 17:42 1.70 1,513 8,713 COMPZ CASING RUNL P RIH 17:42 18:24 0.70 8,713 10,744 COMPZ CASING RUNL P Correct depth at flag, +14'. Wt. check,29K PUW, 13KRIW. Run through window and continue in open hole at 50 FPM. 18:24 19:18 0.90 10,744 11,033 COMPZ CASING RUNL P 10742'Stack weight to-12K, PU 3 times to get by,40K PUW 11031', PU 3 times 11062', PU 1 time 19:18 20:03 0.75 11,033 11,590 COMPZ CASING RUNL P Tag TD. Pump at 1.3 BPM,4000 psi to release liner. PUH pumping down backside. 20:03 20:33 0.50 11,590 10,297 COMPZ CASING DLOG P Tie in:-5'correction. Correction places TOL at 10116';BOL 11585'. 20:33 22:30 1.95 10,297 0 COMPZ CASING TRIP P POOH pumping KWF 0.72 BPM,0.2 BPM returns. 22:30 23:00 0.50 0 0 COMPZ CASING PULD P At surface. Flow check well. Conduct PJSM regarding lay down and P/U tools. 23:00 23:15 0.25 0 0 COMPZ CASING PULD P Lay down liner running tools. 23:15 00:00 0.75 0 0 PROD3 STK PULD T P/U drilling assembly#3(BHA#11). 06/29/2010 Losses for 24 hours 208 bbls. KOB from 10116',drilling ahead-tagged Ankerite @ 10278'.Slow ROP until 10,321' 00:00 00:30 0.50 0 0 PROD3 STK PULD T Complete injector and packoff maintenance that was being performed concurrently with P/U tools. Stab on well and line up to run in hole. 00:30 03:15 2.75 0 8,870 PROD3 STK TRIP T RIH pumping 0.2 BPM KWF followed by 9.4#Powervis,timing out mud to reach BHA with BHA at stop above window. 03:15 04:45 1.50 8,870 8,870 PROD3 STK CIRC T Stop at 8780'and swap hole to 9.4# Powervis. Pumpin 1.0 BPM, initially 0.3 BPM returns gradually increasing to 0.7 BPM. Close ECD in BHA. Page 13 of 33 Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 04:45 05:30 0.75 8,870 10,115 PROD3 STK TRIP T RIH; 11K do wt. Clean through window. Once through window, come online 9.4#Powervis 1.2 BPM, 1.2 BPM returns,3000 CTP, 125 WHP,3976 BHP. 05:30 08:00 2.50 10,115 10,125 PROD3 STK KOST T Tag billet at 10,116'dry. PU 1',start circ,begin time milling sequence. 1 C2, O ' fh k. 1.�P /L y.- O Saw motor work immediately,so PU another 0.5'and restart time milling. 1.4 bpm in&out,0 psi WHP,3500 psi CTP,4085 psi BHP. 08:00 09:54 1.90 10,125 10,264 PROD3 DRILL DRLG T Continue drilling ahead, 1.4 BPM,full returns,3550 CTP Getting some losses at 10,246'. Returns down to 1.0 bpm. 3900 psi CTD,0 psi WHP,4130 psi BHP, 1.45 bpm in. 09:54 11:21 1.45 10,264 10,264 PROD3 DRILL WPRT T Wiper to 9150',29K PUW 11:21 20:51 9.50 10,264 10,321 PROD3 DRILL DRLG T Drilling ahead. Hit ankerite at 10278'. PU with 10k overpull,run back down to drill ahead. Returns fluctuating 50-70%but gradually improving. Several stalls while in ankerite. 3200 psi CTP,0 psi WHP,4000 psi BHP, 1.33 bpm in. 20:51 22:33 1.70 10,321 10,415 PROD3 DRILL DRLG T Drilled through ankerite.losing roughly 4 bbls an hour for losses. Continue drilling ahead-ROP 50, WOB 2.5,CT weight 5.7K, 1.48 bpm, rate out 1.36,circ 3700psi. 22:33 00:00 1.45 10,415 10,415 PROD3 DRILL WPRT T Wiper trip-CT weight 29K,started losing.4 bpm prior to wiper trip. Slight overpull @ 10265'to 38K. POOH to 9150'-RIH seen light tag @ 10,280'(ankerite section). 06/30/2010 Continue drilling ahead. Performed mud swap with 1631'on system.Tight spot @ 10,275',clear drift with 90L TF. 140 bbl losses for 24 hours. 00:00 03:00 3.00 10,415 10,455 PROD3 DRILL DRLG T Continue drilling ahead-good ROP to 10,443'-hit ankerite.Slow ROP. Losses roughly 7 bbls/hour. 03:00 04:00 1.00 10,455 10,565 PROD3 DRILL DRLG T Broke through-drilling ahead-ROP 90 fph,WOB 2.2K,Ct weight 6.5K, 1.40 bpm,returns 1.15 bpm,Circ. 3650, BHP 4052 psi, ECD 11.9. 04:00 06:00 2.00 10,565 10,565 PROD3 DRILL WPRT T Wiper trip with tie in-29K off bottom. -5'correction. RIH,set down 1.5k WOB at 9060 and 1.5k at 10280'but get past without pickup or dropping rate. 06:00 07:45 1.75 10,565 10,715 PROD3 DRILL DRLG T Drilling ahead with excellent ROP. Losses 8-10 bbl/hr. 3500 psi CTP,0 psi WHP, 1.33 bpm in, 1..5 bpm out,4115 psi BHP. Page 14 of 33 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 07:45 09:45 2.00 10,715 10,715 PROD3 DRILL WPRT T Wiper trip to 9150'. 29k clean PU off bottom. RIH,set down twice at 10,275. Got past by orienting at 90L,pumping 0.3 bpm,and slowing to 20 fpm. Drilled TF was 85L. Start mud swap while RIH. Mud system had drilled 1631'and had 0.6% solids. 09:45 10:45 1.00 10,715 10,812 PROD3 DRILL DRLG T Back on bottom drilling. Fresh 9.4 ppg Powervis at the bit. CTP=3800 psi, BHP=4050 psi, WHP=0 psi,WOB=2.8k,CW= 2k,dP=280 psi, In=1.45 bpm,Out =1.29 bpm. 10:45 11:45 1.00 10,812 10,865 PROD3 DRILL DRLG T Hit a little hard streak at 10812'. Drilling ahead. CTP=3700 psi, BHP=4010 psi, WHP=0 psi,WOB=2.7k,CW= -2k, In=1.47 bpm,Out= 1.29 bpm. 11:45 13:51 2.10 10,865 10,865 PROD3 DRILL WPRT T Wiper to 9150'MD. PU=29k. RIH, no bobble at all at 10,275'when followed same process as last time. 13:51 15:21 1.50 10,865 10,950 PROD3 DRILL DRLG T Back on bottom drilling. Losses=4 bbl/hr. CTP=3680 psi, BHP=4080 psi, WHP=50 psi,WOB=2.8k,CW= 1k, In=1.44 bpm,Out=1.3 bpm. 15:21 16:21 1.00 10,950 11,015 PROD3 DRILL DRLG P Drilling ahead. 16:21 19:21 3.00 11,015 11,015 PROD3 DRILL WPRT P Wiper to tie-in correction-5 ft. Slight overpull at 10,275'.Orientate 90 left. Slight weight bobble @ 9058'RIH, nothing else. 19:21 22:21 3.00 11,015 11,070 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm, 1.30 returns,circ 3700 psi, WOB 1.7,Ct weight 1K, BHP=4080 psi, ROP 10, ECD 12.May have faulted into A-5- turning down.SLOW ROP from 11025'. 22:21 23:21 1.00 11,070 11,090 PROD3 DRILL DRLG P Starting to have weight transfer issues @ 11070'.A-5 formation in samples-shale/silt.Mix up a sweep of drillzone-1.48 bpm,3800 psi, BHP 4060, ECD 11.9, ROP 20, WOB 1.8K,CT weight-10K. 23:21 00:00 0.65 11,090 11,113 PROD3 DRILL DRLG P BHA wiper while pumping down the 5 bbl drillzone sweep into CT. Lost prime when came online. P/U weight 31K. Drilling ahead-Weight transfer stayed about the same but ROP _ increased to 60 fph. 07/01/2010 Drilling ahead-Slow ROP due to weight transfer, POOH for Agitator. Drilling ahead-diff.stuck @ 11437' Pulled free. 128 bbls losses. Page 15 of 33 Time Logs Date< From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:00 02:00 2.00 11,113 11,165 PROD3 DRILL DRLG P Drilling ahead-1.45 bpm,3800 psi, BHP 4050, ECD 11.9, ROP 55, WOB 2.2,CT weight-12K. 11130' Pump another 7 bbl sweep, ROP dropping off-poor weight transfer. 02:00 04:00 2.00 11,165 7,500 PROD3 DRILL TRIP P Wiper trip&POOH to P/U agitator- P P 9 still having weight transfer issues to bit.CT weight-13K WOB 1.7K. P/U weight 30K. 04:00 04:30 0.50 7,500 7,500 PROD3 DRILL SFTY P H2S drill(leak in cellar)-Rig- evacuation and muster. Lessons learned captured. 04:30 06:15 1.75 7,500 0 PROD3 DRILL TRIP P Continue POOH following MP schedule holding 11.5 ppg EMW at window. Losses-6 bph. 06:15 10:15 4.00 0 0 PROD3 DRILL PULD P Undeploy lateral BHA#11. Pressure deploy Agitator BHA#12. 10:15 13:45 3.50 0 11,165 PROD3 DRILL TRIP P RIH. No problem getting past window. Slight WOB bobble at 9060. 13:45 16:45 3.00 11,165 11,315 PROD3 DRILL DRLG P Drilling ahead. 1.35 bpm,3950 psi, BHP 4080, ECD 12.0,WOB 2.6,CT weight-1K. 16:45 19:30 2.75 11,315 11,315 PROD3 DRILL WPRT P Wiper trip-P/U weight 32K.Wipe up to 9143'Had to work through Shale section(last 200')to get back to bottom. 19:30 21:30 2.00 11,315 11,437 PROD3 DRILL DRLG P Drilling ahead-1.35 bpm,4000 psi, BHP 4140psi, ECD 12.2, ROP 90, WOB 1.3,Ct weight 3K. 21:30 23:00 1.50 11,437 11,437 PROD3 DRILL CIRC T Indication of stacking-went to P/U 40K and are differentially stuck. Good returns,pump B/U and then sit pumps down for 10 minutes(BHP 3900-WHP 550).CT popped free on 6th attempt @ 55 fpm pulled 58K on CT string. 23:00 00:00 1.00 11,437 9,300 PROD3 DRILL WPRT P Wiper trip&pulled heavy @ 11,110', worked free continue with wiper trip. BHI counter stopped working during wiper-fix&tie in at window. . 07/02/2010 Drilled to TD of 11605'. Pumped sweeps, laid in liner running pill and KWF. P/U liner assembly.Total losses 96 bbls. 00:00 02:30 2.50 9,300 11,437 PROD3 DRILL WPRT P Continue with Wiper trip-Tie in due to BHI counter slippage(fixed). RIH- have to work CT to botttom from 11030'to TD by cycling pumps and speed. P/U weight clean 29K. 02:30 07:24 4.90 11,437 11,512 PROD3 DRILL DRLG P On bottom drilling-1.35 bpm,3800 psi, BHP 4140, ECD 12,WOB 2.2K, CT weight-2K, ROP 60. Drill ahead. Found ankerite at 11450' -ROP 8 fph. Broke thru at 11468. DPS sensor began malfunctioning while drilling ankerite,perhaps due to agitator. Internal P and WOB sensors off scale. Page 16 of 33 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 07:24 09:54 2.50 11,512 9,150 PROD3 DRILL WPRT T Wiper to 9150'to check hole conditions around shaley section and to decide plan forward. PU=32k. Had a 3k overpull(surface weight)at 11,305',and 8-10k overpulls at 11256', 11232', 11222',and 11210'. The overpull at 11222'also gave a motor stall,possibly trying pack off. No problems remainder of trip. 09:54 10:12 0.30 9,150 11,512 PROD3 DRILL WPRT T Wiper back in to 10900'. Drop rate to 0.5 bpm to work thru shaley section. Saw several bobbles between 11140-11310 but no setdowns. Increase rate, RIH to TD. 10:12 12:24 2.20 11,512 11,605 PROD3 DRILL DRLG P Back on bottom drilling. Circ 5 bbl lo-vis/5 bbl hi-vis sweep. 1.33 bpm,3950 psi, BHP 4200, ECD 12.25,CT weight-3K. WOB sensor is toast. 12:24 14:30 2.10 11,605 11,605 PROD3 DRILL CIRC P TD hole at 11605'. PU=32k. Circulate 10 bbl lo-vis/10 bbl hi-vis sweep bottoms up while slowly working pipe to/from 11470'. No shale chunks in returns,only fines and'clay balls'. After sweep displaced,pumped beaded liner pill down coil. 14:30 15:30 1.00 11,605 8,850 PROD3 DRILL DISP P POH laying in liner pill,40 fpm at 0.4 bpm. 15:30 15:45 0.25 8,850 8,870 PROD3 DRILL DLOG P Tie into RA marker, +3'correction. 15:45 18:00 2.25 8,870 0 PROD3 DRILL DISP P POH laying in 11.5 ppq NaBr KWF, 60 fpm at 0.6 bpm. 18:00 19:00 1.00 0 0 PROD3 DRILL SFTY P CT @ surface, KWF to surface.Stop and perform no-flo check and safety meeting with crew change out. 19:00 20:30 1.50 0 0 PROD3 DRILL PULD P Lay down drilling BHA and Agitator 20:30 21:30 1.00 0 0 COMPZ CASING SFTY P Prep the floor and prepare to P/U liner.Safety joint drill. 21:30 00:00 2.50 0 0 COMPZ CASING PUTB P Start P/U liner.Total 43 joints. 07/03/2010 RIH with liner, unable to get past 10280'. POH, reconfigure shoe, rerun liner with no luck. POOH for FCO BHA. 00:00 01:00 1.00 1,438 1,438 COMPZ CASING PUTB P Finish making up BHI tools and prepare to RIH with CT 01:00 03:00 2.00 1,438 8,737 COMPZ CASING RUNL P RIH with EDC closed pumping.3 bpm.Stop pumping @ 6000' 03:00 04:30 1.50 8,737 10,280 COMPZ CASING RUNL P Stop @ flag-correct-5 ft Weight check in cased hole 31K-continue RIH.Tag up @ 10280'-P/U weight 39K.tried 12 times slower speed. P/U 100 ft and try again.Tried 10 more times no luck. 04:30 07:18 2.80 10,280 0 COMPZ CASING RUNL T POOH to change BHA configuration. Lost only 9 bbl of KWF during round trip. Page 17 of 33 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 07:18 08:00 0.70 0 0 COMPZ CASING PULD T PJSM. Lay down CoilTrak BHA. 08:00 10:30 2.50 0 0 COMPZ CASING PULL T Lay down liner assembly(avg.5 jnts per 12 minutes). Hole standing full. Unique shoe was packed full of clay and beads-unable to rotate. Nose on the Unique shoe was also just hand-tight. 10:30 14:00 3.50 0 0 COMPZ CASING PUTB T Reconfigure shoe with Unique indexing shoe,2'pup, 1.5-deg bent sub,and R&R Indexing tool. Lift is equivalent to a 1.8-deg drilling BHA. PU 43 jnts slotted liner. 14:00 15:00 1.00 0 0 COMPZ CASING PULD T Install torq-thru deployment sleeve and torq-thru GS. PU Coiltrak BHA with HOT. 15:00 17:18 2.30 0 8,820 COMPZ CASING TRIP T RIH with segment#1 of 2-3/8"liner assembly. 17:18 18:00 0.70 8,820 10,280 COMPZ CASING TRIP T Tie into pipe flag. PU=28k. Run past window into open hole. 18:00 20:00 2.00 10,280 10,280 COMPZ CASING TRIP T Tagged up a(7.10280'cycle R&R indexing tool 12 times to try to roll through trouble spot. No luck P/U. Start Orientating around the world in 30 degree increments. No luck.Sat down and tried to roll in with no luck also. 20:00 22:00 2.00 10,280 1,457 COMPZ CASING TRIP T POOH for clean out assembly pumping KWF.4 bpm. 22:00 00:00 2.00 1,457 1,457 COMPZ CASING PULD T Ct @ surface,flow-check&lay down BHA&set up rig floor for pipe handling. 07/04/2010 Lay down Liner assembly, P/U D-331 FCO BHA. Drifted through trouble spot no problem. Had difficulty working down through shales starting @ 11,000'.worked down to TD,condition hole for Liner run. P/U liner assembly. 00:00 03:00 3.00 1,457 0 COMPZ CASING PULL T Laying down liner assembly. Bottom of the guide shoe was loose again, but otherwise shoe assembly was clear and free to rotate/index. 03:00 04:00 1.00 0 62 COMPZ CASING PULD T P/U Milling/FCO BHA with 1.1 AKO 04:00 05:30 1.50 62 8,820 COMPZ CASING TRIP T RIH-shale and clay balls coming over shakers while RIH. 05:30 05:42 0.20 8,820 8,820 COMPZ CASING DLOG T Tie-in. +4'correction. 05:42 07:00 1.30 8,820 8,820 COMPZ CASING DISP T Displace out 11.5 ppg KWF with 10 bbl hi-vis spacer and 9.4 ppg Powervis mud at 1.0 bpm. Good recovery: lost total of 42 bbl KWF after two attempts to run liner. Page 18 of 33 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 07:00 09:12 2.20 8,820 10,310 COMPZ CASING REAM T RIH for fill clean out. At 10280'orient to 90L and RIH at 35 fpm. Pass by ledge with only a slight bobble. RIH to 10300'. Back ream 90L to 10250 at 10 fpm. Repeat 2X with same results. RIH to 10310,orient to 70L and backream at 10 fpm. Down ream at 20 fpm at 70L and again don't really see much either. Repeat passes at 70L. At 10310,orient to 50L and backream at 10 fpm. Downream at 20 fpm at 50L and no problem passing ledge. Repeat 50L pass. At 10310,orient to 110L and backream at 10 fpm. Downream at 20 fpm at 110L and still no problem. Repeat pass at 110L. 09:12 10:18 1.10 10,310 11,250 COMPZ CASING FCO T Continue in hole. Lot of difficulty getting past shales at 11130-11250'. Having to cycle pumps to get thru several tight spots. Unable to pass 11250,45k overpull getting back out. 10:18 13:12 2.90 11,250 11,000 COMPZ CASING WPRT T POH to 11100'. Circ 10 bbl lo-vis& 10-bbl hi-vis pill. Chase out of hole to 9150'. Run back in hole to 11000'. 13:12 13:48 0.60 11,000 11,605 COMPZ CASING WPRT T Cut rate to 0.5 bpm to try to work past shales. Get past without any setdowns. Beyond worst shales tried to increase rate to 1.3 bpm but start having setdowns,so keep rate at 0.5 bpm until TD. 13:48 15:30 1.70 11,605 8,820 COMPZ CASING DISP T Circulate bead pill. Begin POOH laying in liner pill from TD. 15:30 19:00 3.50 8,820 63 COMPZ CASING TRIP T POH laying in 11.5 ppg KWF. 19:00 20:30 1.50 63 0 COMPZ CASING PULD T Flo-check,lay down BHA. 20:30 21:30 1.00 0 0 COMPZ CASING CIRC T Move injector over WH,close swabs and circulate new KIM mud through CT string. 21:30 00:00 2.50 0 COMPZ CASING PUTB T Start P/U liner with 1.5 bent sub and bull nose guide. 07/05/2010 RIH with liner assembly to TD. PU and RIH with 2nd liner segment. Liner Set from 11605'-8822'. P/U WS assembly.Set Top of whipstock @ 8800.5'. 00:00 00:30 0.50 1,450 1,450 COMPZ CASING PUTB T Continue to P/U and scribe liner assembly. 00:30 03:30 3.00 1,450 11,605 COMPZ CASING RUNL T RIH with CT pumping 0.3 bpm through GS.Weight check above window 27K,Stop pumping-RIH. Small weight bobble @ 10,280', 10436'. made it to bottom no problems. Page 19 of 33 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 03:30 04:30 1.00 11,605 8,800 COMPZ CASING TRIP P p/U weight 38K,Set back down, bring pump up to 1.2 bpm, disconnect off liner-P/U weight 26K. come up 20 ft and set up to pump down backside while POOH to window. Liner segment#1 set 10209'- _11605'. 04:30 07:18 2.80 8,800 0 COMPZ CASING TRIP P POOH Pumping 11.5 ppg KWF down the CT. NOTE: Inteq counter slipped-400' while POOH. Counter wheel showed wear-replaced. 07:18 08:18 1.00 0 0 COMPZ CASING PULD P LD BHA. 08:18 11:30 3.20 0 0 COMPZ CASING PUTB P PJSM. PU liner segment#2- indexing shoe,34 jnts slotted,9 jnts solid,4'pup,shorty deployment sleeve. 11:30 11:54 0.40 0 0 COMPZ CASING PULD P MU BHA#17 onto liner. 11:54 14:54 3.00 0 8,820 COMPZ CASING RUNL P RIH with liner segment#2. Bobble at 9060'but otherwise run to bottom without trouble. 14:54 15:06 0.20 8,820 8,820 COMPZ CASING TRIP P Circulate to release liner. Liner 1&\ \` segment#2 set 8814'-10209'. POH. 15:06 15:12 0.10 8,820 8,350 COMPZ CASING DLOG P Tie into K1 marker,+8'correction. Top of liner(corrected)=8822'. 15:12 17:18 2.10 8,350 0 COMPZ CASING TRIP P POH. 17:18 17:48 0.50 0 0 COMPZ CASING PULD P PJSM, LD BHA#17. 17:48 19:30 1.70 0 71 PROD4 RPEQP1PULD P PU whipstock BHA#18 19:30 22:00 2.50 71 8,800 PROD4 RPEQP1TRIP P Open EDC-RIH slowly the first 300 ft,Start pumping.3bpm, RIH 60 fpm.Tie in @ 8350. Corection+8ft. Weight check-27K. RIH to 8815' P/U to 8810'26K, HS orientation. IA -300 OA"0" 22:00 22:30 0.50 8,800 8,800 PROD4 RPEQP1WPST P Close EDC-Bring pumps up to 1 bpm,3600 psi,Setting tool pressure drop to 1500 psi. Set down 3K WOB.Top of WS set @ 8800.55'- Good set 22:30 00:00 1.50 8,800 83 PROD4 RPEQPITRIP P POOH laying in KWF. 07/06/2010 Mill 3.5"window exit from 8802.0 to 8808.0. POOH, Perform BOPE Function test, RIH with 7"exit BHA,Tag @ 8807.2 00:00 01:00 1.00 83 0 PROD4 RPEQP1PULD P Ct @ surface-flow check well. Lay down WS BHA. 01:00 01:30 0.50 0 73 PROD4 WHPST PULD P P/U Milling BHA.Open EDC. 01:30 03:30 2.00 73 8,780 PROD4 WHPST TRIP P RIH pumping.3 bpm.Tie in correction+8 ft. 03:30 04:30 1.00 8,780 8,802 PROD4 WHPST CIRC P Circulate B/U to recover KWM. 04:30 05:00 0.50 8,802 8,802 PROD4 WHPST MILL P Stop pumping,Close EDC. Dry tag TOWS @ 8802.2', P/U start pumping 1.45 bpm,3600 psi free spin. Page 20 of 33 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 05:00 09:00 4.00 8,802 8,805 PROD4 WHPST MILL P RIH slowly from 8801.5'-motor work detected @ 8802'. L r0 ( f� \ Start milling-1.45 bpm,3750psi, �J b BHP 3970psi,WOB.8K,Ct weight 7.4K,Auto drill set up-1fph. Seeing cement in the sample by 2.2'into it. 09:00 11:00 2.00 8,806 8,805 PROD4 WHPST MILL P See spike in motor work @ 8805.6'; walked through and see increase of ROP,decrease in pump pressure (-3700 psi).Appear to have exited tubing.Mud pump#2 leaking out cap, PUH clean and bring pump#1 online and begin working pumps in tandem. RBIH and ease back down to 8805',see motor work again where we left it @ 8805.6.Window area appears clean. 11:00 13:00 2.00 8,807 8,807 PROD4 WHPST MILL P At 8806.75'. Pumping 1.44 BPM, 3870 psi, BHP=3948 psi.WOB 2.55k, ROP set @ 0.8 fph. 13:00 14:30 1.50 8,807 8,808 PROD4 WHPST MILL P At 8808'. Begin PUH @ 1'fpm for reaming passes through window to top of whipstock. Pumping 1.45 bpm, 3965 psi,3958 psi BHP.Good clean passes with little to no motor work. 14:30 16:45 2.25 8,808 0 PROD4 WHPST TRIP P Open EDC&POOH following MPD. 16:45 18:45 2.00 0 0 PROD4 WHPST PULD P PJSM,Close EDC,Tag up, UnDeploy BHA#19 18:45 19:45 1.00 0 0 PROD4 WHPST BOPE P Blow down stack, Perform Bi-weekoly BOPE Function test 19:45 21:15 1.50 0 0 PROD4 WHPST PULD P PJSM, P/U BHA#20,2 degree fixed bend Weatherford motor with 2.80"fat radius mill 2.81 go 2.80 NoGo 21:15 23:27 2.20 0 8,360 PROD4 WHPST TRIP P Trip in well with BHA#20 23:27 23:42 0.25 8,360 8,389 PROD4 WHPST DLOG P Log Gamma tie in, +6.5'.Close EDC RIH to mill 7"caseing exit PUW=28K, RIW=10K with no pumps 23:42 00:00 0.30 8,389 8,807 PROD4 WHPST TRIP P 8807.8, Dry tag window, PUH and roll on pumps 1.4 BPM @ 3800PSI FS 8807.2 600lbs WOB,40 PSI Motor work 07/07/2010 Complete Dual String window. P/U Build section BHA, Drill Ahead 00:00 03:45 3.75 8,808 8,810 PROD4 WHPST MILL P 8807.2',Milling 7"casing exit per program 03:45 06:45 3.00 8,810 8,812 PROD4 WHPST MILL P 8809.5. Motor work and WOB dropped off. Possible 7"exit,2.3' down from contact point.Continue @ 1 FPH Page 21 of 33 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 06:45 07:45 1.00 8,812 8,812 PROD4 WHPST MILL P Getting better WOB transfer 2-3K. ROP 1 fph,CT weight 8K.Cement with fine medal shavings in returns. P/U due to no movement and WOB 4K,stacking out. 1.45 bpm,3570psi, BHP 3952, ROP 1.1 fph,WOB 4K, CT weight 8.8K,differential 625 07:45 11:15 3.50 8,812 8,820 PROD4 WHPST MILL P P/U clean 30K, RIH 4 fpm.WOB 3.7K @ 8812.1', Better motor work. Popped through @ 8812.70' WOB dropped to 1K.Start time milling down to 8820'ROP 2 fph,then 5 fph. Formation in returns. 11:15 12:45 1.50 8,820 8,820 PROD4 WHPST REAM P Start backreaming from 8815'to 8800'as per procedure.No motor work detected.Total of 3 passes @ 1 fpm.Shut down pumps-dry run- Clean. 12:45 15:45 3.00 8,820 74 PROD4 WHPST TRIP P Open EDC&POOH, P/U weight 29K. 15:45 17:15 1.50 74 0 PROD4 WHPST PULD P CT @ surface. Undeploy BHA.Mill came out 2.79"No-go 17:15 19:00 1.75 0 0 PROD4 DRILL SVRG P Service Injector,Gripper block bolt broken. E-Z out Crew change, Prep to cut coil,then got call from town changing their mind. 19:00 21:00 2.00 0 0 PROD4 DRILL PULD P PJSM, Deploy BHA#21 with 2.4 degree motor bend with re-run Hughs with cheetah cutters,Surface test good Open EDC 21:00 23:00 2.00 0 8,340 PROD4 DRILL TRIP P RIH 23:00 23:15 0.25 8,340 8,365 PROD4 DRILL DLOG P Gamma Tie in log,+6.5',Close EDC PUW=28K, RIW=10K 23:15 23:27 0.20 8,365 8,819 PROD4 DRILL TRIP P RIH to drill 23:27 00:00 0.55 8,820 8,838 PROD4 DRILL DRLG P Slight bobble @ 8809,Tag @ min rate 8819.1 PUH, Line up on new mud 1.45 BPM@ 3500 PSI BHP=3960 8838 Midnight Depth 07/08/2010 RIH with 2.45 Degree motor drilled 8838 to 8870. High DLS POOH,dial down to 2.2. Drill build 8870 to 9255. POOH for RibSteer 00:00 01:00 1.00 8,838 8,870 PROD4 DRILL DRLG P Drill ahead from Midnight-Mud swap. 01:00 01:30 0.50 8,870 8,350 PROD4 DRILL WPRT T Higher then anticipated DLS Avg 53 degrees Pull off bottom to crunch numbers explore alternatives Pull up through window to log K-1 Marker 01:30 01:45 0.25 8,350 8,381 PROD4 DRILL DLOG P Log K-1 to tie in RA marker 01:45 01:57 0.20 8,381 8,820 PROD4 DRILL TRIP P Trip in well to log RA Page 22 of 33 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 01:57 02:03 0.10 8,820 8,833 PROD4 DRILL DLOG P Log RA to Tie in marker, RA is at 8808.0 TOW=8802 02:03 04:03 2.00 8,833 0 PROD4 DRILL TRIP T POOH to dial down motor angle 04:03 06:03 2.00 0 0 PROD4 DRILL PULD T At Surface, PJSM. Undeploy BHA #21 06:03 08:03 2.00 0 62 PROD4 DRILL PULD T Deploy BHA#22 with a 2.2 AKO instead of 2.45 AKO. 08:03 10:33 2.50 62 8,860 PROD4 DRILL TRIP T Open EDC-RIH following MPS.Tie +6.5',stop pumping close EDC-RIH through window,slight bobble @ 10 fpm. @ 8809'. 10:33 13:33 3.00 8,870 9,020 PROD4 DRILL DRLG P Bring pumps online.drilling ahead- 1.42 bpm,3300 psi, BHP 3910psi, ROP 40,WOB 1.7K,CT weight 8K, returns 1.38 bpm. ECD 11.6 13:33 14:03 0.50 9,020 9,020 PROD4 DRILL WPRT P Wiper trip-P/U weight 30K-Had weight transfer issues going back down,pumping 0.3 bpm, P/U and re-orientate down @ 8914'. 14:03 17:03 3.00 9,020 9,104 PROD4 DRILL DRLG P Drilling ahead-1.40 bpm,3600 psi, BHP 3990, ECD 11.7, ROP 40, WOB 2.5K,Ct weight 7K. 17:03 20:03 3.00 9,104 9,170 PROD4 DRILL DRLG P Quick P/U 30K,due to weight transfer&ROP. Drilling ahead. 20:03 20:33 0.50 9,170 9,170 PROD4 DRILL WPRT P Wiper trip to window PUW=34k Overpulls @ 9091 and 8900 20:33 22:45 2.20 9,170 9,251 PROD4 DRILL DRLG P Drill Ahead 1.45 BPM @ 3822 FS RIW=7K, ROP 60-40 FPH BHP=4065 22:45 23:09 0.40 9,251 9,255 PROD4 DRILL DRLG P Lost motor work and WOB, P/U and have to run back in and dial up traction pressure.46K off bottom. Perform BHA Wiper, ROP 10-15 FPH continue to drill ahead 23:09 00:00 0.85 9,255 7,238 PROD4 DRILL TRIP P 9255, Drilling break looks like back up out of Ankorite.Trip out for RibSteer PUW=32K 07/09/2010 RIH w/RibSteer drill to 9464, POOH to inspect BHA. 00:00 01:30 1.50 7,238 0 PROD4 DRILL TRIP P Continue out of well for RibSteer 01:30 03:00 1.50 0 0 PROD4 DRILL PULD P PJSM,At surface, Undeploy BHA #22 Bit came out with 3 out of 4 nozzles plugged off Connector to lower quick packed with clay MBT up to 0.25 03:00 04:15 1.25 0 68 PROD4 DRILL PULD P PJSN, Deploy BHA#23 Ribsteer with rebuilt Hughes Bi-Center with Cheetah cutters Page 23 of 33 Time Logs Date From To i Dur S.Depth E.Depth Phase Code Subcode T Comment 04:15 06:45 2.50 68 9,255 PROD4 DRILL TRIP P RIH following MPS-tie in with+6.5'. Close EDC-RIH through window 20 fpm-saw about 2K weight resistance but no tag. RIH pumping min. rate to bottom,clean all the way down. 06:45 10:45 4.00 9,255 9,350 PROD4 DRILL DRLG P Drilling ahead-1.45 bpm,3600 psi, BHP 4055, ECD 11.7, ROP 20, WOB 3.17,CT weight 6K. Drilling in/out of Ankerite. Needing to set down 3K+to get through harder Ankerite stringers then 1.5K in faster ROP areas. 10:45 11:45 1.00 9,350 9,350 PROD4 DRILL DLOG P Wiper trip&MADD pass. P/U weight clean @ 29K.9200'&9105'slight weight drag and small pressure spike POOH. 11:45 13:45 2.00 9,350 9,422 PROD4 DRILL DRLG P Drilling ahead-erratic drilling from 9375'Motor work,quick drill off. ROP 30-50.CT weight 9K,WOB 2K, 1.45 bpm,3800 psi, BHP 4085, ECD 11.8 13:45 14:45 1.00 9,422 8,600 PROD4 DRILL WPRT P Weight check-heavy motor work and no WOB. P/U weight 35K, lots of motor dP.Wiper up to window to clean up hole. Bore and differntial pressure increased during wiper. Slow POOH due to possible packing off @ bit. Mix up Hi-lo sweeps. 14:45 15:15 0.50 8,600 8,600 PROD4 DRILL CIRC P Pull into cased hole,slight 1K drag at window and differential pressure dropped off to nearly normal. P/U 300'pumping through bit,stop open EDC and circ. B/U. Heavy thick returns to surface. 15:15 15:45 0.50 8,600 9,422 PROD4 DRILL TRIP P Increase clay stop to 3%and add drillzone to lo-vis sweep for bit balling.Close EDC-RIH. Pump Low/High sweeps with drill zone. Quick weight check before TD. P/U weight 28K-clean. 15:45 16:39 0.90 9,422 9,464 PROD4 DRILL DRLG P Drilling ahead-1.40 bpm,3700psi, BHP 4000, ECD 11.7,WOB 2K,Ct weight 10K, ROP 50, ratty drilling. 9460'- P/U 40'clean 31K. 16:39 18:09 1.50 9,464 9,464 PROD4 DRILL CIRC T Packed off above the bit again, P/U weight 32K,Circ press.4100 psi. Seems like bit balling again. P/U and pump low/high sweeps. 18:09 19:39 1.50 9,464 8,550 PROD4 DRILL WPRT T Wipe to window. Differential pressure high, Bore pressure 4700 to 5200. Pull up through window and pump 5 BBI sweep of drill zone to clear bit. No pressure change through window or after sweep 19:39 21:39 2.00 8,550 0 PROD4 DRILL TRIP T Open EDC and pull to surface to check BHA Bit, FVS, Page 24 of 33 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 21:39 22:39 1.00 0 0 PROD4 DRILL PULD T PJSM,Undeply BHA#23 22:39 00:00 1.35 0 0 PROD4 DRILL PULD T L/D BHA found RSM output shaft _dropped 1.7 inches. Bit @ 1-1 with two plugged ed nozzles on nose 07/10/2010 Drill from 9464 to 9600.Circ pressure high,swap mud, POOH to diagnose High pressure, Ball valve partialy shut.Swap out DBV. RIH and drill to 9960 00:00 01:00 1.00 0 0 PROD4 DRILL PULD T Finish testing BHA#24 and load into PDL 01:00 02:00 1.00 0 0 PROD4 DRILL PULD T PJSM,Deploy BHA#24 into well, Surface test 02:00 04:00 2.00 0 8,350 PROD4 DRILL TRIP T RIH 04:00 04:09 0.15 8,350 8,386 PROD4 DRILL DLOG T Tie into formation for a+7'correction 04:09 04:45 0.60 8,386 9,464 PROD4 DRILL TRIP T Trip in well to drill Good pass through window @ spot tight s 9112. No setdown 9 P 04:45 07:15 2.50 9,464 9,600 PROD4 DRILL DRLG P 9464'Drill Ahead 1.2 BPM @ 4090 FS ROP=50 to 70 FPH @ 2K WOB Circ pressure up to 4300psi. Quick weight check-32K, By pass filters- no change-screens clean. Possible BHA ball valves or old mud. 07:15 08:15 1.00 9,600 8,780 PROD4 DRILL WPRT T Wiper trip due to stall&no working limits. P/U weight 35K. 1.20 bpm, 4300 psi, BHP 4080, ECD 11.7. Pull into cased hole to diagnose Downhole-surface pressures. 08:15 08:45 0.50 8,780 8,780 PROD4 DRILL CIRC T Open EDC-Bring pumps up to check old mud rate vs new mud rate. Old-1.3 bpm=4350 psi New 1.3 bpm=4100 psi(38 bbl pumped)-continue pumping new mud,chase old mud out&POOH to inspect BHA. 08:45 11:15 2.50 8,780 68 PROD4 DRILL TRIP T POOH-new mud in system.CT at surface-Circulate 1.2 bpm to check pressure-4160 psi. 11:15 14:00 2.75 68 0 PROD4 DRILL PULD T Break off BHA-check upper CT connector and ball valves. Lower ball valve was 1/2 closed. Undeploy BHA to replace ball valves. 14:00 14:30 0.50 0 0 PROD4 DRILL SVRG P Injector maintainence. 14:30 15:30 1.00 0 68 PROD4 DRILL PULD T Deploy BHA,Surface test,Tag stripper check pressures 15:30 17:15 1.75 68 8,350 PROD4 DRILL TRIP T Circ 1.3 bpm=3000 psi, RIH with EDC open pumping .45 bpm. 17:15 17:27 0.20 8,350 8,376 PROD4 DRILL DLOG T Gamma tie in for a+6'correction Close EDC, RIH to drill 17:27 17:57 0.50 8,376 9,599 PROD4 DRILL TRIP T Trip in well to Drill,good pass through window 17:57 19:33 1.60 9,600 9,760 PROD4 DRILL DRLG P 9599'Drill Ahead 1.48 BPM @ 3707 PSI FS RIW=9.4K BHP=4150 Page 25 of 33 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 19:33 20:48 1.25 9,760 9,760 PROD4 DRILL WPRT P Wiper trip to window PUW=33K 1.48 BPM@ 3707 FS BHP=4107 20:48 22:18 1.50 9,760 9,910 PROD4 DRILL DRLG P 9760'Drill Ahead 1.50 BPM @ 3700 PSI FS BHP=4102 22:18 23:31 1.22 9,910 9,910 PROD4 DRILL WPRT P 9910 Wipe to window PUW=32K Good clean wiper out and in 23:31 23:59 0.48 9,910 9,960 PROD4 DRILL DRLG P 9910, Drill Ahead 1.5 BPM @ 3650 PSI FS BHP=4105 Midnight Depth 9960 07/11/2010 Drill from 9960 to 10786, Lost 18 BBIs 9.4 to formation 00:00 01:00 1.00 9,960 10,060 PROD4 DRILL DRLG P Drilling ahead 1.5 BPM @ 3650 PSI FS BHP=4105 01:00 01:33 0.55 10,060 8,825 PROD4 DRILL WPRT P Wipe to window with tie into RA Marker 01:33 01:48 0.25 8,825 8,847 PROD4 DRILL DLOG P 8825, Log RA marker,-1'correction continue wiper trip 01:48 02:18 0.50 8,847 10,060 PROD4 DRILL WPRT P Wipe to bottom Good clean wiper trip, No over pulls or setdowns 02:18 03:51 1.55 10,060 10,210 PROD4 DRILL DRLG P 10060', Drill ahead 1.5 BPM @ 3675 PSI FS BHP=4130 03:51 05:15 1.40 10,210 10,210 PROD4 DRILL WPRT P 10210',wipe to window PUW=33k, BHP=4181 Clean wiper in and out 05:15 07:15 2.00 10,210 10,360 PROD4 DRILL DRLG P 10210', Drill ahead 1.5 BPM @ 3700PSI FS RIW=12K BHP=4146 07:15 08:45 1.50 10,360 10,360 PROD4 DRILL WPRT P Wiper trip-31K,clean all the way- slight drag from 9197-9107'. 08:45 11:15 2.50 10,360 10,510 PROD4 DRILL DRLG P Back on bottom drilling-Start turning up to stay in A-4. 1.46 bpm, 4000psi, BHP 4152, ECD 12, ROP 90,WOB 2.4,CT weight 7K. 11:15 13:45 2.50 10,510 10,510 PROD4 DRILL WPRT P Wiper trip-35K off bottom.Clean wiper-tie in(-1 ft correction) 13:45 16:15 2.50 10,510 10,620 PROD4 DRILL DRLG P Back on bottom drilling-1.45 bpm, 3800psi, BHP 4180, ECD 12.2, ROP 60,WOB 2.4K,Ct weight 5K. 16:15 17:00 0.75 10,620 10,660 PROD4 DRILL DRLG P Started stacking weight-BHA wiper -36K off bottom.Continue drilling ahead-1.45 bpm,4000 psi, BHP 4230psi, ECD 12.2, ROP 60,WOB 2.4,CT weight 2K. 17:00 19:12 2.20 10,660 10,660 PROD4 DRILL WPRT P Wiper trip to window PUW=36K, BHP=4191 Good wiper.lost surface weight in Shales from 10475 to bottom. RBIH 19:12 21:42 2.50 10,660 10,784 PROD4 DRILL DRLG P 10660', Drill ahead 1.48 BPM @ 3700PSI FS BHP=4234 WOB=1.9K RIW=-3K Page 26 of 33 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 21:42 22:27 0.75 10,784 10,784 PROD4 DRILL DRLG P 10784'Stack out Can't get restarted drilling Pull 48K to get moving up, Pump Lo Ho Sweep Clean up to 10450 above shaley area that took most of surface weight. RBIH to drill 22:27 22:39 0.20 10,784 10,786 PROD4 DRILL DRLG P 10784 Attempt to drill ahead Surface weight-10 tag bottom @ multiple speeds Call full wiper 22:39 23:33 0.90 10,786 8,825 PROD4 DRILL WPRT P Wipe to window PUW=37K Pump to-hi sweeps coming off bottom 23:33 23:39 0.10 8,825 8,844 PROD4 DRILL DLOG P Log RA marker+1.5'due to overpull and working pipe 23:39 00:00 0.35 8,844 9,615 PROD4 DRILL WPRT P RBIH to Drill 9615'Midnight Depth 07/12/2010 TD Lateral @ 10915, LAy in beaded pill, Kill well, M/U and run liner to 10303. POOH with liner 00:00 00:36 0.60 9,615 10,786 PROD4 DRILL WPRT P On Wiper trip back to bottom. Shales from 10475 Taking away surface weight. Into-8 to-10 getting on bottom to drill 00:36 02:00 1.40 10,786 10,915 PROD4 DRILL DRLG P 10787,took a few tries to get drilling ahead Got it going 15FPM to bottom then keep feeding pipe stay above 100 FPH got surface weight back 1.5 BPM @ 3986 PSI FS, WOB=1.6K RIW=3K BHP=4284 02:00 02:24 0.40 10,915 10,915 PROD4 DRILL WPRT P Wipe footage just drilled while Lo-Hi going down coil PUW=34k Dragging a little heavy 3 to 4 K PUH to 10640 RIH to sweep from bottom 02:24 03:54 1.50 10,915 8,825 PROD4 DRILL WPRT P Lo Hi at nozzle,sweeping off bottom, PUW36, Dragging weight 36-38 03:54 04:00 0.10 8,825 8,844 PROD4 DRILL DLOG P Log RA tie in+1, RIH to lay in liner running pill 04:00 05:15 1.25 8,844 10,915 PROD4 DRILL WPRT P Wipe to bottom to lay in beaded liner pill 05:15 06:15 1.00 10,915 7,800 PROD4 DRILL TRIP P Trip out of well laying in Beaded Pill PUW=38 Corrected TD=10915 06:15 08:30 2.25 7,800 68 PROD4 DRILL TRIP P POOH pumping KWF -Stop @ 7100 to flag pipe. KWF&CT @ surface. 08:30 09:00 0.50 68 0 PROD4 DRILL SFTY P No flow check&safety meeting. 09:00 09:30 0.50 0 0 PROD4 DRILL PULD P Lay down BHA-Get liner running tools ready. Inspect&service injector. 09:30 13:00 3.50 0 1,473 COMPZ CASING PUTB P Start P/U liner.44 joints in total. Page 27 of 33 Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T Comment 13:00 15:30 2.50 1,473 10,287 COMPZ CASING TRIP P RIH pumping.3bpm. EDC closed. 8572'-Correct depth +5.7 ft. Weight check 29K.Smooth through the window. WOB started increasing as the EOP went through window.Starting to push from 10,210'. 15:30 16:00 0.50 10,287 10,300 COMPZ CASING TRIP T Stacking out, P/U weight 48K @ surface-5K WOB.Worked it down to 10,300'. P/U and dragging from 48K-57K.Worked it 3 more times with no success.Weight back to normal @ 9600' 16:00 18:00 2.00 10,300 1,478 COMPZ CASING TRIP T POOH pumping KWF. 18:00 22:00 4.00 1,478 0 COMPZ CASING PULL T Tag up and space out,Close EDC and hold PJSM LID BHA#26 L/D Liner 22:00 23:30 1.50 0 0 COMPZ CASING CIRC P Roll KWF out of coil and stack, Flush stack. Pull checks out of quick connect,Change packoffs, Test inner reel valve and pack offs 23:30 00:00 0.50 0 0 COMPZ CASING BOPE P Start Full BOPE Test Test witness waived by Chuck Sheeve 07/13/2010 Test BOPE,repair injector,pump slack and cut coiled tubing for pipe life management 00:00 06:00 6.00 0 0 COMPZ CASING BOPE P BOPE Test,Test witness waived by Chuck Sheeve,AOGCC. Procedure steps 1 -through 9 completed.All good.250&3500 psi. 06:00 09:00 3.00 0 0 COMPZ CASING BOPE P BOP test Completed 250 low-3500 high. Function tested alarms, drawdown test&check Koomey pressures. 09:00 10:30 1.50 0 0 COMPZ CASING SLPC P Set up to pump slack back into CT prior to injector repairs.Calibrate Micro Motions with fresh water. Pump slack, Blow down coil. 10:30 12:00 1.50 0 0 COMPZ CASING RGRP T PSJM, Rig up and unstab coil ***Start Nabors rig repair time 12:00 20:00 8.00 0 0 COMPZ CASING RGRP T PJSM,Remove packoff assembly, Skate R&R 20:00 22:00 2.00 0 0 COMPZ CASING RGRP T Install packoff assembly. Stab coil. ***End Nabors rig repair time for today(11.5 hours billable repair time) 22:00 00:00 2.00 0 0 COMPZ CASING SLPC P Cut 1100'of coil for pipe life management 07/14/2010 Completed coil cutting operations,rehead coil. Run cleanout assembly to TD, lay in liner running pill and displace well back to KWF. MU 29 joints slotted liner and RIH. 00:00 02:00 2.00 0 0 COMPZ CASING SLPC P Continue cutting coiled tubing for pipe life management Page 28 of 33 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 02:00 04:30 2.50 0 0 COMPZ CASING SLPC P Install CTC,pull test to 30K, rehead E-line,pressure test. Install new pack-offs and make up lubricator and pressure test. 04:30 04:42 0.20 0 0 COMPZ CASING SFTY T PJSM 04:42 05:12 0.50 0 0 COMPZ CASING PULD T PU clean out BHA,#27 05:12 06:12 1.00 0 0 COMPZ CASING DISP T Displace coil to KWF through open EDC 06:12 07:42 1.50 0 8,340 COMPZ CASING TRIP T RIH 07:42 07:48 0.10 8,340 8,367 COMPZ CASING DLOG T Log Gamma tie in for+9'correction 07:48 07:54 0.10 8,367 8,790 COMPZ CASING TRIP T Trip in to window 07:54 09:54 2.00 8,790 8,790 COMPZ CASING CIRC T Circulate/Recover 11.8 KWF 09:54 10:54 1.00 8,790 10,913 COMPZ CASING WPRT T Close EDC,Trip in well,Clean pass through window Clean trip to bottom. Nothing @ 10300 or 10787 RIW+6 to 8K at bottom 10:54 12:24 1.50 10,913 8,850 COMPZ CASING WPRT T Wipe up hole with tool face down 180 degree PUW=33K 1.41 BPM @ 3215, BHP=4298 Clean trip to window, No overpulls or motorwork 12:24 13:54 1.50 8,850 10,913 COMPZ CASING WPRT T RIH to pump lo hi sweeps 13:54 14:54 1.00 10,913 8,820 COMPZ CASING WPRT T Lo-Hi sweeps coming out on bottom, Chase to window and Tie into RA marker 90L TF PUW=35k 14:54 15:00 0.10 8,820 8,837 COMPZ CASING DLOG T Log RA marker 15:00 16:30 1.50 8,837 10,900 COMPZ CASING WPRT T RIH to lay in beaded liner running pill 16:30 19:00 2.50 10,900 0 COMPZ CASING TRIP T POOH laying in beads, Paint EOP flag @ 9800(9862.34) Paint 7700'EOP Flag(7762.34) continue OOH on 11.8 KWF 19:00 20:00 1.00 0 0 COMPZ CASING PULD T Lay down BHA#27, RU for liner ops 20:00 20:12 0.20 0 0 COMPZ CASING SFTY T PJSM for liner 20:12 22:12 2.00 0 983 COMPZ CASING PUTB T PU 29 joints liner,inteq tools,'Eller profile bullnose" 22:12 00:00 1.80 983 COMPZ CASING RUNL T RIH,0.3 BPM 07/15/2010 Ran liner in AL2 in two sections with an anchored billet at 9344'. RIH with drilling BHA and circulated out KWF,tripped for a failed orienter. 00:00 01:00 1.00 8,683 10,916 COMPZ CASING RUNL T Correct to EOP flag,+12',26K PUW, 14K RIW,-3.5K WOB,continue RIH Page 29 of 33 Time Logs Date From To Dur S Depth E.Death Phase Code Subcode T Comment 01:00 04:00 3.00 10,916 0 COMPZ CASING RUNL T Smooth run in hole with no set downs. Release from liner with 1.5 BPM 4500 CTP. POOH pumping down backside,tie in at RA for-3' correction. Circulate down coil whil continue POOH. Paint flag at 8000 EOP. 04:00 06:00 2.00 0 0 COMPZ CASING PUTB P Lay down liner running BHA, RU for liner ops, PU liner string and anchored billet 06:00 07:24 1.40 0 696 COMPZ CASING PUTB P P/U Coil track,M/U FVS,Scribe, stab on,surface test,strip down injector,Open rams,Tag up, set counters 07:24 09:12 1.80 696 8,665 COMPZ CASING TRIP P Trip in well with AL2 liner second run, BHA#29 09:12 09:54 0.70 8,665 9,981 COMPZ CASING TRIP P Correct+10 at flag,close EDC, PUW=30K 09:54 10:18 0.40 9,981 9,380 COMPZ CASING TRIP P Tag @ 9982 with 3.5K WOB, PUW=31 K Set back down to 9978 w 1.7K WOB, Release Liner POOH 10:18 12:18 2.00 9,380 8,746 COMPZ CASING TRIP P 9380, reset counter to bottom of TS -634',Open EDC Continue Out of well 12:18 13:03 0.75 8,746 0 COMPZ CASING PULD P PJSM,At surface, Flow check Lay down liner running tools BHA #29 13:03 14:18 1.25 0 72 PROD5 DRILL PULD P P/U Drill by BHA#30 Surface test,Tag up and set counters 14:18 15:48 1.50 72 8,350 PROD5 DRILL TRIP P RIH with BHA#30 15:48 16:00 0.20 8,350 8,392 PROD5 DRILL DLOG P Log Gamma tie in for a+8.5' correction, RIH to window to displace KWF 16:00 16:12 0.20 8,392 8,760 PROD5 DRILL TRIP P RIH to above window Circ out KWF 16:12 18:30 2.30 8,760 8,760 PROD5 DRILL CIRC P Circ out KWF trying to maintain 1 for 1,starting at.3 BPM 18:30 21:00 2.50 8,760 0 PROD5 DRILL TRIP T Toolface indicator not working properly. Pulled up hole to 8200'and it appeared to begin working,further checks indicate it is in fact not accurate. POOH. 21:00 22:00 1.00 0 0 PROD5 DRILL PULD T Undeploy BHA#30 22:00 23:30 1.50 0 0 PROD5 DRILL PULD T deploy BHA#31. Had trouble with the jib arm for PDL not returning to center,spent about 20 minutes checking it out then it started working again? Mechanic will trouble shoot during day shift. 23:30 00:00 0.50 0 2,406 PROD5 DRILL TRIP T RIH 07/16/2010 Kicked off aluminum billet at 9344',drilled to 9505'and tripped for RSM,continue drilling AL2-01 lateral 00:00 01:30 1.50 2,406 8,350 PROD5 DRILL TRIP T Continue RIH Page 30 of 33 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 01:30 02:00 0.50 8,350 9,344 PROD5 DRILL TRIP P Tie in,continue RIH through window and open hole 02:00 06:30 4.50 9,344 9,355 PROD5 STK MILL P Tag billet at 9344'and begin time milling. Having some stacking issues requiring PU and restarts 06:30 07:00 0.50 9,355 9,385 PROD5 DRILL DRLG P Start drilling ahead after completing time milling IQ - F� / _ 1.43 BPM @ 3436 PSI FS, BHP vb N � `, =4145 ROP=55 FPH,WOB=1.3K, RIW=9.5K 07:00 07:06 0.10 9,385 9,385 PRODS DRILL WPRT P 9385,Mini wiper up past liner top billit PUW=29K.Good clean pass past billit 07:06 09:06 2.00 9,385 9,505 PRODS DRILL DRLG P Drill Ahead 1.31 BPM @ 3551 PSI FS, BHP =4187 ROP=55 FPH,WOB=1.5K, RIW=8.7K 09:06 11:36 2.50 9,505 0 PRODS DRILL TRIP P 9505', POOH for RSM PUW=30K, BHP=4157 11:36 11:54 0.30 0 0 PRODS DRILL TRIP P Stop close EDC,Tag UpCrew change 11:54 13:09 1.25 0 0 PRODS DRILL PULD P PJSM, Undeploy BHA#31 13:09 14:45 1.60 0 0 PRODS DRILL PULD P Deploy BHA#32 RibSteer with Hugh Bicenter 14:45 16:30 1.75 0 8,350 PRODS DRILL TRIP P RIH with RibSteer, EDC Open 16:30 16:42 0.20 8,350 8,375 PRODS DRILL DLOG P Log tie in for a+8.5,Close EDC PUW=8.5k 16:42 17:18 0.60 8,375 9,505 PRODS DRILL TRIP P Trip In to Drill,start mud swap 17:18 20:48 3.50 9,505 9,655 PRODS DRILL DRLG P Drilling ahead, 1.4 BPM,3300 CTP, 4150 BHP,50 WHP w/WOC. 26K PUW, 10K RIW. 20:48 22:24 1.60 9,655 9,655 PRODS DRILL WPRT P Wiper trip to window 22:24 00:00 1.60 9,655 9,780 PRODS DRILL DRLG P Drilling ahead, 1.4 BPM,3300 CTP, 4170 BHP,50 WHP w/WOC. 26K PUW, 10K RIW. 07/17/2010 Drilled AL2-01 lateral. 00:00 00:30 0.50 9,780 9,805 PRODS DRILL DRLG P Drilling ahead, 1.4 BPM,3300 CTP, 4170 BHP, 50 WHP w/WOC. 00:30 01:36 1.10 .9,805 9,805 PRODS DRILL WPRT P Wiper to window,28K PUW, 10K RIW 01:36 05:06 3.50 9,805 9,955 PRODS DRILL DRLG P Drilling ahead, 1.4 BPM,3300 CTP, 4220 BHP,58 WHP w/WOC. 26K PUW, 10K RIW. 05:06 05:54 0.80 9,955 8,825 PRODS DRILL WPRT P Wiper to window,28K PUW 05:54 06:00 0.10 8,825 8,844 PRODS DRILL DLOG P Tie in,+1'Correction 06:00 06:30 0.50 8,844 9,555 PRODS DRILL WPRT P Continue wiper trip to bottom, Clean wiper up and down No sign of billit Page 31 of 33 Time Logs Date From `To Dur S.Depth E.Depth Phase Code Subcode T Comment 06:30 10:30 4.00 9,555 10,105 PROD5 DRILL DRLG P 9550 Drill Ahead 1.37 BPM @ 3100PSi FS BHP=4159, RIW=8.8K,WOB=1.2K 10:30 11:54 1.40 10,105 10,105 PROD5 DRILL WPRT P Wipe to window PUW=28K 11:54 15:54 4.00 10,105 10,255 PROD5 DRILL DRLG P 10105',drill ahead 1.42 BPM @3525PSI FS RIW=5.7K w/2.3K WOB BHP=4212 15:54 17:30 1.60 10,255 10,255 PROD5 DRILL WPRT P 10255,Wiper to window PUW=32 17:30 19:18 1.80 10,255 10,405 PROD5 DRILL DRLG P 10255', Drill ahead 1.36 BPM @ 3250PSI FS BHP=4200 19:18 20:24 1.10 10,405 8,825 PRODS DRILL WPRT P Wiper to window,30K PUW 20:24 20:30 0.10 8,825 8,860 PRODS DRILL DLOG P Tie in, 20:30 21:18 0.80 8,860 10,405 PRODS DRILL WPRT P RIH, 10 K RIW 21:18 22:48 1.50 10,405 10,555 PRODS DRILL DRLG P Drilling ahead, 1.4 BPM,3500 CTP, 4270 BHP with WOC, 1-3K WOB, 200-300 psi motor work 22:48 00:00 1.20 10,555 8,820 PRODS DRILL WPRT P Wiper to window,30K PUW 07/18/2010 TD well at 10850', Kill well with brine and run liner. Shoe left at 10823, liner top at 8781'. Displace well to seawater 00:00 01:18 1.30 8,820 10,555 PRODS DRILL WPRT P Continue wiper trip. 01:18 02:30 1.20 10,555 10,705 PRODS DRILL DRLG P Drilling ahead, 1.4 BPM,3570 CTP, 4285 BHP with WOC, 1-3K WOB, 200-300 psi motor work 02:30 04:42 2.20 10,705 10,705 PRODS DRILL WPRT P Wiper trip to window,31K PUW 04:42 08:03 3.35 10,705 10,850 PRODS DRILL DRLG P Drilling ahead, 1.4 BPM,3550 CTP, 4295 BHP with WOC, 1-3K WOB, 200-300 psi motor work.hard spot with three stalls @ 10827 08:03 09:51 1.80 10,850 8,825 PRODS DRILL WPRT P Reach TD A 10850,Wipe up hole Lo-Hi sweeps heading down coil Sweeps around corner,wipe to window chasing sweeps 09:51 09:57 0.10 8,825 8,841 PRODS DRILL DLOG P Log RA Marker fora+1'correction 09:57 10:57 1.00 8,841 10,845 PRODS DRILL WPRT P Trip in well to lay in beaded liner pill/ KWF 10:57 14:12 3.25 10,845 0 PRODS DRILL TRIP P POOH laying in beaded liner pill followed by KWF PUW=31K, Paint EOP Flags @ 8600&6600' 14:12 15:15 1.05 0 0 PRODS DRILL PULD P PJSM, Flo Check, Review Pulling BHA from dead well. Pull BHA#32 from well 15:15 15:30 0.25 0 0 COMPZ CASING SFTY P PJSM to P/U liner while flo testing well 15:30 18:48 3.30 0 2,085 COMPZ CASING PUTB P P/U AL2-01 Liner 18:48 20:24 1.60 2,085 8,686 COMPZ CASING RUNL P RIH Page 32 of 33 Time Logs Date From To Dur S. Depth E.Depth Phase ' Code Subcode T Comment 20:24 22:48 2.40 8,686 10,823 COMPZ CASING RUNL P Correct depth at flag, +5.5',30K PUW, 10K RIW,continue RIH. Started stacking weight at 9952'with 50K PUW, multiple stacking the rest of the way in hole with PUW up to 60K and RIW down around zero. Release liner at 10823',liner top at 8781' 22:48 00:00 1.20 10,823 8,750 DEMOB WELLPF DISP P Displace brine with SW, 07/19/2010 POOH after running liner, Freeze Protect from 2100", RDMO 00:00 02:00 2.00 8,750 0 DEMOB WELLPF TRIP P r POOH,lay in diesel from 2100'to _ surface 02:00 03:30 1.50 0 0 DEMOB WELLPF DCSG P Undeploy BHA, 170 WHP. 03:30 06:00 2.50 0 0 DEMOB WHDBO NUND P Set BPV 06:00 09:00 3.00 0 0 DEMOB WHDBO DMOB P Blowdown Reel and Rig,blled off air, R/D PUTZ 09:00 10:00 1.00 0 0 DEMOB WHDBO DMOB P Lift BOP stack off tree, Flange Up Wellhead flange and PT to 4K 0 DEMOB WHDBO DMOB P Rig Release @ 10:00 Page 33 of 33 KU P 1 R-06A ConocoPhillips w I tes Max Angle 8 MD TD WNlbore APW WI I Feld Name Well Status Incl(°) rip(ftKB) Act BOO(ftKB)Inc Alaska. Kor,,,oar 500292133101 KUPARUK RIVER UNIT lINJ 10,940.0 Comment IH2S(ppm) (Date Annotation End Date KB-Grd(ft) Rig Release Date wepern 1R,osA, gtz:at tS PM SSSV TRDP IL I Last WO 11 37.61 5/15/1985 �Smematic-ACwel Annotation Depth(ftKB) I End Date IAnnotat Last Mod...End Date Last Tag: 1 Rev Reason'SIDETRACKS,GLV C/O Imosbor 7/21/2010 ' I Casin.Strin.s - _-_- HANGER,33-- ------- ;I- Casing Description String 0... String ID...Top(ftKB) Set Depth f...Set Depth ND Strin Wt...Strin Strin Top Thrd 9 ption 9 9 ( P (TVD)... g g... g 16 15.062 38.0 110.0 65.00 H-40 WELDED rd I r I Casing Description String 0... String ID Top(ftKB) Sat Depth(f...Set Depth(ND).. String Wt...String...String Top Thrd SURFACE 9 5/8 8.765 37.0 4,658.7 36 00 J-55 BTC CONDUCTOR, Casing Description String 0... String ID..Top(6KB) Set Depth(f...Set Depth(TVD)..;String Wt...String...String Top IBM 38-110 WINDOW"A" 8 6.000 8,820.0 8,832.0 o - -- i.� Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String WI...String...String Top Thrd PRODUCTION 7 6.151 34.8 9,279.2 26.00 J-55 BTC Casing Description String 0... String ID..Top(ftKB) Set Depth(T...Set Depth(TVD)...String Wt...String...String Top Thrd SAFETY VLV, - "A"LINER 23/8 1.995 9,460-0 10,245.1 4.70 L-80 STL 1.908 _ _._... Liner Details GAS LIFT, Top Depth 2,041 - (ND) Top Neel Nomi... Top(ftKB) IBKB) (°I Item Description Comment ID(in) GAS LIFT, 9,460.0 Anchor-billet Anchored Aluminum B/lit 1.000 4,326 Tubing Strings SURFACE, Tubing Description String 0...'String ID...Top 16KBl Set Depth(f...SN Depth(N m D)...String Wt...String.. String Top Th 37-4,659 TUBING -_.I 31/2._.-1__-2992 (...-.331 �-__89321 _ _- ..--. 9.30 J55 EUE8rd GAS L'IF, Completion Details Mme Top Depth GAS LIFT, (TVD) Top Ind Nomi... 6,285 Top(ftKB) (ftKB) (°) Itsm DNrriptbn Comment ID(in) 33.1 HANGER FMC TUBING HANGER w/PUP 3.500 GAS LIFT. -_ ._._... 6,762 ` 1,907.8 SAFETY VLV CAMCO TRDP-1A SSSV 2.812 lit 8,421.1 PBR BAKER PBR 3.000 GAS LIFT,_ 7,198 8,434.9 PACKER BAKER'FHL'PACKER 3.000 8,862.0 BLAST JT 2.992 GAS LIFT, 7,615 8,908.4 LOCATOR BAKER LOCATOR SUB w/5'SEAL 4.000 la` GAS LIFT, _ 8,909.4 PACKER BAKER'FB-1'PACKER 4.000 e.061 8,912.7 SBE BAKER SEAL BORE EXTENSION 4.000 GAS LIFT, .-- 8,923.8 NIPPLE CAMCO'D'NIPPLE NO GO 2.750 8,381 8,931.3 SOS CAMCO SHEAR OUT SUB 2.992 PBR,8,421 Other In Hole (reline retrievable �W plugs,valves,pumps,fish,etc.) PACKER,6,435 TopDepth (TVD) Top Ind GAS LIFT,_ 11". Top(6K8) (ftKB) (°) Description Comment Run Date ID(in) 8,473 ' 8,819 WHIPSTOCK BOT 3.5"monobore WS w/retrieval tang/4-deg ramp 6/14/2010 1.000 removed GAS LIFT,8.545 8,921 CIBP 2.69"CIBP 5/26/2010 0.000 9,145 FISH 1 1/2"GLV Valve Dropped;Could Still be in Tubing String 3/15/1986 Perforations 8 Slots -" ;LL Shot Top(TVD) Btm(TVD) Dens Top(RKB]Btm(RKB) (ftKB) (BKB) Zone Date (sh... Type Comment 9.471 10,244 622/2010 32.0 SLOT Alternating solid/slotted pipe- 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non-slotted ends Ntes:General&Safety ,.,.End Date Annotation "' 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED 7/21/2010 NOTE'View Schematic w/Alaska Schematic9.0(2 pages) y WHIPSTOCK,8.819 WINDOW'A',8.820-8,832 GAS LIFT MUG,8,890 LOCATOR. [ 8,908 L PACKER,8,909 SBE,8,913 f'''. CIBP,8,921-- NIPPLE,8,924 1 Mandrel Details___ SOS,8.931 T Top Depth Top - ...._ Port _.. .. .. (ND) Ind OD Verve Latch Side TRO Run Stn Top(ftKB]. (RKB) (7 Make Model gn) Sere TYpe TIT. (In) (psi) Run Dab Com... 1 2,040.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,317.0 7/21/2010 FISH,9.145 --- : 2 4,326.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.156', 1,333.0 7/21/2010 3 5,630.9 CAMCO KBUG 1 GAS UFT DMY BK 0.000 0.011/10/1987 4 6,285.1 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,319.0 7/21/2010 5 6,762.2 CAMCO KBUG 1 GAS UFT.DMY BK 0.000 0.0 11/10/1987 PRODUCTION, 6 7,198.2 CAMCO KBUG 1 GAS UFT DMY BK 0.000 0.0 6/30/1985 35-9,279 7 7,615.3 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,342.0 7/21/2010 SLOT, t 8 8,060.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 9,471-18.244 9 8,381.1 CAMCO KBUG 1 1/2 PROD OV rdo20 0.188 0.0 7/21/2010 'A'LINER, 9,468-10.245 10 8,473.5 CAMCO hMAG-2 1 1/2 PROD OPEN 0.000 0.0 11/21/1993 TD(1R-O6A), 10,940 I. 2 to S 0 to N O p'- p N m in i0 p b. r O G .- a 0 C , N N O C p . w C W 2 ro 2 m m m O— m a d ° c° m m m - m N v a c `m ° m N v m3� ro^^co -Q N W i� J m b O__ J N N W N tmD< 4.M� mm `t< C N M L GG 03 5_ O QNQ^QNKIJ < J <NQ ca. aNm` J m m m C 0; N M 1 as V lh pip t @ 0 0 . v ` — 0 N —° -2/o c $ o m o— g m• r- c_` - ;n 4 4 2 N o O _ N c0 y $ C < m o, m x2 m2 CJw a�n ,,,6-2 6 � ". b om 0 w r m '` 0Z@ i � p p Y r N m m. 1gcl 0 d' / E4 Eoi �'J= E U a U� b L+. 0 m`m w 0 E 'o N N ^ N g m m N m y &N N 0 �N N N A A A U 07 m M m m A 6 i W ,, . / _ ___ , _, „............„....., .. .. . ... 1 1 -,mi .. , , ------ ...... ■i 1110 Illil • 03 I N -:\ i p 1 III p Ifl CC I m 3 c 141 V p m a 0 p N °2.wm 00 16 _a U Ea, m /�1 N B Y CO /- QmmOpi v w ro EN°m r S U.w m A N N m p KU P 1 R-06A ConocoPhillips IKB-Grd(ft) Rig Release Dab 37 61 5/15/1985 Sct948880.1180,80, I HANGER.33 -- - CONDUCTOR, , I 38-110 SAFETY VLV, - _ 1,908 GAS LIFT, 2,041 GAS LIFT, 4,326 SURFACE,. 37-4,859 GAS LIFT, 5,831 O GAS LIFT, 6,285 OW GAS 6,,62 .'. GAS LIFT, 7,198 GAS LIFT, 7,615 GAS LIFT, 8,061 111t GAS LIFT, jr- 8,381 ilt PBR,8,421 . '1 PACKER,8,435 GAS LIFT, Oil 8,473 GAS LIFT, 8,545 I k J WHIPSTOCK, 8,819 WINDOW-A', e 8,820-8,832 8' GAS LIFT MMG,8,890 LOCATOR,_ 6.908 ^,..,- PACKER.8,909-. -..- ' S86,8,913 lir CIBP,8,921- NIPPLE,8,924 ,IL Mandrel Details SOS,8,931 : Top Depth Top (TVD) Incl OD Valve Latch Size TRO Run Stn Top jfKB) (HKB) (°) Make Model (in) Sery Type Type (in (psi) Run Date Can... 11 8,544.5 CAMCO MMG-2 1 1/2 PROD DMY F/K 0.000 0.0 5/21/2010 FISH,9,145 ik ® 8,890.3 CAMCO MMG-2 1 1/2 PROD OPEN I 0.000 0.0 5/21/2010 PRODUCTION, 35-9,279 N SLOT, 9,471-10,214 'A"LINER, 960.10,245 1 ' TO OR-08A), 10,910 W' AO gldhl CO V C �� L ca 0 �C a. RS_ w t c o Q H A `r Q. c cn .— = stn LI O = > U O > a M 1 TT •- 4-11 0 0 N = o . . 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CD m a) m m w co m m m m a) m m rn 0 0i m m am 0 0 0 0 0 0 00 0 0 0 0 O {Y p ,2 = m m m O ct. 6 0 7 Cn N N. a j .- CO illibea0 40 0 O O N C6 C7 O En C a Q O U 0 Z co o 0 O o H F m N N N N N N N N N N N N N N N N N N N W co• 5 5 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 0_ N CO V N- O O) m N V CD CD M N m O) N N N 0 ■ C CO N O N O) CO 0 n n 0 N 0 O) DT CD CO Cr) CD C) m 0 m C n m m V V N m N V m O) N 4 a M O 4 ( (D v ij SN O) n V co O) n CD N C) M C) C) C C) N 'C N N O O O O O O O O O O O O O m m m m m m CO m m CO m m m m m O co- m� � ` j ■ gg Pl\ R Elc\I\ SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Von Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1R-06A ConocoPhillips Alaska, Inc. Permit No: 210-056 Surface Location: 272' FNL, 222' FEL, Sec. 19, T12N, R10E, UM Bottomhole Location: 456' FNL, 2419' FWL, Sec. 30, T12N, R10E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. S' cerely, Daniel T. Seamount, Jr. Chair 71-c, DATED this ( day of May, 2010. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 6 2010 PERMIT TO DRILL Jaska Oil&Gas Caw CaongsSian 20 AAC 25.005 Anctitirge la.Type of Work: • 1 b.Proposed Well Class: Development-Oil ❑ Service-Winj 0 - Single Zone 1511• lc.Specify if well is proposed for: Drill ❑ Re-drill El Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 1 R-06A - 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 11700' ' TVD: 6574' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:272'FNL,222'FEL,Sec. 19,T12N,R10E,UM • ADL 25635,25640 Kuparuk River Oil Pool- Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1031'FSL, 1073'FWL,Sec. 19,T12N, R10E,UM 2568,2571 6/1/2010 Total Depth: 9.Acres in Property: 14.Distance to 456'FNL,2419'FWL,Sec.30,T12N,R10E, UM 2560 Nearest Property: 18550' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: ' 84 feet 15.Distance to Nearest Well Open Surface:x- 539470 . y- 5990930• Zone- 4 GL Elevation above MSL: 41 feet to Same Pool: 1G-08,870' 16.Deviated wells: Kickoff depth: 8819 • ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 100° deg Downhole:3115 psig • • Surface:2545 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 2350' 9350' 6644' 11700' 6574' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 9303' 6998' 9188' 6890' 9145' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 215 sx CS II 110' 110' Surface 4575' 9.625" 1390 sx PF E,425 sx PF C 4659' 3694' Intermediate Production 9194' 7" 510 sx Class G,250 sx PF C 9278' 6975' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 8582'-8588',8692'-8742',8860'-8867',8976'-8984',8994'-9024',9028'-9038' 6379'-6383',6465-6505',6801'-6607',6700'-6707',6715-6741',6745'-6754' 20.Attachments: Property Plat❑ BOP Sketch El Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 MC 25.050 requirements El 21.Verbal Approval: Commission Representative: Date: CJ f 5Ik0 22. I hereby certify that the foregoing is true and correct. Contact J. G. Eller @ 263-4172 \\Ts. Printed Name V. Cawvey Title Alaska Wells Manager ]v�' Signature &A n a v i' : _ "I'% _� ..euou Phon 265-6306 Date 5I5I l0 uoivkur� � JVCcmission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: 0.47/0Qs,,0 50 9.2/..f.S/d/O0 Date: r7l I 1 ij 0 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales: * 3SQo LSc� Bd P 1 S Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No 0 Otheroz. ei,,. Atin...4ti 67' )H2S measures: Yes [J No ❑ Directional svy req'd: Yes 21 No ❑ • — Ulti.hwit or�r :o^ ��Ge r.Q c,,. ,410 28 M CT- fr�I L / AtIl APPROVED BY THE COMMISSION /7 < DATE: COMMISSIONER For 10-401 ( vised 7/2009) This permit is valid 4f r- n4 fl e eeapproval 0 AAC 25.005(g)) Submit in DypliCate Ill�..dd tttttt tt�E !! ttE.��E.......... „ 7-13.16 , 5/3/,� / S-/Z O KRU 1R-06A, AL1, AL2, AL2-01 —Coiled Tubing Drilling Summary of Operations: Well 1R-06 is a Kuparuk A-sand and C-sand injection well equipped with 31/4"tubing x 7"casing. Four, proposed A-sand CTD laterals will improve sweep efficiency and reserve recovery. Prior to drilling,the existing C-sand perfs in 1R-06 will be squeezed with cement and the A-Sand perfs will be plugged with a . bridge plug. After squeezing the existing C-sand perfs with cement,a mechanical whipstock will be placed in the 31/4" tubing at the first kickoff point. The 1R-06A-sidetrack will make a 2-string exit through the 31/4"tubing and 7" casing at 8819' MD.•It will target the A3 sand south of the existing well with a 2881' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,700' MD with a liner top aluminum billet at 9350' MD. The 1R-06AL1 lateral will kick off from the aluminum billet at 9350' MD and will target the A4 sand south of the existing well with a 2250' lateral. The hole will be completed with a 23/8" slotted liner to the TD of 11,600' MD with the final liner top located just inside the 3'/2"tubing at 8814' MD. The 1R-06AL2 lateral will make another 2-string exit through the 31/4"tubing and 7"casing at 8791' MD via a second mechanical whipstock placed in the 31/4'tubing. It will target the A3 sand north of the existing well with a 2259' lateral. The hole will be completed with a 23/" slotted liner to the TD of 11,050' MD with a liner top aluminum billet at 9250' MD. The 1R-06AL2-01 lateral will kick off from the aluminum billet at 9250' MD and will target the A4 sand north of the existing well with a 1500' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,750' MD with the final liner top located just inside the 31/4'tubing at 8780' MD. CTD Drill and Complete 1R-06: June 2010 Pre-Rig Work 1. Test packoffs—T&IC. 2. Positive pressure and drawdown tests on master valve& swab valve 3. Load tbg&IA. MIT-IA. MIT-OA. 4. Obtain updated static BHP on A-sand& C-Sand 5. Permanently lock out the SCSSV at 1908' MD 6. Set 3'/2"CIBP at 8920' MD to plug off A-sand perfs 7. Shoot squeeze perfs thru the 31/4"tubing and 7"casing at 8791' & 8819' ELM 8. Lay in cement on top of CIBP isolating A-sand. Squeeze the C-sand perfs with cement. 9. RU slickline. Tag cement top. Pressure test cement squeeze. 10. Drill out cement from the 31/4"tubing to 8920' using special clearance bi-center bit 11. Run whipstock dummy 12. Run slimhole CBL to evaluate C-sand squeeze 13. Prep site for Nabors CDR2-AC. Page 2 of 5 k'✓t I G I N IA t May 5,2010, FINAL KRU 1R-06A, AL1, AL2, AL2-01 — Coiled Tubing Drilling Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 1R-06A Lateral(A3 sand, south) 01,4,54,1 $&I`1'fri° a. Mill 2.80"2-string window with high-side orientation at 8819' MD. b. Drill 2.70"x 3"bi-center lateral to TD of 11,700' MD. • 9 c. Run 2%" slotted liner with an aluminum liner-top billet from TD up to 9350' a i0-056 3. 1 R-06AL 1 Lateral (A4 sand, south) a. Kick off of the aluminum billet at 9350' MD b. Drill 2.70"x 3"bi-center lateral to TD of 11,600' MD. c. Run 2%"slotted liner from TD up to 8814' MD,up inside the 7"casing 4. 1 R-06AL2 Lateral(A3 sand,north) a. Set 3Y2"monobore whipstock in 3'/2"tubing at 8791' MD with high-side orientation. b. Mill 2.80"2-string window with high-side orientation at 8791' MD. c. Drill 2.70"x 3"bi-center lateral to TD of 11,050' MD. d. Run 2%" slotted liner with an aluminum liner-top billet from TD up to 9250' 5. 1 R-06AL2-01 Lateral (A4 sand,north) a. Kick off of the aluminum billet at 9250' MD b. Drill 2.70"x 3"bi-center lateral to TD of 10,750' MD. c. Run 2%"slotted liner from TD up to 8780' MD,up inside the 3Y2"tubing 6. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Obtain static BHP 2. Run GLVs 3. Flow back well to the system for clean up prior to putting on injection 4. Conduct MIT-IA 5. Put well on injection Mud Program: • Will use chloride-based Biozan brine or used drilling mud(8.6 ppg)for milling operations, and chloride- based Flo-Pro mud(8.6 ppg)for drilling operations. Because the SCSSV installed in 1R-06 will be locked out,we will have to kill the well to deploy 2%" slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • • Class II drill solids to Grind& Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1R-06A: 2%",4.7#, L-80, ST-L slotted/solid liner from 9350' MD to 11,700' MD • • 1R-06AL1: 2%",4.7#, L-80, ST-L slotted/solid liner from 8814' MD to 11,600' MD • 1R-06AL2: 2%",4.7#, L-80, ST-L slotted/solid liner from 9250' MD to 11,050' MD • 1R-06AL2-01: 2%",4.7#,L-80, ST-L slotted/solid liner from 8780' MD to 10,750' MD Existing Casing/Liner Information Surface: 9%", J-55, 36 ppf Burst 3520 psi; Collapse 2020 psi Production: 7", J-55,26 ppf Burst 4980 psi; Collapse 4320 psi Page 3 of 5 O R I G I N A L May 5,2010, FINAL KRU 1R-06A, AL1, AL2, AL2-01 — Coiled Tubing Drilling Well Control: • Two well bore volumes(-205 bbl)of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite,but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2"coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Maximum potential surface pressure in 1R-06 is 2545 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on the highest recent measured bottom hole pressure in the vicinity,which is 3115 psi at 6490 SSTVD(i.e. 9.3 ppg)from 1R-08 to the north in September 2009. • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans: 1. 1R-06A,plan#4 2. 1R-06AL1, plan#3 3. 1R-06AL2,plan#2 4. 1R-06AL2-01, plan#2 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • • 1R-06 CTD southern laterals(A&AL1): 18,550' to property line,—870' to well 1G-08 " • 1R-06 CTD northern laterals(AL2 &AL2-01): —19,500' to property line,—1050' from well 1R-08 Logging • MWD directional,resistivity, and gamma ray will be run over the entire open hole section. . Reservoir Pressure • The most recent static BHP survey in well 1R-06 was taken April 2010 after several months of shut-in. The measured A-sand reservoir pressure was 2998 psi at 6571' SSTVD,corresponding to 8.7 ppg EMW. We generally expect to encounter similar pressure as the laterals are drilled away from the mother well. Hazards • Lost circulation is usually not particularly troublesome in the A-sand, but it is a possibility in 1R-06 • because of the generally low formation pressure in this area. • Shale stability is a potential problem, particularly in the build section where the A6 sand will be encountered. Will mitigate potential sloughing problems by cutting this interval at less than 70°hole angle,and by holding a constant pressure on the formation throughout drilling operations. • Well 1R-06 has no measured H2S since it is an injection well. Well 1R-05 is located 60' to the right side and 1R-07 is 60' to the left side of the 1R-06 surface location. Well 1R-05 has 40 ppm H2S and 1R-07 has 25 ppm H2S,both being measured on 8/6/09. The maximum H2S level on the pad is 150 ppm from - well 1R-20(8/15/05). All H25 monitoring equipment will be operational. . Page 4 of 5 } GINA L May 5,2010, FINAL KRU 1R-06A, AL1, AL2, AL2-01 —Coiled Tubing Drilling Managed Pressure Drilling Managed pressure drilling(MPD)techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits,and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%"BHA will be accomplished utilizing the 23/8"pipe rams and slip rams. The annular preventer will act as a secondary isolation during deployment and not as a stripper. The SSSV in well 1R-06 will be locked out, so the well will have to be killed prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Expected reservoir pressure is 2933 psi at 8819' MD(6483' SSTVD), or 8.7 ppg EMW. • • Expected annular friction losses while circulating: 882 psi(assuming annular friction of 100 psi/1000 ft due to the 3'/2"tubing) • Planned mud density of 8.6 ppg equates to 2899 psi hydrostatic bottom hole pressure at 6483' SSTVD • • While circulating 8.6 ppg mud,bottom hole circulating pressure is estimated to be 3781 psi or 11.2 ppg EMW without holding any additional surface pressure. This is sufficient to overbalance expected formation pressure in 1R-06. If increased formation pressure is encountered,mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability, but not necessarily for well control. • When circulation is stopped,—880 psi of surface pressure shall have to be applied to maintain the same • borehole pressure as during drilling operations. Quarter-Mile Injection Review The following wells lie within one-quarter mile of the proposed 1R-06 CTD laterals. • 1R-06 motherbore(injector). This well is a selective completion in the Kuparuk A-sand and C-sand. The A-sand perfs will be isolated with a cast iron bridge plug in the tubing tail and the C-sand perfs will - be squeezed with cement. • 1R-06 CTD southern laterals(A&AL 1): • 1R-05 (active producer). This wellbore is located 1335' to the northeast of wells 1R-06A and 1 R- 06AL1. It is a selective completion in the Kuparuk A-sand and C-sand. The Kuparuk sands are isolated by cemented 7"casing. • 1G-08 (plugged& sidetracked producer)—This abandoned wellbore is located—873' to the southeast of wells 1 R-06A and 1 R-06AL 1. The Kuparuk interval was abandoned in June 2004 with a balanced cement plug placed on top of a 7"retainer prior to being sidetracked. • 1R-06 CTD northern laterals(AL2&AL2-01): • 1R-08 (active injector)—This wellbore is located 1055' to the north of wells 1R-06AL2 and 1R- 06AL2-01. It is a selective completion in the Kuparuk A-sand and C-sand. The Kuparuk sands are isolated by cemented 7"casing. Page 5 of 5 t A t May 5,2010, FINAL I Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing 'P. ■ ' Lubricator Riser I- 7 Annular/ Blind/Shear 2"Pipe/Slip(CT) II Pump into Lubricator �J L - IN above BHA rams Choke 1 2-3/8"Pipe/Slip(BHA) Choke Equalize Manifold 2-3/8" Pipe/Slip(BHA) J Lp� Kill �Q 1 • 1 C Blind/Shear 2"Pipe/Slip(CT) Choke 2 i 1-Pr Swab Valves Wing Valves �'� i� � Tree Flow Cross 1 qSurface Safety Valve BOPE: 7-1/16", 5M psi,TOT Choke Line: 2-1/16", 5M psi Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, CO62 Union ORIGINAL 1 1 k $ p '`g \. - , ) > - / S. - m\ - To & «eE AS r • • \ \\ . . ; | \ ` a © } ! E2 . z \ \ !: % f 7 } \/ z/` / m / - - 20 o - I'-: { f( \)\ ) • �\ j �- 7! k #! - - )� k\E 8 °° ) E - 7 § j \ A o \\ \ \\ A A \) � ^ ` y ° .i o i . z , 1- 2. ' ' - - � 7- - \IIIII1I I;III I\ \ = a� /I°\� \ . . -- \ IlEl . . � a�. . — -- —–-� 1 Q� b / co- - - - ! 1: „...., k o __I2 _a \ §9 ;} k \ - ` \ f {, ; ; -co f/ \ { %%# ()//®!$| \ �\ - \ )CO F.� \ J\ 2 \i§ E§ / Z. ORIGINAL 10.-- KUP 1R-06 Conoc hi lips -',A Well Attributes Max Angle&MD TD ( Wellbore APW WI [Field Name Well Status Inoi r) MD(flKB) Act Btm(ftKB) 1[�nx�}1nLW 500292133100 _ LKUPARUK RIVER UNIT INJ 60.30 3,100 00 9,303.0 Comment �H2S(ppm) Date Annotation End Date IKB-Grd(ft) Rig Release Date W c 1R- 1 5s AM -- SSSV:TRDP Last WO: 37 61 5/15/1985 .__,_.El.-..a6 9M456Q4.�,t S� "' .._ SdnWjatlo-ACWaI .. Annotation Depth(MOM lend Date Annotation Last Mod By End Date Last Tag-SLM-L 8,986.0_..I 4/22/2010 I Rev Reason:Tag,Pull Plug/Gauges/Leak I Imosbor 4/27/2010 Casing Strings CONDUCTOR, String OD String ID Set Depth Set Depth(TVD) String Wt String 110 _Casing Description (In) (in) Top(ftKB) (ftKB) (KB) (Ibs/ft) Grade String Top Thrd CONDUCTOR 16 15.062 0.0 110.0 110.0 65.00 H-40 WELDED SAFETY VLV, � SURFACE 95/8 8.765 0.0 4,659.0 3,693.3 36.00 J-55 1,909 PRODUCTION 7 6.151 0.0 9,278.0 6,974.8 26.00 J-55 I3ASUFr._ Tubing Strings 2,041 String OD Sh my ID Set Depth Set Depth(TVD) String Wt String Tubing Description (In) ( ) Top(RKB) (flKB) (ftKB) (lb,/ft) Grade String Top Thrd !TUBING 312 2 si921 0.0 8,932.0 6.662.6 9.30IJ-55 EUE 8RD GAS LIFT, 4,326 Other In Hole lAll Jewelry Tubing Run&Retrievable,Fish,etc.) Top Depth (ND) Top Incl SURFACE, Top(flKB) (flKB) C) Desoripton Comment Run Date ID(In) 1,908 1,850.2 29.48 SAFETY VLV Camco'TRDP-1A'(NOT Locked Out) May hang up 5/21/1995 2.812 toolstring if control line pressure bleeds down. GAS LIFT, 5,631 2,041 1,963.4 33.00 GAS UFT CAMCO/KBUG/1/DMY/BK///Comment STA 1 11/9/1987 2.875 4,326 3,4494 43.26 GAS UFT CAMCO/KBUG/1/DMY/BK/ll Comment STA 2 11/10/1987 2.875 GAS LIFT. .- 5,631 4,355.8 49.37 GAS UFT CAMCO/KBUG/1/DMY/BK///Comment STA3 11/10/1987 2.875 6,285 6,285 4,787.5 48.27 GAS UFT CAMCO/KBUG/1/DMY/BK///Comment STA 5 6/30/1985 2.875 6,762 5,103.8 48.32 GAS LIFT ''CAMCO/KBUG/1/DMY/BK///Comment STA 5 11/10/1987 2.875 GAS LIFT, it 6,762 7,198 5,396.3 47.03 GAS LIFT CAMCO/KBUG/1/DMY/BK///Comment STA 6 6/30/1985 2.875 7,615 5,683.6 46.05 GAS LIFT CAMCO/KBUG/1/DMY/BK///Comment STA 7 11/10/1987 2.875 GAS LIFT,__ -f: 8,061 5,995.8 44.95 GAS LIFT CAMCO/KBUG/1/DMY/BK///Comment STA 8 11/10/1987 2.875 7,198 - 8,381 6,225.8 42.60 GAS LIFT CAMCO/MMG-2/1.5/DMY/RK///Comment STA 9 11/10/1987 2.922 y d, 8,421 6,255.8 41.30 PBR Baker PBR 6/30/1985 3.000 GAS LIFT, -. _-- 7,615 8,435 6,266.1 41.09 PACKER Baker'FHL'PACKER 6/30/1985 3.000 8,473 6,294.6 40.50 PRODUCTION CAMCO/MMG-2/1.5/DMY/RW//Comment STA 10 11/21/1993 2.992 8,544 6,349.1 39.40 PRODUCTION CAMCO/MG-2/1.5/DMY/RK///Comment STA 11 11/21/1993 2.992 GAS LIFT, 8,061 -- _ 8,890 6,626.0 33.19 PRODUCTION CAMCO/MMG-2/1.5/DMY/RK/.25//Comment STA 12 4/21/2002 2.992 8,909 6,643.9 32.57 PACKER Baker'FB-1'PACKER 6/30/1985 4.000 8,924 6,656.0 31.85 NIPPLE Camco'0'Nipple NO GO 6/30/1985 2.750 GAS LIFT, 8,381 8,931 6,661.7 31.51 SOS ',Camco 6/30/1985 2.992 8,932 6,662.6 31.46 TTL 6/30/1985 2.992 PBR,8,421 9,145 6,852.0 22.94 FISH 1 1/2"GLV Valve Dropped;Could Still be in Tubing String 3/15/1986 Perforations&Slots Shot PACKER,8,435 Top(1VD)I Btm(TVID Dens Top(ftKB) Blur(11KB) (flKB) (ttKB) Zone Date (sh... Type Comment 8,582 8,588 6,378.5 6,383.1 C4,1R-06 6/30/1985 12.0 IPERF 5.5"HJ II Csg Gun;120 deg phase PRODUCTION, 8,692 8,742 6,465.0 6,505.0 C-1,UNIT B, 6/30/1985 12.0 IPERF 5.5"HJ II Csg Gun:120 deg phase 8,473 1R-06 8,860 8,867 6,601.4 6,607.1 UNIT B,1R-06 6/30/1985 12.0 IPERF 5.5"HJ II Csg Gun;120 deg phase PRODUCTION, ' 8,976 8,984 6.699.6 6,706.6 A4,1R-06 6/30/1985 4.0 IPERF 4"HJ II Csg Gun'90 deg.ph e'er 8,994 9,024 6,715.3 6,741.2 A-3,1R-06 6/30/1985 4.O'IPERF 4"HJ II Csg Gun'90 deg.ph _ 9.028 9.038 6.744.8 6,853 9 A3,1R-06 6/30/7985 4.0 IPERF 4"NJ II Csg Gun'90 deg.ph IPERF, I 8,582.8,588 Notes:General&Safety a ,..;a, _ _, 1"-ns f.;, End Date Annotation 1 4/23/2010 NOTE:Suspect Tubing leak between 8572'&8868' IPERF, -- 8,692-8,742 6.880-8.867 PRODUCTION, .. 8,890 .y,. I PACKER,8,909 NIPPLE,8,924 SOS,8,931 f [1 TTL,8,932- IPERF, _.. 8,976.8,984 IPERF, . 8,994-9,024 __ 9,028-9,03RF8 Se.o FISH,9,145 PRODUCTION, 9,278 TD.9.303 _ _ ORIGINAL ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1R Pad 1R-06 1R-06A Plan: 1 R-06A_wp04 Standard Planning Report 30 April, 2010 BAKER HUGHES ORIGINAL y,,- ConocoPhillips Fril ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 R-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 1 R-06 @ 84.00ft(1 R-06) • Site: Kuparuk 1R Pad North Reference: True Well: 1 R-06 Survey Calculation Method: Minimum Curvature Wellbore: 1 R-06A Design: 1 R-06A_wp04 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution)• System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1R Pad Site Position: Northing: 5,991,050.01 ft Latitude: 70°23'11.370 N From: Map Easting: 539,829.93ft Longitude: 149°40'33.803 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.31 ° Well 1 R-06 Well Position +N/-S 0.00 ft Northing: 5,990,930.21 ft • Latitude: 70°23'10.210 N +E/-W 0.00 ft Easting: 539,469.74 ft • Longitude: 149°40'44.368 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 1R-06A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 7/1/2010 17.20 79.85 57,390 Design 1 R-06A_wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,800.00 Vertical Section: Depth From(TVD) +WS +E/-W Direction (ft) (ft) (ft) r) 0.00 0.00 0.00 156.00 4/30/2010 11:44:56AM Page 2 COMPASS 2003.16 Build 69 ORIGINAL ' ConocoPhillips red aV ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 R-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 R-06 @ 84.00ft(1 R-06) Site: Kuparuk 1R Pad North Reference: True Well: 1R-06 Survey Calculation Method: Minimum Curvature Wellbore: 1 R-06A Design: 1 R-06A_wp04 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (1100ft) (°/100ft) (°/100ft) (°) Target 8,800.00 35.67 231.88 6,467.67 -3,969.24 -3,516.90 0.00 0.00 0.00 0.00 8,819.00 35.11 231.93 6,483.16 -3,976.02 -3,525.56 2.95 -2.95 0.26 177.06 8,839.00 43.11 231.93 6,498.67 -3,983.80 -3,535.48 40.00 40.00 0.00 0.00 8,913.91 54.35 231.93 6,548.00 -4,018.46 -3,579.74 15.00 15.00 0.00 0.00 9,162.87 86.00 210.46 6,632.24 -4,194.12 -3,727.59 15.00 12.71 -8.62 323.00 9,262.87 84.84 195.46 6,640.27 -4,285.64 -3,766.38 15.00 -1.16 -15.00 265.00 1 9,362.87 90.32 181.48 6,644.51 -4,384.18 -3,781.03 15.00 5.48 -13.98 291.00 9,512.87 99.61 202.07 6,631.41 -4,529.55 -3,811.14 15.00 6.19 13.73 65.00 9,622.87 90.66 188.13 6,621.53 -4,634.98 -3,839.49 15.00 -8.13 -12.67 238.00 9,872.87 90.53 150.63 6,618.83 -4,876.32 -3,794.25 15.00 -0.05 -15.00 270.00 9,942.87 95.43 159.93 6,615.19 -4,939.73 -3,765.05 15.00 7.00 13.29 62.00 10,142.87 90.23 130.34 6,605.09 -5,101.69 -3,652.08 15.00 -2.60 -14.80 261.00 10,342.87 89.35 100.35 6,605.84 -5,186.33 -3,473.39 15.00 -0.44 -14.99 268.30 I 10,492.87 89.40 77.85 6,607.49 -5,183.99 -3,324.38 15.00 0.03 -15.00 270.00 10,592.87 89.94 92.84 6,608.07 -5,175.90 -3,225.00 15.00 0.54 14.99 88.00 10,672.87 100.31 98.91 6,600.93 -5,184.01 -3,145.88 15.00 12.97 7.58 30.00 10,772.87 100.47 114.16 6,582.78 -5,211.91 -3,051.88 15.00 0.16 15.25 88.00 10,922.87 97.77 91.53 6,558.70 -5,244.49 -2,908.46 15.00 -1.80 -15.09 265.00 11,072.87 90.15 112.77 6,548.23 -5,275.91 -2,763.14 15.00 -5.08 14.16 108.80 11,142.87 90.15 123.27 6,548.04 -5,308.74 -2,701.43 15.00 0.00 15.00 90.00 11,392.87 90.12 85.77 6,547.43 -5,370.31 -2,463.71 15.00 -0.01 -15.00 270.00 11,700.00 80.48 131.03 6,573.96 -5,463.48 -2,180.92 15.00 -3.14 14.74 103.40 4/30/2010 11:44:56AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL - ' ConocoPhillips ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1R-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 1 R-06 @ 84.00ft(1 R-06) Site: Kuparuk 1R Pad North Reference: True Well: 1 R-06 Survey Calculation Method: Minimum Curvature Wellbore: 1 R-06A Design: 1 R-06A_wp04 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +rus +EI_W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (11OOft) r) (ft) (ft) 8,800.00 35.67 231.88 6,467.67 -3,969.24 -3,516.90 2,195.62 0.00 0.00 5,986,942.86 535,974.18 TIP 8,819.00 35.11 231.93 6,483.16 -3,976.02 -3,525.56 2,198.30 2.95 177.06 5,986,936.03 535,965.56 KOP 8,839.00 43.11 231.93 6,498.67 -3,983.80 -3,535.48 2,201.37 40.00 0.00 5,986,928.20 535,955.67 End DLS 40 8,900.00 52.26 231.93 6,539.69 -4,011.58 -3,570.96 2,212.32 15.00 0.00 5,986,900.23 535,920.35 8,913.91 54.35 231.93 6,548.00 -4,018.46 -3,579.74 2,215.03 15.00 0.00 5,986,893.31 535,911.61 4 9,000.00 64.97 223.39 6,591.49 -4,068.58 -3,634.30 2,238.63 15.00 -37.00 5,986,842.91 535,857.32 9,100.00 77.80 215.18 6,623.39 -4,141.86 -3,693.92 2,281.33 15.00 -32.66 5,986,769.32 535,798.09 9,162.87 86.00 210.46 6,632.24 -4,194.12 -3,727.59 2,315.37 15.00 -30.02 5,986,716.89 535,764.70 5 9,200.00 85.53 204.90 6,634.99 -4,226.90 -3,744.79 2,338.32 15.00 -95.00 5,986,684.02 535,747.68 9,262.87 84.84 195.46 6,640.27 -4,285.64 -3,766.38 2,383.20 15.00 -94.59 5,986,625.18 535,726.40 6 9,300.00 86.86 190.25 6,642.96 -4,321.73 -3,774.61 2,412.82 15.00 -69.00 5,986,589.05 535,718.36 9,362.87 90.32 181.48 6,644.51 -4,384.18 -3,781.03 2,467.26 15.00 -68.62 5,986,526.57 535,712.27 7 9,400.00 92.67 186.53 6,643.54 -4,421.19 -3,783.62 2,500.02 15.00 65.00 5,986,489.55 535,709.88 9,500.00 98.84 200.28 6,633.47 -4,517.71 -3,806.55 2,578.87 15.00 65.13 5,986,392.92 535,687.46 9,512.87 99.61 202.07 6,631.41 -4,529.55 -3,811.14 2,587.82 15.00 66.52 5,986,381.05 535,682.93 8 9,600.00 92.54 191.00 6,622.17 -4,612.44 -3,835.69 2,653.56 15.00 -122.00 5,986,298.04 535,658.82 9,622.87 90.66 188.13 6,621.53 -4,634.98 -3,839.49 2,672.60 15.00 -123.18 5,986,275.49 535,655.14 9 9,700.00 90.65 176.56 6,620.64 -4,711.91 -3,842.65 2,741.60 15.00 -90.00 5,986,198.55 535,652.39 9,800.00 90.59 161.56 6,619.55 -4,809.81 -3,823.73 2,838.73 15.00 -90.13 5,986,100.76 535,671.82', 9,872.87 90.53 150.63 6,618.83 -4,876.32 -3,794.25 2,911.48 15.00 -90.30 5,986,034.41 535,701.65 1 10 9,900.00 92.44 154.23 6,618.13 -4,900.36 -3,781.70 2,938.55 15.00 62.00 5,986,010.44 535,714.32 9,942.87 95.43 159.93 6,615.19 -4,939.73 -3,765.05 2,981.28 15.00 62.09 5,985,971.17 535,731.18 11 10,000.00 94.03 151.45 6,610.47 -4,991.57 -3,741.63 3,038.17 15.00 -99.00 5,985,919.46 535,754.87 10,100.00 91.40 136.66 6,605.70 -5,072.20 -3,683.15 3,135.61 15.00 -99.70 5,985,839.15 535,813.76 10,142.87 90.23 130.34 6,605.09 -5,101.69 -3,652.08 3,175.19 15.00 -100.41 5,985,809.82 535,844.99 12 10,200.00 89.98 121.77 6,604.99 -5,135.28 -3,605.94 3,224.65 15.00 -91.70 5,985,776.47 535,891.31 10,300.00 89.53 106.78 6,605.42 -5,176.28 -3,515.04 3,299.07 15.00 -91.72 5,985,735.96 535,982.41 10,342.87 89.35 100.35 6,605.84 -5,186.33 -3,473.39 3,325.19 15.00 -91.65 5,985,726.13 536,024.11 13 10,400.00 89.36 91.78 6,606.48 -5,192.36 -3,416.64 3,353.79 15.00 -90.00 5,985,720.40 536,080.89 10,492.87 89.40 77.85 6,607.49 -5,183.99 -3,324.38 3,383.67 15.00 -89.90 5,985,729.25 536,173.09 14 10,500.00 89.44 78.92 6,607.56 -5,182.56 -3,317.40 3,385.20 15.00 88.00 5,985,730.73 536,180.07 10,592.87 89.94 92.84 6,608.07 -5,175.90 -3,225.00 3,416.70 15.00 87.99 5,985,737.87 536,272.421 15 10,600.00 90.87 93.38 6,608.02 -5,176.29 -3,217.88 3,419.95 15.00 30.00 5,985,737.52 536,279.54 10,672.87 100.31 98.91 6,600.93 -5,184.01 -3,145.88 3,456.29 15.00 30.00 5,985,730.18 536,351.57 16 10,700.00 100.43 103.04 6,596.04 -5,189.09 -3,119.68 3,471.58 15.00 88.00 5,985,725.24 536,377.79 10,772.87 100.47 114.16 6,582.78 -5,211.91 -3,051.88 3,520.00 15.00 88.74 5,985,702.78 536,445.71 4/30/2010 11:44:56AM Page 4 COMPASS 2003.16 Build 69 0A ConocoPhillips la kW ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 R-06 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 1 R-06 @ 84.00ft(1 R-06) Site: Kuparuk 1R Pad North Reference: True Well: 1R-06 Survey Calculation Method: Minimum Curvature Wellbore: 1R-06A Design: 1 R-06A_wp04 Planned Survey Measured ND Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +14/-S +E!-p/ Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°llOOft) r) (ft) (ft) 17 10,800.00 100.09 110.04 6,577.94 -5,221.95 -3,027.15 3,539.23 15.00 -95.00 5,985,692.87 536,470.49 10,900.00 98.27 94.96 6,561.89 -5,243.21 -2,931.06 3,597.74 15.00 -95.74 5,985,672.12 536,566.68 10,922.87 97.77 91.53 6,558.70 -5,244.49 -2,908.46 3,608.11 15.00 -98.16 5,985,670.96 536,589.29 18 11,000.00 93.92 102.50 6,550.82 -5,253.87 -2,832.43 3,647.60 15.00 108.80 5,985,661.98 536,665.35 11,072.87 90.15 112.77 6,548.23 -5,275.91 -2,763.14 3,695.91 15.00 109.92 5,985,640.31 536,734.75' 19 11,100.00 90.15 116.84 6,548.16 -5,287.29 -2,738.52 3,716.32 15.00 90.00 5,985,629.06 536,759.43 11,142.87 90.15 123.27 6,548.04 -5,308.74 -2,701.43 3,751.01 15.00 90.01 5,985,607.80 536,796.62 20 11,200.00 90.15 114.70 6,547.89 -5,336.40 -2,651.50 3,796.58 15.00 -90.00 5,985,580.41 536,846.69 11,300.00 90.14 99.70 6,547.64 -5,365.89 -2,556.25 3,862.26 15.00 -90.02 5,985,551.43 536,942.09 11,392.87 90.12 85.77 6,547.43 -5,370.31 -2,463.71 3,903.94 15.00 -90.06 5,985,547.50 537,034.64 21 11,400.00 89.87 86.81 6,547.43 -5,369.84 -2,456.60 3,906.41 15.00 103.40 5,985,548.00 537,041.75 11,500.00 86.44 101.42 6,550.67 -5,376.98 -2,357.19 3,953.36 15.00 103.40 5,985,541.39 537,141.19 11,600.00 83.23 116.14 6,559.72 -5,408.92 -2,263.16 4,020.78 15.00 102.93 5,985,509.95 537,235.37 11,700.00 80.48 131.03 6,573.96 -5,463.48 -2,180.92 4,104.07 15.00 101.59 5,985,455.84 537,317.89 TD 4/30/2010 11:44:56AM Page 5 COMPASS 2003.16 Build 69 n Di nim Al ConocoPhillips Vedas ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 R-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 1R-06 @ 84.00ft(1R-06) Site: Kuparuk 1R Pad North Reference: True Well: 1R-06 Survey Calculation Method: Minimum Curvature Wellbore: 1 R-06A Design: 1 R-06A_wp04 Point 3 0.00 -5,342.59 -3,967.93 5,985,567.28 535,530.45 Point 4 0.00 -5,021.03 -3,685.22 5,985,890.30 535,811.43 1R-06A t6 0.00 0.00 6,552.00 -5,249.44 -2,852.35 5,985,666.31 536,645.41 70°22'18.577 N 149°42'7.814 W -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") l'7 11,700.00 6,573.96 2-3/8" 2-3/8 3 Plan Annotations , Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 8,800.00 6,467.67 -3,969.24 -3,516.90 TIP 8,819.00 6,483.16 -3,976.02 -3,525.56 KOP 8,839.00 6,498.67 -3,983.80 -3,535.48 End DLS 40 8,913.91 6,548.00 -4,018.46 -3,579.74 4 9,162.87 6,632.24 -4,194.12 -3,727.59 5 9,262.87 6,640.27 -4,285.64 -3,766.38 6 9,362.87 6,644.51 -4,384.18 -3,781.03 7 9,512.87 6,631.41 -4,529.55 -3,811.14 8 9,622.87 6,621.53 -4,634.98 -3,839.49 9 9,872.87 6,618.83 -4,876.32 -3,794.25 10 9,942.87 6,615.19 -4,939.73 -3,765.05 11 10,142.87 6,605.09 -5,101.69 -3,652.08 12 10,342.87 6,605.84 -5,186.33 -3,473.39 13 10,492.87 6,607.49 -5,183.99 -3,324.38 14 10,592.87 6,608.07 -5,175.90 -3,225.00 15 10,672.87 6,600.93 -5,184.01 -3,145.88 16 10,772.87 6,582.78 -5,211.91 -3,051.88 17 10,922.87 6,558.70 -5,244.49 -2,908.46 18 11,072.87 6,548.23 -5,275.91 -2,763.14 19 11,142.87 6,548.04 -5,308.74 -2,701.43 20 11,392.87 6,547.43 -5,370.31 -2,463.71 21 11,700.00 6,573.96 -5,463.48 -2,180.92 TD 4/30/2010 11:44::56AM Page 7 COMPASS 2003.16 Build 69 OR U U I N s . l_.. • I lire ° sums . $ . 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BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 5, 2010 Commissioner-State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits permit to drill applications for four lateral sidetracks out of Kuparuk Well 1R-06 (PTD# 185-071) using the coiled tubing drilling rig, Nabors CDR2-AC. Work is scheduled to begin on 1 R-06 in June 2010. The CTD objective is to drill four A-sand lateral sidetracks (1R-06A, 1 R-06AL1, 1R-06AL2, and 1 R-06AL2-01). The original wellbore perforations will be plugged with cement and a bridge plug prior to CTD operations (Sundry application is attached). Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms for 1 R-06A, 1 R-06AL1, 1 R-06AL2, 1 R-06AL2-01 — Proposed &Current Wellbore Schematic — BOP Schematic — Detailed Summary of Operations — Directional Plans — Sundry application for plugging the KRU 1R-06 motherbore If you have any questions or require additional information please contact me at my office 907-263-4172. S cerely, Gary Eller ConocoP ' Alaska Coiled Tubing Drilling Engineer . \?.2. / Ca, 177'4:--'---- ---,..,„ : ''N.,..__ . 0 al 1 CO ILSI P , t- ,,{' -----.1,-,.._ g -.._ ft ! 1- (1) s'N • t )-: 3 ../g (- 1 i--- ,., / r CA 0 t :1 42 / (3) 1 kr) W oa o ■/••■ ‹ = Co) CNI 8 0 Nj CP) C1 0 r e C., v•-• "C"'• 1 2,____;- 3 Li--) t- o-f-- --2-1- ___•'•' ° 1---- co Lc) co 40 . 0 . :;:- --f.:,-- 77' Is•-• 0 0 CO -114a_ CD 2 0 CD 4 00 •n ...-.. N.... ---____•4 < .:. / tO • 0‘ -\p 0 ._, -;• CO r---- -., .. LC) . CO 0) ESOP CA CO CA \R CI ' ':-. ;:.-=.' c.-) ,-- . to F-- . ■ - ;, 03 1-- ID \I • IA, / s C4 oo rev' CO () Ili _ 0)1 1 - .1-- r r--- r-- r 3 . Fr \ CNI 0) . bwpm 'C' ' LO • . A p •• .71- 0 ‘—' ce) 0 kr) v, I 0 '-''. 7) 0 ' CO CA - C) 0 I LC) 0 orir ....1 0 ,-- 0 I 07 I' il"' - • V ' r -I ' T -- 0 0 r d (0 0 - /, C") _ l i it) 0 e- d , VI VI 0814 CX-I in 0 c., 1.15.7_ 6'4-0 o 0 C":1 1 „rir 2 LET .44 1 .i. , a 00 63-T--..' 'r- 0, 0 00 C 1"" "l "i— ( -' -:_-4 Z ig°-) 0, • •1 0....,, 0 -.,_ ' CO tour C\I cp .. cot's,' "1' 0 \-s.,\`' N- 0 r LO 1 in k 9,40' 0 01 CO ""t0i c+0 .71- vt-NFIv- lug. a) .N - o c) g :S._0::::n-__.e.• r4 `'--' CO r,,71, -,4 7r , co co c• 0.) Nwr, -4. . . N. C Co co x=1 el ct -.:\ § ''l . 'l ' \ 4 t— 0 CC e-- -) . a) 4c T.- \1 (/) c. N- . oo 0 :PC' to ,_ eq -4 - ,, 0 c.1 (3) 0 CA \ .. 1 C) \ • in v- , . \8 8 \ 0 co IV" •I'' et... 1 ...., 0 co Q "IL ' 'Il w C2 - kr, " ..t— IA . 2 r.% in 7 p\ •\ cri '4, V TRANSMITTAL LETTER CHECKLIST WELL NAME Je/C. L/ /, O,(aiQ PTD# C Development ✓ Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: / 1./ . ,/', ,f POOL: /<!/..4)Q422 Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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