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Home My WebLink About198-243CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:NSK Wells Integrity Eng CPF2 Subject:10-426 form for 2T-pad SI non-witnessed MIT-IA"s 6-15-25 Date:Monday, June 16, 2025 9:52:34 AM Attachments:image001.png MIT KRU 2T PAD SI TESTS 06-15-25 .xlsx Morning, Please see the attached 10-426 form from the 2T-pad SI non-witnessed MIT-IA’s that was performed on 6-15-25. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .587 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1982430 Type Inj N Tubing 293 2530 2430 2410 Type Test P Packer TVD 2789 BBL Pump 2.6 IA 310 2530 2440 2410 Interval 4 Test psi 1500 BBL Return 2.3 OA n/a n/a n/a n/a Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1982030 Type Inj N Tubing 3 69 79 77 Type Test P Packer TVD 3009 BBL Pump 0.5 IA 280 1810 1750 1735 Interval 4 Test psi 1500 BBL Return 0.4 OA 550 750 725 725 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 2T Pad Non-witnessed Cook/Sheets 06/15/25 Notes: Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:CMIT T x IA plug in hole and open pocket in tubing. Notes: 2T-209 2T-210 Form 10-426 (Revised 01/2017)2025-0615_MIT_KRU_2T-209 9 9 9 9 9 9 999 9 9 9 9 -5HJJ CMIT T x IA 2T-209 Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 1Y-27 50-029-22379-00 n/a Kuparuk River Packer Setting Record Field- Final 8-Sep-20 0 1 2 2B-02 50-029-21154-00 906718091 Kuparuk River Packer Setting Record Field- Final 20-Sep-20 0 1 3 2F-05X 50-029-22730-00 906726469 Kuparuk River Packer Setting Record Field- Final 28-Sep-20 0 1 4 2H-09 50-103-20050-00 n/a Kuparuk River Plug Setting Record Field- Final 6-Sep-20 0 1 5 2M-03 50-103-20160-00 906439276 Kuparuk River Packer Setting Record Field- Final 21-Sep-20 0 1 6 2M-24 50-103-20171-00 906726590 Kuparuk River Leak Detect Log Field- Final 23-Sep-20 0 1 7 2M-24 50-103-20171-00 906726590 Kuparuk River Packer Setting Record Field- Final 23-Sep-20 0 1 8 2T-209 50-103-20281-00 906722868 Kuparuk River Water Flow Log Field & Processed 28-Sep-20 0 1 9 3B-03 50-029-21322-00 906711627 Kuparuk River Leak Detect Log Field- Final 15-Sep-20 0 1 10 3B-03 50-029-21322-00 906711627 Kuparuk River Packer Setting Record Field- Final 16-Sep-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/04/2020 PTD: 1982430 E-Set: 34337 12/07/2020 Abby Bell STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS APR 0 5 2019 1. Operations Abandon Ll Plug Perforations LJ Fracture Stimulate LJ Pull Tubing LJ OperationsshutQ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Convert Prod to Inj_ ❑� 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ❑ Stratigraphic ❑ Service ❑ 198-243 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20281-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025569 KRU 2T-209 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field / Tabasco Oil Pool 11. Present Well Condition Summary: Total Depth measured 4690 feet Plugs measured None feet true vertical 3318 feet Junk measured None feet Effective Depth measured 4555 feet Packer measured 3915 feet true vertical 3250 feet true vertical 2909 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 75' 16" 112' 112' Surface 4045' 9.625" 4082' 3002' Intermediate Production Liner 751' 4.5" 4680' 3313' Perforation depth Measured depth 3929 - 4680' feet True Vertical depth 2917 - 3313' feet Tubing (size, grade, measured and true vertical depth) 4.5 x 3.5" L-80 3927' 2916' Upper Packer: Baker 813-47x38 Torqmstr 3690' 2789' Packers and SSSV (type, measured and true vertical depth) Lower Packer: Baker Model TA' Retrievable 3915' 2909' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 135 43 6590 230 Subsequent to operation: 0 0 2403 1016 1054 14. Attachments (required per 20 AAc 25.070, 25.071, a 25283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-510 Authorized Name: Adam Childs Contact Name: Adam Childs Authorized Title: Staff Petroleum Engineer Contact Email: adam.d.childsrrDcoo.com Authorized Signature: Date: S (Q Contact Phone: (907) 263-4690 Form 10-404 Revised 412017 RBDMS_6✓ APR 0 0 2019 Submit Original Only WSR - Well Service Report Well Service Report Page 1 of 1 Well Job Scope IF CPAI Rep 2T PAD ANNCOMM RICHWINE, BRUCE Date Daily Work Unit Number 4/4/2019 DHD Nehvork # Compam Unit Supervisor 10402725 AES AREND,GRANT Initial & Initial T/I= 1400/560 Final FinalKU T/I= 1400/565 Field: PARUK RIVER UNIT Pressures: 24 hr. (ISW) 2T-209 STATE WITNESSED (MATT HERRERA) MITIA (PASS) @ Summary 2190 PSI STARTTIME OPERATION 06:00 AM Sync computer, travel from KOC to 2T pad. (ISW) 2T-209 STATE WITNESSED (MATT HERRERA) MITIA (PASS) @ 2190 PSI Initial T/I= 1400/560. IA FL @ SF Pressured IA to 2190 psi w/ 2 BBLS of diesel. 06:30 AM SI for 30 min monitor. Initial T/I= 1400/2190 15 min T/I= 1400/2110 (-80 psi) 30 min T/I= 1400/2100 (-10 psi) Bled IA back to 565 psi. 2 BBLS bled back. Final T/I= 1400/565 07:30 AM ITravel from 2T pad to 2G pad. Fluid Type To Well From Well Non- irecoverableT Note http://akapps.conocophillips.netlalaskawelleventquerylworklog.aspx?Wellname=2T%2OPA... 4/5/2019 KUP INJ i, �''' Wall Attribute$ COIIOCOP%11��1(�S TmMName Alaska, Inc. TABASCO NIPPLE WELLNAME 2T-209 WELLBORE 2T-209 z7-ae.xvm+s,+anAM Last Tag VeNCJeslwretic(xOwl Anamown askmiRKBI F Ertl Dab I wow'. I lostis By ...................... Last Tag -RKB(SMART WIRE) J.YU, 0 111/12018 27-209 1C.na,m HAxcER: 282 CONDUCTOR, 3].61120 Twkg; wu4 11 Gn6LIPT', 2.9,09 GA6LE;3.6016 LOGTOR', 3,EBa5 PRR;a�T.o ANCHOR, 3683.0 c.,.m PLG. ow. Mae PAcneR;3,Mut NmPLE 3.e694 PATCH- UPPER PACKER IME): ameo TURING PUNCK 3.M00 TURWG NNCH; 3,a38.0 SPACER PIPE 3.6820 PATCH - LOWER PACMR IMakaas2o PACKFR, 3.9,x3 LOCATOR:A9R6 Mwslm;3.91ad OM a91A xo RusxlrvD:3.me 'NLEG; awes OBSTRUCTION, COL4PM??. 3.S350 suRPAce, 3l a4.M3.,� 12/132010 1 10 LINER: a829.9i,96p,p� Last Rev Reason Anamamn Ene D.b Wellm,e lest Moa By Rev Reason. INSTALL PATCH icongqw Casing Strings CasLq Description On (m) ID (n) Tap (nKBI bet DeplM1 IM(BI set nep,M1 NDL.. VNLen R-. r+raae T.'TM1(aatl CONDUCTOR 16 1506 37.0 1120 1120 62.58 M-00 WELDED Casing Demm"non DOM .Don, rop MKe) eet Depminnel sat .,RTool...mLen(I...crwe Tep Th. SURFACE 9518 8.70 37.5 4.082.1 3,0014 40.00 L-80 BTC Casbg Deaalpfwn OD(in) IDers Topirmte SNDepMryn(BI leas Usas RVDl... WlAon g...6me, Top TM1rttl LINER 4.623 3.55 3,928.9 4,680.0 31313.1 1160 LA0 SLHT Liner Details Top (nrca) TOPIrvDI Otica) iop Nmt rl nem aNominal IDs cam (m) 3,928.9 2,9168 5658 -1 PACKER BAKER SCA Gravel Pack Packer 4.150 3,934.0 196 58.53 EXTENSION 3.548 3.938.8 2,922.2 56.49 SLEEVE BAKER Gravel Pack Sliding Sleeve 4.875 3,9419 2,923.4 56.47 SBE BAKER SEAL BORE 4.750 3,9417 2923,9 56.47 EXTENSION 3.548 3,962.2 2,9352 5641 KOIV BAKER&KOIV VALVE 3.437 4,038.6 2,977.5 56.47 SCREEN BAKERWELD Gravel Pack Screen .548 4,668.1 3,307.1 59.60 O-RING BAKER O-RING Masai lock 2.375 4,669.3 3,307] 59.60 Flapper VLV BAKER FLAPPER VALVE 2875 Tubing Strings TULIng Descripnan et, - Ma... 10 (int TOp /MIB) aet qpM lfl.. SN DepIM1 jNDI 1... WtBIMfl) Braae Top ConneOmn TUBING45" _ 3112 2.99 28.1 3.9202 2912.0 9.30 L-80 EUE-MOD Completion Dehlls Top /Too) Tooled Nwninat TCP IM(BI (nN81 I.Ibm Des Co. ID pnl 28.1 281 0. HANGER FMC TUBING HANGER q.500 31.9 319 0.0 XOReducing CROSSOVER 4.5 x 3.5 2992 511.9 5119 0. NIPPLE CAMCO2875"DS NIPPLE 2,992 -3597 3,663.5 2.774.9 LOCATOR LOCATOR SUB w/ 3.44 FT SPACE OUT 3,000 -R- 366)0 2,7767 5 A6 7B BAKER 80-00 PBR 4.000 3688.0 778)4 59.03 ANCHOR ML TORQUEMA TER PRODUCTIONANCHORSEAL 3.850 3690.1 2788.5 MN PACKER BAKER813-47x38TORQUEMq TERPACKER 4750 3 94 2.884.3 57.10 NIPPLE2.813" CAMC NIPPLE 2.813 3.176 2,910.6 5.68 LOCATOR BAKER 8117170 ATOR I MULESHOE 3240 3,9187 2,9110 56.7 Joule Shoe 1.61 FT FULL MULE HOE(w/ SEALS)BELOW LOCATOR 4,850 Tmemo De ulamm" -ma Me... ID Qn) T. asst 1. DepM (n._ alt DapM (NDI 1... WIIINRI .. Top.memac n TUBING Original 412 600 3,915.3 13,928.0 12,9163 1260 L-80 Completion Details iap(NDI Topincl nominal Ile. Daa TOp (M{B) lex.) (') Co. ID (in) 3,915.3 2,909.3 JO PACKEfl BAKER MODEL'FARETRIEVABLE PACKER 6.000 3,9 r7 9 2.9101 56,67 GUIDE 6.000 3,91.8 2,912.9 5.4 KOIV KNOCKOUT ISOLATION VALVE 4000 3,923.8 2,914.0 5. XO BUSHING CROSSOVER U RING 3. 8 3926.6 2.915.5 56. WLEG WIRELINE RE-ENTRY GUIDE 3.956 Other In Hole (1111i line retrievable plugs, valves, pump$, fish, etc.) Top("") Top (WC) ("KR) li mca 1°) a- Co. Run ode so (I.) 3,878. 2,888.9 57.02PATCH- UPPER PACKER(ME) P PACKER PP 5" DX4. ',w/ 9.TSPACER PIPE, SNAP LATCH CPAL35B93,(DAL= 14.9) 11 18 1630 3,880. 78900 57.1TUT-NU---19/16" PUNCH X 2' TUBINGPUNCH 4 SPF, 0 DEG PHASING. 415 18 2992 $882.0 2,891.1 99 SPACERPIPE -BI -NT 2-1116'P110SPACER PIPE 1111216 1.600 3,686.0 2,893.3 5.85 7U -2'X7 PUNCH TUBING PUNCHd SPF ,ODE PHASING. I 7 2.992 3,892.0 2,896.5 56.90 AT H- LOWER PACKER(ME) P2P PACKER DPP35177, 2725"ODX4 o1' 11/12018 1630 3,965.0 2,936.1 5640 A OBSTRUCTION . COLLAPSE?] POSSIBLE CEME H HAN E N FROM PACKER SQUEEZE, POSSIBLE GRAVEL PACK SCREEN IS DAMAGED, COLLAPSED OR OBSTRUCTED 11/112018 8000 Cement Squeezes mP1TV0) 1iRm.IU sin We) (.8) BUD 1Nq Inns) Des sbn Dom Com 3,6911.0 3915.0 27 .5 2,909.1 Cement Plug 12/23/201 7 Mandrel Inserts a, an se N TO IMtB Tap (ND) p ) MKB) Make Veale lekh pwtsW TRO Run Memel 006n) SemTim Type (a /Pep Rim, un Dam Co. 1 2,9109 23964 CAM O MMG 112 GAS LIFT OMY RK 0.000 00 625/2012 21 JbU961 2,7477 ICAMCO Immu I iir2JUASLIFT JUMY IRK 1 0,0001 0.0 1&712017 Notes: General 8 Safety EM Dam Annomtlon NOTE: View Sc5ema9c w] Alaska Schematic9.0 2R 12 0 1 0 NOTE: Top w Baker Mooei lW FA 75x80 915, muleshm is @39 8 which is 1 X inside the top of pkr 2017 NOTE:CBLfrmn122917$ho nocement,n1Aeb.M35' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg f DATE: Wednesday, April 10, 2019 P.I. Supervisor I e �' 41,7-1,1 Ly' SUBJECT: Mechanical Integrity Tests 666 CONOCOPHILLIPS ALASKA, INC 2T-209 FROM: Matt Herrera KUPARUK RIV U TABS 2T-209 Petroleum Inspector Sre: Inspector Reviewed By: p� P.I. Supry -J �— NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U TABS 2T-209 API Well Number 50-103-20281-00-00 Inspector Name: Matt Herrera Permit Number: 198-243-0 Inspection Date: 4/4/2019 Insp Num: mitMFH190407053125 Rel Insp Num: Packer Depth Well 2T-209 Type Inj W TVD 2792 Tubil PTD 1 1982430 Type Test I sPT (Test psi 1500 IA BBL Pumped: BBL Returned: 2 OA Interval. L _ INITAL " jP/_ P ✓ Notes: MIT -IA per Sundry 318-510 post conversion from producer to injector Pretest Initial IS Min 30 Min 45 Min 60 Min 1400 1400 1400 140 560 2190 2110 - 9100 - Wednesday, April 10, 2019 Page I of 1 • 19824 WELL LOG TRANSMITTAL #904441677 23 8 9 4 To: Alaska Oil and Gas Conservation Comm. June 14, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUN202018 RE: Plug Set Record and Perforation Record: 2T-209 AOGCC Run Date: 11/18/2017 and 11/19/2017 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 2T-209 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20281-00 Plug Set Record and Perforation Record(Field Print) 1 color log 50-103-20281-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. jUN 5 "16Anchorage, Alaska 99518 SL�� Office: 907-275-2605 FRS ANC@halliburton.com Date: 0(Q/ 2.13/60/Y Signed: • • p7-0 / 9e- 2 g3 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday,April 03,2018 9:32 AM To: 'Drake, Steve G' Subject: Well:2T-209 PTD#: 198-243 Sundry#:317-362 Updated Procedure Follow Up Flag: Follow up Flag Status: Completed Steve, Approval is granted for the modification outlined below. Please include this approval with the approved PTD. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer SCANNEV State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepo(d2alaska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it',to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.aov From: Drake,Steve G<Steve.G.Drake@conocophillips.com> Sent:Tuesday,April 03,2018 9:23 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE:Well:2T-209 PTD#: 198-243 Sundry#: 317-362 Updated Procedure Victoria, Slickline tagged higher than anticipated and was not able to uncover my previous tubing punches so that I have access to pump into the IA. I have added a step to this procedure to shoot 2'of tubing punches and perform an injectivity test sq that we can move forward with this conversion and pump cement into the IA. I have included the amended procedure to this email. Please let me know if you have any questions. Below is a snipit of the addition: • • RELAY/EL- Tubing punch and infectivity test (4/3/2018 Amendment) 1. MIRU RELAY/EL and associated support equipment. 2. RIH with 2' tubing punch to tag depth of 3881' MD. (SL tag on 3/1/18 @ 3882' RKB, 4' above 3. Tie into jewelry and correct depth. 4. Tag bottom, pull tension out of wire and pick up 2' to shoot holes from 3878 to 3880' RKB. P 5. Using diesel, perform injectivity test begining with 0.5 bbl/min for 5 minutes and stepping up 6. Report injectivity data on WSR. 7. RDMO. Well ready for CTU cement job. Thanks, Steve Steve Drake CPF2/Alpine Wells Engineer ConocoPhillips Alaska, Inc. steve.g.drakeconocophillips.com Office: (907) 263-4062 Mobile: (907)223-1166 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, February 13, 2018 8:59 AM To: Drake, Steve G<Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL]RE: Well: 2T-209 PTD#: 198-243 Sundry#: 317-362 Updated Procedure Steve, Approval is granted for the changes outlined below for this sundry. Please include this approval with the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp c(D.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservati n Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it o you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Drake, Steve G [ ilto:Stev, a.Drake@conocophillips.com] Sent: Friday, February 02, 2018 8:08 AM 2 • To: Loepp,Victoria T(DOA)<victTaloepp@aIaska Dov> Subject:Well: 2T-209 PTD#: 198-243 Sundry#: 317-362 Victoria, Please see the attached schematic, indicating the current state of the well, as well as an updated procedure with all prior steps marked with a red uuiv. The revision to the original procedure is noted with (2/1/2018 Arrienwinent) as well as an annotation of(continuation of original procedure)where we get back into what was originally submitted. I've attached the entire procedure but for sake of ease, have copy and pasted the revision into the email below. Please let me know if you have any questions or need anything else from me. CTU-Spot cement/squeeze 11/2018 Amendment) 1. MIRU CTU and associated equipment. 2. Contact SLB to supply 4.0 bbls of 15.8 ppg Class G cement. 3. RIH with side jetting nozzle assembly and lightly tag top of sand @ 3890' RKB for depth correction. (Run side jet nozzle on same run to cement if possible. If not,will have to make separate jetting and cementing runs) 4. PUH to position nozzle at tubing punch, 3886'. While pumping with an open choke, reciprocate across tubing punc in attempt to regain some injectivity. After several passes over the punches close choke and pressure up on tubing to test injectivity. 5. =F, injectivity has improved (anywhere from >or=to 0.25 bpm)plan on placing 3 bbls of the 4 bbl cement pill behind pipe. a. IF injectivity has NOT improved, plan on laying 1 bbl in tubing,applying squeeze pressure, laying in another 1 bbl. of cement and apply squeeze pressure,then lay remaining 2 bbls on top. If all 4 bbls are layed in tubing plan on cleaning out cement to a depth of 3786', leaving 100'of cement over the tubing punch. 6. Bring cementers online with 4 bbl. pumpable 15.8 ppg class G cement with a 6 hour working time. Immediately follow cement with 5 bbl.fresh water spacer and diesel. Monitor pressures. 7. Drop ball to contaminate and clean out per Step 5. 8. POOH freeze protecting well. Allow cement 72 hours to cure. DHD-MITT 1. MIRU DHD and associated equipment 2. Perform MIT on tubing to 2500 psi. 3. Record and report results. 4. RDMO Thanks, Steve Drake CPF2/Alpine Wells Engineer ConocoPhillips Alaska, Inc. steve.g.drake(aconocophillips.com Office: (907)263-4062 Mobile: (907) 223-1166 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday,January 31,2018 1:35 PM To: Drake,Steve G<Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL]RE: 2T-209 3 i • Hi Steve, This is a change to an approved sundry. Please include the well name, PTD#and Sundry#in the Subject line. Outline, changes to the approved sundry in red. We may approve the changes by email or we may require a change of approved program sundry.Also,a wellbore schematic with the current status is needed. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp analaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Drake,Steve G [mailto:Steve.G.DrakePconocophillips.com] Sent:Wednesday,January 31,2018 1:02 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Childs,Adam G<Adam.G.Childs@conocophillips.com> Subject:2T-209 Hi Victoria, I wanted to give you an update on 2T-209 and talk about our plan forward. • All of the prep work for coil to pump cement was done as well as the cement job. 1. Drift done 2. Plug set. Sand dumped on plug. 3. Tubing punch done 4. Cement pumped But, after we went to tag cement we found that there was none there. I believe what had happened is this: I had written the procedure up to have a balanced plug in the tubing to keep the heavier weight cement from coming back into the tubing. However,the coil supervisor at the time trapped 1300 psi on the tubing when he left the well,thus making the pressure greater on the tubing than what was pushing back from the IA. Recent MITT's have failed with a liquid leak rate of 0.17 gallons per minute. This is a problem for me as attempting to squeeze even an amount as small as 3 barrels would take over 12 hours with a leak rate so small. That being said, my thoughts for a plan forward is as follows: 1. Send coil out to the well to pump about a barrel of 15.8 class G cement in the tubing so that we have cement across the tubing punch. They will attempt a squeeze on this for about an hour to see what they can push through the tubing punch then leave the well SI for 72 hours for the cement to cure. 2. Return after 72 hours and perform a MITT to 2500 psi. 4 3. If the testpasses, mint cement,clean out sand and pull RBP.• 4. Next,while pumping water down the tubing from surface, utilize eline to verify that there is no leak across the tubing punch as well as look for upflow around the lower packer to ensure we aren't injecting out of zone. If the MITT in step 2 doesn't pass we will have to consider a different path forward based on the leak rate etc. I'll be sure to touch base with you and let you know if the plan deviates from what I've put forth in this email. As always, let me know if you have any questions or concerns and I'll be sure to address them. Thanks! Steve Drake CPF2/Alpine Wells Engineer ConocoPhillips Alaska, Inc. steve.g.drake ,conocophillips.com Office: (907)263-4062 Mobile: (907)223-1166 5 STD / 9c9 — Z4 3 • Loepp, Victoria T (DOA) From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Tuesday, February 13, 2018 9:00 AM To: Loepp,Victoria T (DOA) Subject: RE: [EXTERNAL]RE:Well:2T-209 PTD#: 198-243 Sundry#: 317-362 Updated Procedure Follow Up Flag: Follow up Flag Status: Flagged Thank you From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, February 13, 2018 8:59 AM To: Drake,Steve G<Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL)RE: Well: 2T-209 PTD#: 198-243 Sundry#: 317-362 Updated Procedure Steve, Approval is granted for the changes outlined below for this sundry. Please include this approval with the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer SCANNED MAR 212018 State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeppisalaska.gov From: Drake, Steve G [ nailto:Steve.G.Drake@conocophillips.com] Sent: Friday, February 02,2018 8:08 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:Well: 2T-209 PTD#: 198-243 Sundry#: 317-362 Victoria, Please see the attached schematic, indicating the current state of the well, as well as an updated procedure with all prior steps marked with a red The revision to the original procedure is noted with(2/1/2018 Amendment) as well as an annotation of(continuation of original procedure)where we get back into what was originally submitted. • • I've attached the entire procedure but for sake of ease, have copy and pasted the revision into the email below. Please let me know if you have any questions or need anything else from me. CTU-Spot cement/squeeze(2/1/2018 Amendment) 1. MIRU CTU and associated equipment. 2. Contact SLB to supply 4.0 bbls of 15.8 ppg Class G cement. 3. RIH with side jetting nozzle assembly and lightly tag top of sand @ 3890' RKB for depth correction. (Run side jet nozzle on same run to cement if possible. If not,will have to make separate jetting and cementing runs) 4. PUH to position nozzle at tubing punch, 3886'. While pumping with an open choke, reciprocate across tubing punch in attempt to regain some injectivity. After several passes over the punches close choke and pressure up on tubing to test injectivity. 5. IF, injectivity has improved (anywhere from >or=to 0.25 bpm) plan on placing 3 bbls of the 4 bbl cement pill behind pipe. a. IF injectivity has NOT improved, plan on laying 1 bbl in tubing, applying squeeze pressure, laying in another 1 bbl. of cement and apply squeeze pressure,then lay remaining 2 bbls on top. If all 4 bbls are layed in tubing plan on cleaning out cement to a depth of 3786', leaving 100'of cement over the tubing punch. 6. Bring cementers online with 4 bbl. pumpable 15.8 ppg class G cement with a 6 hour working time. Immediately follow cement with 5 bbl. fresh water spacer and diesel. Monitor pressures. 7. Drop ball to contaminate and clean out per Step 5. 8. POOH freeze protecting well. Allow cement 72 hours to cure. DHD-MITT 1. MIRU DHD and associated equipment 2. Perform MIT on tubing to 2500 psi. 3. Record and report results. 4. RDMO Thanks, Steve Drake CPF2/Alpine Wells Engineer ConocoPhillips Alaska, Inc. steve.g.drake(aconocophillips.corn Office: (907)263-4062 Mobile: (907)223-1166 From: Loepp,Victoria T(DOA) [mailto:victoria.Ioepp@alaska.gov] Sent:Wednesday,January 31,2018 1:35 PM To: Drake,Steve G<Steve.G.Drake@conocophillips.corn> Subject: [EXTERNAL]RE:2T-209 Hi Steve, This is a change to an approved sundry. Please include the well name, PTD#and Sundry#in the Subject line. Outline changes to the approved sundry in red. We may approve the changes by email or we may require a change of approved program sundry.Also, a wellbore schematic with the current status is needed. Thanx, Victoria 2 • • Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppa.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria,Loepp@alaska.gov From: Drake,Steve G [mailto:Steve.G.Drake@conocophillips.corn] Sent:Wednesday,January 31,2018 1:02 PM To:Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Childs,Adam G<Adam.G.Childs@conocophillips.com> Subject:2T-209 Hi Victoria, I wanted to give you an update on 2T-209 and talk about our plan forward. All of the prep work for coil to pump cement was done as well as the cement job. 1. Drift done 2. Plug set. Sand dumped on plug. 3. Tubing punch done 4. Cement pumped But,after we went to tag cement we found that there was none there. I believe what had happened is this: I had written the procedure up to have a balanced plug in the tubing to keep the heavier weight cement from coming back into the tubing. However,the coil supervisor at the time trapped 1300 psi on the tubing when he left the well,thus making the pressure greater on the tubing than what was pushing back from the IA. Recent MITT's have failed with a liquid leak rate of 0.17 gallons per minute. This is a problem for me as attempting to squeeze even an amount as small as 3 barrels would take over 12 hours with a leak rate so small. That being said, my thoughts for a plan forward is as follows: 1. Send coil out to the well to pump about a barrel of 15.8 class G cement in the tubing so that we have cement across the tubing punch. They will attempt a squeeze on this for about an hour to see what they can push through the tubing punch then leave the well SI for 72 hours for the cement to cure. 2. Return after 72 hours and perform a MITT to 2500 psi. 3. If the test passes, mill out cement,clean out sand and pull RBP. 4. Next,while pumping water down the tubing from surface, utilize eline to verify that there is no leak across the tubing punch as well as look for upflow around the lower packer to ensure we aren't injecting out of zone. If the MITT in step 2 doesn't pass we will have to consider a different path forward based on the leak rate etc. I'll be sure to touch base with you and let you know if the plan deviates from what I've put forth in this email. 3 • As always, let me know if you have any questions or concerns and 191 be sure to address them. Thanks! Steve Drake CPF2/Alpine Wells Engineer ConocoPhillips Alaska, Inc. steve.g.drakeaconocophillips.com Office: (907)263-4062 Mobile: (907)223-1166 • 4 /-11----. KUP PROD • 2T-209 ConocoPhillips $ \ Well Attributes Max Angle&MD TD Alaska,Ulu. 1 wellbore APW WI Field Name Wellbore Statue ncl(") MD(ftKB) Act atm(HKB) C:xrDc�PrB�ia / 501032028100 TABASCO PROD 61.05 2,645.18 4,690.0 ,. Comment H2S(ppm) Dare Annotation End Date KBGrd(ft) --Rig Release Date 2T-209.I/1312016 1226,35 PM SSSV:NIPPLE 450 1/11/2009 Last WO: 6/25/2012 36,00 12/22/1998 Vertical schematic(acllal) Annotalbn Depth(ftKB) End Date Annotation Last Mod By End Dare _ _ Last Tag: 4,221.0 8/30/2014 Rev Reason:SET PLUG,SAND&PERF(TBG pproven 1/13/2018 HANGER.282 f) 1"a. PUNCH) Casing Strings Casing Description OD(In) ID(In) Top(ftKB) Set Depth(wKB) Set Depth(TVD)... WULen(L..Grade Top Thread CONDUCTOR 16 15.062 37.0 112.0 112.0 62.58 H-40 WELDED OD(In) ID(in) Top(ftKB) Set Depth(HKB) Set Depth(TVD)...WULen(I...Grade Top Thread SURFACE 95(8 8697 37.5 4,082.1 3,001.4 40.00 1-80 BTC Casing Description OD 1 ( 1Top(ftKB) Depth( ) Depth(TVD)...WULen(I...Grade Top Thread I j LINER 1 n) ID in ftKB Set ftKB Set 4.623 3.548 3,928.9 4,680.0 3,313.1 11.60 L-80 SLHT • Liner Details -',/,'"CONDUCTOR;37.0.112.0 Top(ftKB) Top(TVD)(ftKB) Top Incl(') Hem Des Com Nominal ID 3,928.9 2,916.8 56.58 SC-1 PACKER BAKER SC-1 Gravel Pack Packer 44j 4.750_ Tulin l4812 3,934.0 2,919.6 56.53 EXTENSION 3.548 3,938,8 2,9222 56.49 SLEEVE BAKER Gravel Pack Sliding Sleeve 4.875 3,941.0 2,923.4 56.47 SBE BAKER SEAL BORE 4 750 8941.7 2923.9 56.47 EXTENSION 3548 ds 1111818962.2 2935.2 56.41 KOIV BAKER B-KOIV VALVE 3.437 4,038.6 2.977.5 58.47 SCREEN 'BAKERWELD Gravel Pack Screen 3.548 4,668.1 3.307.1 59.60 0-RING BAKER 0-RING w/seal lock 2.375 4,689,3 8307.7 59.60 Flapper VLV BAKER FLAPPER VALVE 2 875 Tubing Strings GAS LIFT 2.910.9114 Tubing Description String Ma...lb(In) Top(ftKB) Set Depth(ft..Set Depth(TVD)(,..Wt(IbIH) Grade Top Connection TUBING 4.5"x3.5' 312 2.992 28.1 3,920.21 2.912.0 9.30 LEO EUE-MOD Completion Details Nominal ID Top(ROB) Top(TVD,(MB) lop Incl(") Hem Des GAS LIFT.3,808 8 28.1 31.9 28.1 0.00 HANGER FMC TUBING HANGER 4.6609 31.9 0.00 XO Reducing CROSSOVER 4.5x 3.5 Com 2992 511.9 511.9 0.98 NIPPLE CAMCO 2.875"DS NIPPLE (In) P-994 3,663.5 2,774.9 59.53 LOCATOR LOCATOR SUB W/3.44 FT SPACE OUT 3,000 LOCATOR'3,8030 3,667.0 2,776.7' 59.46 PIR BAKER 80-40 PBR 4.000098;3,687.0 f 3,688.0 2.787.4 59.03 ANCHOR ML TOROUEMASTER PRODUCTION ANCHOR SEAL 3.850 rin 3,690.1 2,788.5 58.98 PACKER BAKER 813-07x38 TORQUEMASTER PACKER 4.750 ANCHOR;3,666.0 � r- 3,869.4 2,884.3 57.10 NIPPLE 2.813'CAM000S NIPPLE 28)3 PACKER;3.680.1 Ik'tr..i, 3,917.6 2,910.6 56.68 LOCATOR BAKER BUILT LOCATOR w/MULESHOE 3.240 3,918.4 2,911.0 56,67 Mule Shoe 1.81 FT FULL MULESHOE(WI SEALS)BELOW 4,850 LOCATOR Tubing Description String Ma...ID(In) Top(ftKB) -801 Depth(II..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING Original 4 1/2 6.000 3,915.3 3,928.0 2.916.3 12.60 1-60 ! Completion Details NIPPLE 3668.4 Top(HKBJ Top(150)(ORB) Top Incl)1 HDesem y Nominal ID Com (in) 3,915.3 2,909.3 56.70 PACKER BAKER MODEL TA'RETRIEVABLE PACKER 6,000 ,L. 3,9)7.9 2,910.7' 56.67 GUIDE 6.000PERFP:3,886,0-3,888.0-mow 3,921.8 2,912.9 56.64 KOIV KNOCKOUT VALVE . .,_ 4000 8923.8 2,914.0 56.62 XO BUSHING CROSSOVER BUSHING 3.998 1111 3,926,6 2,915.5 56.60 WLEG WIRELINE RE-ENTRY GUIDE 1958 PACKER•3.915.3, , Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PLUG;3.815.3 : , Top(TVD) Top Incl Top(HKB) (ROB) 1°) Des Com Run Dae ID(In) LOCATOR;3,817.6 3.913.0 2,908.0 56.72 PLUG 2.72'RBP(2.72"P2P(#CPP35148),EO VLV ''�� j (#CPE035021),FILL EXT,BULL PLUG!8.87 OAL)- Cub Sloe;3,816.4 ! DUMP BAILED 6.15 gal SILICA SAND O RBP. (1/18/2017 Cf (11/19/17)-DUMPED 2.05 gal of SILICA SAND Perforations&Slots KOIV:3,921.8 n, Shot XO BUSHING;3.923.9 mammas _ Deny a. Top(ftKB) atm(1108) T op MKS)) Bern 8) (ah (ftKB! Zone Data 1)q Type Com 3.886.0 3,888.0 2,893.3 2,894.4 TABASCO, 11/19/2017 4.0 PERFP 2"x 2'TBG PUNCH(4 WLEG'.3,925.6 2T-209 sof,0`phase) Mandrel Inserts St • �e•., all on Top(T90) N Top IRKS) (ftKB) Make Model OD(in) Sera Type Typeatch Port) TRO Run ISI 1 2,910.9 2,396.4 CAMCO MMG 112 GAS LIFT OMY RK1� 0.000 (pail 0 6R�12 Com M 2 3,609.6 2,747,7 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 8/7/2017 4 I- Notes:General&Safety End Dale Annotation IP12/13/2010 NOTE:Top of Baker Model 194 FA 75x60(:/3915,mules/me is X3928 which is 1 ft inside the top of pkr 12/13/2010 NOTE:View Schematic w/A)aska Schematic9.0 I [SURFACE 37.54,082,1._-..-.* %titin LINER:3,928.9-4,680.0 is Goal Well Work Request Form • Well: 2T-209 Date of Request: 9/21/2017 Request SPOC: I CPF2 PE David/Stephanie x7519,pgr 252 Well Type: Producer Req.Written by: Steve Drake,263-4062 Job Scope:I Ann Comm Shut-In Reason Code: 270 Tubing/Casing/Packer Leaks Well Shut in Date(if SI): 4/14/2012 Prioritization Category: I Opportunity/Rate Adding Budget Category: Kuparuk Base Expense Network: 10404087 Job/SAP Comment: 2T-209 Diagnostics and Repair(PROD) Well Work is not justified via increased production Preventive Maintenance Program Request Aftr,r',Pgn"W'rk Dat; Current Oil Rate(BOPD) 0 Post-Job Oil Rate(BOPD) 150 Risked NOB(BOPD) Enter Rates Last SBHP 1290 psi Last Tag 4,090'md H2S(PPM): 450ppm on Jan 11,2011 SBHP Date 9/16/2016 Tag Date 9/16/2016 Any Fluid Restriction on Well? No SBHP Datum(TVD/SS?) 4083 SS Max Inclin. 61° Max Dogleg 7°/100'and Min.I.D(at/above work) 2.813" Max Incl.Depth 2,645'md Max Dogleg Depth 942'md Well Work Justification &Objectives(and date required if anpronriate): 2T-209 is a Tabasco producer that was drilled in December 1998 and completed in February 1999 with an ESP completion. During a work over of the well to conventional gas lift in June of 2012, EL performed a leak detect log,caliper run as well as CAST-M in pipe inspection mode. A leak was identified at 3770'with significant pipe damage from 3770'to 3860'RKB. A packer was stacked during the RWO to cover the casing damage/leak. More recently,the well has been shut in due to high water cut. A RST log was run on 9/22/16 in preparation to convert the producer to an injector. Data from the log identified upward flow behind pipe at 3800'RKB,indicating a packer leak that was subsequently exiting the known casing leak at 3770'RKB. This procedure will outline the steps needed to place cement in the IA between packers in order to fix the packer leak with the intention of also fixing the casing leak as a secondary objective and convert this well to injection. An RST log will follow the cement/mill out plug portion to confirm isolation of the packer/PC leak. Risk/Job Concerns. No AnnComm issues No surface casing,single annulus,gravel-pack screen liner No SSSV Min ID above work is 2.813"Camco DS Nipple @ 3869'RKB Ste RELAY-Set plug and punch tubing 1. RU RELAY and associated support equipment. 2. Make drift run down to 4668'RKB with dummy composite plug to ensure plug can be pushed to bottom by coil after cement job.DONE 3. Brush setting area for retrievable bridge plug down to packer @ 3915'RKB. Plug will be set just above this lower packer.DONE 4. RIH with retrievable bridge plug,tie into jewelry and set center element @ 3913'RKB. Element will be 2'above packer. Top of plug will be 2.45' higher @ 3910.55'. POOH. DONE 6. Perform MITT to 2500 psi.to test integrity of plug set and tubing. Troubleshoot any failed test. 5. Dump 15'of sand on top of catcher and plug. Top of sand should be approximately 3895'RKB. 6. RIH with tubing punch,tie into jewelry and punch holes from 3886'-3888'RKB w/2"tubing punch at 4SPF. Holes will be 2-3 feet above sand top. POOH. 7. Utilize LRS to perform injectivity test at step increments of 0.5 bpm,1.0 bpm and 1.5 bpm. Include injectivity results in WSR for review and planning of cement job. 8. RDMO. Well ready for CTU. CTU-Cement selective 1. MIRU CTU and associated support equipment. DONE 2. Contact SLB to supply 16.0 bbls of cement for pumping in the IA and a 3 bbl.15.8 ppg weighted pill.DONE IA volume between packers:3915'-3690'=225' => 225'x 0.0613=13.79 bbls cement. This volume will/should fill the entire IA between packers,however,it is only necessary to place cement on top of the packer to stop the leak and above the production casing leak 3770'. 3 bbls.extra cement is to attempt a squeeze through the open PC leak behind the production tubing. 3. RIH and lightly tag top of sand @ 3890'RKB for depth correction.DONE 4. PUH to position nozzle just above tubing punch location,approximately 3885'RKB for 1'above holes. DONE 5. Bring cementers online with 16 bbls.pumpable 15.8 ppg class G cement with a 6 hour working time. Immediately follow cement with 5 bbl. fresh water spacer and diesel. Monitor pressures. Once 13 bbls.are away continue to monitor pressures and attempt to squeeze 2 bbls.into PC leak. If cement won't squeeze,lay in remaining cement in tubing and drop ball to contaminate and clean out down to 100'above tubing punch, 3785'RKB.DONE (Estimated top of cement from laying in 3 bbls in the tubing is 3545'RKB. Optimally we would like to squeeze 2 barrels of cement away and leave 1 bbl in the tubing so that there is cement across the tubing punch location.) ****Procedure continued on next page**** 2T-209 Cement Packer Repair 09-29-17 SOD Rev D.xlsm Printed 2/13/2018 • • Page 2 Well: 2T-209 Date of Request: 9/21/2017 Request SPOC: CPF2 PE David/Stephanie x7519,pgr 252 I Steps Continued (list service type): 7. After cement is placed or contaminate/cleanout is complete, lay in 3 bbls.of 15.8 ppg weighted pill on top of the cement. 8. POOH freeze protecting well. Allow cement 72 hours to cure. 9. RDMO. 'ONE CTU-Spot cement/squeeze ,endment) 1. MIRU CTU and associated equipment. 2. Contact SLB to supply 4.0 bbls of 15.8 ppg Class G cement. 3. RIH with side jetting nozzle assembly and lightly tag top of sand @ 3890'RKB for depth correction. (Run side jet nozzle on same run to cement if possible. If not,will have to make separate jetting and cementing runs) 4. PUH to position nozzle at tubing punch,3886'. While pumping with an open choke,reciprocate across tubing punch in attempt to regain some injectivity. After several passes over the punches close choke and pressure up on tubing to test injectivity. 5. IF,injectivity has improved(anywhere from>or=to 0.25 bpm)pian:,5 1.4 lacings WAS 01 the 4 bbl cement pill behind pipe. a. IF injectivity has NOT improved,plan on laying 1 bbl in tubing,applying squeeze pressure,laying in another 1 bbl.of cement and apply squeeze pressure,then lay remaining 2 bbls on top.If all 4 bbls are layed in tubing plan on cleaning out cement to a depth of 3786', leaving 100'of cement over the tubing punch. 6. Bring cementers online with 4 bbl.pumpable 15.8 ppg class G cement with a 6 hour working time. Immediately follow cement with 5 bbl.fresh water spacer and diesel. Monitor pressures. 7. Drop ball to contaminate and clean out per Step 5. 8. POOH freeze protecting well. Allow cement 72 hours to cure. DHD-MITT 1. MIRU DHD and associated equipment 2. Perform MIT on tubing to 2500 psi. 3. Record and report results. 4. RDMO CTU-Mill out composite plug(continuation of original procedure) 1. MIRU CTU and associated equipment. 2. MU and RIH with 5 bladed junk mill. 3. Mill up any remaining cement in the tubing down to sand plug at 3894.5'. DO NOT clean out sand plug 4.Perform a Combo MIT pressure test on cement squeeze to 2500 psi for 30 min,document test and discuss any failing test results with Steve Drake for a plan forward. 5. If combo MIT passes,pick up slim nozzle as necessary to clean out to EQ sub which is 2.6'down from the top of the RBP(1.62"ID). 6. If time permits pull plug. 7. POOH freeze protecting well. RDMO. SL-Contingency if CTU did NOT pull catcher and plug 1. MIRU SL and associated equipment. 2. RIH and bail sand off plug. 3. RIH and pull plug. 4. RDMO. Turn over to EL for RST log. EL-LDL w/RST 1. MIRU EL and associated equipment. 2. MU and RIH with RST oriented for upflow. 3. 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W Y o re C 0 C7 v Q o ' 'O la Z Y N n 0 stca, M Ocz o M 0 76 ++ a v) tto. = FC v) r Ch U W Z Q > i Q U = E ` F to a C O_ <C O N N M e- N M N M r in Z in co •C '"t V O (t. 0 C G) c6 OCA o_ 3 Q C7v t 0- H a a Q • Pry /98- 24-3 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday, September 20, 2017 1:24 PM To: Drake, Steve G Subject: KRU 2T-209(PTD 198-243,Sundry 317-362)Cement packer repair Steve, The change to the procedure is approved. Please include this approval with the approved sundry. This email is sufficient for the change. Thanx, Victoria Victoria Loepp SCANNED t ] 5 2{'' Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 • Victoria.Loepp a(�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeau@alaska.gov From: Drake,Steve G [mailto:Steve.G.Drake@conocophillips.com] Sent:Wednesday,September 20,2017 12:43 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Angel,Vanessa M<Vanessa.M.Angel@conocophillips.com> Subject: RE: [EXTERNAL]RE: [EXTERNAL]KRU 2T-209(PTD 198-243,Sundry 317-362)Cement packer repair Victoria, Attached is my revised procedure for 21-209. As discussed earlier, plan is to set a RBP with sand cap as we were unable to drift below to be able to push a composite to bottom. Please let me know if you are ok with this or if you require anything else. Thanks, Steve From: Loepp,Victoria T(DOA) [mailto:victoria.Ioepp@alaska.gov] Sent: Monday,September 18,2017 8:01 AM To: Drake,Steve G<Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL]RE: [EXTERNAL]KRU 2T-209(PTD 198-243,Sundry 317-362)Cement packer repair 1 • Please send me a WBS highlighting changes- Thanx, Victoria From: Drake,Steve G [mailto:Steve.G.Drake@conocophillips.com] Sent: Monday,September 18,2017 6:50 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 2T-209(PTD 198-243,Sundry 317-362)Cement packer repair Good Morning Victoria, I'm writing to ask a question about my 21-209 procedure. In the original procedure we had mentioned that we were going to drift for a composite plug down to the bottom of the well so that after all the work was done we could mill it out and push I to bottom. Well,slickline went out to the well and was unable to drift for the plug to the bottom. We got about 130' into the gravel pack below. So, in lieu of the recent information I would like to change my procedure a little bit and was wondering if I needed to inform you. What I would like to do now is set a retrievable bridge plug in the 3.5"tubing and then dump bail about 15'of sand on top of the plug and use that to pump against for the cement I want to place in the IA. So, basically the same thing except instead of milling out cement and then the plug and pushing it to bottom we'll mill out the cement,clean out the sand on top of the plug and then pull the plug to normal up the well. Is this email enough or would you like to see a revised procedure? Thanks, Steve From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.govj Sent: Friday,August 04,2017 11:16 AM To:Drake,Steve G<Steve.G.Drake@conocophillips.com> Subject: (EXTERNAL]KRU 2T-209(PTD 198-243,Sundry 317-362)Cement packer repair Steve, What was the date and results of the latest MIT-IA? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepo alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended 2 General Well Work Request Form Well: 2T-209 Date of Request: 7/21/2017 Request SPOC: CPF2 PE David/Stephanie x7519,pgr 252 Well Type: Producer Req.Written by: Steve Drake,263-4062 Job Scope: Ann Comm Shut-In Reason Code: 270 Tubing/Casing/Packer Leaks Well Shut in Date(if SI): 4/14/2012 Prioritization Category: Opportunity/Rate Adding Budget Category: Kuparuk Base Expense Network: Job/SAP Comment: Well Work is not justified via increased production EPreventive Maintenance Program Request n�nrr Current Oil Rate(BOPD) 0 Post-Job Oil Rate(BOPD) 150 Risked NOB(BOPD) Enter Rates Last SBHP 1290 psi Last Tag 4,090'md H2S(PPM): 450ppm on Jan 11,2011 SBHP Date 9/16/2016 Tag Date 9/16/2016 Any Fluid Restriction on Well? No SBHP Datum(TVD/SS?) 4083 SS Max Inclin. 61° Max Dogleg 7°1100'and Min.I.D(at/above work) 2.813" Max Incl.Depth 2,645'md Max Dogleg Depth 942'md Well Work Justification&Objectives(and date required if appropriate): 2T-209 is a Tabasco producer that was drilled in December 1998 and completed in February 1999 with an ESP completion. During a work over of the well to conventional gas lift in June of 2012,EL performed a leak detect log,caliper run as well as CAST-M in pipe inspection mode. A leak was identified at 3770'with significant pipe damage from 3770'to 3860'RKB. A packer was stacked during the RWO to cover the casing damage/leak. More recently,the well has been shut in due to high water cut. A RST log was run on 9/22/16 in preparation to convert the producer to an injector. Data from the log identified upward flow behind pipe at 3800'RKB,indicating a packer leak that was subsequently exiting the known casing leak at 3770'RKB. This procedure will outline the steps needed to place cement in the IA between packers in order to fix the packer leak with the intention of also fixing the casing leak as a secondary objective and convert this well to injection. An RST log will follow the cement/mill out plug portion to confirm isolation of the packer/PC leak. Risk/Job Concerns: No AnnComm issues No surface casing,single annulus,gravel-pack screen liner No SSSV Min ID above work is 2.813"Camco DS Nipple @ 3869'RKB Step— RELAY-Set plug and punch tubing 1. RU RELAY and associated support equipment. 2. Make drift run down to 4668'RKB with dummy composite plug to ensure plug can be pushed to bottom by coil after cement job. 3. Brush setting area for retrievable bridge plug down to packer @ 3915'RKB. Plug will be set just above this lower packer. 4. RIH with retrievable bridge plug,tie into jewelry and set center element @ 3913'RKB. Element will be 2'above packer. Top of plug will be 2.45' higher @ 3910.55'. POOH. 6. Perform MITT to 2500 psi.to test integrity of plug set and tubing. Troubleshoot any failed test. 5. Set 5'catcher on plug. Top of catcher will be at approximately 3905'RKB. Dump 15'of sand on top of catcher and plug. Top of sand should be approximately 3890'RKB. 6. RIH with tubing punch,tie into jewelry and punch holes from 3886'-3888'RKB w/2"tubing punch at 4SPF. Holes will be 2-3 feet above sand top. POOH. 7. Utilize LRS to perform injectivity test at step increments of 0.5 bpm,1.0 bpm and 1.5 bpm. Include injectivity results in WSR for review and planning of cement job. 8. RDMO. Well ready for CTU. CTU-Cement selective 1. MIRU CTU and associated support equipment. 2. Contact SLB to supply 16.0 bbls of cement(Blend to be determined from injectivity test)for pumping in the IA. IA volume between packers: 3915'-3690'=225' => 225'x 0.0613=13.79 bbls cement. This volume will/should fill the entire IA between packers,however,it is only necessary to place cement on top of the packer to stop the leak and above the production casing leak @ 3770'. 3. RIH and lightly tag top of sand @ 3890'RKB for depth correction. 4. PUH to position nozzle just above tubing punch location. 5. Bring cementers online and place cement in IA. 6. Pump of balanced pill,placing it in the TBG with diesel freeze protect cap.(Amount and weight TBD from injectivity test) 7. POOH freeze protecting well. Allow cement 72 hours to cure. 8. RDMO ****Procedure continued on next page**** 2T-209 Cement Packer Repair 09-20-17 SGD Rev A.xism Printed 10/4/2017 • Page 2 Well: 2T-209 Date of Request: 7/21/2017 Request SPOC: CPF2 PE David/Stephanie x7519,pgr 252 Steps Continued (list service type): CTU-Mill out composite plug 1. MIRU CTU and associated equipment. 2. MU and RIH with 5 bladed junk mill. 3. Mill up any remaining cement in the tubing down to sand plug. 4. At COP Wells Supervisor discretion,use mill assembly to clean out as much sand as possible. Pick up nozzle as necessary to clean off of top catcher. 5. If time permits,pull catcher and plug. 6. POOH freeze protecting well. RDMO. SI-Contingency if CTU did NOT pull catcher and plug 1. MIRU SL and associated equipment. 2. RIH and pull catcher. May be necessary to bail off of top of catcher. 3. RIH and pull plug. 4. RDMO. Turn over to EL for RST log. EL-LDL w/RST 1. MIRU EL and associated equipment. 2. MU and RIH with RST oriented for upflow. 3. Utilize LRS to pump SW down the tubing,looking for upflow behind pipe,concentrating on area around packers,3600'-3925'RKB. 4. POOH freeze protecting well. RDMO. 2T-209 Cement Packer Repair 09-20-17 SGD Rev A.xlsm Printed 10/4/2017 • • PTD !gg —Z43 Loepp, Victoria T (DOA) From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Friday,August 04, 201711:23 AM To: Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL]KRU 2T-209(PTD 198-243,Sundry 317-362) Cement packer repair Follow Up Flag: Follow up Flag Status: Flagged Victoria, On 7/5/17, 21-209 had a passing MIT on the tubing to 2500 psi. as well as a passing CMIT TXIA to 2500 psi. Let me know if this works for you or if you need any other information. Thanks, Steve From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday,August 04, 2017 11:16 AM To: Drake,Steve G<Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL]KRU 2T-209(PTD 198-243,Sundry 317-362)Cement packer repair Steve, What was the date and results of the latest MIT-IA? Thanx, Victoria SCANNED Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp analaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.aov 1 • ° OF Tli� • • I/7; • THE STATE Alaska Oil and Gas oAL ASKConservation Commission : : _`1�f>E== 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 (4'ALA11‘P' Fax: 907.276.7542 www.aogcc.alaska.gov Steve Drake Senior Wells Engineer ConocoPhillips Alaska, Inc. alb Ci 1 1201,1 PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tabasco Oil Pool, KRU 2T-209 Permit to Drill Number: 198-243 Sundry Number: 317-362 Dear Mr. Drake: 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, 01 Cathy '. Foerster Commissioner DATED this 41b—day of August, 2017. RBDMS L PRA) - 9 2017 • • 0 • RECEIVED STATE OF ALASKA AUG 0 3 ?,O17 i'7 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown❑ Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: Cement Packer Repaid]• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Exploratory 0 Development [] • 198-243 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20281-00 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 0 No 0 / KRU 2T-209 9.Property Designation(Lease Number): 10.Field/Pool(s): • ADL 25569 . Kuparuk River Field/Tabasco 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): 4,690' - 3,318' , NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 75' 16" 112' Surface 4,045' 9 5/8 4,082' Production Liner 751' 4 5/8 4,680' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 4 1/2 x 3 1/2 L-80 3,927' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER 813-47 X 38 TORQUEMASTER PACKER ' MD=3690 TVD=2789 PACKER-BAKER MODEL'FA'RETRIEVABLE PACKER " MD=3915 TVD=2909 • 12.Attachments: Proposal Summary E Wellbore schematic (] 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 8/1/2017 15.Well Status after proposed work: Commencing Operations: OIL [i6 WINJ 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: 414 GINJ 0 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: Steve Drake Steve Drake Contact Name: Authorized Title: Senior Wells Engineer Contact Email: Steve.G.Drake@cop.com ;/ ct Contact Phone: (907)263-4062 Authorized Signature: ,'J ,...6---Orr-iiiDate: c�/" / 3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number "6 k.-7- Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No V Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: 10--40 �/ RBDMS IL AUG - 9 2017 APPROVED BY Approved by:CV&/0 COMMISSIONER THE COMMISSION Date: S _q_...., C3�� 0 R 'AJeIrAjmijs n valid for 12 months from the date of approval. Attachments in Duplicate Goal Well Work Request Form • Well: 2T-209 Date of Request: 7/21/2017 Request SPOC: CPF2 PE David/Stephanie x7519,pgr 252 Well Type: Producer Req.Written by: Steve Drake,263-4062 Job Scope: Ann Comm Shut-In Reason Code: 270 Tubing/Casing/Packer Leaks Well Shut in Date(if SI): 4/14/2012 Prioritization Category: Opportunity/Rate Adding Budget Category: Kuparuk Base Expense Network: Job/SAP Comment: EWell Work is not justified via increased production EPreventive Maintenance Program Request Current Well Date= After Well Work Data Current Oil Rate(BOPD) _ 0 Post-Job Oil Rate(BOPD) 150 Risked NOB(BOPD) Enter Rates Last SBHP 1290 psi Last Tag 4,090'md H2S(PPM): 450ppm on Jan 11,2011 SBHP Date 9/16/2016 Tag Date 9/16/2016 Any Fluid Restriction on Well? No SBHP Datum(TVD/SS?) 4083 SS Max Inclin. 61° Max Dogleg 7°/100'and Min. I.D(at/above work) 2.813" Max Incl. Depth 2,645'md Max Dogleg Depth 942'md Well Work Justification&Objectives(and date required if appropriate): 2T-209 is a Tabasco producer that was drilled in December 1998 and completed in February 1999 with an ESP completion. During a work over of the well to conventional gas lift in June of 2012, EL performed a leak detect log,caliper run as well as CAST-M in pipe inspection mode. A leak was identified at 3770'with significant pipe damage from 3770'to 3860'RKB. A packer was stacked during the RWO to cover the casing damage/leak. More recently,the well has been shut in due to high water cut. A RST log was run on 9/22/16 in preparation to convert the producer to an injector. Data from the log identified upward flow behind pipe at 3800'RKB,indicating a packer leak that was subsequently exiting:the known casing leak at 3770' RKB. This procedure will outline the steps needed to place cement in the IA between packers in order to fix the packer leak with the intention of also fixing the casing leak as a secondary objective and convert this well to injection. An RST log will follow the cement/mill out plug portion to confirm isolation of the packer/PC leak. Risk/Job Concerns: No AnnComm issues No surface casing,single annulus,gravel-pack screen liner No SSSV Min ID above work is 2.813"Camco DS Nipple @ 3869'RKB RELAY-Set plug and punch tubing 1. RU RELAY and associated support equipment. 2. Make drift run down to 4668'RKB with dummy composite plug to ensure plug can be pushed to bottom by coil after cement job. 3. Brush setting area for composite bridge plug down to packer @ 3915' RKB. Plug will be set just above this lower packer. 4. RIH with millable composite bridge plug,tie into jewelry and set @ 3913'RKB. POOH. 5. RIH with tubing punch,tie into jewelry and punch holes from 3895'-3897'RKB w/2"tubing punch at 4SPF. POOH. 1. 6. Utilize LRS to perform injectivity test at step increments of 0.5 bpm,1.0 bpm and 1.5 bpm. Include injectivity results in WSR for review and planning of cement job. 7. RDMO. Well ready for CTU. CTU-Cement selective 1. MIRU CTU and associated support equipment. 2. Contact SLB to supply 14.0 bbls of cement(Blend to be determined from infectivity test)for pumping in the IA. IA volume between packers: 3915'-3690'=225' => 225'x 0.0613=13.79 bbls cement. This volume will/should fill the entire IA between packers,however,it is only necessary to place cement on top of the packer to stop the leak and above the production casing leak @ 3770'. 3. RIH and lightly tag composite plug @ 3913'for depth correction. 4. PUH to position nozzle just above tubing punch location. 5. Bring cementers online and place cement in IA. 6. Pump <X bbls.of XX.X ppg balanced pill,placing it in the TBG with diesel freeze protect cap. '4mount and weight TBD from infectivity test) 7. POOH freeze protecting well. Allow cement 72 hours to cure. 8. RDMO CTU-Mill out composite plug 1. MIRU CTU and associated equipment. 2. MU and RIH with 5 bladed junk mill. 3. Mill up any remaining cement in the tubing as well as the composite plug. 4. Push composite plug to bottom as deep as possible. Bottom is a 2.375"restriction(o-ring sub)@ 4668'RKB. 5. POOH freeze protecting well. RDMO. ****Procedure continued on next page***" 2T-209 Cement Packer Repair 07-21-17 SGD(002).xlsm Printed 7/24/2017 • • • • Page 2 Well: ,.ti Date of Request: 7/21/2017 Request SPOC: CPF2 PE David/Stephanie x7519,pgr 252 Steps Continued (list service type): EL-LDL w/RST 1. MIRU EL and associated equipment. 2. MU and RIH with RST oriented for upflow. 3. Utilize LRS to pump SW down the tubing,looking for upflow behind pipe,concentrating on area around packers,3600'-3925' RKB. 4. POOH freeze protecting well. RDMO. • • • • • • • • • • • • • • • • • • • • • • • • • • 2T-209 Cement Packer Repair 07-21-17 SGD(002).xlsm Printed 7/24/2017 • Loepp, Victoria T (DOA) From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Friday,August 04,2017 11:23 AM To: Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL]KRU 2T-209(PTD 198-243, Sundry 317-362) Cement packer repair Victoria, On 7/5/17, 2T-209 had a passing MIT on the tubing to 2500 psi. as well as a passing CMIT TXIA to 2500 psi. Let me know if this works for you or if you need any other information. Thanks, Steve From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday,August 04,2017 11:16 AM To: Drake,Steve G<Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL]KRU 2T-209(PTD 198-243,Sundry 317-362)Cement packer repair Steve, What was the date and results of the latest MIT-IA? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a7alaska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp©alaska.gov 1 KUP D • 2T-209 ConocoPh1(hps t e Well Attribu Max Angle D TD G,-Nz$ Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) .AldakB`111t,° 501032028100 TABASCO PROD 61.05 2,645.18 4,690.0 CoruocoPhdtips °.. Comment H2S(ppm) Date Annotation End Date KB-Grd(k) tRig Release Date 2T-209,7/24/20176:58:18 AM SSSV:NIPPLE 450 1/11/2009 Last WO: 6/25/2012 36.00 12/22/1998 ....Vertical schernatic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag 4,221.0 8/30/2014 Rev Reason:SET CATCHER,GLV C/O,PULL pproven 9/21/2016 HANGER, MAN CATCHER&PLUG it asing rings tion OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I... e Top I • ir •°' 16 1 1 1 °•1WELDED. H, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)...Wt1Len(I...Grade Top Thread° „ Casing SURFACE 9 5/8 8.697 37 5 4,082.1 3,001.44111 :1 BTC Detailsf i.: 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread i ; 1 i 4 623 3 548 3,928.9 4,680.0 3,313.1 11.60 L-80 SLHT Nominal ID -'�i"-CONDUCTOR 37.0.112.0li Top(kKB) Top(TVD)(ftl(B) Top Inc!(°) Item Des Com (in) 3,928.9 2,916.8 56.58 SC-1 PACKER BAKER SC-1 Gravel Pack Packer 4.750 Tubing;481 2 3,934.0 2,919.6 56.53 EXTENSION 3.548 3,938.8 2,922.2 56.49 SLEEVE BAKER Gravel Pack Sliding Sleeve 4.875 3,941.0 2,923.4 56.47 SBE BAKER SEAL BORE 4.750 3,941.7 2,923.9 56.47 EXTENSION 3.548 3,962.2 2,935.2 56.41 KOIV BAKER B-KOIV VALVE 3.437 4,038.6 2,977.5 56.47 SCREEN BAKERWELD Gravel Pack Screen 3.548 4,668.1 3,307.1 59.60 0-RING BAKER 0-RING w/seal lock 2.375 4,669.3 3,307.7 59.60 Flapper VLV BAKER FLAPPER VALVE 2.875 Tubing Strings RI Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(WD)(...Wt(lb/ft) Grade Top Connection GAS LIFT;2,910.9 TUBING 4.5"x3.5" I 31/21 2.992) 28.11 3,920.21 2,912. 01 9.301L- 80 EUE-MOD Completion Details Nominal ID Top(kKB) Top(TVD)(kKB) Top Incl(°) Item Des Com (in) 28.1 28.1 0.00 HANGER FMC TUBING HANGER 4.500 GAS LIFT;3,609.6 li 31.9 31.9 0.00 X0 Reducing CROSSOVER 4.5 x 3.5 2.992 ia 511.9 511.9 0.98 NIPPLE CAMCO 2.875"DS NIPPLE 2.992 3,663.5 2,774.9 59.53 LOCATOR LOCATOR SUB wl 3.44 FT SPACE OUT 3.000 3,667.0 2,776.7 59.46 PBR BAKER 80-40 PBR 4.000 3,688.0 2,787.4 59.03 ANCHOR ML TORGUEMASTER PRODUCTION ANCHOR SEAL 3.850 LOCATOR 3,663.5 11 3,690.1 2,788.5 58.98 PACKER BAKER 813-47 x 38 TOROUEMASTER PACKER 4.750 PER,3,667.0 3,869.4 2,884.3 57.10 NIPPLE 2813"CAMCO DS NIPPLE 2.813 3,917.6 2,910.6 56.68 LOCATOR BAKER BUILT LOCATOR w/MULESHOE 3.240 ANCHOR;3,688.0 3,918.4 2,911.0 56.67 Mule Shoe 1.81 FT FULL MULESHOE(w/SEALS)BELOW 4.850 PACKER;3,690.1 � LOCATOR Y Tubing Description !StringMa...ID(in) Top(ftKB) Set Depth(k..Set Depth(TVD)(...Wt Ilb/ft) Grade TopConnection ,`Iry/y_�//Jr�_'/' TUBING Original 4 1/21 6.0001 3,915.3 3,928.01 2,916.31 12601E-80 1 r "4 Completion Details C 1 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) _ 3,915.3 2,909.3 56.70 PACKER BAKER MODEL'FA'RETRIEVABLE PACKER 6.000 616, 3,917.9 2,910.7 56.67 GUIDE 6.000 /� •NOt �: 3,921.8 2,912.9 56.64 KOIV KNOCKOUT ISOLATION VALVE 4.000 '� 3,923.8 2,914.0 56.62 XO BUSHING CROSSOVER BUSHING 3.998 3,926.6 2,915.5 56.60 WLEG WIRELINE RE-ENTRY GUIDE 3.958 PACKER;3,915.3 Mandrel Inserts LOCATOR;3,917.6 f Stati Q on Top(TVD) Valve Latch Port Size TRO Run Mule Shoe,3,918.4 I N, Top(ftKB) (ftKB) Make Model OD(In) Sew Type Type (in) (psi) Run Date Corn �I 1 2,910.9 2,396.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/25/2012 N 2 3,609.6 2,747.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/16/2016 Notes:General&Safety KOIV;3,921.8 _ End Date Annotation XO BUSHING;3,923.9 12/13/2010 NOTE:Top of Baker Model 194 FA 75x60 @3915,muleshoe is @3928 which is 1 ft inside the top of pkr lii'0 12/13/2010 NOTE:View Schematic w/Alaska Schematic9.0 WLEG;3,926.8 ii 1 M la ;i ce • I 1 I SURFACE,37.5-4,082.1- AIM 72 LINER;3,928.9-4,680.0 J L • PT,D P79 "243 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Thursday, March 16, 2017 3:26 PM To: Drake, Steve G Subject: Re:2T-209 Cement Selective Candidate I will take a closer look-a packer waiver depth can be requested in the sundry. Need to know where TOC is in the intermediate- Sent from my iPhone On Mar 16,2017,at 3:23 PM, Drake,Steve G<Steve.G.Drake@conocophillips.com>wrote: Victoria, No. Not at all. The cement will be placed between the packers. Thanks, scANKEDAPR 2 4 al ; Steve From: Loepp,Victoria T(DOA) [mailto:victoria.loeppPalaska.gov] Sent:Thursday, March 16, 2017 3:20 PM To: Drake,Steve G<Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL]RE:2T-209 Cement Selective Candidate Steve, Are you proposing to cement the IA to surface? If so,this type of procedure will not be approved at this time. We will be having a hearing on Remedial IA cementing on 4/18/17 for a few PB well sundries. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppalaska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793- 1247 or Victoria.Loepp@alaska.gov 1 • • From: Drake,Steve G [mailto:Steve.G.Drake@conocophillips.comj Sent:Thursday, March 16, 2017 10:35 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:2T-209 Cement Selective Candidate Hi Victoria, I wanted to start a dialogue with you about a job that I am planning at 2T-209. 2T-209 is a producer that is currently on LTSI. We would like to convert this well to an injector. There was a leak identified in the PC at approximately 3800' as well as a leaky packer at 3915' (hence the stacked packer at 3690'). I'll try to keep this brief as this is the first email discussing my plans, but,what I'd like to do is: 1. Set a composite plug just above the lower packer 2. Punch a hole in the tubing above that plug 3. Set a millable cement retainer above the tubing punch 4. Fill the IA with resin or cement 5. Let it cure 6. Mill everything out. The main goal here is to fix the packer leak with the PC leak being secondary. My biggest question right now is: 1. As the competent packer will not be within 200'of the perforations will we need AA to inject on this well? I'm waiting on an answer from the DPE on whether or not they plan on putting this on water or gas....Or consider wagging it either way. Hope this is a good start. Please let me know if you have any questions. Thanks, Steve Drake CPF2 Wells Engineer ConocoPhillips Alaska, Inc. steve.g.drake(a�conocophillips.com Office: (907)263-4062 Mobile: (907)223-1166 2 "' csj • • � ru 6- 1.0 a o a; 0 4 7Yr� W N▪ ° `Oh Wa co '' o ( 6 0*- w -a U N Z p .cl O N E N O W O o (O 0 v O � m a a c c QY (o , N ,� +' -C O o- to O 'a a n3 7 Lu O .O ▪ E a 6 CO t0 coto CD COt0 l0 J t L a) U N 0 w N N N N N - D +' ON to L7 to co co 4= C t 13 o C y1c _::%. F 6 6 O O N O C UJ 0 Z Q N N N OU -0 '0 O U Z C CiN > E -O N O C L l u 2 r6 O ❑ ❑ ❑ ❑ ❑ ❑ O ,.. ,:u O � J J J J J J bA O yW —',� CI) L 0 `_ H LL LL LL LL LL LL 4-+ O N N -0 a Q > L cu (0 +" F- < < < < < < v N O �+- v- Z 0) <c) of ci Z Z Z Z Z Z u co v 0 0 LL LL LL LL LL LL , > DO 4 21 _ C .- N t O _O a? u E vcU M ( z c 0 co U 5.) C co > Y u L c C. H > u v U 3 Q ali a ° a C v• N E'j a) LL LL is O 'Q pvi O O J a F LJL. y a) a ;II "' aa � .�� R F O x cc I .. w m U 5 IA > m MM U D7 0 FSI t6 J'.0 w QJ co O > sz0 aoa'f < 93 0 a0 ''�o � i io °^�' . O i 09 h. 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Operations Performed: Abandon r Repair well 17 Plug Fbrforations r Perforate r Other Straddling a Rill Tubing Stimulate - Frac Waiver Casing Leak Alter Casing r 9 r r � Ti me Extension �" Change Approved Program r Operat. Shutdow n r Stimulate - Other '-" Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ;p Exploratory r - 198 - 243 3. Address: 6. API Number: Stratigraphic r Service '"` P. O. Box 100360, Anchorage, Alaska 99510 r 50 - 103 - 20281 - ^ 00 7. Property Designation (Lease Number): 8. Well Name and Number: „ ADL 25569 ' 2T - 209 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): NONE Kuparuk River Field / Tabasco Oil Pool 11. Present Well Condition Summary: Total Depth measured 4690 feet Plugs (measured) 3869 true vertical 3318 feet Junk (measured) None Effective Depth measured 4690 feet Packer (measured) 3690, 3915, 3929 true vertical 3318 feet (true vertucal) 2788, 2909, 2917 Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 16 112 112 SURFACE 4045 9.625 4082 3002 LINER 751 4.5 4680 3313 RECEIVED JUL 2 � 4 ' 2 � 012 Perforation depth: Measured depth: screens 3929' - 4680' AOGCC True Vertical Depth: 2917' -3313' SC 60F3 SCANNED MAR 0 4 6 Tubing (size, grade, MD, and TVD) 3.5, L - 80, 3920 MD, 2912 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER TORQUEMASTER PACKER @ 3690 MD and 2788 TVD PACKER - BAKER MODEL 'FA' RETRIEVABLE PACKER @ 3915 MD and 2909 TVD PACKER - BAKER SC -1 GRAVEL PACK PACKER @ 3929 MD and 2917 TVD NIPPLE - CAMCO DS NIPPLE @ 512 MD and 512 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 16 3 683 -- 408 Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory E Development - Service r Stratigraphic E 16. Well Status after work: . Oil Gas r WDSPL r Daily Report of Well Operations xxx GSTOR r WINJ r WA E GI r SUSP fl 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: 312 -234 Contact Ian Toomey as 263 -4773 Printed Name Ian Toomey Title Wells Engineer Signature .- s - Phone: 263 -4773 Date t / Form 10 -404 Revised 11/2011 JUL V L � '' Submit Original Only c‘IG; I f � ?., I t KUP 2T -209 Conoc 0= Well Attributes Max Angle & MD TD tli�ISh�i, t1, ,:. Wellbore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (IKB) 501032028100 TABASCO PROD 61.05 2,645.18 4,690.0 "" Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "• SSSV: NIPPLE 450 1/11/2009 Last WO: 6/25/2012 36.00 12/22/1998 Well Config - 2T -209, 7/13/2012 4:11: PM schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 4,500.0 11/9/1999 Rev Reason: WORKOVER ninam 7/13/2012 HANGER. ' Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd Mil CONDUCTOR 16 15.062 37.0 112.0 112.0 62.58 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 , 8.697 37.5 4,082.1 3,001.5 40.00 L - 80 BTC r3,10 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd LINER 4 3.548 3,928.9 4,680.0 3,313.1 11.60 L -80 SLHT i Liner Details Top Depth (ND) Top Incl Noml... Top (MB) (ftKB) ( °) Item Description Comment ID (in) CONDUCTOR. 3,928.9 2,916.8 56.46 SC - 1 PACKER BAKER SC - 1 Gravel Pack Packer (old) 4.750 37 - 112 3,934.0 2,919.6 56.45 EXTENSION 3.548 Tubing. 481 3,938.8 2,922.2 56.44 SLEEVE BAKER Gravel Pack Sliding Sleeve (old) 4.875 Mill 3,941.0 2,923.4 56.44 SBE BAKER SEAL BORE 4.750 t 3,941.7 2,923.9 56.44 EXTENSION 3.548 3,962.2 2,935.2 ' 56.41 KOIV BAKER B-KOIV VALVE (old) 3.437 © i 3,963.8 2,936.1 56.40 X0 Reducing 3.428 4,038.6 2,978.0 57.28 Gravel Pack BAKERWELD Gravel Pack Screen (old) 3.548 SCREEN 4,668.1 3,307.1 59.60 O -RING BAKER 0 -RING w /seal lock 2.375 Ill 4,669.3 3,307.7 59.60 Flapper VLV BAKER FLAPPER VALVE 2.875 GAS LIFT, Tubing Strings 2,911 '' Tubing Description String 0... String ID ... Top (8656) Set Depth (f... Set Depth )TVD) ... String Wt... String ... String Top Thrd TUBING I 3 1/2 I 2.992 I 28 1 3,920.2 2,912.0 9.30 L 80 I EUE -MOD IL Completion Details j Top Depth (TVD) Top Inc! Noml... GAS LIFT, r (MO) Top (ftKB) (M) 0 Item Description Comment ID (in) 3'610 28.1 28.1 0.00 HANGER FMC TUBING HANGER 4.500 IIII 31.9 31.9 0.00 X0 Reducng CROSSOVER 4.5 x 3.5 3.500 IN 512.0 511.9 0.37 NIPPLE CAMCO 2.875" DS NIPPLE 2.992 LOCATOR, 3,663.6 2,774.2 58.00 LOCATOR LOCATOR SUB w/ 3.44 FT SPACE OUT 3.000 3,664 INE 3,667.0 2,776.0 57.99 PBR BAKER 80-40 PBR 4.000 PBR, 3,667 gall 3,688.0 2,787.0 57.91 ANCHOR ML TORQUEMASTER PRODUCTION ANCHOR SEAL 3.850 in 3,690.1 2,788.1 57.90 PACKER BAKER 813-47 x 38 TORQUEMASTER PACKER 4.750 ANCHOR, ` «' 3,888 - 3,869.5 2,884.0 56.54 NIPPLE 2.813" CAMCO DS NIPPLE w/ RHC PLUG 2.813 t�1 PACKER, 3,690 3,917.6 2,910.5 56.47 LOCATOR BAKER BUILT LOCATOR w/ MULESHOE 3.240 3,918.4 2,911.0 56.47 Mule Shoe 1.81 FT FULL MULESHOE (w/ SEALS) BELOW LOCATOR 4.850 MI Tubing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (ND) ... String Wt... String ... String Top Thrd NiI TUBING Original 1 4 1/2 I Str 4.902 I 3,915.3 I 3,928.0 I 2,916.3 I 12.60 L -80 I Completion Details NIPPLE, 3,889 Top Depth Mg: ;Z: f, (ND) Top Inc! Nomi... I. Top (ftKB) (9KB) 0) Item Description Comment ID (in) 3,915.3 2,909.2 56.48 PACKER BAKER MODEL RETRIEVABLE PACKER 6.000 Ili 3,921.8 2,912.9 56.47 KOIV KNOCKOUT ISOLATION VALVE 4.000 3,923.9 2,914.0 56.46 BUSHING CROSSOVER BUSHING 3.998 PACKER, 3,915 ,A. M..' 3,926.6 2,915.5 56.46 WLEG WIRELI NE RE -ENTRY GUIDE 3.958 LOCATOR, L; Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) 3,918 Top Depth )ND) Top Inc! Mule Shoe, To (ftKB) )ftKB) ( ° Descri tlon Comment Run Date ID in S hoe, P I ) P ) ) 3,869 2,884.0 56.54 PLUG RHC PLUG 6/25/2012 0.000 a Notes: General & Safety KOIV, 3,922 r End Date Annotation 12/13/2010 NOTE: Top of gravel pack SC - 1 Packer @3929 BUSHING. ° +` 3,924 12/13/2010 NOTE: Top of Baker Model 194 FA 75x60 @3915, muleshoe is @3928 which is 1 ft inside the top of pkr 12/13/2010 NOTE: View Schematic w/ Alaska Schematic9.0 WLEG, 3,927 ',$ Mt Mandrel Details I Top Depth Top Port (ND) 1001 OD Valve Latch Sae TRO Run Stn Top (8656) (ftKB) ( °) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,910.9 2,396.4 59.63 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/25/2012 2 3,609.6 2,748.5 60.64 CAMCO MMG 1 1/2 GAS LIFT SOV RK 0.000 0.0 6/25/2012 SURFACE. _A F ' 37-4,082 AC Ilk- 4 LINER, 3,929 -4,680 TD, 4,690 f . • ConocoPhiliips Time Log & Summary We(Mew Web Repornn9 Report Well Name: 2T - 209 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 6/14/2012 7:00:00 AM Rig Release: 6/28/2012 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/12/2012 24 hr Summary Completed Well 1D-110A Program. RDMO. Nordic Rig 3 Move from 1D pad to 2T -209. 14:00 15:00 1.00 DEMOB MOVE DMOB P Move off well slot 1D-110A. Drop BOPE. Prep Rig for move. 15:00 20:00 5.00 MIRU MOVE MOB P Move Rig from 1D pad to KOC pad. 20:00 21:00 1.00 MIRU MOVE MOB P Stop and set down, check torque on tires, check air pressure, grease planetary. 21:00 00:00 3.00 MIRU MOVE MOB P Continue Rig move KOC pad to 2T -209. 06/13/2012 Nordic_Rig 3 Move 1 Dyad to 2T 209. Prep site for worko_ver. 00:00 04:30 4.50 MIRU MOVE MOB P Continue Rig move toward 2T -Pad from KOC to CPF -2. 04:30 07:30 3.00 MIRU MOVE MOB P Stop and set down, check torque on tires, check air pressure, grease planetary. Wait on field crew change outs. 07:30 11:00 3.50 MIRU MOVE MOB P Continue Rig move toward 2T -Pad from CPF -2. Broke thru road between 2F & 2G pad access roads, lay mats and continue on to 2B pad 11:00 16:30 5.50 MIRU MOVE MOB P Stop and set down, check torque on tires, check air pressure, grease planetary. Shuffle mats around rig. 16:30 19:00 2.50 MIRU MOVE MOB P Continue Rig move toward 2T -Pad from 2B pad to 2A pad. 19:00 20:00 1.00 MIRU MOVE MOB P Stop and set down, check torque on tires, check air pressure, grease planetary. Wait on mats. 20:00 22:00 2.00 MIRU MOVE MOB P Continue Rig move toward 2T -Pad from 2A pad. 22:00 00:00 2.00 MIRU MOVE MOB P Arrive on 2T pad, set down, prep for BOPE change out when skid delivered. Set pit liner and T mats on 2T -209. 06/14/2012 Swami out BOP double gates. M1BU over Well Slot 2T -209. PJSM. Pull BPV. Attempt to Kill Well. Weight up to 9.1 brine 00:00 01:00 1.00 COMPZ MOVE OTHR P Continue to Prep for BOPE change out until skid delivered from 1D pad. 01:00 05:30 4.50 MIRU MOVE OTHR P 11" BOP skid onsite, swap out Shaffer for Hydrill double gates, wellhead will not accept STA. Kill tank and cuttings box delivered. Page 1 of 16 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment - 05:30 07:00 1.50 MIRU MOVE MOB P Move Nordic Rig 3 over 2T -209. Set down and berm up. Spot auxiliary equipment. Start loading pits w/ 8.6 ppg KWF. Rig accepted at 07:00 on 06/14/2012 07:00 09:00 2.00 MIRU WELCTL OTHR P Wait on support group to RU hardline. 09:00 11:30 2.50 MIRU WELCTL OTHR P Wait on Seatwater Transport. RU Lubricator. 11:30 12:15 0.75 COMPZ WELCTL MPSP P PJSM. Pull BPV. Obtain Tubing and IA Pressure. 300 psi on both. 12:15 12:30 0.25 COMPZ WELCTLSFTY P PJSM. Discuss hazard for Bleeding Gas & Killing Well with Nordic, MI, FMC and AES. Called DSO and Security. 12:30 13:00 0.50 COMPZ WELCTL PRTS P Fluid Pack treating iron and PT to 250 / 3500 psi. 13:00 14:30 1.50 COMPZ WELCTL CIRC P Start Bleeding gas cap from tubing to kill tank. On Line with Mud down IA taking returns up TBG at 4 bpm. ICP 320 psi down IA and 200 psi on TBG. Circulated 290 bbls of Hot 8.6 ppg seawater. FCP 180 psi on IA and 90 psi on TBG. 14:30 15:15 0.75 COMPZ WELCTL OWFF P Shut down pump and check return tank. 325 bbls return. Spot another fluid truck and empty kill tank. 15:15 17:00 1.75 COMPZ WELCTL CIRC P Start Circulating at 4 bpm, 280 psi down IA and 30 psi up TBG. Pump another 115 bbls. Monitor well. Still seeing 70 psi on well with a trace of Diesel and crude. 17:00 17:30 0.50 COMPZ WELCTL CIRC P Start Reverse Circulating again at 3 bpm, 120 psi on IA and 30 psi on tubing. 17:30 19:00 1.50 COMPZ WELCTL OWFF P Shut down and Monitor well. SITP 70 psi. 19:00 20:30 1.50 COMPZ WELCTL CIRC P Start Circulating down TBG at 4 bpm, 200 psi, 20 psi up IA. Pump 278 bbls. FCP 200 tbg and 30 psi on IA. 20:30 21:00 0.50 COMPZ WELCTL OWFF P Shut and Monitor well. TBG 50 psi / IA 50 psi. Clean 8.54 heavy KWF at surface. 21:00 00:00 3.00 COMPZ WELCTL OTHR P Confer w/ town engineer. Decision was made to Weight Up to 9.2 ppg. 450 bbls of 8.5 ppg is Pits. Send for more product from 1 Q -pad and Weight up. 06/15/2012 ) and Kill Well. Install BPV. ND Tree. Install Blanking Plug. NU BOPE and Test Same. 00:00 01:30 1.50 COMPZ WELCTL CIRC P Fluid up to weight.( 9.1 ppg Heavy) , 1 Start Circulating down tubing at 4 bpm, 160 psi and 70 psi on IA . ( 1 Pump 320 bbls total with 240 bbls return. Page 2 of 16 • 4 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:00 0.50 COMPZ WELCTL OWFF P _ Shut down and Monitor well. Tubing 0 and IA 0 Sliaht Vac. 7 02:00 02:30 0.50 COMPZ WELCTL MPSP P Set BPV., 17 02:30 05:00 2.50 COMPZ WHDBO NUND P ND Tree,and Inspect Threads and Install blanking plug. Threads show signs of wear and pitting. 05:00 09:00 4.00 COMPZ WHDBO NUND P PJSM. Crew Change Out. NU BOPE, Open up doors in double gate and install VBR's in upper, blind rams in lower. 09:00 12:00 3.00 COMPZ WHDBO RGRP P Inspect Lower Single gate Ram body. Found trace of cement inside ram body, clean out and inspect VBR's. 12:00 13:30 1.50 COMPZ WHDBO NUND P Continue to NU BOPE. 13:30 17:30 4.00 COMPZ WHDBO RGRP P Replace Annular rubber element. Inspect and found trace of cement inside cap, clean out. Inspect piston. 17:30 19:30 2.00 COMPZ WHDBO NUND P Wellhead leaning, straighten and install riser. 19:30 00:00 4.50 COMPZ WHDBO BOPE P Fill 11" 5M Class III stack and lines with water and RU Test equipment. Held PJSM and Test BOPE at 250 / 3,500 psi w/ 3.5" and 4.5" test joints. Perform Accumulator Draw Down Test- System pressure 3,000 psi, After Close 1,950 psi. Function Tested both Chokes. 06/16/2012 Continue to test BOPE. Pull Blanking Plug and BPV. Install Side Port Isolation Sleeve. Pull Tbg Hanger to Big1onr p to pull Completion. Single down the 4 -1/2" ESP Completion. MU Clean -out String. Wait on Tools. 00:00 03:30 3.50 COMPZ WHDBO BOPE P___.Test BOPE at 750 / 3.500 psi w/ 3.5" and 4.5" test joints. Perform Accumulator Draw Down Test - System pressure 3,000 psi, After Close 1,950 psi. Function Tested both Chokes. RD test equipment. Static fluid level close to surface, less than 90 -ft, shot at 03:00. 03:30 04:30 1.00 COMPZ WELCTL MPSP P PJSM- Pull blanking plug and BPV, fluid level at surface. 04:30 05:30 1.00 COMPZ RPCOM THGR P PJSM- MU Landing Joint with Side Port Isolation Sleeve, mark at rotary table. BOLDS. 05:30 06:30 1.00 COMPZ RPCOM THGR P Un -land tubing hanger at 90k and pull to rig floor, Up wt 85k. Dn wt 70k. remove penetrators and lay down tubing hanger while monitoring well on trip tank. 06:30 16:00 9.50 3,820 110 COMPZ RPCOM PULL P RU Cable Spooler and TOOH sideways spooling TEC wire and ESP Cable while maintaining proper hole fill. Page 3 of 16 • • Time Logs - Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 19:00 3.00 110 0 COMPZ RPCOM PULD P Reached Lower ESP Section. Continue to Lay Lower Motor section. 4 1/2" Tbg and Jewelry showed heavy signs of Paraffin and Corrosion. The pin and collar end showed pitting and Lower ESP section was completely covered with Paraffin and possibly H2S damage. Recovered w/ completion: 2 ea. Cable Guards. 3 ea. Protectolizers. 13 ea. 1 -1/4" SS bands (17 ran) 64 ea. 4 -1/2" Cannon Clamps w/ SS pins. 19:00 20:30 1.50 0 0 COMPZ WELLPF PULD P PJSM. Load 9 5/8" Casing Scraper Assembly. Clean and Clear floors, pipe shed. Change over floors to run clean out string. Wellbore Clean out Nozzle delivered to Doyon 141 on 3N pad, DTH to bring back. 20:30 21:30 1.00 0 0 COMPZ WELLPF PULD P PJSM- MU 9 5/8" Casing Scraper Assembly with String magnet and Jars. 2 7/8" Wash Nozzle with 6' Pup Joint on location, bring to floor. Nozzle jets 1/8" x 9ea. 21:30 22:00 0.50 0 0 COMPZ WELLPF OTHR P Bring in and Set Wear Bushing. 22:00 00:00 2.00 0 0 COMPZ WELLPF OWFF XT Confer with town engineer, will run RCJB with dual Boot Baskets first run to recover 4 ea. of 1 -14" SS bands still in hole. Wait on RCJB, Boot Baskets and Pump Out Sub for wash nozzle run. 06/17/2012 RIH with the RCJB. Encountered heavy paraffin from 3,868 -ft, clean up CSG to 3,915 -ft POOH well not taking proper amount of fluid. Weight up fluid back to 9.1 heavy. Circulate well. 00:00 03:30 3.50 0 0 COMPZ WELLPF OTHR XT Continue wait on RCJB, Boot Baskets and Pump Out Sub from Prudhoe. Bring in Baker Tools. weight up 290 bbls to 9.1 ppg. 03:30 04:00 0.50 0 62 COMPZ WELLPF PULD P PJSM- MU 7 -7/8" RCJB, Dual Boot Baskets to 9 5/8" Casing Scraper Assembly with String magnet and Jars already assembled. 04:00 08:00 4.00 62 3,868 COMPZ WELLPF TRIP P PJSM. Single in with RCJB / Scraper Assembly on Drill Pipe down to 3868' RKB 08:00 10:15 2.25 3,868 3,915 COMPZ WELLPFCIRC P Heavy paraffin was encounter. Start Circulating at 6 bpm, 1385 psi while reciprocating. Continue to wash down to target depth of 3,915 -ft. Page 4 of 16 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:15 14:00 3.75 3,915 3,900 COMPZ WELLPFCIRC P Reached Target Depth with RCJB. CBU after pumping a 35 bbl High -Vis sweep at 7 BPM, 3300 PSI until returns are Clean. Shut down pumps and monitor well after CBU x3. Up Wt 82k / Dn Wt 74k, Start TOOH , stood back on stand and started pulling heavy, unable to TOOH or RIH, start circulating and rotating to get free. 14:00 15:15 1.25 3,900 2,761 COMPZ WELLPFTRIP P TOOH with C/O assembly, maintaining proper hole fill.Up Wt 82k / Dn 74k. 15:15 16:00 0.75 2,761 2,761 COMPZ WELLPFOWFF T Well not taking the proper amount fluid. Stop and Monitor well for flow. Pits showed a 5 bbl gain while tripping. Start Circulating at 2 bpm, 235 psi to gauge pits and check the fluid properly. Circulated 31 bbls and had 20 bbls return of 8.9 ppg heavy. Well shows be static after watching for 15 minutes. 16:00 17:30 1.50 2,761 1,128 COMPZ WELLPF TRIP P Continue to TOOH with C/O assembly. 17:30 22:30 5.00 1,128 1,128 COMPZ WELLPFOWFF T Well not taking the proper amount fluid. Stop and Monitor well for flow. Start Bullheading 9.1 heavy down DP at 2 bpm, ICP 470 psi, 100 bbls, FCP 540 psi. shut in and monitor well, 20 psi on IA, 8.9 ppg at surface, TBG at 0 psi, bleed IA down to 0 psi, TBG at 0 psi, Monitor well 30 minutes, IA has slight flow, weight up pits to 9.1 heavy. Monitor well on trip tank, well static. 22:30 00:00 1.50 1,128 1,128 COMPZ WELLPFCIRC T Bullhead 150 bbls 9.1 heavy, 2 bpm, ICP 480 psi, FCP 600 psi. shut down TBG at 0 psi, IA at 10 psi with 8.9 ppg at surface. 06/18/2012 Continue to circulate and monitor well. POOH with RCJB. RIH with Wash Nozzle / Scraper string. POOH.., F:IH w/ Retrievable Bridge Plug. Unable to pas; w_/ 8.44" OD. Order Up IBP. 00:00 01:00 1.00 1,128 1,128 COMPZ WELLPF CIRC T Start Circulating at 3 bpm, 600 psi , 20 psi back pressure, gauge pits and check the fluid properly. Circulated 75 bbls and had 70 bbls return, 9.1 heavy at surface on IA. 01:00 02:00 1.00 1,128 1,128 COMPZ WELLPF OWFF T Shut down and monitor well on trip tank, well taking 2 bph. 02:00 03:00 1.00 1,128 0 COMPZ WELLPF TRIP P PJSM- Continue to TOOH with C/O assembly. 03:00 03:30 0.50 0 0 COMPZ WELLPF PULD P OOH, lay down and inspect junk basket and boot basket and lay down same. Recovered all bands and large piece of rubber element out of RCJB and approximatly 2.5 gallons of Heavy scale from boot baskets. Page 5 of 16 • Time Logs Date From To Dur $. Depth E. Depth Phase Code Subcode T Comment 03:30 04:00 0.50 0 68 COMPZ WELLPF PULD P MU 3 -1/2" OD Wash Nozzle w/ 9ea. X 1/8" jets / Scraper / Boot Basket / Magnet Assembly. 04:00 08:00 4.00 68 3,913 COMPZ WELLPF TRIP P TIH with Clean Out assembly down to 3,915' RKB, reciprocate and Jet across FA packer upper profile. PUH drop 1 -7/8" ball to open Pump Out Sub. 08:00 10:00 2.00 3,913 3,913 COMPZ WELLPF CIRC P Circulate and condition well at 4 bpm, 230 psi. Continue until returns are clean. 10:00 11:00 1.00 3,913 3,913 COMPZ WELLPF OWFF P Monitor well. Change out cable on trip tank. 11:00 12:00 1.00 3,913 2,200 COMPZ WELLPF TRIP P TOOH with C/O assembly, maintaining proper hole fill. 12:00 13:30 1.50 2,200 2,200 COMPZ WELLPF PULD P Un -load ESP spool from rig floor and load empty spool to rig floor. 13:30 14:45 1.25 2,200 67 COMPZ WELLPF TRIP P TOOH with C/O assembly, maintaining proper hole fill. 14:45 16:00 1.25 67 0 COMPZ WELLPF PULD P Reached surface with BHA. Lay down,lnspect Clean Out Assembly. Recover minimal amount of scale in boot basket. LID and Kickout C/O assembly. 16:00 16:45 0.75 0 34 COMPZ WELLPF PULD P PJSM. PU and MU the 9 -5/8" RBP and Test Packer. 16:45 17:00 0.25 34 419 COMPZ WELLPF TRIP P TIH with Testing assembly down to 3900' RKB. Set down with Testing assembly at 419 -ft. 17:00 18:00 1.00 419 0 COMPZ WELLPF TRIP T TOOH and Inspect Testing BHA. Tool looks good, Tool guage 8.44" OD 18:00 19:00 1.00 0 31 COMPZ WELLPF PULD T Crew change out. PJSM- MU RCJB w/ 8.5" OD shoe, 9-5/8" Casing Scraper w/ 8" OD body, bumper Sub, Jars. 19:00 19:30 0.50 380 380 COMPZ WELLPF TRIP T TIH with 8.5" OD RCJB / Scraper assembly to 380 -ft. unable to pass. 19:30 19:45 0.25 380 0 COMPZ WELLPF TRIP T TOOH and Inspect BHA. small piaces of bottom carbide broke off. 19:45 20:15 0.50 0 0 COMPZ WELLPF PULD T Drop RCJB and MU 9 -5/8" Casing Scraper w/ 8" OD body, 4 -5/8" Bull nose. 20:15 20:45 0.50 0 470 COMPZ WELLPF TRIP T TIH with 9 -5/8" Scraper assembly, no weight lose or problems thru tight areas at 380 -ft and 419 -ft. 20:45 21:15 0.50 470 0 COMPZ WELLPF TRIP T TOOH, work tight areas several times. Inspect and lay down BHA. 21:15 22:00 0.75 0 386 COMPZ WELLPF OTHR T PJSM- MU Model "G" Lock -set RBP on Model "L" Retrieving head. and TIH on DP to 387 -ft, lower 8.44" gauge on RBP at 380 -ft, SO 5k will not fall thru. 22:00 22:45 0.75 386 0 COMPZ WELLPF TRIP T TOOH, standing back Drill Pipe. Inspect BHA, marks all the way around lower gauge ring on RBP, UD RBP. Page 6 of 16 Time Logs 1111 • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 0 0 COMPZ WELLPF OWFF XT Confer with town engineer. Order up IBP and tools needed. Off load Baker tools. Clean floors and shed. 06/19/2012 Monitor Well. RIH with 4 -1/4" IBP. Test Casing, Failed. POOH. RIH w/ Bullnose. Dump Sand. PQQ11. 00:00 03:00 3.00 0 0 COMPZ WELLPF OWFF T Monitor well on trip tank while waiting on delivery of IBP. well taking 7.5 bph. load and weight up pits. repair hydraulic choke control. 03:00 03:15 0.25 0 0 COMPZ WELLPF PULD T Bring in Baker tools 03:15 04:00 0.75 0 18 COMPZ WELLPF PULD T PJSM- MU Baker retrievable 4 -1/4" IBP. 04:00 06:00 2.00 18 3,890 COMPZ WELLPF TRIP T TIH with 4 -1/4" IBP to 3,890 -ft (bottom of elements at 3,886 -ft) TOP of IBP at 3,880 -ft. 06:00 07:15 1.25 3,890 3,890 COMPZ WELLPF PACK T Climatize IBP 07:15 09:30 2.25 3,890 3,890 COMPZ WELLPF PACK T Drop 1/2" ball and wait to seat 09:30 11:45 2.25 3,890 3,890 COMPZ WELLPF PACK T Inflate 4 1/4" IBP and pressure test IA at 1,500 psi. Found packing gland on lock down leaking at 1,100 psi, bleed off pressure and tighten packing gland. Attempt to re -test IA at 1,500 psi, pumping away at 700 psi, bleed back to 400 psi, multiple times. Check surface equipment, no leaks found. 11:45 12:45 1.00 3,890 3,890 COMPZ WELLPF OWFF T Monitor well on trip tank for 1 hour, gained 3/10 of a bbl. Losses prior to setting IBP were 7.5 bph. 12:45 15:45 3.00 3,880 0 COMPZ WELLPF TRIP T PJSM, POOH with Baker IBP setting tool 15:45 18:00 2.25 0 3,775 COMPZ WELLPF TRIP T PJSM, RIH w/ Bull nose on 3 1/2 DP to 3,775 -ft 18:00 22:00 4.00 3,775 3,868 COMPZ WELLPF OTHR T Dump 1000# 20/40 sand (21.8 -ft) on IBP, reciprocate and clear DP, Soft tag TOS at 3,868 -ft. 22:00 00:00 2.00 3,868 0 COMPZ WELLPF TRIP T PJSM -TOOH Standing back DP Up wt 80k, Dn wt 72k, LD bullnose. BDTD. 06/20/2012 RU E -line. Run Temp, Caliper, with memory_and,CAST -M logs, RD E- line.. Begin Csg swedging o•erations. 00:00 00:45 0.75 0 0 COMPZ WELLPF PRTS T Attempt to pressure test 9 -5/8" Csg. well started taking fluid at .5 bpm, 500 psi, shut down pump at 800 psi, 2.5 bbls pumped, pressured dropped to 500 psi then slowed, bleed to 0 psi and monitor for flow, well static. Install 23 -ft of Dutch Riser lubricator. 00:45 01:00 0.25 0 0 COMPZ WELLPF SFTY P PJSM- E -line operations hazards. 01:00 02:15 1.25 0 0 COMPZ WELLPF RURD P RU E -line on dutch Riser. Test equipment on surface. Page 7 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment - 02:15 04:00 1.75 0 3,865 COMPZ WELLPF ELOG P RIH with HES Temp / GR / CCL / Caliper memory and GYRO data tool assembly to 3,865 -ft, Caliper starts at 3,860 -ft, GYRO starts at 3,830 -ft. Load, Drift and Tally 3 -1/2" completion. Drift first row to 2.91" (1200 -FT), drift remainder of completion 2.867 ". 04:00 06:30 2.50 3,865 0 COMPZ WELLPF ELOG P Log up 50 fpm from 3,860 -ft to surface. Caliper set to close at 06:30. Lay down tools 06:30 13:00 6.50 0 3,860 COMPZ WELLPF ELOG T MU and RIH w/ Leak detect log to 3,860 -ft and log out, pumping at .5 bpm at 840 psi, found temperature change over at 3,770 -ft. Continue to log out with no other leaks. 13:00 19:00 6.00 3,860 0 COMPZ WELLPF ELOG P MU and RIH w/ Cast M to 3,860 -ft and set down pick up to 3,840 -ft and log out to surface. RD E -line. 19:00 19:30 0.50 0 0 COMPZ WELLPF OTHR T PJSM- Bring in Baker tools. 19:30 20:30 1.00 0 235 COMPZ WELLPF PULD T PU and RIH w/ 8.5" OD CSG Swage to 235 -ft. 20:30 21:00 0.50 235 522 COMPZ WELLPF SWDG T RIH w/ BHA #9 on DP from 235 -ft, 3k down drag at 380 to 384 -ft, no problems to 522 -ft, PUH, 5k up drag from 384 to 380 -ft, work area several times w/ 3k down and 3k up thru 380 to 384 -ft on final pass. 21:00 22:00 1.00 522 0 COMPZ WELLPF PULD T TOOH and UD 8 -1/2" Swage, PU 8 -5/8" OD CSG Swage on same DC / Jar / Intensifier Assembly. 22:00 23:00 1.00 0 522 COMPZ WELLPF SWDG T RIH w/ BHA #10 on DP, 10k down drag at 380 to 384 -ft, slight bobble at 419 -ft, no problems to 522 -ft, PUH, 15k up drag from 384 to 380 -ft, work area several times w/ 4k down and 6k up thru 380 to 384 -ft on final pass 23:00 00:00 1.00 522 0 COMPZ WELLPF PULD T TOOH and UD 8 -5/8" Swage. 06/21/2012 Continue Csgswedging operations. RIH w/ Retrievable Bridge Pluq. Test Casing. POOH. Wash Sand From Top of IBP. 00:00 00:30 0.50 0 240 COMPZ WELLPF PULD T PU MU 8 -3/4" OD CSG Swage on same DC / Jar / Intensifier Assembly to 240 -ft. 00:30 03:00 2.50 240 522 COMPZ WELLPF SWDG T RIH w/ BHA #11 on DP, Up wt 55k, Dn wt 55k, stack out at 380 -ft, work down thru to 384 -ft, no problems to 522 -ft, PUH, 20k overpull from 384 to 380 -ft, work area with little progress, 20k down and 20k up 380 to 384 -ft on final pass 03:00 04:00 1.00 522 0 COMPZ WELLPF TRIP T TOOH and UD 8 -3/4" Swage. 04:00 05:00 1.00 0 242 COMPZ WELLPF PULD T PU MU 8 -3/4" x 8 -5/8" OD tandem CSG Swage on same DC / Jar / Intensifier Assembly. Page 8 of 16 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 06:00 1.00 242 522 COMPZ WELLPF SWDG T RIH w/ BHA #12 on DP, Up wt 57k, Dn wt 57k, stack out at 380 -ft, work down thru to 384 -ft, work thru to 387 -ft w/ 8 -3/4" swg. no problems to 522 -ft, PUH, 20k overpull from 387 to 380 -ft, work area with little progress, 20k down and 20k up 380 to 387 -ft on final pass. 06:00 09:00 3.00 522 0 COMPZ WELLPF TRIP T TOOH 8 -3/4" x 8 -5/8" OD tandem CSG Swage, UD Tandem Swages, Jars and LBS. 09:00 09:30 0.50 0 0 COMPZ WELLPF SVRG T Post Swageing Derrick inspection 09:30 10:00 0.50 0 0 COMPZ WELLPF OTHR T Load out tools, Bring in Baker tools. 10:00 11:30 1.50 0 204 COMPZ WELLPF PULD P PJSM- PU MU 9 -5/8" Retrievamatic Test packer / 6 -1/4" DC assembly. 11:30 14:00 2.50 204 3,701 COMPZ WELLPF TRIP P RIH w/ testing assembly BHA #13 and set at 3,701 -ft w/ 20k down wt. 14:00 17:00 3.00 3,701 3,701 COMPZ WELLPF PRTS P PJSM- Pressure test IA from 3,701 -ft to_ 1500 psi, had a packing gland, leak, retest to 1500 psi, had a sensor leak,. retest IA to 1500 psi x 30._minutes on chart bleed IA to 0 psi. 17:00 20:00 3.00 3,701 0 COMPZ WELLPF TRIP P TOOH with testing assembly, Up wt 90k, Dnwt71k, UDBHA #13 20:00 20:30 0.50 0 0 COMPZ WELLPF OTHR P Clean and clear floors, Load out DC's and Baker tools. 20:30 21:00 0.50 0 12 COMPZ WELLPF PULD P PJSM- PU MU Model "L" Retrieving head (7.86" OD shoe, 3" ID) 21:00 22:00 1.00 12 3,866 COMPZ WELLPF TRIP P RIH with BHA #14 on DP and tag TOS and 3,866 -ft. Up wt 80k, Dn wt 72k. 22:00 00:00 2.00 3,866 3,882 COMPZ WELLPF CIRC P Line up pumps and reverse circulate sand from top of IBP 8 bpm, 930 psi, strip thru annular / circ sand thru TD down to 3,882 -ft, line pumps up and circulate 20 bbl high vis sweep 8 bpm, 800 psi. 06/22/2012 Continue to wash sand from top of IBP. RIH with IBP Retrieving Tool. Release IBP. Circulate and, Condition welt P00H: to Run Completion. Run 3 m -1/2" tubing with packer copletion. Stack ouiZk at 382 -ft with bottom of 8.44" OD Premier Packer. POOH. Prep for Csg Swege Operations. 00700 - 00:30 0.50 3,882 3,882 COMPZ WELLPF CIRC P Continue to circulate 20 bbl high vis sweep 8 bpm ICP 800 psi, FCP 800 psi. 00:30 01:00 0.50 3,882 3,880 COMPZ WELLPF SFTY P PJSM- POOH w/ wash over BHA and BDTD 01:00 02:45 1.75 3,880 0 COMPZ WELLPF TRIP P TOOH with Wash over tool, UD BHA #14. 02:45 03:30 0.75 0 15 COMPZ WELLPF PULD P PJSM- PU MU IBP retrieving tool / Stabilizer assembly. 03:30 05:15 1.75 15 3,775 COMPZ WELLPF TRIP P RIH w/ IBP retrieving tool assembly to 3,775 -ft. 05:15 07:30 2.25 3,775 3,775 COMPZ WELLPF SLPC P PJSM- Slip /Cut Drill Line and inspect draw works Page 9 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 09:00 1.50 3,775 3,880 COMPZ WELLPF FISH P Held PJSM w/ crew and Baker Thru TBG hand. RIH to 3,880 -ft, Engaged IBP and allow to equalize with losses at 10.2 bph. Pull 5k osw and monitor well on trip tank while elements relax with losses at 14.8 bph. 09:00 09:30 0.50 3,880 3,880 COMPZ WELLPF OTHR P Drop ball and rod, pressure up to 1,580 psi and shear out sub. Reverse circulate 76 bbls at 6 bpm at 400 psi, recovered small amount of sand at bottoms up. 09:30 10:00 0.50 3,880 3,880 COMPZ WELLPF OWFF P Monitor well on trip tank w/ losses at 10 bph. 10:00 13:30 3.50 3,880 0 COMPZ WELLPF TRIP P PJSM with rig crew, POOH with BHA #15 (4 1/4" IBP) and lay down same. 13:30 14:00 0.50 0 0 COMPZ WELLPF OTHR P Offload all Baker tools. 14:00 14:30 0.50 0 0 COMPZ WELLPF OTHR P Pull wear ring and install test plug 14:30 17:00 2.50 0 0 COMPZ WELLPF OTHR P MU and RIH w/ bull nose, Baker circ sub on 3 1/2 DP, locate test plug and mark. PU and circulate at 8 bpm at 150 psi while oscillating thru BOP stack washing out ram cavities. POOH and remove Baker circ sub and RIH to Test plug, PU 1 -ft and close UPR's reverse circulate thru kill line at 8 bpm at 140 psi. Open UPR's and POOH RD BOP wash BHA and pull Test plug. 17:00 18:00 1.00 0 0 COMPZ WELLPF OTHR P Change over and Prepare to RIH w/ 3 1/2 TBG recompletion 18:00 20:30 2.50 0 591 COMPZ RPCOM RCST P PJSM- PU and RIH with 3 -1/2" completion w/ Baker 9 -5/8" Premier Packer to 591 -ft, Stack Out 5k, bottom of packer at 382 -ft, PU and attempt to pass again w/ SO of 5k, pick off clean. 20:30 21:15 0.75 591 591 COMPZ RPCOM RCST P Confer with town engineer and Baker reps. Attempt to pass with Max SO of 7k, 2.5k to free packer from tight spot at 382 -ft. Confer with town. 21:15 22:30 1.25 591 0 COMPZ RPCOM TRIP XT PJSM POOH with 3 -1/2" completion from 591 -ft, light marks on lower 8.44" OD guage ring and another 180° opposite side on 8.42" OD guage ring just below packer elements. No signs /marks on locator. 22:30 00:00 1.50 0 0 COMPZ WELLPF OTHR T PJSM- Bring in Bakers tools, Load and tally 6ea. 6 -1/4" Drill Collars. Set Wear Bushing. Change over floors. 06/23/2012 Continue Csg swedging. operations. RIH with Test Packer / Taiipe assemblv,,.Test CasinQ. .E.QOIL — P.e.p..to Run,. • u •1 Be•in Weekl BOP Test. 00:00 01:30 1.50 0 245 COMPZ WELLPF PULD T PJSM- PU MU 8 -3/4" x 8 -1/2" x 8 -5/8" Casing Swege BHA #16. Page 10 of 16 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 04:30 3.00 245 522 COMPZ WELLPF SWDG T RIH w/ BHA #16 on DP to 380 -ft, Up wt 55k, Dn wt 57k, slide thru 380 -ft 10k and Stack Out at 384 -ft, work down thru to 386 -ft, SO at 390 -ft, work down thru to 392 -ft and fell thru, PUH w/ 25k to 40k over pull, continue to work tight areas between 380 -ft and 392 -ft with little change, no problems to 522 -ft 04:30 06:30 2.00 522 0 COMPZ WELLPF TRIP T POOH w/ BHA #16, UD same. 06:30 08:30 2.00 0 0 COMPZ WELLPF OTHR T Load tools for BHA #17 (Test packer assy) / Post Jarring derrick inspection 08:30 10:00 1.50 0 405 COMPZ WELLPF PULD T PU and RIH w/ BHA #17 to 405 -ft - Seen 8.5" OD x 6" head on 7 7/8" RCJB take 500 to 1,000 lbs slack off at 386 -ft. 10:00 11:00 1.00 405 1,192 COMPZ WELLPF TRIP T RIH w/ BHA #17 from 405 -ft to 1,192 -ft - Seen Retrievamatic PKR w/ 8.42" OD Gage rings take 500 lbs slack off at 386 -ft. with RCJB at 601 -ft. 11:00 11:15 0.25 1,192 1,192 COMPZ WELLPF PACK T Set Packer at 1,000 -ft 11:15 15:30 4.25 1,192 1,263 COMPZ WELLPF PRTS T Pressure IA up to 1,000 psi - Gland nut leaking on LDS - retighten. Pressure up to 1,500 psi and loss 200 psi in 25 minutes, Move up hole to 997 -ft and reset PKR, PT at 1,450 psi - loss 150 psi in 10 minutes. Bump back up to 1500 psi and loss 100 psi in 10 minutes. Move down hole to 1,063 -ft and reset PKR, PT at 1,450 psi - loss 50 psi in 10 minutes and straight lined for 20 minutes. Release Packer 15:30 18:00 2.50 1,263 0 COMPZ WELLPF TRIP T POOH w/ no problems - Set back DC's and laydown RCJB 18:00 19:30 1.50 0 0 COMPZ WELLPF OTHR T PJSM- Pull wear Bushing, Change Over floors 19:30 20:00 0.50 0 0 COMPZ RPCOM PULD T PJSM- PU Locator, 2.81" DS nipple w/ RHC installed, crossthreaded 1st joint on nipple, threads on nipple and joint #1 bad, lay down Locator, order up new DS nipple. 20:00 21:30 1.50 0 0 COMPZ WHDBO BOPE P Drain / rinse BOP stack, Grease Choke valves, HCR and Top Drive valves. 21:30 00:00 2.50 0 COMPZ WHDBO BOPE P Fill 11" 5M Class III stack and lines with water and RU Test equipment. Held PJSM and Test BOPE at 250 / 3,500 psi. 06/24/2012 Complete weekly BOP Test. Attempt to run 3 -1/2" tubing with packer completion_ Wait on Orders. RIH with ft 8.5 - x 8 -1/8" OD Drift. POOH. . Page 11 of 16 • • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 0 0 COMPZ WHDBO BOPE P Continue to Test BOPE at 250 / 3,500 psi w/ 3.5" test joint. Perform Accumulator Draw Down Test - System pressure 3,000 psi, After Close 1,850 psi. Function tested both chokes 01:30 02:00 0.50 0 0 COMPZ WHDBO BOPE P Pull Test Plug and rig down test equipment 02:00 03:00 1.00 0 585 COMPZ RPCOM RCST T PJSM- PU and RIH w/ 3 -1/2" completion to 585 -ft, 8.44" OD Premier Packer parked at 375 -ft. 03:00 03:30 0.50 585 585 COMPZ RPCOM CIRC T RU head pin and reverse circulate 35 bbls of KWF w/ Safe -tube 3 bpm, 60 psi 03:30 04:00 0.50 585 591 COMPZ RPCOM RCST T RIH w/ completion, Stacked Out 5k at 591 -ft, bottom of packer at 383 -ft, pick off clean, PUH and turn completion 1/2 turn, packer will not pass or slid thru with 5k stacked out. 04:00 04:30 0.50 591 591 COMPZ RPCOM OTHR T Confer with town engineer, POOH with completion while waiting on orders from town. 04:30 05:30 1.00 591 0 COMPZ RPCOM TRIP T PJSM- POOH with 3 -1/2 completion, 05:30 16:30 11.00 0 0 COMPZ WELLPF OTHR T Clean paint and scrub on rig. Shuffle DP in derrick for proceeding forward on well after operational decisions were made. Load Baker tools on rig. 16:30 17:00 0.50 0 16 COMPZ WELLPF PULD T PJSM, PU MU and RIH w/ BHA #18 to 16 -ft. 17:00 21:30 4.50 16 3,917 COMPZ WELLPF TRIP T RIH w/ BHA #18 from 16 -ft picking up 3 1/2 production tubing. Soft Tag Top of FA Packer at 3916.77 -ft. 21:30 22:30 1.00 3,917 3,917 COMPZ WELLPF CIRC T Reverse circulate 105 bbls of KWF 8 bpm, ICP /FCP 380 psi. BDTD 22:30 00:00 1.50 3,917 0 COMPZ WELLPF TRIP T PJSM- POOH laying down 5joints, stand back 41 stands of 3 -1/2" production tubing. Up wt 65k, Dn wt 60k. UD BHA #18. 06/25/2012 Prep to Run Completion. Run TorqueMaster Packer /Locator tailpipe assembly on 3 -1/2" Drill Pipe. Several attempts to get locator seals to enguage. POOH with Packer /Locator assembly. Round up Clean our equipment. MU Clean Out Assembly. 00:00 01:30 1.50 0 0 COMPZ WELLPF OTHR T PJSM- off load tools. Clean and Clear floors. Change over floor equipment. 01:30 02:30 1.00 0 0 COMPZ WELLPF PULD T PJSM- PU and lay down 2 stands of -1/4" Drill Collars. 02:30 03:00 0.50 0 0 COMPZ WELLPF OTHR T PJSM- Change over floor equipment. Set Wear Bushing. 03:00 04:00 1.00 0 242 COMPZ RPCOM PULD T PJSM- PU Locator, DS nipple w/ RHC installed and Baker TorqueMaster Packer assembly. Change over floors to run DP. Page 12 of 16 Time Logs • Date From To Dur S. Depth E. Depth Phase' Code Subcode T Comment 04:00 12:00 8.00 242 3,919 COMPZ RPCOM TRIP P RIH with Packer / Tail Pipe Assembly on 3 -1/2" DP, SO 3k slide thru 380 -ft, continue to RIH with assembly to 3,918.55 -ft. 80k up wt, 70 dn wt. Circulating at 1 bpm at 60 psi. Made 7 attempts, with different orientations in attempt to insure seals are engaged into FA Packer. - No luck. Call town engineer with information - follow up with confirmation. 12:00 17:30 5.50 3,919 0 COMPZ RPCOM TRIP T POOH, seen 4k over pull at 380 -ft, Continue to POOH and inspect Torque master packer and FA seal assy. - All checked good. Packer was fluid packed and pressured to 240 psi - good test. 17:30 22:30 5.00 0 0 COMPZ WELLPF OTHR T Gather equipment for Seal bore clean up w/ snozzleator. 22:30 00:00 1.50 0 0 COMPZ WELLPF PULD T PJSM- Bring in tools. PU MU wash tool (schnozzleator) w/ 6.625" no -go. Change over floor eqipment. 36/26/2012 RIH with Wash Tool. POOH Run TorqueMaster Packer /Locator tailpipe assembly on 3 -1/2" Drill Pipe. Set and Test Packer. POOH w/ Setting Tool. Prep to Run Completion. RIH 3 -1/2" completion_ w/ Anchor seal- PBR assembly. - -•• _ 00:00 04:00 4.00 0 3,909 COMPZ WELLPFTRIP T RIH with Wash Tool assembly to 3,909 -ft, Kelly up w/ working joint. 04:00 05:00 1.00 3,909 3,921 COMPZ WELLPF CIRC T Bring on pumps 3 bpm, 280 psi, wash down thru FA packer 3,917 -ft and sit down 2k at 3,921 -ft, reciprocate several times thru packer, sit down 4k at 3,921 -ft, pump 1 bpm, getting returns, shut dow pumps, well taking approxiately 5 bph, top of FA packer not sealing with no -go of wash tool. reciprocate thru packer several more time 3 bpm, 280 psi. BDTD 05:00 07:30 2.50 3,921 0 COMPZ WELLPFTRIP T PJSM- POOH with Wash Tool, lay down same. 07:30 08:30 1.00 0 0 COMPZ RPCOM OTHR T Change over floor equipment for running 3 1/2" 8rd Packer completion 08:30 09:30 1.00 0 241 COMPZ RPCOM TRIP T RIH w/ Seal assy for Baker 194 FA Packer and straddle assy, with Torque master packer and setting tool 09:30 11:30 2.00 241 3,917 COMPZ RPCOM TRIP T Change over floor equipment for running 3 1/2" 8rd Packer completion on 3 1/2 DP to 3,917 -ft. Seen slack off of 3.5 k thru tight spot at 383 -ft. 11:30 12:00 0.50 3,917 3,919 COMPZ RPCOM PACK T Locate and insert seals into Baker FA Packer 194 packer at 3,917 -ft to 3,919.05 -ft. 80k up wt, 70k dn wt. Pump down drill string at 1 bpm at 60 psi with returns. Notify Town engineer with results. Pull up to 3,911 -ft. Page 13 of 16 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 3,911 3,911 COMPZ RPCOM OTHR T Wait for town engineers to gather and review objectives w/ AOGCC On 2T -209 we RIH with our seals and packer assembly, stung into the existing FA packer bore and were unable to confirm that the seals are sealing in the packer bore. We TOOH inspected the seals & packer and everything looked good. To make sure the packer bore was clean we ran a clean out run to wash out the packer bore of any possible debris. Again we RIH with the same assembly and still are unable to confirm the seals are engaging. We would like to go ahead and set the TorqueMaster packer to give us a barrier on the annulus but would still have communication between the Tabasco formation and the casing leak that is to a non -oil bearing /productive zone. The CBL indicates that we have competent cement between the two zones. As we discussed you have approval to proceed with setting the upper TorqueMaster packer which will effectively isolate the reservoir and provide an additional barrier. Although the casing leak will not be isolated from the reservoir it is in non productive rock and there is little likelihood of crossflow. It is possible as you said that the FA packer is completely trashed and this upper TorqueMaster packer at 3700, and is now the only isolation on the IA side. 13:00 13:30 0.50 3,911 3,911 COMPZ RPCOM CIRC T Held PJSM, Pump 30 bbls of CI 9.1 ppg Brine and follow w/ 25 bbls of 9.1 ppg brine at 2 bpm at 120 psi. 13:30 14:45 1.25 3,920 3,920 COMPZ RPCOM PACK T Drop ball, Lower seals into FA Packer, close annular, ball on seat. Pressure up to 1,750 psi and set Torque master packer. Pull 25k osw of 80k. PT IA at 2,500 psi for 5 minutes - located visual leak at lock down packing - bleed off IA, then follow with bleeding of the DP. Pressure IA to insure setting tool released, Bleed off pressure. Page 14 of 16 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 15 :00 0.25 3,920 3,689 COMPZ RPCOM OTHR T Pull setting tool from torque master packer - seen slight over pull. Top of Torque Master packer at 3,689 -ft. Pressure up to 4,000 psi with test pump and shear out ball seat in setting tool. 15:00 17:00 2.00 3,689 0 COMPZ RPCOM TRIP P Reveiw PJSM, POOH w/ setting tool on 3 1/2 DP. 17:00 19:00 2.00 0 0 COMPZ RPCOM PULD P PJSM, Prep to run Completion. Pull Wear Ring 19:00 23:30 4.50 0 3,635 COMPZ RPCOM TRIP P RIH w/ 3 -1/2" Tubing completion w/ Anchor seal- PBR assembly to 3635'. Up Weight 63k# and Down Weight 60k #. 23:30 00:00 0.50 3,635 3,635 COMPZ RPCOM CIRC P PJSM. Rig Up and Circulate the Well to 9.1 ppg Corrosion Inhibited Seawater (1% by volume of Baker Petrolite CRW -132) 280 bbls. 4 bpm at 260 psi. 36/27/2012 Land Hanger and Test Packoffs 5000 psi. Test IA to 2500 psi. Shear out SOV. ND BOPs and _NU Tubing Head Adapter and Tree. Freeze Protect Well and Install BPV. Released Nordic 3, RDMO. 80'00 u r.su 1.50 3,635 3,635 ' COMPZ RPCOM CIRC P PJSM. Rig Up and Circulate the Well to 9.1 ppg Corrosion Inhibited Seawater (1% by volume of Baker Petrolite CRW -132) 280 bbls. 5 bpm at 400 psi. 01:30 03:30 2.00 3,635 3,694 COMPZ RPCOM HOSO P RIH and Latch Anchors at 3694', Verify Latch and Shear Off at 33k# over. Retag and Space Out. Up 63k# and Down 60k #. 03:30 05:30 2.00 3,694 0 COMPZ RPCOM HOSO P MU Tubing Hanger and Dummy all Ports. MU Landing Joint, Land Hanger, and RILDS. 05:30 07:30 2.00 0 0 COMPZ RPCOM PRTS P RU Test Equipment- Test Seals to 5000 PSI for 10 minutes, OK. RD Test Eq 07:30 10:00 2.50 0 0 COMPZ RPCOM PRTS P PJSM, Drop Ball and Rod, PT tubing casing 2500 psi, SOV, monitor well, static. 10:00 10:30 0.50 0 0 COMPZ RPCOM HOSO P PJSM, BOLJ, set TWC 10:30 11:00 0.50 0 0 COMPZ RPCOM PRTS P R/U Hoses, Pressure Test TWC in Direction of Flow to 1000 psi, OK 11:00 12:30 1.50 0 0 COMPZ RPCOM NUND P PJSM, ND BOPs 12:30 14:00 1.50 0 0 COMPZ RPCOM NUND P PJSM, N/U Tree 14:00 16:30 2.50 0 0 COMPZ RPCOM PRTS P PJSM, PT Packoffs/Tree to 250/5000 psi. OK 16:30 17:00 0.50 0 0 COMPZ RPCOM THGR P Pull TWC 17:00 19:00 2.00 0 0 COMPZ RPCOM FRZP P PJSM, Freeze Protect Well at 2 BPM at 400 psi, 136 bbls 19:00 20:00 1.00 0 0 COMPZ RPCOM FRZP P Let Diesel U -tube 20:00 21:30 1.50 0 0 COMPZ RPCOM THGR P PJSM, Install BPV w /Lubricator, Dress Tree 21:30 22:30 1.00 0 0 COMPZ RPCOM RURD P PJSM, Split Drill Pipe in Derrick and Secure Page 15 of 16 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 0 0 COMPZ RPCOM MOB P Released Nordic Rig @ 00:00 hrs on 6- 28 -12. RDMO Nordic 3 Page 16 of 16 • • SICATIE DEF A[LAZIA 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 Ian Toomey 3 Wells Engineer ConocoPhillips Alaska, Inc. 1 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tabasco Oil Pool, 2T -209 Sundry Number: 312 -234 Dear Mr. Toomey: St.-MINED in 0 5 ',/-01 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, Cathy • . Foerster Chair, Commission DATED this Ay of June, 2012. Encl. • STATE OF ALASKA O 6 /z / j ALIA OIL AND GAS CONSERVATION COMMI•N � ii 6 • zg. 12... � .- 1 APPLICATION FOR SUNDRY APPROVALS - . 11--- 20 AAC 25.280 L Z 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell Change Approved Program r Suspend r Flug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other:Straddling a Casing Leak jai' . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development I' • Exploratory r 198 -243 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20281 -00 • 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 [ No 17 2T -209 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25569 • Kuparuk River Field / Tabasco 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): 4690 • 3318 ' 4690' 3318' Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 16 112' 112' SURFACE 4045 9.625 4082' 3002' RECEIVED LINER 751 4.5 4680' 3313' JUN 2 a 2012 AOGCC Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 'Tubing MD (ft): slotted liner 3929' -4680' 2917' -3313' 4.5 L -80 _ 3846 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER MODEL 'FA' RETRIEVABLE PACKER MD= 3915 TVD= 2909 PACKER - SC -1 GRAVEL PACK PACKER MD =3929 TVD =2917 NO SSSV 12. Attachments: Description Summary of Proposal l✓ 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r ' Exploratory Development f Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/25/2012 Oil i✓ Gas f WDSPL r Suspended r 16. Verbal Approval: Date: 6/22/2012 WINJ r GINJ r WAG fl Abandoned r Commission Representative: Guy Schwartz GSTOR 1 SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ian Toomey @ 263 -4773 Printed Name Ian Toomey Title: Wells Engineer Signature l -`---- ^ — Phone: 263 -4773 Date C, - 2 I - "Z Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3l) - 3q Plug Integrity r BOP Test 1j,"Mechanical Integrity Test r Location Clearance r Other: h02-50 DS c.- gC ,G Subsequent Form Required: / b — 4 / d APPROVED BY -� ® ,'1./ Approved by: ,P COMMISSIONER THE COMMISSION Date:6 •- 2�O — n Form 10 -403 R vised 1/2010 G 1 N A si813MS-- JUN 2 9 2012 ' S It' pli to 7'� • i 2T -209 Capital Rig Workover (PTD #: 198 -243) Current Status The rig workover plan was to pull the current ESP assembly, install a new 3 -1/2" completion with Premier packer to • preserve the wellbore for future development opportunities while providing a second barrier to the formation in this single casing producer. During the RWO we successfully pulled the ESP completion. As we were attempting to RIH with a test packer assembly to test the integrity of the 9 -5/8" casing we tagged up at 419' RKB. We then set an IBP at 3880' RKB and failed a pressure test on the 9 -5/8" casing. A caliper run and leak detect log determined there was a casing restriction at 380' RKB and a casing leak at 3770' RKB. Using swedges we were able to open up the casing restriction in order to get our packer down to the desired depth. We ran and set a test packer at 3701' RKB and passed a pressure test on the 9 -5/8" casing to 1500 psi. Scope of Work Our plan forward is to complete this well by stabbing a seal assembly into the existing FA packer at 3915' RKB and • setting a TorqueMaster packer at 3700' RKB thus straddling the leak. Then run back in with the TorqueMaster production anchor and a PBR to finish the completion. General Well info MASP: 1034 psi (utilizing 0.1 psi /ft gas gradient and SBHP listed below) Reservoir pressure /TVD: 1348 psi at 4341' MD (3142' TVD) calculated from Baker Sentry Gauge Wellhead type /pressure rating: FMC Gen IV, 11" 5K btm x 11" 5K top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams Well Type: Producer Estimated Start Date: June 25, 2012 Production Engineer: Mike Balog / Deanna van Dam Workover Engineer: Ian Toomey (263 - 4773 / Ian .A.Toomey @conocophillips.com) Proposed Procedure 1. MU and RIH with the TorqueMaster packer assembly on DP: . 2. Continue RIH to the top of the Baker FA packer at 3915' RKB. S'e A 14S 3. Spot corrosion inhibited seawater on the backside. 4. Slowly slack off until fully located, PU to neutral weight, and drop the setting ball down the DP. 5. Once ball is on seat, set the TorqueMaster Packer. 6 Pressure test the annulus and TorqueMaster packer to 2500 psi for 5 minutes. Bleed off the pressure. 7. Release setting tool and POOH tool laying down DP and lay down setting tool. 8. MU and RIH with TorqueMaster Production Anchor, PBR, and completion on 3 -1/2" tubing 9. RIH to just above the TorqueMaster Packer. Circulate the well to corrosion inhibited seawater. 10. Slack off slowly and land the TorqueMaster Anchor into the TorqueMaster Packer. 11. PU to ensure anchor is latched into the packer, continue picking up to shear out the seal assembly from the PBR. 12. Slowly slack off until fully located, PU to neutral weight and mark the pipe. Space out with pups. • 13. MU tubing hanger. Dummy off all ports; ESP, heat trace, I -wire and control line ports (if present). 14. MU landing joint, land the tubing hanger, and run in all LDS. PT hanger packoffs to 5000 psi. 15. Drop ball and rod. — Proposed RWO Procedure Continued - 16. With the annulus open, PT 3 -1/2" tubing to 2500 psi. Monitor the annulus for returns. Bleed the tubing pressure down to 2000 psi. While holding 2000 psi on the tubing, PT the IA to 2500 psi for 30 minutes and record on chart. 17. Bleed IA to 0 psi, bleed tubing to 0 psi. Ramp up the IA pressure to shear the SOV (2000 psi csg -*tbg differential required). Monitor the well for 30 minutes. 18. Back out the landing joint and wash out the BOP stack. Drain the BOP stack and lay down the landing joint. Install two -way check. Pressure up on the annulus to 1000 psi to test the TWC in the direction of flow. Verify barriers in place. 19. ND BOP, NU tubing head adapter and tree. PT tree to 250/5000 psi. PT the hanger void/packoffs to 250/5000 psi. 20. Pull two -way check. 21. Freeze protect the well. Set BPV. 22. Pressure up on the IA to 1000 psi to test the BPV from below. Bleed IA to 0 psi. 23. RDMO Nordic 3. 24. Turn well over to operations. Post -Rig Work request: 1. Pull BPV. 2. RU HES Slickline: a. Conduct PJSM. b. Pull ball and rod. c. Pull SOV from GLM #1. d. Run DV in GLM #1. e. Pull RHC plug body from DS nipple 3. RDMO HES Slickline. 4. Turn well over to operations. C�n�coPhillip? • 2T 209 - - 500' MD, 2.875" DS Nipple 112' MD, 16" 62.5 #, H -40 3 -1/2" 9.3 #, L -80, 8rd EUE -Mod 11111 -2918' MD, Camco MMG GLM Existing Proposed f-- -3670 MD, Camco MMG GLM PBR * Baker TorqueMaster Production Anchor -3700' MD, Baker TorqueMaster Packer -Al- -3730' MD, 2.813" DS Nipple 3770' MD, Leak in the 9 -5/8" casing 3915' MD, Baker Model FA Production Packer Locating Seal Assembly 3922' MD, Knockout Isolation Valve d 3930' MD, SC -1 Gravel Pack Packer I 1 4082' MD, 9 -5/8" 40 #, L -80 -- Gravel Pack Screens —1 ' 2T -209 ,.. KUP • Conoco Phillips u ' Well Attributes Max Angle & MD TD Alaska Ir1C Wellbore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) ca.gcaPhdkp 501032028100 TABASCO PROD 61.05 2,645.18 4,690.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date - SSSV: NONE 450 1/11/2009 Last WO: 2/13 /2002 36.00 12/22/1998 Well Cantu. -2T -209, 5/29201210:57:51 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 4,500.0 11/9/1999 Rev Reason: GLV C/O ninam 5/29/2012 HANGER, 29 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd CONDUCTOR 16 15.062 37.0 112.0 112.0 62.58 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.697 37.5 4,082.1 3,001.5 40.00 L - 80 ETC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 4.623 3.548 3,928.9 4,680.0 3,313.1 11.60 L -80 SLHT CONDUCTOR, Liner Details 37 -112 Top Depth (TVD) Top Intl Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 3,928.9 2,916.8 56.46 PACKER BAKER SC -1 Gravel Pack Packer (old) 4.750 3,934.0 2,919.6 56.45 EXTENSION 3.548 3,938.8 2,922.2 56.44 SLEEVE BAKER Gravel Pack Sliding Sleeve (old) 4.875 3,941.0 2,923.4 56.44 SBE BAKER SEAL BORE 4.750 3,941.7 2,923.9 56.44 EXTENSION 3.548 ESP 3,962.2 2,935.2 56.41 KOIV BAKER B-KOIV VALVE (old) 3.437 MANDREL, 2,133 3,963.8 2,936.1 56.40 XO Reducing 3.428 _:: 4,038.6 2,978.0 57.28 SCREEN BAKERWELD Gravel Pack Screen (old) 3.548 4,668.1 3,307.1 59.60 0 -RING BAKER 0 -RING w /seal lock 2.375 4,669.3 3,307.7 59.60 Flapper VLV BAKER FLAPPER VALVE 2.875 ESP MANDREL, 4,670.91 3308.51 59.60IFIapper VLV (BAKER FLAPPER VALVE 1 2.875 3,5118 allil Tubing Strings Tubing Description ' 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVG) .. String Wt... String... String Top Thrd ill ESP TUBING 1 4 1/2 I 3,958 I 28.6 I 3,845,8 l 2,871.5 I 12,60 L -80 BTCM IF Completion Details Top Depth SLEEVE -C, (TVD) Top Inc' Semi... 3,710 Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) IL 28.6 28.6 0.00 HANGER FMC TUBING HANGER 4.500 all 3,710.0 2,798.6 57.82 SLEEVE -C BAKER CMU SLIDING SLEEVE (CLOSED) 3.810 GAUGE, 3,751 , 3,751.4 2,820.7 57.66 GAUGE BAKER SENTRY GAUGE mounted outside of tubing 3.958 3,756.0 2,823.2 57.64 PUMP C -LIFT 44KC 12000 PUMP KPHVMTAR 3,773.8 2,832.7 57.57 PUMP C -LIFT 15KC 2000 PUMP KPHVLTAR PUMP, 3,755 4 3,783.0 2,837.6 57.53 SEAL ASSY C -LIFT GST3 CL -5 SEAL ASSEMBLY "- 3,796.7 2,845.0 57.48 MOTOR/kmhl C -LIFT 266 HP KMH 1660/98A MOTOR PUMP, 3,773 Y � PUMP, 3,774 ice. 3,819.7 2,857.4 57.38 MOTOR/kmhu C -LIFT 304 HP KMH 1900/98A MOTOR V \, Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING Original 8.435 6.000 3,915.3 3,928.0 2,916.3 SEAL ASSY, 3,783 Completion Details MOTORIkehI, Top Depth 3,797 - �, (TVD) Top Inc' Nomi... MOTOR/kmhu, - i Top (ftKB) IRKS) ( °) Item Description Comment ID (in) 3,820 i. - ..:, 3,915.3 2, 909.2 56.48 PACKER BAKER MODEL 'FA' RETRIEVABLE PACKER 6.000 _ 3,921.8 2,912.9 56.47 KOIV KNOCKOUT ISOLATION VALVE 4.000 PACKER, 3,915 3,923.9 2,914.0 56.46 XO BUSHING CROSSOVER BUSHING 3.998 Ili 3,926.6 2,915.5 56.46 WLEG WIRELINE RE -ENTRY GUIDE 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (ND) Top Inc! KOIV, 3,922 Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) ,•t�= 3,773 2,832.3 57.57 PUMP C - LIFT 15KC20000 KPHVLTAR 2/9/2002 XO BUSHING, ., . 3,924 Notes: General & Safety End Date Annotation 12/13/2010 NOTE: Top of gravel pack SC - 1 Packer @3929 WLEG, 3,927 12/13/2010 NOTE: top of Baker Model 194 FA 75x60 @3915, muleshoe is @3928 which is 1 ft inside the top of pkr 12/13/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Alt Mandrel Details Top Depth Top Port (ND) !not OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... p- 1 1 2,133.3 1,991.4 50.07 CAMCO MMG 1 1/2 ESP DMY RK 0.000 0.0 2/9/2002 I 4 2 3,505.9 2,696.0 60.21 CAMCO MMG 1 1/2 ESP OPEN 0.000 0.0 5/28/2012 SURFACE, Y' ' 3F ( aka LINER. 3,929 -4,880 TD, 4,890 • • Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, June 26, 2012 1:44 PM To: 'Toomey, Ian A' Subject: RE: 2T -209 (PTD 198 -243) Ian, As we discussed you have approval to proceed with setting the upper TorqueMaster packer which will effectively isolate the reservoir and provide an additional barrier. Although the casing leak will not be isolated from the reservoir it is in non productive rock and there is little likelihood of crossflow. It is possible as you said that the FA packer is completely trashed and this upper TorqueMaster packer at 3700' and is now the only isolation on the IA side. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Toomey, Ian A [mailto: Ian .A.Toomey @conocophillips.com] Sent: Tuesday, June 26, 2012 1:11 PM To: Schwartz, Guy L (DOA) Subject: 2T -209 Guy, On 2T -209 we RIH with our seals and packer assembly, stung into the existing FA packer bore and were unable to confirm that the seals are sealing in the packer bore. We TOOH inspected the seals & packer and everything looked good. To make sure the packer bore was clean we ran a clean out run to wash out the packer bore of any possible debris. Again we RIH with the same assembly and still are unable to confirm the seals are engaging. We would like to go ahead and set the TorqueMaster packer to give us a barrier on the annulus but would still have communication between the Tabasco formation and the casing leak that is to a non -oil bearing /productive zone. The CBL indicates that we have competent cement between the two zones. Regards, Ian Toomey Wells Engineer ConocoPhillips Alaska, Inc. Office: 907.263.4773 Cell: 907.903.3987 6/26/2012 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 25, 2012 �� E' �� Commissioner Dan Seamount JUN 2 5 State of Alaska 2 012 Alaska Oil & Gas Conservation Commission /� ®�� 333 West 7 Avenue Suite 100 �"1 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2T-209 (PTD 198 -243). Well 2T -209 was drilled in December 1998 and completed in February 1999 as a vertical Tabasco producer with ESP completion. The well was started on ESP production in March 1999. The initial tubing conveyed (TC -ESP) pump was in service until October 2001. A RWO in February 2002 was required to repair the failed ESP. Well 2T -209 was returned to production with TC -ESP, until it was shut -in June 2009 • for high water cut. The purpose of the workover on 2T -209 (single casing well) was to install a second barrier to comply with the new CPAI policy which dictates that we must have two barriers between any energized fluid and the atmosphere. Originally the well was designed as single- casing packerless ESP wells, which meant only one barrier between the reservoir and the atmosphere. The rig workover plan was to pull the current ESP assembly, install a new 3 -1/2" completion with Premier packer to preserve the wellbore for future development opportunities while providing a second barrier to the formation in this single casing producer. During the RWO we successfully pulled the ESP completion. As we were attempting to RIH with a test packer assembly to test the integrity of the 9 -5/8" casing we tagged up at 419' RKB. We then set an IBP at 3880' RKB and failed a pressure test on the 9 -5/8" casing. A caliper run and leak detect log determined there was a casing restriction at 380' RKB and a casing leak at 3770' RKB. Using swedges we were able to open up the casing restriction in order to get our packer down to the desired depth. We ran and set a test packer at 3701' RKB and passed a pressure test on the 9 -5/8" casing to 1500 psi. Our plan forward is to complete this well by stabbing a seal assembly into the existing FA packer at 3915' RKB and setting a TorqueMaster packer at 3700' RKB thus straddling the leak. Then run back in with the TorqueMaster production anchor and a PBR to finish the completion. If you have any questions or require any further information, please contact me at 263 -4773. Sincerely, Ian Toomey Wells Engineer CPAI Drilling and Wells • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, June 22, 2012 1:33 PM To: Toomey, Ian A Subject: Re: 2T -209 straddling leak Ian, Thanks for schematic... You have verbal approval to proceed as outlined below by adding additional packer to straddle casino leak. Submit sundry as soon as you can. Guy Sent from my iPhone On Jun 22, 2012, at 1:17 PM, "Toomey, Ian A" < Ian .A.Toomey @conocophillips.com> wrote: > Guy, > Here is the current schematic and a drawing with the proposed completion straddling and isolating the leak in the 9 -5/8" casing. Let me know if you have any questions. > Regards, > Ian Toomey > Wells Engineer > ConocoPhillips Alaska, Inc. > Office: 907.263.4773 > Cell: 907.903.3987 • From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] • Sent: Friday, June 22, 2012 11:36 AM • To: Toomey, Ian A • Subject: [EXTERNAL]RE: 2T -209 straddling leak • Ian, • After some more thought the well should have a sundry now to document the casing leak and get Commission approval to repair. Send me a schematic of your proposed new completion and repair and I will get you a verbal so you can continue operations over the weekend. • Guy Schwartz • Senior Petroleum Engineer > AOGCC > 793 -1226 (office) • 444 -3433 (cell) > From: Toomey, Ian A [mailto: Ian .A.Toomey @conocophillips.com] • Sent: Friday, June 22, 2012 11:10 AM > To: Schwartz, Guy L (DOA) > Subject: 2T -209 straddling leak > Guy, • Well 2T -209 was drilled in December 1998 and completed in February 1999 as a vertical Tabasco producer with ESP completion. The well was started on ESP production in March 1999. The initial tubing conveyed (TC- ESPCP) pump was in service until October 2001. A RWO in February 2002 was required to repair the failed ESP. Well 2T -209 was returned to production with TC- ESPCP, until it was shut -in June 2009 for high water cut. :> The purpose of the workover on 2T -209 (single casing well) was to install a second barrier to comply with the new CPAI policy which dictates that we must have two barriers between any energized fluid and the atmosphere. Originally the well was designed as single- casing packerless ESP wells, which meant only one barrier between the reservoir and 1 the atmosphere. • > The rig workover plan was to pull the current ESP assembly, install a new 3 -1/2" completion with Premier packer to preserve the wellbore for future development opportunities while providing a second barrier to the formation in this single casing producer. > During the RWO we successfully pulled the ESP completion. As we were attempting to RIH with a test packer assembly to test the integrity of the 9 -5/8" casing we tagged up at 419' RKB. We then set an IBP at 3880' RKB and failed a pressure test on the 9 -5/8" casing. A caliper run and leak detect log determined there was a casing restriction at 380' RKB and a casing leak at 3770' RKB. Using swedges we were able to open up the casing restriction in order to get our packer down to the desired depth. We ran and set a test packer at 3701' RKB and passed a pressure test on the 9 -5/8" casing to 1500 psi. > Our plan forward is to complete this well by stabbing a seal assembly into the existing FA packer at 3915' RKB and setting a Premier packer at 3700' RKB thus straddling the leak. As per our discussion, COP will not be required to submit a 10 -403 sundry application before proceeding ahead with operations. A casing repair like the straddle assembly to be run in this well would normally require a 10 -403 submittal. In this case you have requested that we only submit a 10 -404 after the completion of the job. > Please reply back with your concurrence of this path forward. Let me know if you need additional information or have any questions. > Regards, > Ian Toomey > Wells Engineer > ConocoPhillips Alaska, Inc. > Office: 907.263.4773 > Cell: 907.903.3987 > <Visio- 2T- 209.pdf> > <2T -209 schematic.pdf> 2 • • Page 1 of 1 Schwartz, Guy L (DOA) From: Toomey, Ian A [ Ian .A.Toomey @conocophillips.com] Sent: Friday, June 22, 2012 11:10 AM To: Schwartz, Guy L (DOA) b 7 Subject: 2T -209 straddling leak Guy, Well 2T -209 was drilled in December 1998 and completed in February 1999 as a vertical Tabasco producer with ESP completion. The well was started on ESP production in March 1999. The initial tubing conveyed (TC- ESPCP) pump was in service until October 2001. A RWO in February 2002 was required to repair the failed ESP. Well 2T -209 was returned to production with TC- ESPCP, until it was shut -in June 2009 for high water cut. The purpose of the workover on 2T -209 (single casing well) was to install a second barrier to comply with the new CPAI policy which dictates that we must have two barriers between any energized fluid and the atmosphere. Originally the well was designed as single- casing packerless ESP wells, which meant only one barrier between the reservoir and the atmosphere. The rig workover plan was to pull the current ESP assembly, install a new 3 -1/2" completion with Premier packer to preserve the welibore for future development opportunities while providing a second barrier to the formation in this single casing producer. During the RWO we successfully pulled the ESP completion. As we were attempting to RIH with a test packer assembly to test the integrity of the 9 -5/8" casing we tagged up at 419' RKB. We then set an IBP at 3880' RKB and failed a pressure test on the 9 -5/8" casing. A caliper run and leak detect log determined there was a casing restriction at 380' RKB and a casing leak at 3770' RKB. Using swedges we were able to open up the casing restriction in order to get our packer down to the desired depth. We ran and set a test packer at 3701' RKB and passed a pressure test on the 9 -5/8" casing to 1500 psi. Our plan forward is to complete this well by stabbing a seal assembly into the existing FA packer at 3915' RKB and setting a Premier packer at 3700' RKB thus straddling the leak. As per our discussion, COP will not be required to submit a 10-403 sundry application before proceeding ahead with operations. A casing repair like the straddle assembly to be run in this well would normally require a 10-403 submittal. In this case you have requested that we only submit a 10-404 after the completion of the job. Please reply back with your concurrence of this path forward. Let me know if you need additional information or have any questions. Regards, Ian Toomey Wells Engineer ConocoPhillips Alaska, Inc. Office: 907.263.4773 Cell: 907.903.3987 6/22/2012 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 27, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool /Leak Detect Log/CAST -M: 2T -209 Run Date: 6/20/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -209 Data in LAS format, Digital Log Image files 1 CD Rom 50 -103- 20281 -00 CASE Log 1 Color Log 50- 103 - 20281 -00 �u �.�. NED toR 2 7 ? ACE Log � 1 Color Log 50 -103- 20281 -00 CAST -M Field print 1 Color Log 50- 103 - 20281 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: Signed: ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 1, 2010 r, ~; „, ~Ir +~- ` _ ~~ Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ~~g_~~s 2-T- aoy RECElbEG ~~~~~~ ~ zo~cj Al~s~ra ~//G~~~~~ ~55~gqa))r-~~~y. ~~m Pe 1l4~11'I iS~C+ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped. July 21St. The corrosion inhibitor/sealant was pumped July 30th, 31St 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8101/10 ~R ~K ~r aen Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2B-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7/31!2010 2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7/31/2010 2K-20 50103201200000 1891180 10" n/a 10" n/a 2 7/31/2010 2K-23 50103201250000 1900140 SF n/a 18" n/a 2.6 7/31/2010 2K-24 50103201220000 1891300 SF n/a 18" n/a 2.6 7/31/2010 2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010 2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7/30/2010 2T-20 50103202150000 1950290 SF n/a 23" n/a 2.6 7/30/2010 2T-21 50103202120000 1950130 SF n/a 21" n/a 3.4 7/30/2010 2T-26 50103202230000 1950820 SF n/a 27" n/a 4.3 7/30/2010 2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7/30/2010 2T-30 50103202190000 1950570 SF n/a 30" n/a 6 7/30/2010 2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7/30/2010 2T-36 50103202280000 1951020 SF 0.40 12" 7/21/2010 2.6 7/30/2010 2T-39 50103203920000 2011830 30" 0.54 14" 7/21/2010 4.3 7/30/2010 2T-201 50103202300000 1951220 60" 1.57 32" 7/21/2010 7.7 7/30/2010 2T-204 2T-209 50103203270000 50103202810000 2000160 1982430 SF 40" n/a 1.20 24" 19" n/a 7/21/2010 5.1 4.8 7/31/2010 7/31/2010 2T-218 50103204490000 2030170 31" 0.73 9" 7/21!2010 2.6 7/31/2010 2T-220 50103202830000 1982530 38" 0.49 19" 7/21/2010 5.1 7/31/2010 I~/ELL LOfs TRANSIt~f TTAL ,,. PROACTIVE DIACINOSIIC SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTV The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Magnetic Thickness Tool 16 Apr`10 2T-209 1 Report 50-103-20281-00 2) ~~~ -a~ .~ Signed Print Name: ':. 7l1~ is r 41 ''~. ~.f~i . -~ Date ; MAY 1 t 2010 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : QdsanchoraaeCa~memorvlog.com WEBSITE : www.melnorylog.com C:\Documents and Settings\Dia~~e Williams\Desktop\Transmit_Conoco.docx • • Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2T-209 Log Date: April 16, 2010 Field: Tobasco Log No.: 10624 State: Alaska Run No.: 2 API No.: 50-103-20281-00 Pipet Desc.: 4.5" 12.6 Ib. L-80 BTCM Top Log Intvl1.: Surtace Pipet Use: Tubing Bot, Log Intvl1.: 213 Ft. (MD) Pipet Desc.: 9.625" 40 Ib. L-80 BTC Top Log tntvl1.: Surtace Pipet Use: Surtace Casing Bot. Log Intvll.: 213 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl1.: Surface Pipe3 Use: Conductor Bot. Log Intvl1.: 78 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This MTT data is tied into the Mandrel Hanger ~ 0' Depth. This is the second time this welt has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total metal thickness of the 4.5" tubing and 9.625" casing, with some influence from the 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20 fpm, with the 5Hz and 10Hz passes selected for analysis in this report. ' COMPARISON TO PREVIOUS MTT LOG RESULTS (Surface - 213'1 A log plot overlay of the current 5Hz and 10Hz passes, and the previous 10Hz pass (October 14, 2007) from surface to 213' is included in this report. This plot indicates an area of possible significant metal loss over the ' interval (11' - 30'). Both 5Hz and 10Hz MTT recordings indicate a ~11 % circumferential metal loss in this interval, similar to the metal loss indicated in the previous log recorded at 10Hz (~-10°k cLD 20'). The reduction of the recording frequency from 10Hz to 5Hz enables the signal to permeate metal further from ' the tool. Therefore the inverted tool responses in the 10Hz passes in areas of known additional metal are not observed in the current 5Hz pass. These areas of additional metal include all the 9.625" casing collars, as well as the interval (40' - 60') in the conductor pipe, which showing less metal volume in the previous log ' than the current log. The fact that the 5Hz pass does not exhibit any inverted response over the interval (65' - 76') leads us to believe the possible metal loss reported over the interval (11' - 30') is not an inverted response of the tool. ' INTERPRETATION OF MTT LOG RESULTS ' The MTT log results cover the interval 0' - 213'. Changes in metal volume are relative to the calibration points at 52' and 200', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 4.5" tubing, 9.625" casing and 16° conductor pipe. A comparison log plot of the individual MTT sensor readings at 5Hz and 10Hz is included in this report, along with an overlay of the assessed average metal thickness (%} from both passes. In the interval of possible ' significant metal loss (11' - 30'), indications of isolated metal loss appear to be more pronounced in the 5Hz pass than the 10Hz pass. Further examination of the characteristic of the current and the previous log passes supports the likelihood that the metal loss in this interval could be the result of damage to the casing. 1 ,~~s-au3 i • Indications of isolated metal loss are recorded by the MTT throughout the logged interval in both 5Hz and 10Hz passes. A log plot of the entire 5Hz pass is included in this report. Below the conductor, there are many areas indicating isolated metal loss events on individual sensors, but no indications of any areas of substantial overall volumetric metal loss. A maximum ~11 % circumferential metal loss is indicated in the interval between 11' - 30' in the 5Hz pass. A maximum ~7°~ circumferential metal loss is indicated in the interval between 36' - 48' in the 5Hz pass. A maximum ~6°~ circumferential metal loss is indicated in the interval between 55' - 60' in the 5Hz pass. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 4.5", 9.625" and 16" pipe. If all of the metal loss is specific to the 9.625" casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Field Engineer: G. Efherton Analyst: HY. Yang/J. Burton (MTT) Witness: C. Kennedy A o`~MwE`~s Compari~n - Current 5Hz and 10Hz t~revious 10Hz Overla Q` ~~; 2T-209 (Surface to 213'} t` vew\crivc Di,~r°sric Scaviccs April 16, 2010 and October 14, 2007 Database File: d:lwarriorldata\2t-2091comparison.db Dataset Pathname: comparison Presentation Format: comps Dataset Creation: Thu Apr 22 11:19:21 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2010 (5Hz) (%) 50 -50 Delta Metal Thickness 2010 (10Hz) (%) 50 -50 Delta Metal Thickness 2007 (10Hz) (~°) 50 0 r--r---~-~ Metal Thickness 2007 (1 ~1- (Inverted Respon: 20 Metal Thickness 2~-0-0-7t-a-n--d~2-0-1~0- (Inverted Response; Delta Metal fi0 Delta Metal Thickness 2010 (1 I I I Metal Thickness 2007 (10Hz) Metal Thickness 2010 Metal Thickness 2010 Metal Thickness 2010 (Inverted Response Bottom of 1I6" Conduc SO ~T"TTT • 100 Delta Metal 120 140 rnerted Metal Thickness 2007 and 2010 (1 180 180 Delta Metal Thickness 2007 (Inverted Respc 200 Delta Metal Thickness 2010 (5Hz) ~ -~ ~ ' ' ' ' T i i i Delta Metal Thickness 2010 (10Hz}_ End of 2010 L Delta Metal Thickness 2007 (10Hz) -50 Delta Metal Thickness 2010 (5Hz) (%) ~ -50 Delta Metal Thickness 2010 (10Hz) (%) 50 -50 Delta Metal Thickness 2007 (10Hz) (%) 50 ot~,MWelts pF ~ Comparison - 5Hz & 10Hz~TT Passes Qa °~ 2T-209 April 16, 2010 PnoAcrivc Dinyn°sric Scaviccs Database File: d:lwarrior\datal2t-209\5hz&10hz comparison.db Dataset Pathname: merge Presentation Format: 1.8&2.6 Dataset Creation: Thu Apr 22 19:33:12 2010 Charted by: Depth in Feet scaled 1:480 1.8 MTTP01 (5Hz) 11.8 2.6 MTTP01 (10Hz) 12.6 -20 5Hz Delta Mtl. Thickness (%) 20 -7 MTTP12 (5Hz) 3 -6.2 MTTP12 (10Hz} 3.8 -20 10Hz Delta Mtl. Thickness (%} 20 a Pass Delta Metal 10Hz Delta Metal 100 Pass Dat-1 mar-rr~r-Q~--ii ~ 10Hz 200 1.8 MTTP01 (5Hz) 11~ 2.6 MTTP01 (10Hz) 7 MTTP12 {5Hz) 3 -6.2 MTTP12 (10Hz) 12.6 -20 5Hz Delta Mtl. Thickness (%) 20 3.8 -20 10Hz Delta Mtl. Thickness (%} 20 o~`'MwEusAR Receded Magnetic Thickness L~Data - 5Hz Pass ¢~ `~~ 2T-209 April 16, 2010 PROACTIVE DIATIROSTIC SERVICES Database File: d:\warrior\datal2t-20915hz dawn pass.db Dataset Pathname: SHzDn Presentation Format: 1.8 scale Dataset Creation: Thu Apr 22 14'03:32 2010 Charted by: Depth in Feet scaled 1:150 ' -50 Delta Metal Thickness (%) 50 1.8 0 Line Speed (ft/min) 200 -7 Tree ' Line Spee Hanger ~~ Tubin Colla Ita Metal Thickness Isc Tubing Jt. 1 ' 11 % Metal Loss 20 ' Tubing Collar ~~ ' asing Collar ~ 7% Metal Loss ' Tubing Jt. 2 ' 6 % M eta l Lo ss 60 , ' Tubing Co llar ~~ ' Casing Co llar Bo ttom of 15' Cond uctor; 80 Tubing Jt. 3 ' MTTP01 MTTP12 Metal Loss I solated Metal Loss Metal Loss I 11.8 3 Metal Loss Indication ~ Tubin Col lar ' 1~ Tubing Jt. 4 ' asin Col lar 120 ' ' Tubin Co llar ~' 3% Metal Loss 140 Tubing Jt. 5 Casin Collar ' Tu bing Co llar ~~ 160 t Tubing Jt. 6 180 ' u bin ~ Collar ~~ asing Collar Delta Metal Thickness 200 Tubing Jt. 7 ' 3% Metal Loss ' Line Spee ' -50 Delta Metal Thickness (%) 50 1.8 0 Line Speed (ft/min} 200 -7 Loss Indications Metal Loss Loss Indications Metal Loss MTTP01 11.8 MTTP12 3 ConocoF'hillips A4wke, Ins:. 2T-209 ._. ESP TUBING DETAIL 4.112" '1(' Block ESP Completion PHILLIPS ALASKA. INC. 2T Z09 DATE: 021681oZ 1 OF i PAGE3 # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Nordic RT to LDS 28.60 28.80 WGR FMC Tb .Han r w/ 5" RH Acme Thread w/ 1,6' Pu 4.10 28.60 68 Jts Jts #53 -120 4'/: x 12.6# x L-80 x IBTC MOD Tb Z094.8t3 32.70 u Pu Jt 4'h x 12.8# x L-80 x IBTC MOD 5.74 2'!27.56 GLM` Camco MMG 4.5 x 1.5" GLM W/ DGLV installed RK Latch 8.67 2133.30 u Pu Jt 4'/s x 12.6# x L-80 x IBTC MOD T 5.83 2141.97 44 Jts Jts #9 - S2 4Y~ x 128# x L-80 x IBTC MOD 1352.34 2147.80 u Pu Jt 4'/s x 12.6# x L-80 x IBTC MOD Tb 5.74 3500.14 GLM Camco MMG 4.5 x 1.5" GLM Wl DGLV installed RK Latch 8.68 3505.88 u Pu Jt 4'/s x 12.61E x L-80 x #BTC MOD Th 5.83 3514.56 6 is Jts #3 - 8 4'/: x 12.6# x L-80 x IBTC MOD Tb 183.89 3520.39 u Pu Jt 4'/z x 12.E x L"80 x IBTC MOD Tb 5.71 3704.28 1 std. Stv eaacer "CMU" dialing Sleeve {Closed Position} Ic>=s.81" DB Profile 4.67 3709.99 u Pu Jt ~L'/a x 12.8# x L-80 x IBTC MOD 5.71 3794.E 1 J# Jt #2 4'/z x 12.8# x L~$0 x IBTC MOD Tb 31 Al 3720.37 XO Pu 4.5" IBTC x 4.3" NSCT L-80 Sentu Ga a 3749 and / 2820" tvd 3.10 3751.38 XO Pu 4.5" NSCT x 3.5" 8rd x 8 Cr Material 1.55 3754.48 C-Llft Pum 44KC12000 KPNVMTAR Sr# 01 K-~909 17.79 3758.03 C-Lift P~tm 15KC20000 KPWYLTAR SrAI 01K-89908 9,13 3773.82 C-Lift GST3 CL-S Seri Ass . Sr# 31G"73728 / 73728 13.78 3782.95 Glift 304 HP KMHU 1660/98ASr# 21K59608 23.Oi 3796.?3 ca-ift 266 HP I(lIOHL 1SOO/S6A Sig 27K'.~606 vtrl Dent [/.5'~ on bottom 28.09 3819.74 Total aom nent column 8 Bottom of Motor 3845.83 3845.83 S lice location is on t #105 21' from box end Baker Mod FA Rat Paker size 104 FATS ro # 413-0 2.65 3915.28 "B" aide 5.5" LTi~C Box down 1.15 3917.83 XO m #498.41 IDIOD 5,55 ! 4.902" 2.00 3919.08 X Sub Pro # 298-69 iD/OD 5.88/4.27' drifted to 4.151 .76 3921.08 Knockout isolation Va1veOD/iD 8.37 14.OO/Drft 3.85 when in lace 2.01 3921.84 XQ Bushin OD/ID 5.62!3998" ro# 494015193 .65 3923.85 XO Pu OD/iD 4.531394 d'# 494024671 2.13 3924.50 t WLRG ODlID 4.98/3,875 Pro#169-71 1.37 3926.63 3928.00 Note to of Baker Mode1194 "FA" 75 x BO 391 mule shoe Is 3928` whic h is 1 ft inside the to of SC7 Pkr 81 ft above stack out. Note To of~~Baker " ravel Pads" SC • 1 Packer 3929 Gannon Clam s - 64, SS Bands 17, 2 Flat ards, & 3 rotecterlizers. rcematxs: stung W819nts [all Mar, tJ6CKK8!'jWith BIOGKS: 70tC~f Up, 55titF Dn. Z3KiF BlOGKB. tzars '1711 jomtS t]t Drift~i tubing, GLM. 8 hanger with 4.151" Dlastic rabbit. Used Arctic Grade API Modified No Lead tnresa rompotuta on an tanneCUOns. Tubing is non-coated. Nordic ~ #3 Dry#ng Supervi~r: R. W. Bowie `: WELL LOS TF>j~4NSl~/l/TT~4L ProActive Diagnostic Services, Inc. To: ACC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907j 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing lnspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknawledge receipt by returr+ing a signed capy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechn'ical Data Center Attn: Andy Farmer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProQctive Diagnostic Services, Ina Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907) 245-8951 1 j Caliper Report / MTT 14-0ct~07 50-103-20281-00 2j 2T,209 1 Report (Caliper Report delivered 10/24) Signed Print Name: ~ .~ t (t.5, ' ~A~~ n ~,tt,t,le„c,. PROACTIVE DIAGNOSTIC SERVICES, (ISr., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 9951$ PHONE:{807)245-8951 FAX: (907)245.88952 E-MAIL: ~~~a~~r3~r~g~~~a I~~r~,.e;~~.:;~~ WEBSITE: vAs~~rrr..~~s~aar*t~~.~~ss: D:Uvlsster Copy_00_PDSAI3C-20aoc\Z Word\Distribution\Transmitfal_Sheets\Tratismit_Chi~nal_New.doc • X11 Memory MTT & Multi~inger Caliper Log Results Summary Company: ConocoPhiilips Alaska, Inc. Well: 2T-209 Log Date: October 14, 2007 Field: Kuparuk Log No.: 9517 State: Alaska Run No.: 1 API No.: 50.103-20281-00 Pipet Desc.: 4.5" 12.61b. L-80 Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 3,724 Ft. (MD} Pipet Desc.: 9.625" 40 Ib. L-80 BTC Top Log Intvl1.: Surface Pipet Use: Surface /Production Casing Bot. Log Inivl1.: 3,724 Ft. (MD} Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl1.: Surface Pipe3 Use: Conductor Bot. Log Intvl1.: 78 Ft. (MD} Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: The caliper portion of this log is tied into GLM 2 ~ 3,506' (Driller's depth). The MTT portion of this log is tied into the tied into the Casing Hanger ~ 0'. This is the first log of this well made a 40 Arm Caliper and a 12 Arm Magnetic Thickness Tool (MTT). The caliper records internal features of the 4.5" tubing and the MTT responds to the total thickness of metal of the 4.5" tubing and 9.625" surface casing, with some influence from the 16" conductor pipe. INTERPRETATION OF CALIPER LOG RESULTS This log was run to assess the condition of the 4.5" tubing with respect to corrosive and mechanical damage. The caliper recordings indicate that the 4.5" tubing interval logged is in good to poor condition with respect to corrosive damage. A maximum wall penetration of 52% is recorded in joint 54 ~ 1,688'. Overall, wall penetrations in excess of 20% are recorded in 121 of the 129 joints logged. The damage appears in the form of general corrosion, tine corrosion and shallow pitting. No areas of significant cross-sectional metal loss (>11%) are recorded. Light deposits are recorded throughout the tubing interval logged, with a minimum I.D. of 3.71" recorded in joint 119 ~ 3,742'. 4.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS; Corrosion (52%) Jt. 54 @ 1,688 Ft. {MD) Corrosion (49%) Jt. 33 @> 1,014 Ft. (MD) Corrosion (46%} Jt. 47 ~ 1,449 Ft. (MD) Corrosion (46°to) Jt. 34 @ 1,061 F#. (MDy Corrosion (46%) Jt. 40 ~ 1,229 Ft. (MO) 4.5" TUBING -MAXIMUM RECORDED CROSS-SEGTIONAL METAL LOSS: No areas of significant cross-sectional wail loss (> 11°~) are recorded. ProActive Diagnostic Services, Inc. J P.O. Sox 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~a~memoryiog.com Prudhoe Say Field Office Phone; (907} 659-2307 Fax: {907) 655-2314 ,q~-ayac~ 1 ~ • I' 4.5" TUBING -MAXIMUM RECORDED iD RESTRICTIONS: Lt. Deposits Min I.D. = 3.71" Jt. 119 (~ 3,742 Ft. (MD) Lt. Deposits Min I.D. = 3.76" Jt. 109 ~ 3,386 Ft. (MD) Lt. Deposits Min I.D. = 3.77" Jt. 92 ~ 2,866 Ft. (MD) Lt. Deposits Min I.D. = 3.77" Jt. 94 r~ 2,919 Ft. (MD) Lt. Deposits Min I.D. = 3.77" Jt. 99 ~ 3,087 Ft. (MD) INTERPRETATION O1F MTT LOG RESULTS ; The MTT log results indicate an overall reduction in metal volume {from both the 4.5" tubing and 9.625" casing) ranging from 3% to 8%, relative to the calibration paint (1,010'}. While some of this metal loss can be attributed to the corrosion recorded by the caliper on the internal surface of the tubing, the MTT results show a line of metal loss throughout the log interval that is not a feature of the caliper recordings. This leads us to conclude that there is additional metal loss from the outside of the tubing and/or the production casing. A plot of average metal thickness as recorded by the MTT on a joint by~oint basis is included in this report, as well as detailed plots of the MTT recordings over the intervals 0' - 200', 1,700' -1,860' and 3,030' - 3,180'. Due to the cumulative volume of metal exceeding the tools ability to pertorm normally, inverted tool responses indicate average metal loss in areas of known additional metal (conductor pipe and casing collars). This anomaly occurs at almost all 9.625" casing collars, as well as the entire interval of 16" conductor pipe logged. fn the joint.-by joint plot ofi Average Metal Thickness Relative to Calibration Point the MTT tool's inverted ' response to the conductor pipe is very evident at the top of the graph. Two noticeably larger indications of lower metal volume in joints 58 and 101 are attributed to inverted tool responses to metal masses outside of the tubing. A detailed log plot of the interval including joint 58 is inducted in this report. A large inverted response to a casing collar is included in joint 58. The source of two apparent inverted responses recorded approximately 18 ft above and below this casing collar is unknown but do not appear to be valid meta4 lass indications. Inverted responses to casing collars are noted in the other detail recording plots as well. Indications of a line of metal loss are recorded by the MTT throughout the togged interval This feature is ' annotated in all three detailed log plots included in this report. Several significant isolated metal toss events are also indicated within the apparent line of meta! loss recorded by the MTT. As these metal loss indications do not appear to correspond to the damage recorded by the caliper an the internal surface of the ' tubing, they appear to represent metal loss to the casing or outside surface of the tubing. Due to the concentric pipe strings in the log interval, the MTT response is qualitative -indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in ' metal thickness occurs. In this tog, the MTT was calibrated down hole {1010'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 4.5" tubing, 9.625" casing, and 16" conductor pipe. The original M7T data recorded in this well exhibited a high signal to noise ratio throughout the data set and was high-pass filtered prior to being ana/yzed. While this filtering of the original data may have masked some high frequency isolated damage indications, it should have no significant efhed~ on the measurement of _ overall circurrrferentia! meta! loss discussed in this analysis. Field Engineer: 5. Carpenter Analyst: B. Qi (Caliper) /M. Lawrence & J. Burton (MT7) Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.Q Box 1369, StafFard, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PD5+a~memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~I • • Correlation of Recorded Damage to Borehole Profile ~ Pipe 1 4.5 in (19.6' - 3720.1') WeA: 2T-209 Field: Kuparuk Company: ConocoPhilips Alaska, Inc. Country: USA Survey Date: October 14, 2007 ^ A pprox. Tool D eviation . A pprox. Borehd e Profil e 1 z_s 10 293 20 609 30 917 40 1224 50 1534 O ~ 60 1842 ,; ~ ~ GLM 1 ~ a ~0 70 2175 p 8U 2478 90 2787 100 ^ 3098 110 3406 GLM 2 119 3720 0 5 0 1 00 Dam age P rofile (% wall) / Tod D eviatio n (degr ees) Bottom of Su rvey = 119 • • PDS Report Overview ~, S. Body Region Analysis Well: 2T-209 Survey Date: October 14, 2007 Field: Kuparuk Tool Type: MFC 40 No. 30807 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: B. i Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4.5 ins 12.6 f L-80 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°Ao wall) ~ penetration body ~ metal loss body 5 1 0 00 1 o~ ~ 50 , , 0 0 to 1 to 10 to 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of'oints anal se d total = 126 pene loss . 0 0 5 1 115 10 104 17 0 0 0 0 Damage Configuration (body ) 150 100 50 0 isolated general line ring hole/pons pitting corrosion corrosion corrosion ible hole Number of'oints dama ed total = 126 2 102 22 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 0 50 GLM 1 98 GLM 2 Bottom of Survey = 119 Analysis Overview page 2 ~ i PDS REPORT JOINTTABUTATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 Body Wall: 0.271 in Upset Wall: 0.271 in Nominal I.D.: 3.958 in Well: 2T-209 Field: Kuparuk Company: ConocoPhitlips Alaska, Inc. Country: USA Survey Date: October 14, 2007 Joint No. Jt. Depth (Ft.) Pcn. U~ric~t (Ins.) Pen. Body (Ins.) Pen. % Met.il I uss "r~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 0 U 0.07 2t3 ~~ 3.88 PUP rro i 1 t~ 0. 29 (~ 3.8 orrosion. . De 2 54 t~ .08 3U (~ 3.8 Corrosio t. De its. 3 8 s~ 0.06 11 !~ 3.81 Corrosion. t. a its. 4 116 U.US 0.08 i 1 - 3.86 Corrosion. Lt. De i 147 ~) 0.08 aU tt 3.81 C r ~ n. t. e it . 6 178 n 0.06 21 t~ Corrosion. Lt. sit . 7 207 t) 0.09 ;5 7 3.84 orrosion. t. De "ts. 8 234 U 0.1 43 ~ .85 C r osion. a 'ts. 9 269 U 0. 4 13 4 3.87 h Ilo 'tti 10 9 c) 0.08 28 lt) 3.79 Corrosi n. t. De i 11 3 6 l).~)~ 0.08 2t3 I1~ 8 Co ion. t e it . 12 57 l) 0.10 35 - 3.83 Corrosion. Lt. e i s. 13 390 t?.Il) 0. 1 4U I I 3.85 Corrosion. t. D sits. 14 23 0 0. 8 Z~) 4 .80 Cor ion. t. De 'ts. 15 452 O.U(, .11 39 I I 3.80 o rosion. Lt. De its. 1 4 O.Ub 0.0 27 3 3.8 r 'on. Lt. a its. 17 7 t ~ 0.0 ~ (i 3.81 C r ion Lt. a s; s. 18 543 O.U6 0.07 2 7 I ~ ~ 3.80 Corrosion. t. De i 19 574 O.US 0.0 31 I I 3.85 Lin Corrosio Lt. De it . 0 609 U.U4 0.11 39 I u 3.85 Line corrosion. Lt. e its. 21 6 t).t); 0.08 <<) I U 3.86 L~ne orrosion. Lt. De ~ts. 2 670 U.t)(~ 0.1 42 ~ 3.8 Line corrosi n. t. its 23 700 l).Ub 0.09 3 3 t3 3.86 Corrosion. Lt. De its. 7 1 U.uS .11 41 3.85 or Sion. 25 760 U.US 0.09 a2 1 U 3.82 Corrosion. Lt. De its. 26 794 U.Ub 0.09 32 I1 3. 5 C rrosi n. t. its. 27 823 O.US 0.09 32 10 3.85 Corrosion. Lt. De sits. 28 858 t).05 0.0 ~ ~ l U 3.87 rrosion. t. D its. 29 885 U.U~ 0.11 42 I 1 3.85 Corrosion. Lt De 'ts. 30 917 t).U; 0.12 45 I 1 .81 Corrosion. Lt. De si 31 948 t) 0.07 ~t9 Ic) 3.88 Corrosion. Lt. De sits. 32 975 0.0(~ 0.10 3t3 ~ .85 ion. t. De si s. 33 1010 O.U6 0.13 49 1 U 3.85 Corrosion. Lt De its. 34 10 0.05 0.12 4b 1 Z 3. 7 orrosion. Lt. i 35 1070 U 0.09 ~3 (, 3.87 Corrosion. Lt. De sits. 36 1 1 O 0.09 32 I u .87 orrosion. t. De it . 37 1128 t).Utt 0.11 4U 1 u 3.88 Corrosion. Lt. De its. 38 116 a .09 > 1 ~ 3.89 Corrosio t De sits. 39 1194 U.U6 0.12 44 12 3.87 Corrosion, Lt. De sits. 40 1 24 U.US 0. 4b 7 3.86 C rrosi n t. De 41 1256 U.O' 0.07 ?7 t9 3.82 Corrosion. Lt De 'ts. 4 1 81 0 0.11 40 10 3.87 or i n. t D - 43 1319 U.Ob 0.09 34 Ili 3.83 Corrosion. Lt. De its. 44 1347 U.03 0.11 40 ti .81 Corrosio Lt. its. - 45 1379 U.~)b 0.11 41 t3 3.89 Corro ion. Lt. De sits. 46 1411 t).Uti 0.11 3~) Iii 3.83 Corrosi Lt De ~ts. 47 1443 ~ ~ 0.13 4(, I I 3.88 Corrosion. Lt. De its. 1473 ' ~' ~ 0.10 ~ `~ 3. in r i n. L . De its. 49 1502 0.09 ~~ 3.84 Line rosion. LL De sits. _ _ Penetration Body Metal Loss Body Page 1 Pipe: Body Wall: Upset Wall: Nominal LD.: ~ ~ PDS REPORT JOINT TABULATION SHEEP 4.5 in 12.6 ppf L-80 Well: 2T-209 0.271 in Field: Kuparuk 0.271 in Company: ConocoPhilips Alaska, Inc. 3.958 in Country: USA Survey Date: October 14, 2007 Joint No. )t. Depth (Ft.) I'~•n. l )L~sc~t (his.) Pen. Body (Ins.) I'~~n. `% Vlc~tal I u,s ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 50 1534 0.U6 0.10 37 7 3.87 Line corrosion. Lt. De its. - 51 1567 0.06 .1 3ti ti 3. Line rosion. L . D its. 52 1598 0 .10 36 ~+ 3. 1 Line corrosion. Lt. 'ts. 3 1628 U 0.10 35 ti 3.83 Corrosion. Lt. De sits. 54 1660 U.06 0.14 52 I U 3. 3 Corrosion. Lt e i 55 1690 U.Oti 0.11 -) I 7 .85 Corrosion. Lt. De sits. 56 1719 11.06 0.10 3~i 7 3.85 orrosi n. Lt. De its. 57 1750 U.07 0.10 36 i 3.84 Corrosion. Lt. De sits. 58 1781 U.U6 0.09 34 7 3.86 Co ion. Lt. De its. 59 1810 n 0. 8 2ti 6 3.8 Cor 'on. Lt. De it . 0 1842 0 0.0 3U 7 3.84 Corrosion. Lt. De its. 61 1877 t) 0.10 if3 - 3.85 Corrosion. Lt. De its. 62 1907 U.07 0.09 3_> -1 .82 Corrosion. Lt. De its. 1940 0.U7 0.07 26 3.83 Corrosion. Lt. e si 64 1970 U.Ub 0.08 30 5 .81 Line corrosion. t. De sits. - 65 1999 O.Uh 0.12 ~14 7 3.80 Line corrosion. t. De its. 66 2030 0.07 0.10 35 t'> 3. 3 Line cor osion. Lt. De its. 67 2062 0.U6 0.10 i i 3. 3 Line Corr ion. L De sits. - 68 093 0 0. 0 37 6 3.8 i e corrosion. Lt. De its. 68.1 2124 0.07 0.0 1 ti -1 3.81 PUP Shallow corrosion. Lt. De its. 68.2 2129 0 0 0 t) N A GLM 1 Latch ~ 4:00 6 . 2138 0.06 0.04 15 3.82 PUP Shallow corrosi n. t. i s. 69 2145 t).06 0.07 25 -} 3. 2 Corrosion. . De its. 70 2175 U.0% 0.08 30 > 3.80 Corrosion. Lt. De sits. 71 2 03 U .1 48 9 3. Corr ion. a 'ts. 72 2237 0 0.10 3t3 7 3.83 Corrosion. Lt. De its. 73 2 69 0 0.08 i l 6 3.81 Corrosi n. Lt. a its. 74 2299 i ~.t 14 0.10 35 4 3.80 Corrosion. Lt. De its. 7 2330 0 0 31 5 3.81 Corrosion. Lt. De its. 76 2361 U.US 0.09 3~ ~~ 3.81 Corrosion. Lt. De its. 77 2389 0 0.10 3E3 5 3.81 Corrosion. L De its. 78 2422 0.t~6 0.07 '6 _) 3.79 Corrosion. Lt. De sits. 79 2451 U.U6 0.07 27 ~ 3.78 Corrosion. Lt. De its. 80 2478 0 0.10 35 5 3.81 Corrosion. Lt. De its. 81 2511 U.Ub 0.09 31 7 3.8 Corrosion. Lt De sits. 82 2543 U 0.08 3U i 3.82 Corrosion. Lt. De sits. 83 2574 U.U7 0.10 35 5 3.81 Corrosi n. ~ e ~ts. 84 2605 0.07 0.09 ; 3 ? 3.83 Corrosion. L~ De its. 85 263 U.ub 0.09 to 4 3.83 Cor sion. t. De its. 86 2666 t~ 0.07 ~'7 i 3.82 Corrosion. Lt. De its. 87 269 0 9 32 6 3.81 Line Corr ion. Lt. De ~ts. 88 2726 t~.05 0.08 31 8 3.80 Line corrosion. Lt. De 'ts. 89 2759 0 0. 7 26 5 .81 Corrosio t. D its 90 2787 0 0.10 37 7 3.81 Corrosion. Lt. De its. 91 2818 U.U7 .08 3U (, 3.80 Corrosion. Lt. a its. 92 2850 t1.tt7 0.09 3-1 3.77 Corrosion. Lt. De sits. 93 2879 0 0.11 i9 -1 3.79 Line corrosion. t. De its. 94 2912 0.09 0.08 30 (~ 3.77 Line corrosion. Lt De its. 95 2942 ! ~ !~~ ~ 0.09 -i 380 Corrosion. Lt. De sits. 96 2973 '~~ ~~~; 0.08 ~~ t, 3.80 Corrosion. Lt. De sits. Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEEP Pipe: 4.5 in 12.6 ppf L-80 Web: 2T-209 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 14, 2007 Joint No. Jt. Depth (Ft.) Pe•n. UF>s~•t (Ins.) Pen. Body (Ins.) Pen. `;4> ~t~~t,~l I~,.~ •~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 97 3010 l).U6 .10 ~5 ~~ 3.78 Corrosion. t. D its. 98 036 U.UZ 0.11 42 ~~ 3.8 or n. Lt. its. 99 3069 u.US 0.1 36 3.77 ine corr io Lt. De 'ts. 00 3098 0.115 0.0 31 i 3. ine rosi n. t. De its. 10 312 tLU2 0.07 26 4 .80 Line corrosion. t. De it . 10 3157 U 0. 9 33 4 3.7 Line corrosion. t. De its. 103 3187 a 0. 9 ~2 V 3. 1 o rosi n Lt. a sits 104 3219 O.Ut3 0.10 ti I 1 3.79 orrosion. Lt. De ~ts. 1 5 3250 1).1)7 0.11 39 5 3.8 Cor i n. t 't . 106 3 8 U.U; 0. 7 27 7 .8 orrosion. Lt. De its. - 107 3316 (1 0. 7 ~'6 ~ .8 Co Sion. Lt. a its. 108 3345 O.O6 0.07 't3 3.85 C ion t e its. 109 3375 O.U5 0.0 ?t3 (, 3.76 Cor 'on. Lt. a its. 110 3406 O 0.07 Z7 4 3. 1 Corrosion. L . 'ts. - 11 3438 O 0.07 Z(i 3. orrosi n. De its. 11 469 U.(Li 0.07 Z5 5 .78 rrosi n. t. D sits. 1 2.1 3499 U .04 14 ~ 3.81 P P Ilow ittin L . De its. 112. 3505 U 0 O U N A LM 2 Latch ~ 12:00 1 .3 3514 U 0.13 40 4 3.84 PU Corr ion. t De its 113 3520 U.US 0.08 )U - 3. Corrosion. Lt. D i 114 3551 U.U6 0.07 Z4 (, 3.8 orrosi n. t. De its. 115 3580 u. I U 0.08 2) 4 3. orrosi n. L . e 116 3611 O.Ub 0. 7 27 4 85 Corrosion. Lt. De i 117 3642 O.US 0.07 2V t3 3.84 Corrosion. Lt. De sits. 1 7 0 32 5 .85 Cor i n i 118,1 3704 l).O 5 0.07 27 3.89 PUP corrosion. 1 .2 3709 O 0 O ~) 3.8 leeve-C 118.3 3714 i~ 0.05 1 ~) I 3.80 PUP shallow corrosion. Lt. De its. 119 3720 ~~ 0.08 it b 3.71 Corrosion. Lt Uc x)sits. `~ Penetration Body Metal Loss Body Page 3 n~ ~ ~ ~ r ~^ ~ ~ ~ ~ ~ ^~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections u Well: 2T•209 Survey Date: October 14, 2007 Field: Kuparuk Tool Type: MFC 40 No. 30807 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 4U Tu__bing;_ 4.5 ins 12.6 ppf L-80 ------ Analyst: --- -- - --8• Q~ - - Cross Section for Joint 54 at depth 1688.283 ft Tool speed = 72 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 94 Tool deviation = 2 7 ° Finger 37 Penetration = 0.142 ins Corrosion .14 ins = 54% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 ~ PDS Report Cross Sections Well: 2T-209 Survey Date: October 14, 2007 Field: Kuparuk Tool Type: MFC 40 No. 30807 Company: ConocoPhillips Alaska, Inc. Toof Size: 2.75 Country: USA No. of Fingers: 4U Tubin 4.5 ins 12.~pf_ L-80_ _ __ __ Analyst: B. Qi Cross Section for Joint 33 at depth 1013.857 ft Tool speed = 70 Nominal ID = 3.958 Nominal OD = 4.5 Tool deviation = 9 ° Corrosion .13 ins = 49°~ Wall Penetration HIGH SIDE = UP i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ • • Cross Sections page 1 PDS Report Cross Sections ~~ - ~~~ Well: 2T•209 Survey Date: October 14, 2007 Field: Kuparuk Tooi Type: MFC 40 No. 30807 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.73 Country: USA No. of Fingers: 40 Tubin 4.5 ins 12.6 f L-80 _____ _ Analyst: B. Oi Cross Section for Joint 119 at depth 3742.05 ft Tool speed = 65 Nominal ID = 3.958 Nominal OD = 4.5 Tool deviation = 54 ° Lt. Df~lx„iis Alin LI). = 3.71" HIGH SIDE = UP i ~ r ~ ~ ~ ~ ~ ~ ~ S ~ ~ a ~ ~ ~ ~ r • • Cross Sections page 3 ~ _ ~~ , PDS Report Cross Sections Well: 2T-209 Survey Date: October 14, 2007 Field: Kuparuk Tool Type: MFC 40 No. 30807 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 4U Tubin 4.5 ins 12.6 f L-80 Anal st: B. i Cross Section for Joint 109 at depth 3385.583 ft Tool speed = 66 Nominal ID = 3.958 Nominal OD = 4.5 Tool deviation = 50 ° Lt. Deposits Min I.D. = 3.76" HIGH SIDE = UP • Cross Sections page 4 Pipe 1 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: October 14, 2007 ^ D ecrease ^ In crease 1 23 10 293 20 609 30 917 40 1224 50 1534 ~ 60 1842 E ~ ~ ._ Z GLM 1 '~ -. - ~0 70 2175 °' 80 2478 90 2787 100 3098 110 3406 GLM 2 119 3720 - 50% 0 5 0% C hange in Metal Thick ness (% ) Bottom of Survey = 119 • • Average Recorded Metal Thickness Relative to Calibration Point 4.5 in (19.6' - 3720.1') Well: 2T-209 Magnetic Thickne~Log (10Hz} Surface to 200' rwoAc,nre Dlwgwos~ic Se.~IcB, Inc. Database File: d:\warriorldatal2t-20912t-209.db Dataset Pathname: 1/1/1/filtl Presentation Format: ~6SCAL-1 Dataset Creation: Thu Oct 25 19:24:44 2007 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ft/min) -200 -6.2 MTTP12 (rad) 3.8 Tree --F---~--~ Hanger --4.5" Collar~6~.~ Pup Jt. 0.1 5" Colla ~~ 10 Apparent Line of N 20 Arms 4.5" Joint 1 30 5" i25" Casing Collar 40 50 4.5" Joint 2 60 70 Casing ted Rey vv 4.5" Joint 3 it Line of Metal Loss ,. ~ ~~ ~ ,~ 90 4 .5" Colla - - - - - ~ 100 Apparent Line o f Metal Loss 110 ; (Arms 1-3, 11-12) 9.625" Casing Collar (inverted Response) Joint 4 1 0 2 . 5" C ollar~~ 130 A ppar ent Line of Metal Lo ss (Arms 9-12) 140 4.5" Joint 5 5 1 0 I rt d R ( nve e esponse} ~ ~ ~ i 9.625" Casin Collar 4 .5" Collar' 1~ - 70 1 4.5" A ppa rent Line of Metal L os ~' Joint 6 Arms 7-11 180 4.5" Collar 190 .625" Casing Collar " (I nverted Response) 4.5 Joint 7 ,t -50 Delta Metal Thickness (%} 50 2.6 MTrP01 (rad) 12.6 0 Line Speed (ft/mit7) -200 -6.2 MTTP12 (rad) 3.8 '~ Magnetic ThickneaLog (10Hzj ,~_,1 -~ 1,700'to 1,860' ol~gws.~o spa, u~. Database File: d:lwarrior\data\~`'t-209\2t-209.db Dataset Pathname: 1N/1/filt1 Presentation Format: 26SCAL--1 Dataset Creation: Thu Oct 2519:24:44 2007 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ftlmin) -200 -6.2 MTTP12 (rad) 3.8 1700 4.5" Collar 1710 4.5" Joint 56 1720 1730 4.5" Collar 625" Casing Collar 1740 4.5" Joint 57 1750 Apparent Inverted Response > interval of increased 1760 -+-9.625" Casing Collar 1770 Inverted Response ) 1780 4 5" . Joint 58 --A pparent Inverted Response inte rval of increased 1790 -me tal volum ~ 4.5" Collar at~parent line of metal I of Apparent Metal Loss (Arms 9-111 . ~.,,, I ZSUU 4 - 625"C asin Collar g ( Inverted Res onse) 1810 p } r " ~ 4.5 Joint 59 ' Line of Apparent Metal Loss ~ (Arms 9-11~) 1820 ti , 4 5 " Co llar . ~~ 1830 r 4.5.. Joint 60 1840 9 625" Casing Collar . . I rt d R nv ( e e espo nse ) 1850 t ~~ _ -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ftlmin) -200 -6.2 MTTP12 (rad) 3.8 Magnetic Thickne+Log (10Hz) 3,030' - 3,180' F'woAcnie olwgnontc Sewvlce, Inc. Database File: d:lwarriorldata\2t-20912t-209.db Dataset Pathname: 1 /111 /filtl Presentation Format: 26SCAL~1 Dataset Creation: Thu Oct 25 19:24:44 2007 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%} 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ft/min) -200 -6.2 MTTP12 (rad) 3.8 3020 3030 4.5" Joint 98 d Response 3040 62" Casing Collar 4.5" Collar~~ 3050 3060 4.5" Joint 99 3070 Collar ~. 'Casing Collar ~,,,,,,,,,,,,,,~ Jt1tiU 3090 4.5" Joirrt 100 3100 Line of Metal Loss ~~ ~ ~, ~ ,~ Metal Loss Isolated Metal 4.5.. 3110 Line of 625" Casi ollar20 ted Response) 4.5" Joint 101 3130 4.5" Collar 3140 3150 4.5" Joint 102 3160 625" Casing Collar red Responsee) 4.5" Collarl~ 4.5" Joint 103 -50 Delta Metal Thickness (%) 50 `' 6 0 Line Speed (ft/min) -200 -6.2 Isolated Metal Line of Metal Lc L-}-{Arms 9-1 MTTP01 (rad) MTTP12 (rad) 1 3.8' • . . WELL LOG TRANSMITTAL ProAc1:ive Dia9l1ost:ic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmittal letter to the foRewing: BP Exploration (AlaskaJ.Inc. Petrotechnical Data Center Attn: Andy Fanner LR2 -1 900 E. Benson Blvd. Anchorage. Alaska 99508 :s~ANNED NOV 0 1 Z007 and ProActive Diagnostic. Services..1nc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AI( 99518 Fax: (907) 245-8951 Iq't-~- 1t.(~~3 1) 2) Caliper Report 14Qc1¡.Q7 2T-2æ 1 Report / EŒ 50-103-20281-00 Signed: éu~ Date: 9 4' '):1117 .~, LUU i Print Name: (I J. r¡;..,h ú g...-- Mn.IAAA-{ÜU", PROACTIVE DIAGNOSTIC SERVICES, INC.. 138W.1NrERNA11ONALAIRPORI'RD SUlTEC, ANCHORAGE, AI( 89518 PHONE: (807)24&-8911 FAX: (I07)24I-18H2 E-MAIL: pdsanchoraae@memorv!oti.com WEB&rrE: 1ivw'N.memory!oQ.com D:\MaII!r_ CopyJIIU'DSANC-2OxxIZ_ Wœd\DisIåIIaIion\ThlllslllilllltSbeols\1bmsmit-,m,inatNIIIV.doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. october 14, 2007 9517 1 4.5" 12.6 lb. L-80 Tubing 2T -209 Kuparuk Alaska 50-103-20281-00 Surface 3,743 Ft. (MO) Well: Field: state: API No.: Top Log Intvl1.: Bot. Log Intvl1.: Inspection Type: Conoslve & Mechanical Damage Inspection COMMENTS: This log is tied into the GUf 2 @ 3,506' (Driller's depth). This log was run to assess the condition of the 4.5" tubing with respect to corrosive and mechanical damage. The caliper recordings indicate that the 4.5· tubing interval logged is in good to poor condition with respect to corrosive damage. A maximum wall penetration of 52% is recorded in joint 54 @ 1,688'. OVerall, wall penetrations in excess of 20% are recorded in 121 of the 129 joints logged. The damage appears in the form of general corrosion, line corrosion and shallow pitting. No areas of significant cross-sectional metal loss are recorded. Light deposits are recorded throughout the tubing interval logged, with a minimum 1.0. of3.71" recorded in joint 119 @ 3,742'. 4.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Corrosion ( 52%) Jt. 54 @ Corrosion ( 49%) Jt. 33 @ Corrosion ( 46%) Jt. 47 @ Corrosion ( 46%) Jt. 34 @ Corrosion ( 46%) Jt. 40 @ 4.5" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: 1,688 Ft. (MD) 1,014 Ft. (MD) 1,449 Ft. (MD) 1,061 Ft. (MD) 1,229 Ft. (MD) No areas of significant cross-sectional wall loss (> 11%) are recorded. 4.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: Lt. Deposits Min 1.0. = 3.71" Jt. 119 @ 3,742 Ft. (MD) Lt. Deposits Min 1.0. = 3.76· Jt. 109 @ 3,386 Ft. (MD) Lt. Deposits Min 1.0. = 3.77· Jt. 92 @ 2.866 Ft. (MD) Lt. Deposits Min 1.0. = 3.77· Jt. 94 @ 2,919 Ft. (MD) Lt. Deposits Min 1.0. = 3.77" Jt. 99 @ 3,087 Ft. (MD) I Field Engineer: S. Carpenter Witness: c.~ED Analyst: B. Qí OCT 2. 4 Z007 ProActive Diagnostic Services¡ Inc. / P.O. Box 1369¡ Stafford¡ TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@ìmemorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 41aska Oil & Gas Cons. Commission Anchorage 1'11f-c9'f3 ':It: 155~3 I of Profile I 4.5 in (19.6'- Well: 2T-209 Field: Kuparuk I ConocoPhilips Inc. USA Date: October 14,2007 I I Tool Deviation Approx. Borehole Profile 23 I 293 I 609 I 917 1224 I 1534 I 1842 ti c I GlM 1 2175 I 2478 2787 I 3098 I 3406 GlM2 I 119 3720 0 50 100 I Profile / Tool Deviation I Bottom of "" 119 I I I I I Well: Field: Company: Country: 2T-209 Alaska, inc. USA I Tubing: Nom.OD 4.5 ins 12.6 Grade 8< Thread L-80 I I Penetmtic:m and Metal loss (% I penetration 150 I 100 I 50 o 0 to 1% 1m 10% I I Configuration ( body ) 150 I 100 I 50 I o isolated general line ring hole j poss pitting corrosion corrosion corrosion íbfe hole I I I I I over 85% o o o ew Analysis Date: Tool Type: Tool Size: No. of Anal t: Nom'!D 3.958 ins October 14,2007 MFC 40 No. 30807 2.75 40 B. Upper len. 6.0 ins lower len. 6.0 ins Nom. Upset 4.5 ins Damage Profile penetration 100 GLM 1 GlM2 Bottom of Survey = 119 Analysis Overview page 2 I I PDS JOINT TAB LATION 4.5 in 12.6 ppf L-80 Well: 2T-209 WaUl 0.271 in Field: Upset WaN: 0.271 in Inc. Nomina! I.D.: 3.958 in Country: USA Date: October 14,2007 I I I Joint Jt. Depth Pen. Pen. PeR ¡v\eì;¡I Min. .~ Profile No. (::~~i;1 !.D. Comments wall) (Ins.) (Ins.) 0 50 100 .1 20 0.07 3.H8 æcol1osion. 1 23 ! 0.08 3.82 rosion. Lt. Deoosits. 2 54 ) 0.08 3.81 Corrosion. Lt. Denosits. 3 85 0.06 3.81 Corrosion. ¡ t Oenosits. 4 116 O. )'1 3.86 Corrosion. It. Del:JOSits. 5 147 3.81 Corrosion. Lt. Del:JOSits. 6 178 2 Corrosion. Lt. Del:JOSits. 7 207 7 3.84 Corrosion. Lt. Del:JOSits. 8 234 n H 3.85 Corrosion. It. Denosits. 9 269 n 11 3.87 Shallow ruttinŒ. 1°ti 10 3.79 Corrosion. It OeDOsit!.. n 3.83 Corrosion. It. DeDOsits. 12 13 390 14 423 0 15 452 80 Corrosion. It. DelJOSits. 16 481 82 Corrosion. It. Oenn<;its. 17 517 ( -0.07 '7 181 Corrosion.. U Denn<;its. 18 543 OJ 0.07 10 3.80 Corrosion. It. DeDOsits. 19 574 OJ 0.08 1 3.85 Line mrrosion. It. r: eoosits. 20 609 O. 0.11 10 3.85 Line corrosion. Lt. [ eoosits. 21 640 ( 0.08 10 3.86 Line corrosion. Lt. 0 eoosits. 22 670 ( 0.11 3.83 tine corrosion. It. Deoosits. 23 700 ( 0.09 ~ Corrosion. It. Deoosits. 24 7i1 Corrosion. I t Oeno<;its. 25 760 ( 0.09 Ii) 3.82 Corrosion. It. Denosits. 26 794 ( 0.09 11 3.85 Corrosion. I t. Denosits. 27 823 0.09 '1 10 3.85 Corrosion. U. Denosits. 28 858 0.09 10 3.87 Corrosion. Lt.Denosits. 29 885 0.11 I 3.85 Corrosion. It. Deoosits. 30 917 0.12 3.81 n. It. DelJOSits. 31 948 0.07 I¡ n. It. Deoosits. 32 975 o. n. Lt. Deoosits. 33 =æ= r It. Oeoosits. 34 OOS Corrosion. i l Deoosits. 35 0 Corrosion. Lt. Deoosits. 36 1101 ( 3.87 Corrosion. It. DelJOSits. 37 1128 O. Jß 0.11 Ii) 3.88 Corrosion. It. Oeoosits. 3R 1163 0.09 . if 3.R9 Corrosion. II Dpmsits. 39 1194 ( 0.12 . 12 3.87 Corrosion. It. Denosits. 40 1224 ( 0.12 186 Corro<;ion. It. Oeoosits. 41 1256 I 0.07 3.82 Corrosion. It. Deoosits. 42 1281 0.11 0 3.87 Corrosion. U Deoosits. 43 I~ 0.09 § Corrosion. It. Oel:JOSits. 44 0.11 Corrosion. It. DelJOSits. 45 1379 0.11 Corrosion, Lt. DelJOSits. 46 1411 o.m 0.11 10 3.83 Corrosion. It Deoosits. 47 1443 ( 0.13 11 3.88 Corrosion. It DelJOSits. 48 1473 n ¡S M 9 3.84 ! ine cow",ion. It Deoosits llJ 49 1502 O. 16 9 3.84 line corrosion. It. Denosits. I I I I I I I I I I I I Body Metal loss Body Page 1 I I I PDS I I Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6 0.271 in 0.271 in 3.958 in l-80 I JL Depth Pen. ,j (Ins) Joint No. Pen. Pen. ! !\letal Min. JOINT ULATION SH Well: Field: 2T-209 Kuparuk ConocoPhiUips Alaska, Inc. USA October 14, 2007 I ;~$m' 567 0 or, 52 1598 0 "i3 1628 54 55 56 57 58 59 60 61 1 62 1 63 1940 64 1970 0.08 ±ti~ö g~d1Sf '.8' 6687 2062 O( . r .l.J!l. 2093 ~ 68.1 2124 0 )7 3.81 68.2 2129 ( 68.3 213f1 O. 0.04 15 j 69 ? 145 70 7175 71 +=22Oi 3.Rl 72 2237 3.83 73 2269 3.B1 74 2299 ())4 ¡ 0.10 3.80 75 2330 I 0.08 ¡¡ 3.81 76 2361 OJ 0.09 ! ~1 77 23R9 ( !~1 78 2422 0 16 , 3.79 ~ ~1~~ Ii ~:~~ 81 2511 7 381 82 2543 3.82 83 2 <;7 AI') 5-J-,1JrL 84 260511 ~ 85 2633 on6m¡ 3.83 86 2666 I 0.07 3.82 87 2698 3.81 88 2726 O. 15 3.80 89 275q ( 0.û7 U 3.81 90 2787 0.10 113.81 !i m!~ ill?:ii=: ¡ f~ 95 2942 ~i.80 96 2973 o.on 0.08 ! ( 3.80 1.0. (ins.) ;1J It: r~¡~~. ! t. De!1Œ';its. rosion. L1. De!1Œ';its. 1.131 . L1. Deoosits. ) ~;~: I [~~: "oe~: 3.B5 It Dei:1OSÎts. n. It. Deoosits. n. It Deoosits. Corrosion. It Denosits. 3.83 Corrrn;ion. It Denru:íts. Corrosion. .t Demsits. Corrosion. t DeOO!;its. Corrn"¡on. t Deoosits. r or rnsion. .t. DeOO!;its. Un'" rJ'lrroskm. Lt DerJo..¡t" Une corr()Çion. Lt Deno..jt... ! ine cnrro<;ion It De!1Œ';its. Line corro<;ion. Lt. fJpnosits. line corro<;ion. Lt. Deoosits. PUP Shallow corrosion. Lt. Deoosits. GLM 1 {latch @ 4:OOì PUP Shallow corrosion. Lt neno<::its. Corrosion. Lt. Dei:1OSÎts. Corrosion. Lt. Oeoosits. C ! t DPnn<:jt... Corrosion. Lt Deoosits. Corrosion. Lt. lJeoosits. Corrosion. It. Deoosits. í'orrnsinn. Lt.Deoosits. Corrosion. It DeOO!;its. Corrosion. It. Deoosits. Corrosion. Lt. Deoosits. Corrosion. Lt lJeoosits. Corrosion. Lt. Deoosits. Corrosion. Lt. DeOO!;its. Corrosion. L1. Deoosits. Corr""iol1. t Deoosits. Corrosion. L1. Deoosits. Corrosion. It. Deoosits. Corrosion. U. Deoosits. Une corrosion. It fJennsits. line corrosion. ¡ 1. Deoosits. Corrosion. I t. DeOO!;its. Corrosion. U. OeOO!;its. í' Of """io n. Lt. Dei:1OSÎts. Corroskm. U. Deoosits. I inf> corrosion. Lt Deno<;jt... Une corrosion. Lt. Deno<;its. Corrosion. I t fJenosits. Corrosion. Lt Deoosits. 'Y;, 7 g 9 I 1690 1719 1750 Î 781 1810 0.10 0.10 0.14 on ":;7 'IR :16 I I I I I I I I I I I I I Comments 2 .~ Profile o 50 100 REPORT JOINT TABULATION SH I Pipe: Body Wall: Upset Wail: Nomina! I.D.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in Well: Reid: Company: Country: Survey Date: 2T-209 Kuparuk ConocoPhiUips Alaska, Inc. USA October 14,2007 I I Joint Jt. Depth Pen Pen. Pen ;\Aelal Min. mm;¡<>p Profile No. 1.0. Comments (% wall) (Ins) (Ins.) (Ins.) 0 50 100 97 3010 ;) 3.78 Corrosion. U. Deoosits. 98 3036 0.02 011 BE ') 3.82 Corrosion. It. Deoosits. 99 3069 0.05 0.10 2 3.77 Line corrosion. Lt. Deoosits. 100 309B OJ)5 0.08 3.80 Line corrosion. U. Deoosits. 101 3128 Oi rJ 0.07 3.80 Line corrosion. Lt. Deoosits. 102 3157 0.09 3.78 Line corrosion. Lt. Deoosits. 103 3187 0.09 3.81 t:orrosion. Lt. Denosits. 104 3219 0 )(j 0.10 1 ~ Corrosion. Lt. Denosits. 105 3250 0 17 0.11 -fH- L Corrosion. Lt. Deoosits. 106 3283 0 17 0.07 3.82 Corrosion. Lt. Deoosits. 107 3316 (~)I; i.82 Corrosion. Lt. Deoosits. 108 3345 006 113 3.85 Corrosion. Lt. Deoosits. 109 3375 OOS 6 3.76 Corrosion. Lt. Deoosits. 110 3406 i 0.07 3.81 Corrosion. It. Deoosits. 111 ~O¡I)S 0.07 3.88 Corrosion. Lt. Denosits. 112 007 3.78 Corrosion. It. Deoosits. 112.1 3499 I 004 3.B1 PUP Shallow nittil1!:!. It. Deoosits. 112.2 3505 i 0 ( N/A GlM 2 II atch @ 12:00\ 112.3 3514 ( 0.13 .¡ 3.84 . PUP Corrosion. Lt. Deoosits. 113 3520 OOS 0.08 7 3.84 ; Corrosion. U.Deoosits. 114 3551 I Of, 0.07 ;) 3.82 Corrosion. ! t. Deoosìts. 115 3580 in 0.08 4 3.M Corrosion. It Deoosits. 116 3611 1m, 0.07 3.85 Corrosion. Lt. Del1Osits. 117 3642 iOS 0.07 3.84 . n. Lt. Deoosits. 118 ~ii Corrosion. ¡ t Deoosits. 118.1 ~0.07 3. PUP corrosion. 118.2 3709 0 0 3.81 Sleeve· C 118.3 3714 I 0 I 0.05 ! 3.80 PUP shallow corrosion. U. Deoosits. 119 3720 I n I 0.08 {1 Ii 3.71 Corrosion. Lt Deoosits. I I I I I Body Metal Loss Body I I I I I 3 I I .. .. .. .. .. .. .. .. Well: Field: Company: Country: Tubin : 2T-209 Kuparuk ConocoPhimps Alaska, Inc. USA 4.5 ins 12.6 f L-80 at Tool '" 72 Nominal 10 '" 3.958 Nominal 00 '" 4.500 wall area'" 94 % Tool deviation'" 27· .. .. .. .. .. .. .. s c Survey Date: Too! Tool Size: No. of Fingers: Anal st: October 14, 2007 MFC 40 No. 30807 :U5 40 B. ¡ 1 Finger 37 Penetration = 0.142 ins Corrosion .14 ins'" 54"/" Wall Penetration HIGH SIDE '" UP Cross Sections page 1 .. s .. .. .. .. .. .. .. Well: Field: Company: Tubin : .. 2T-209 .. USA 4.5 ins 12.6 f l-80 Alaska, Inc. .. .. .. .. .. .. .. .. s s October 14, 2007 MFC 40 No. 30807 2.75 40 El i Tool '" 70 NominallD'" 3.958 Nominal OD '" 4.5 Tool deviation'" 9 0 Corrosion .13 ins'" 49"1" Wall Penetration HIGH SIDE '" UP Cross Sections page 1 .. s .. .. .. ............ Well: Field: Company: Tubin: Tool = 65 10 = 3.958 Nomina! 00 = 4.5 Tool deviation = 54 " 2T·209 .............. ConocoPhiWps Alaska, loc. USA 4.5 ins 12.6 f l·80 for .. .. s Survey Date: Tool Type: Tool Size: No. of Anal st: October 14, 2007 MfC 40 No. 30807 2.75 40 B. ¡ .05 ft It Min !.D. = 3.71" HIGH SIDE = UP Cross Sections page 3 .. .. .. .. s - - - - - .. - - - - - - - - - S 55 S S Well: 2T·209 Survey Date: October 14,2007 Field: Kuparuk Tool Type: MFC 40 No, 30807 Company: ConocoPhillips Alaska, Inc Tool Size: 2.75 Country: USA No, of 40 Tubin : 4,5 ins 12.6 f L-BO Anal st: S, I for Joint 109 at ft Too! '" 66 Nomina! 10'" 3,958 Nominal 00 '" 4.5 Tool deviation'" 50 0 Lt Deposits Min 1.0. '" 3.76" HIGH SIDE '" UP Cross Sections page 4 - - - - I I KRU I I I I PUP (~756, I 00:4.500) PUMP ~ I 00:5.620) PUMP (37m783, I 00:5.620) SEAt t:J7æ:3W, I 00:6.125) MOTOR (3797 -31120, I 00'1,125) I I WLEG (3927-392$, I 00:4.980) I SCREEN (~ OD:4640) 00O PHILLIPS PHILLIPS Alaska, Inc. / W A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 February 22, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7`h Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2T-209 (198-243 / 302-008) Dear Commissioner Oechsli Taylor: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover on the KRU well 2T-209. If there are any questions, please contact Skip Coyner at 265-6074. Sincerely, C. Mallary Drilling Engineering Supervisor Phillips Drilling CM/skad RECEIVED FEB 2 Z002 Alaska0il &Gas Commission A OR!�Ii E�f-�L STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _X Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development Exploratory _ Nordic 3 RKB 28' 3. Address 7. Unit or Property name P. O. Box 100360 Stratigraphic Anchorage, AK 99510-0360 Service_ Kuparuk River Unit 4. Location of well at surface 8. Well number 4623' FNL, 4723' FEL, Sec. 1, T11 N, R8E , UM (asps 498945, 5970635) 2T-209 At top of productive interval 9. Permit number / approval number 2803' FSL, 143' FWL, Sec. 1, T11 N, R8E, UM 198-243 / 302-008 At effective depth 10. API number 50-103-20281 At total depth 11. Field / Pool 1991' FNL, 5169' FEL, Sec. 1, T11 N, R8E , UM (asp's 498497, 5973267) Kuparuk River Field / Tabasco Oil Pool 12. Present well condition summary Total depth: measured 4690 feet Plugs (measured) XX plug @ 3730' MD true vertical 3318 feet Effective depth: measured 4678 feet Junk (measured) true vertical 3312 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 112' 16" 9 cu yds High Early 112' 112' SURF/PROD 3971' 9-5/8" 505 sx AS III & 760 sx Class G, 60 4082' 3001' Liner 4" gravel pack screen 4678' 3312' Perforation depth: measured none RECEIVED true vertical none FEB 2 2 20Q2 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 3754' MD Alaska Oil & Gas Cons. Commission Packers & SSSV (type & measured depth) gravel pack packer @ 3929', Baker Model F pkr @ 3915' with KOIV below Anchorage No SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Infection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation SI Subsequent to operation SI 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil _ X Gas _ Suspended _ Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Todd Mushovic 265-6974 Signed , �+ Title: Drilling Engineering Supervisor Date Z / �`a—'> C. Ma/1 Prepared by Sharon Allsup-Drake 263-4612 u OR I G IN11 A L Form 10-404 Rev 06/15/88 • SUBMIT IN DUPLICATE PHILLIPS PHILLIPS ALASKA INC. Page 1 of 12 o a Operations Summary Report Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To Hours Code Sub Code Phase Description of Operations 1/20/2002 18:00-00:00 6.00 MOVE MOVE MOVE Moving rig from 1 M pad to 2T pad 20.6 miles 1/21/2002 00:00-14:00 14.00 MOVE MOVE MOVE Moving rig from 1M pad to 2T pad 20.6 miles -temp 37 below -hydraulic oil thick & blowed breakers- replace one breaker -pull out for cr ew change C 0600 C X pad. (Note) Camp on 2T pad @ 1800 hrs. 01-20-2002. Rig on pad @ 1300 hrs. Spot rig over well. (Accept rig 1400 hrs. 01/21/2002.) 14:00-17:00 3.00 MOVE MOVE MOVE Load 'A' frame -guards & esp spool on rig flo or w/ crane. 17:00 - 20:00 3.00 WELLS OTHR WRKOVR Pull V R plug & BPV . 20:00-21:00 1.00 WELLS OTHR WRKOVR Rig up circ. equipment test hard lines w/ air 21:00-23:30 2.50 WELLSF CIRC WRKOVR PJSM-displace well w/ 350 bbls. seawater. 23:30-00:00 0.50 WELLSF OTHR WRKOVR Rig down kill manifold -install BPV-break do wn hardline. 1/22/2002 00:00 - 01:00 1.00 WELLSF NUND WRKOVR Nipple down tree. 01:00-06:00 5.00 WELLSF NUND WRKOVR Nipple up bope-install 4 1/2" rams. 06:00-07:00 1.00 WELLSF OTHR WRKOVR Function test rams. Pull bpv & install 2 way check. 07:00-10:30 3.50 WELLSR SEOT WRKOVR Test bope 250-3500# ok. 10:30-13:30 3.00 WELLSR PULD WRKOVR Pull 2 way check -install landing jt.-bolds-pu II hanger loose @ 160k-pull to floor slow-kn otty all the way pulling from 80k to 150k-es p electric cable missing. POH laying down 4 1/2" tbg. tight & knotty. Layed down 9 jts.- 35 raychem bands missing & 5 flat guards m issing-18 centralift bans missing. 13:30-15:00 1.50 WELLS CIRC WRKOVR Rig up & circ. while waiting on orders. 15:00-16:30 1.50 WELLS PULD WRKOVR Lay down 11 its. 4 1/2" tbg. Pulling tight. 16:30-00:00 7.50 WELLS OTHR WRKOVR Pipe stuck w/ Bottom motor leg @ 3170'. Wo rk same -change out bails to run free point & chemical cutter. (Load pipe shed w/ dc,s-d p & fishing tools while waiting on sws. Schl umberger running late due to rigging unit fo r free point & cutter.) 1/23/2002 00:00-06:00 6.00 WELLS OTHR WRKOVR Waiting on sws-make up free point. 06:00-10:30 4.50 WELLS OTHR WRKOVR PJSM-rig up sws E-line & sheaves -pick up fr ee point. 10:30-22:00 11.50 WELLS OTHR WRKOVR Rih w/ freepoint-free pointing several depth s from 1600' to 3100'. POH w/ free point & r ig down same. 22:00-00:00 2.00 WELLS OTHR WRKOVR PJSM-pick up -make up string shot-rih & fire string shot @ 3035' to 3045'-poh & lay down string shot. 1/24/2002 00:00-08:00 8.00 WELLS OTHR WRKOVR PJSM-RIH w/ chemical cutter to top of 2 7/8 " @ 3061'-log up -hung up in 4.5" X 3.5" XO- work same loose -pump capacity of tbg. & po h-check tool -clean debrie out of bottom cent ralizer & point spring-rih & cut 3.5" tbg. @ 3040'. (pump capacity of tbg. while running in hole-90k up wt. prior to cutting-50k up wt Printed: 2/14/2002 1:24:27 PM PHILLIPS CP PHILLIPS ALASKA INC. Operations Summary Report Page 2 of 12 Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 Date From -To Hours Code Sub I Code Phase Description of Operations I1/24/2002 00:00 - 08:00 8.00 WELLSOTHR 08:00-12:00 4.00 WELLS PULD 12:00 - 15:00 1 3.001 WELLSROTHR 15:00- 17:00 1 2.001 WELLS" OTHR 17:00 - 00:00 1 7.001 W ELLSR OTHR 1/25/2002 00:00 - 06:00 6.00 WELLS OTHR 06:00 00:00 18.00 WELLS OTHR 11/26/2002 100:00-00:00 I 24.001 WELLSROTHR 1 /27/2002 100:00 - 00:00 1 24.001 W E LLSR OTHR 1/28/2002 100:00- 12:00 1 12.001 WELLSROTHR 12:00 - 00:00 1 12.001 WELLSR OTHR 1/29/2002 00:00-01:00 1.00 WELLS�OTHR 01:00 - 12:30 11.50 WELLS OTHR 12:30 - 13:00 0.50 WELLS OTHR 13:00 - 00:00 11.00 WELLS SEOT WRKOVR . after cutting.) WRKOVR POH Laying down tbg.-recovered 1708' heat trace w/ bands & flat guards -heat trace gon e & all bands guards & clamps gone after he at trace. WRKOVR Change out bails & floor equipment -rig down sws-send out heat trace,bands, & flat guar ds-test lower pipe rams to 250-3500#-set we ar ring. WRKOVR Pick up bha-rope spear & rih-tag esr cable @ 110'-latch fish-poh to rotary table w/ cab] e-5k over string wt.. WRKOVR Fabricate handling tools for esp cable w/ we Ider-clean & inspect derrick. WRKOVR Fabricate clamps & handling tools for retrie ving esp cable. WRKOVR Fishing for esp cable w/ rope spear -recover ed 635'' of cable-19 flat guards & several b ands w/ cable. (circ. well to hot seawater @ 750'.) Recovered 876' By 0600) WRKOVR Continue making trips w/ rope spear recover ing esp cable & various metal pieces includi ng flat guards & bands.(recovered-2229' esp cable-300' heat trace-82 flat guards & bun ch of bands & pieces. (Total since starting 2864' esp cable-101 flat guards-300' heat tr ace & bunch of bands) WRKOVR Retrieving esp completion w/ rope spear (pi ck up 7- 4 3/4" dc,$) Retrieved=984' Heat tr ace-127 flat guards-162 bands+ -.(Total retri eved-2864' esp cable-228 flat guards-1284' heat trace-Approx. 200 bands.) Circ. hot se awater complete circ. @ 1934'. Fishing @ 22 40'. @ midnight. Stacked out on bands. WRKOVR Tripping w/ spear & retrieving esp completio n. (circ. hole @ 2240') WRKOVR Make up washpipe w/ 'E' claw tool & disk -di sk sheared 3 stands off bottom-rih & rig up - reverse & clean out from 2250' to 2265'-rec overed 25 gals. corrosion & scale-3' esp ca ble & bucket full of band pieces-rih w/ same -clean out from 2265' to 2283'. Poh recover ed 5 gals. scale & corrosion-1 flat guard & bucket full of band pieces-5' esp cable.. ( t otal recovered today-23' esp cable- 30 gals. corrosion-2 flat guards & 2 buckets band pi eces. WRKOVR Lay down washpipe assembly. WRKOVR Tripping & fishing w/ spear from 2283' to 23 05' recovered 180' esp cable-32 flat guards- 1 bucket band pieces & 2 nova clamps. WRKOVR Clean metal from stack & function rams. WRKOVR Test bope-change element in annular preven Printed: 2/14/2002 1:24:27 PM PHILLIPS PHILLIPS ALASKA INC. Page 3 of 12 0 ! Operations Summary Report Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To Hours Code Sub Code Phase Description of Operations 1/29/2002 13:00-00:00 11.00 WELLS SEQT WRKOVR ter -repair -outside kill line valve -top drive d ouble ball sub -Test same to 250-3500# OK. 1/30/2002 00:00-02:30 2.50 WELCT BOPE WRKOVR Complete testing bope 3500 / 350 psi / 5 mi in, annular 3000 / 350 psi.Set wear bushing. 02:30-03:30 1.00 WELLS OTHR WRKOVR Slip & cut drlg line. 03:30-04:00 0.50 WELLS TRIP WRKOVR Make up fishing assmby od Ingth Spear 8.375" x 13.45' xo 5.75 x 2.03 lubricated Bump. Sub 4.75 x 7.86 Bowen F. Jars 4.75 x 12.53 Pump out cir sub 4.75 x 1.48 9 do 4.625 x 279.30 Total = 316.65' 04:00-05:00 1.00 FISH TRIP WRKOVR Rih to tag @ fish 2483'. 05:00-05:30 0.50 FISH FISH WRKOVR Work spear down to 2487' 05:30-06:30 1.00 FISH TRIP WRKOVR Pooh, recovered 6 flat guards. 06:30-07:30 1.00 RIGMNT RSRV WRKOVR Rig service & clean floor. 07:30-08:30 1.00 FISH TRIP WRKOVR Rih w/ spear assmby to tag fish @ 2487'. 08:30-09:00 0.50 FISH FISH WRKOVR Work spear down to 2505'. Work spear @ td , pulled up to 70k Ibs off bottom. Weight dr opped back to 6 k over when 30' off bottom. 09:00-10:30 1.50 FISH TRIP WRKOVR Pooh dragging 6k Ibs over - when pulled int o stack heard debris fall off spear. When o ut of the hole recover 2 ea 1/8" x 3/4 x 6" banding material. Ld spear assmbly. 10:30-11:30 1.00 FISH PULD WRKOVR Pu / Mu reverse cir assmby: Reverse Cir b asket 5.75" 7.3' 2 J t s wash pipe 5 .75 62.25 Top sub 1 .87 Bumper sub 4.75 7.86 Bowen Oil Jar 4.75 12.53 Cir - c ontrol sub 4.75 1 .48 9 do 4.625 279.30 xo 1.2 Stop Sub 4.75 1 .8 xo 2.03 Rupture Sub 4.75 1.45 total 3 .35' 11:30-13:00 1.50 FISH TRIP WRKOVR Rih to tag debris @ 2495'. 13:00-14:30 1.50 FISH OTHR WRKOVR Work rev cir sub to 2506' @ 9.7 bpm / 600 p si. Rotate slowly w/ max torque to 8k ft-Ibs Recovered heavy rust & black sand size i ron debris @ shaker for ? 7 minutes. 14:30-15:30 1.00 FISH TRIP WRKOVR Pooh w/ reversing assmby. 15:30-16:30 1.00 FISH PULD WRKOVR Recovered 2 mangled flat guards [estimated ] from reversing assmby. Ld reverse assm bly. 16:30-18:00 1.50 FISH TRIP WRKOVR Rih w/ spear assmbly as above. 18:00-19:00 1.00 FISH OTHR WRKOVR Work spear on bottom & down to 2522' w/ ov er pulls to 60k Ibs over string wt. Pull up 6 0' off td, wt dropped to 6k Ibs over. 19:00-20:00 1.00 FISH TRIP WRKOVR Pooh w/ spear assembly. Printed: 2/14/2002 1:24:27 PM PHILLIPS 9P PHILLIPS ALASKA INC. Page 4 of 12 Operations Summary Report Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 nl433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To Hours Code Sub Code Phase Description of Operations 1/30/2002 20:00-20:30 0.50 FISH OTHR WRKOVR Recovered approx. 2 complete Nova clamps & 30 Ibs of flat guard material which = ?10 f lat guards. 20:30-21:00 0.50 FISH OTHR WRKOVR Clean floor & repair spear 21:00-22:00 1.00 FISH TRIP WRKOVR Rih w/ spear assmby as above. Tag up @ 2 522', push down 4' to 2526' w/ light wt. 22:00-00:00 2.00 FISH OTHR WRKOVR Rotate / circulate down 3 singles. Continue to rotate down singles [not circulating] to 2850' where started taking weight. Mu tds f or circulation, & prepare to rot cir string d own. 1/31/2002 00:00-00:30 0.50 FISH OTHR WRKOVR Continue to circulate [300 psi / 5.2 bpm] & r otate down to 2932' where torque built to 55 00 ft-Ibs. 00:30-01:30 1.00 FISH CIRC WRKOVR Circulate 2 x bottoms up. Very light corrosi on material on shakers. 01:30-03:30 2.00 FISH TRIP WRKOVR Pooh 10 stands slowly to 2000', dragging 12 Ok Ibs over string & swabbing 18 bbl per 5 s tands. Ck for flow each 5 stands [15 mins]. 03:30-06:00 2.50 FISH TRIP WRKOVR Weight dropped backed to calculated string wt plus some light drag. Continued to pooh w/ correct hole fill. Recovered 1 Nova cl amp, part of a flatguard & 30' of esp cable. 06:00 - 07:00 1.00 RIGMNT RSRV WRKOVR Rig Service 07:00-08:00 1.00 FISH TRIP WRKOVR Rih w/ spear assmby to tag debris @ 2934' Dailey planning meeting held 0700 hrs [too I pushers, ppco,brine engineer] 08:00-08:30 0.50 FISH FISH WRKOVR Work spear down to 2942'. Difficult to get a good catch & hole same. Got one good ov er pull of 100k Ibs & started out w/ slight dr ag. 08:30-10:00 1.50 FISH TRIP WRKOVR Pooh dragging 1500 - 2500 lbs. Recovered 6' of ESP line. 10:00-11:00 1.00 RIGMNTRGRP WRKOVR Replace hydraulic cylinders on TDS compens ator. 11:00 - 12:00 1.00 FISH PULD WRKOVR L d spear b h a . 12:00-14:00 2.00 FISH PULD WRKOVR Pick up & make up wash pipe bha: 8.375" Wash Pipe shoe 2.35' XO & Dragon Tooth Extension 4.88 1 it 8.125' wash pipe 32.05 xo junk basket 5.69 2 each junk baskets 9.24 Bit sub 70 Bumper Sub 7.86 B owen Oil Jars[4.75"] 12.53 9 x 4.7 5" do 279.30 C i r pump o ut sub 2.12 Total 358.72 14:00-15:00 1.00 FISH TRIP WRKOVR Rih on 3.5" dp to tag debris @ 2935'. 15:00-20:00 5.00 FISH WASH WRKOVR Washing over junk / debris from 2935' to 29 90.5'. 1st 7' slow, then broke through & wa shed ahead. 7.8 bpm / 550 - 660 psi, wts 2 Printed: 2/14/2002 1:24:27 PM PHILLIPS WOperations PHILLIPS ALASKA INC. Page 5 of 12 Summary Report Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 nl433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To Hours Code Sub Phase Description of Operations Code 1/31/2002 15:00-20:00 5.00 FISH WASH WRKOVR - 12 k Ibs, 60 - 70 rpm, torque 1500 - 6500 f t lbs. Shakers 25% coverage w/ hi percenta ge of rust - corrosion material, not much "fr esh steel material". NOTE - SIMULTANEO US OPS: During this time block cleaned hol e w/ hi-vis sweep, 50 bbl hot diesel pill & di splaced w/ 580 bbl warm clean sea water tre a t e d w/ KCI to 2%. 20:00-21:00 1.00 FISH CIRC WRKOVR Cir / cond sweep hole. 21:00-23:00 2.00 FISH TRIP WRKOVR Pooh w/ washover string. Ld jars [will repla c e ] . 23:00-00:00 1.00 FISH PULD WRKOVR Shoe in good shape, wash pipe in good cond ition. Clean out string recovering 4?' of ste el & copper, weight = ?50 lbs. Junk baskets full of steel & copper [1.5 gallons]. 2/1/2002 00:00-01:00 1.00 FISH OTHR WRKOVR Continue to clean out washover assembly. Note: recovery on previous rpt [# 12]. 01:00-02:30 1.50 FISH TRIP WRKOVR Trip in hole w/ washover string, tag up on d ebris @ 2990' [previous depth was 2990.0']. 02:30-06:00 3.50 FISH WASH WRKOVR Wash over debris from 2990 to 3011'. 8' of washover was accomplished in first hour, aft er that the rate decreased gradually to .5 - 1' foot per hour. No increase in pump press ure due to all recovery below slots cut in "d ragon tooth" catch sub. Parameter 350 - 45 0 psi @ 6 - 7 bpm, torque 1500 to average o f 3800 w/ peaks to 6500 ft-Ibs [to make any head way near the end w/ 15k Ibs on the sho e ] . RPMs in the 65 to 75 range dependent o n weight. Weight 5 to max of 15k Ibs near e nd of run. 06:00-07:00 1.00 FISH CIRC WRKOVR Circulate cond, prep for trip. Held dailey ops meeting [ppco, 2 x pushers, brine engin eer] 07:00-09:30 2.50 FISH TRIP WRKOVR Pooh w/ washover assembly. 09:30-10:00 0.50 FISH WRKOVR Clean out wash pipe, rec 4.5', recover @ to wer dragon tooth. 10:00-12:30 2.50 FISH TRIP WRKOVR Trip in hole w/ wash -over assembly, tag pre vious td on depth of 3011'. Did not run "dr agon tooth" sub in wash - over assembly. 12:30-14:00 1.50 FISH WASH WRKOVR Wash over debris from 3011 to 3024'. Pump press increased from 650 to 1000 psi. N e c essary to increase weights from 2K Ibs to 1 OK + Ibs to to make assembly cut @ end of r un. Torque mild @ 2500 - 3500 ft-Ibs. S h a kers yielding fine black steel / copper / rub ber & not much. 14:00 - 16:00 2.00 FISH TRIP WRKOVR P o o h 16:00-17:00 1.00 FISH OTHR WRKOVR Break off shoe, recover estimated 4 Nova cl amps & 30 + feet of esp cable. Junk basket s full, 1.5 gallons. 17:00-18:30 1.50 FISH TRIP WRKOVR Rih w/ wash over assembly to include "drago Printed: 2/14/2002 1:24:27 PM PHILLIPS PHILLIPS ALASKA INC. Page 6 of 12 t t Operations Summary Report Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 Date From -To Hours Code Sub Code Phase Description of Operations 2/1/2002 17:00-18:30 1.50 FISH TRIP WRKOVR n tooth sub. Tag up @ 3024'. 18:30-22:00 3.50 FISH WASH WRKOVR Wash over fish from 3024 to 3029'. Slow en tire way. Torque in the 3500 - 4500 ft-lb r ange, not definitive [to pump pressure or we ight on shoe]. 22:00-23:30 1.50 FISH TRIP WRKOVR Pooh, incomplete @ rpt time. 2/2/2002 00:00-02:30 2.50 FISH TRIP WRKOVR Complete Tih to tag @ 3029' [previous td = same]. 02:30-05:00 2.50 FISH WASH WRKOVR Wash over fish from 3029 - 3035', no progre ss last hr. 05:00 - 06:30 1.50 FISH TRIP WRKOVR P o o h 06:30-08:00 1.50 FISH OTHR WRKOVR Recover 60 Ibs esp cable & Nova clamps ma ngled & compressed together by milling act ion W/ a 1 .5' X 3.875' CENTER CORE. Ju nk baskets full. Noted that recover was s hort of 1st dragon tooth. 08:00-09:30 1.50 FISH TRIP WRKOVR Rih w/ washing assembly to tag debris @ 30 34' [previous td 3035']. 09:30-15:00 5.50 FISH WASH WRKOVR Work pipe to insure over 3.5" stick up. W o r k over 3.5" cut off to 3050', based on the 1. 5" core on the previous run this will place t he shoe several inches above the "Y" block. During washing ops picked up several time s to 25k Ibs over to engage debris well. 15:00-16:00 1.00 FISH CIRC WRKOVR Pump hi viscosity (120 sec +) 8.7 ppg 30 bb I pill. Some minor increase in material @ s haker. 16:00-17:30 1.50 FISH TRIP WRKOVR Pooh w/ wash string. Rotate slowly off 3.5" stem. Very little drag / wt increase on trip out. 17:30-19:00 1.50 FISH OTHR WRKOVR Recover 6' of mangeled debris [50 Ibs] from wash pipe, lower dragon teeth were engaged debris exibited a ? 3.8" core through the recovery. Bottom piece of debris was the in tact "Sentry Gage" clamp which sits on top of the "Y" block. 19:00-20:30 1.50 FISH TRIP WRKOVR Rih w/ wash pipe assembly, did not run "Dr agon" tooth sub. 20:30-22:30 2.00 FISH WASH WRKOVR Precautionary wash ream over fish: A n t i c i p ate & tag top of 3.5" as per tally, rotate ove r same & 3 '. Wash to bottom of 3049'+. 22:30-00:00 1.50 FISH CIRC WRKOVR Cir condition one bottoms, pump 30 bbl hi vi s sweep, continue to circulate sweep down [ sweep - circulation incomplete @ rpt time]. 00:00-00:30 0.50 FISH CIRC WRKOVR Complete cir 30 bbl hi vis sweep, continue to circulate sweep down for bottoms up + on e additional bottoms up. Set down 5k Ibs du ring ops, fish did not move. Very little mat erial to surface. 00:30-03:00 2.50 Pooh, Id tools not required for grapple run, clean out wash over string, recovering some minor material from lower junk basket. Printed: 2/14/2002 1:24:27 PM PHILLIPS PHILLIPS ALASKA INC. Page 7 of 12 i e Operations Summary Report Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To Hours Code Code Phase Description of Operations 2/3/2002 03:00-05:00 2.00 FISH PULD WRKOVR Completing making up grapple bha assembly Item length 8.125" shoe 2.68 w/ 3.5" id internal d r e s s i n g mill xo to wash pipe 1.45 8.125" over shot 1.75 dressed w/ 3.5" b a s k e t grapple 8.125" extension 3.30 8.125" top sub 1.14 Bumper Sub 8.98 Oil jar 11.54 xo 2.67 7 6.25" do 11.04 xo 1.30 9 4.7 5" do 279.30 pump out sub 2.12 total 527.27 05:00-06:00 1.00 FISH TRIP WRKOVR Complete rih w/ grapple assmby to tag top o f 3.5" tbg as per tally @ 3034'. Rotate over fish & swallow a total of ?9', 4.5' of 3.5 tb g above grapple. No circulation - fish plugg ed. Fish will move down hole w/ 6k Ibs over , pull [smooth] w/ no jarring @ 25k Ibs over string. 06:00-07:00 1.00 FISH SFTY WRKOVR Crew change / ops meeting / rig service 07:00-12:00 5.00 FISH PULL WRKOVR Pooh slowly w/ fish, string wet. Dragging 2 0-25k over string. 12:00-15:30 3.50 FISH PULL WRKOVR Break out fish from fishing string. Ld pump & pump assemble. Noted severe corrosion increasing w/ depth. 15:30-18:00 2.50 WELLSP TRIP WRKOVR Make up reversing assemby. Item length Rev Basket 8.5" o d 7.3' 2 jts 5.75" wash Pipe 62.25 top sub 1.87 XO 1.05 Bit s by 1.7 Bumper sub 6 .25" 8.98 Oil jar 6.25" 1 1 .54 xo's 2.31 Stop sub 1.08 x0 2.03 Cir nt jt 1.48 9 4.75 do 279.30. otal 350.89 blank sub [w/ disk insta lied] in dp 20 stands from surface. 18:00-20:30 2.50 WELLSR TRIP WRKOVR RIH w/ reversing assembly. Rupture disk fa iled @ ?10 stands (900') in hole. Taged up solid @ 3725', [top of Y block originally @ 3727']. 20:30-21:30 1.00 WELLSR CIRC WRKOVR Close annular w/ 350 psi closing pressure, start reverse circulation, work down to conn ection @ 3735', string taking no weight. Ru n in to 3745' not circulating when tagged up Start reverse circulating, pressure increa sed gradually to 450 as rate was brought to 6 bpm work down to 3768' when string plug ged off after 6 minutes. Work w/ string - u nable to reverse circulate. Line up & pump out pump out plug @ 320 psi. Printed: 2/14/2002 1:24:27 PM PHILLIPC(P PHILLIPS ALASKA INC. Operations Summary Report Page 8 of 12 Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 Date I Sub From - To Hours Code f Code I Phase 2/3/2002 21:30 - 00:00 2/4/2002 00:00 - 02:00 02:00 - 04:00 04:00 - 05:00 05:00 - 06:00 06:00 - 07:00 07:00 - 00:00 2.501 WELLSROTHR 2.00 WELLS TRIP 2.00 WELLS CIRC 1.00 W 1.00 W 1.00 W 17.00 W 2/5/2002 00:00 - 12:30 12.50 WAITON WOW 12:30 - 13:30 1.00 WELLSR OTHR 13:30 - 15:00 1.50 WELLS 15:00 - 16:00 1.00 WELLS OTHR 16:00 - 17:30 17:30 - 23:00 23:00 - 00:00 1.501 WELLSF1OTHR 5.501 WELLSR TRIP 1.001 WELLSFICIRC Description of Operations WRKOVR Pooh w/ bailer string, recovered 2 x 6" pie ces of flat band & a 1' section of Nova clam p. The recovered material had the flapper i n the reversing basket wedged open. WRKOVR Rih w/ bailing string, install rupture disk 12 stands from surface. WRKOVR Tag up @ 3768', work down reversing to 383 9' minimum rotation. Pump pressure @ 3b pm increased from 600 to 1600 psi & plugge d off. WRKOVR Pooh 10 stands, string dry. WRKOVR Phase 3 WX restrictions in effect. WRKOVR Continue to WOW - PPCO rep. discretion. WRKOVR Kuparuk area in Phase 3 WX conditions. @ 0300 hrs 5 Feb Spine rd to CPF2 are in Pha se 2[plowed]. All rds / locations to the W & SW of CPF2 are in Phase 3 [not plowed]. T he crew on duty [#1) reported to the rig & worked from 2100 hrs 3 Feb. Crew #1 has b een split since 0700 hrs 4 Feb [ well watch / roll hole ea hr & walk around & rig inspecd tion]. Nordic 3's plan is to meet the relief [ crew #2, 2 crews are @ Kuparuk]] @ CPF2 @ 0700hrs today w/ loader, bring into locatio n & escort crew #1 to CPF2 & on to KCC if n ecessary. Change out crew [3dr crew] is in Anchorage & is scheduled to ary Kuparuk 23 00 hr 5 Feb, will report to work 0600 hrs 6 F eb [normal day schedule]. Satellite ima ge of NW Alaska depicts ccw bands of cloud s approaching from the west. Temp 0 to -10 ?F, w/v = 13 to 35 mph & increasing. WRKOVR Wait on weather. Well watch & roll pumps. Continue w/ scheduled rig maintenance. Conduct cps meeting @ 0900 hrs [PPCO, pu shers, baker fish & brine engineer]. WRKOVR Prepare to pooh w/ reversing assembly. WRKOVR Pooh w/ reversing asembly. WRKOVR Recovered mangled centry gage, ? nova cla mp, bits & pieces of flat guard / banding ma terial [total of 15 Ibs steel material]. R e v e r s i n g basket flappers damaged. WRKOVR Discuss options on location & later w/ PPCO engineering precipitated by weather / logis itics. WRKOVR Make up finger basket reverse circulating ba sket on 5.75" wash pipe w/ bumper sub, jar s & dcs. Rih to tag @ 3866'. This depth is a correction - error incurred on rpt #15, Ops Summary 02:00 - 04:00, should read "work ed down down reversing to 3868''. WRKOVR Break cir & reverse cbu. Start working dow n reversing: Initially Rev cir 8 bpm / initial Printed: 2/14/2002 1:24:27 PM PHILLIP(P Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PHILLIPS ALASKA INC. Operations Summary Report 2T-209 2T-209 WORKOVER/RECOMP Start: 1/21/2002 NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Nordic 3 Rig Number: 3 Date From - To Hours Code Sub ICode Phase 12/6/2002 Page 9 of 12 Spud Date: 1 /1 /1999 End: 2/10/2002 Group: Description of Operations 23:00-00:00 1.00 WELLS CIRC WRKOVR 600 psi building quickly to 1600 psi. D e c r e ased rate gradually to 3 bpm as pressure co ntinued to build. When picking up OFF b o t t om pressure would INCREASE. Working do wn to 3868'. 00:00-00:30 0.50 WELLSFICIRC WRKOVR Initially Rev cir 8 bpm / initial 600 psi build ing quickly to 1600 psi. Decreased rate gra dually to 3 bpm as pressure continued to bui Id. When picking up OFF bottom pressure would INCREASE w/ a final off bottom pr essure to 2100 psi. This pressure increase developed over numerous cycles, approx a t otal of 3 hrs of working @ or near bottom. Final td = 3839.5'. This is essentially the same depth achieved 0400 hrs 4 Feb. 00:30-01:30 1.00 WELLS TRIP WRKOVR Pooh w/ rev assembly. Recovered 2.5 gallo ns of debris from 1 to 3", appears to be larg ely banding material / esp cable along w/ 1" square pieces of clamp material & one part of sentry gage - 2"od [round] 8" long. Some material on top of stop sub screen which w as above the jars, 90' off bottom, 4 of 7 hol es [3/8"] in stop screen plugged. Finger b asket not damaged. 01:30-03:30 2.00 RIGMNTRSRV WRKOVR Cut drlg line. Discuss options, ck wx & bak er machine progress, special tools are read y, drlg tool house will retrieve ASAP in Con voy. Entire field in phase 2 @ 0221 hrs. 3rd crew that was waiting in Anchorage is @ Kup. 03:30-04:30 1.00 RIGMNT WRKOVR Rih w/ finger basket assembly. Did not run stop sub in bha, will place in string 5 stand s from surface in dp. Tag up @ 3839'+. 04:30-08:30 4.00 RIGMNT WRKOVR Reverse cir & work down to 3874'. Pu & cle an stop sub screen 3 x times, on 3rd clean out left out Out string. Recovering metal de bris ? half dollar size & shape [@ shaker], 8 0%+ esp cable. Circulate hole 45 minutes, r ecovering small amts of frac like sd. Last 2 washed like sand. Make [0600 hrs] crew change in convoy. Ops planning Meeting [0730] 08:30-10:30 2.00 WELLSP TRIP WRKOVR Pooh w/ finger basket. break out & clean w ash pipe above finger basket recovering .5 gallon of 1 .5 - 2.5' planner steel, large % o f esp cable material. 10:30-15:30 5.00 WELCT BOPE WRKOVR Test Bope to 3500 / 250 psi 5 min each, a n n ular to 3000 psi. Good test, no leaks. 15:30-16:30 1.00 WELLS TRIP WRKOVR Pu / Mu 8.125" cable type washing shoe on t wo jts of 8.125" wash pipe, xo to bumper su b & jars w/ dcs. 16:30 - 18:00 1.50 WELLS TRIP WRKOVR Rih w/ bha on 3 . 5 " d p . 18:00-19:00 1.00 RIGMNT RSRV WRKOVR Crew change & rig service. Printed: 2/14/2002 1:24:27 PM PHILLIPS PHILLIPS ALASKA INC. Page 10 of 12 Cc 0", Operations Summary Report Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 Date From -To Hours Code Code Phase 2/6/2002 19:00 - 19:30 0.50 WELLSR TRIP WRKOVR 19:30-22:30 3.00 WELLSR WASH WRKOVR 22:30 - 00:00 1.50 WELLSR WRKOVR 2/7/2002 00:00 - 01:00 1.00 WELLSR CIRC WRKOVR 01:00-02:30 1.50 WELLS TRIP WRKOVR 02:30 - 03:30 1.00 WELLSR PULD WRKOVR 03:30-05:00 1.50 WELLSR WRKOVR 05:00-07:30 2.50 WELLSR WRKOVR 07:30-10:30 3.00 WELLSR TRIP WRKOVR 10:30-12:00 1.50 WELLSR TRIP WRKOVR 12:00-13:30 1.50 WELLSR CIRC WRKOVR 13:30-15:00 1.50 WELLSR CIRC WRKOVR 15:00 - 17:30 2.50 WELLSR OTHR WRKOVR 17:30 - 21:00 3.50 WELLS TRIP WRKOVR 21:00-22:30 1.50 WELLSR CIRC WRKOVR 22:30-00:00 1.50 WELLSR CIRC WRKOVR 2/8/2002 00:00-01:30 1.50 WELLS TRIP WRKOVR 01:30 - 02:30 1.00 RIGMNT RSRV WRKOVR Description of Operations Complete rih to tag @ 3874'. Pu off bottom & establish reverse circulatio n. Reverse circulate @ 7 bpm / 600 psi. R everse down to 3898' [30 minutes], pump pr essure increased to 1600 psi, cir 2x botto ms up convertionally [1hrs], sd on shaker. Return to reversing mode & work down to 39 25' [30 minutes], recovering sd w/ small ste el [1 -2 "]. Some light torque variations do wn to ? 3915'. Reverse cir & pump 2 x 30 bbl hi vis sweeps sd to surface, traces of very small steel [I ast sweep in hole @ rpt time]. Continue to reverse cir out 2nd sweep. Sd on shaker w/ trace of small metal [.5"]. Pooh w/ cable basket, recovered .5 gallon h and size clamp material w/ a 11' long solid sand core in the near bottom of cable baske t. Ld wash pipe & cable basket assembly, pu t ools for bit & scraper run. Rih w/ bit [8.5" x MXC1 x open jets] & scra per. Tag up @ 3925. Reverse down to 3927 where set down solid. Reverse cir displacing 2 x 30 bbl hi vis swe eps @ 7 bpm / 460 psi. Pooh w/ bit & scrapper, Id same. Rih w/ 3?" 29' stinger on 3? dp. Tag up on SC-1 packer @ 3927', as per tally. Press ure test csg to 1000 psi / 5 minutes. Establish reverse circulate & rotate as requi red from 2927 to 3955' @7 bpm / 575 psi. R equired 15k Ibs wt to start into packer bore or break up sd.. Reverse cir hi vis 30 bbl pill & displace sam e, some light sd @ shaker, majority of sd ha d been circulated out prior to sweep. Prepare to pooh w/ 3?" stinger & Load ESP spool on to rig floor. PU 3 jts of 2.875" hydrill 511 tbg [flush jts] & rih to 3939' [SC-1 Pkr @ 3927'] where to ok weight, rotate through & continue to 3955 [ 3.5" stinger went to 3955']. Set up to reverse cir. Rev cir 3955 to 3997' 7 bpm / 600 psi. Recovering sand @ shak er. Pump pressure increased to 700 psi @ b ottom w/ 1000 Ibs set down. Cir cond 3995 - 3997'. Decreasing sd on sh aker, @ end no sand. Pooh w/ 3.5" dp & 90" of 2.875" H-511 stiing er. Change out wash pipe on tds, & link tilt cyli nder, bring esps into pipe shed & Pu ret too Printed: 2/14/2002 1:24:27 PM PHILLIPS PHILLIPS ALASKA INC. Page 11 of 12 9P Operations Summary Report Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To Hours Code Sub Code Phase Description of Operations 2/8/2002 01:30 - 02:30 1.00 RIGMNT RSRV WRKOVR I f o r i b p . 02:30-04:00 1.50 WELLSP TRIP WRKOVR Rih w/ 2.875" flush jt tbg w/ retreaving tool on 3.5" dp,to 3900'. 04:00-05:00 1.00 WAITONPERS WRKOVR Wo echo meter tech. 05:00-07:00 2.00 FISH FISH WRKOVR Rih to top of IBP @ 3996', wash last 5' [not precautionary] to fishing neck, catch same p u & release IBP. Allow elements to relax, I osing fluid to well bore. Wait 5 minutes, pu II up into 9.875" csg dragging 2-5 k Ibs over string. 07:00-07:30 0.50 FISH OTHR WRKOVR Wo fluid level to stablize & shoot two fluid I evels of 475 & 500', no fluid added to well b ore. 07:30-10:30 3.00 FISH PULL WRKOVR Pooh w/ ibp, no damage to same. Adding 50 bl fluid to well / hr, shoot two fluid level s per ?1000', fluid level staying @ ? 500'. 10:30-14:30 4.00 WELLS PULD WRKOVR Pu Baker Model F packer assembly & rih to t ag up inside SC -1 gravel paker 2' @ 3928'. Continue to add completion fluid @ 50 bbl per hr. 14:30-16:00 1.50 WELLS OTHR WRKOVR CBU, drop ball cir down, set Model F w/ 200 0 psi, shear off w/ 15k Ibs over sting, fill h ole w/ 22 bbls & monitor static. Top of M odel @ 3915', mule shoe Inside SC-1 one fo of @ 3928', spaced out one foot off stack ou t point. Fluid invertory review indicates hole took 400 bbls since IBP released. 16:00-20:00 4.00 WELLSR TRIP WRKOVR Pooh, laying down setting tool & other un-ne eded equip. Clean rig floor & organize sam e. 20:00-00:00 4.00 WELLSR SFTY WRKOVR Pjsm. Pu 4.5" prod tbg / Trip standing back in derrick [incomplete @ rpt time]. 2/9/2002 00:00-03:00 3.00 WELLSR OTHR WRKOVR Complete picking up & standing back 4.5" pr od tbg. 03:00-04:00 1.00 WELLSR SFTY WRKOVR PJSM / ops on pu & running pump -motors &e sp completion. 04:00-12:00 8.00 WELLSR PULD WRKOVR Run in hole w/ esp completion. Esp cable a s sent out was reported as having 4800' foot on same. However, w/ 900' of esp completi on to run the real is short 500' of esp cabl e [discovered @ 1030 hrs]. Have located re placement cable & ordered same. 12:00-16:00 4.00 WAITONEQIP WRKOVR Wait on esp cable: ESWP cable arrives. Upon evaluation on rig floor determined esp cable not of sufficient quality to run in h o I e. Cable is 90% covered w/ general red r u s t w/ numerous corrosion cells. Located an available unused partial reel of line. Will tr uck over [3 hrs] & use same. 16:00-19:00 3.00 WAITONEQIP WRKOVR Wo second Esp cable. 19:00-20:00 1.00 WELLS OTHR WRKOVR Remove Esp spool from rig floor & install se cond reel on floor. 20:00-22:00 2.00 WELLS OTHR WRKOVR Make Esp cable splice. Printed: 2/14/2002 1:24:27 PM PHILLIPS (1p PHILLIPS ALASKA INC. Operations Summary Report Page 12 of 12 1 Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 Date From -To Hours Code Sub Code Phase Description of Operations 2/9/2002 22:00-23:00 1.00 WELLSP TRIP WRKOVR Complete running a total of 119 its 4.5" x 1 2.6 Ib x L - 8 0 x I b t c mod to complete E s p s t r ing. 23:00-00:00 1.00 WELLSR OTHR WRKOVR Make up Esp lower connector. 2/10/2002 00:00-03:00 3.00 WELLSR TRIP WRKOVR Complete mu of lower esp connector & test same. Mu Sentury gage "I" wire & test. test shows bhp = 1200 psi / 62?f, calculated = 1 246 psi. 03:00-04:30 1.50 WELLSR OTHR WRKOVR Ldg hanger, checking alignment. RILDB, set 2 way bpv & Id Idg jt. Bottom of pump @ 3 846'. 04:30 - 06:00 1.50 WELLSR NUND WRKOVR N d riser & 1 1 " B O P E . 06:00-09:30 3.50 WELLSR DEQT WRKOVR Nu production tree ,leaking around "R" ring seal, replace same, test good. Complete 2 50 / 5000 psi test [10 min] on void & pack o ff. 09:30-11:00 1.50 WELLSR DEQT WRKOVR Make final continunity checks & Sentury Gag e ck. RD test lines. Pull 2 way BPV. 11:00-16:00 5.00 WELLSR FRZP WRKOVR Load annulus w/ 130 bbl sw treated w/ 30 ga IIons Concor 404 & 5 gallons of Safe Scav H 2S scavanger. Follow w/ 155 bbl diesel. Ma nifold annulus to tbg & allow to equalize via a chocked line. Limit flow rate to 1.25 by m max as directed by Center Lift. 16:00-18:30 2.50 WELLS OTHR WRKOVR Clean pits & rig down equalizing lines. 18:30-19:30 1.00 WELLS OTHR WRKOVR Prepare rig to move off well & move off. 19:30-20:30 1.00 WELLS OTHR WRKOVR Remove pit liner from rig foot print & berms Inspect location, well hd & police location Rig released @ 2030 hrs. Rig off locatio n @ 2045 hrs 01/10/2002 & moving to 1 R - 1 8. Printed: 2/14/2002 1:24:27 PM 2T-209 Event History Date Comment 10/26/01 SPOT 5 BBL 7.5% HCL ACID ON ESP. PUMPED 15 BBL DIESEL LEAD, 5 BBL ACID, 51.5 BBL TAIL. AGITATE ESP, PUMPED AN ADDITIONAL 5 BBL DIESEL DURING PUMP AGITATION. [ESP WORK] 01/04/02 POT-T - PASSED, PPPOT-T - PASSED [WH MAINTENANCE] 01/10/02 UNABLE TO PULL PLUG @ 3730' RKB. SUSPECT ASPHALTINES. 01/11/02 BROACHED & FLUSHED SCALE/ASPHALT RESIDUE W/2.12" BROACH TO 3190' WL. PROGRESS SLOW. JOB SUSPENDED PENDING CTU. 01/12/02 WASHED OUT SCALE / FILL TO TOP OF PLUG AT 3730' RKB W/1.75" VORTECH JET -SWIRL NOZZLE USING SEAWATER W/ J313 & SLICK DIESEL. RBIH W/ WF FISHING BHA (2.25" MHA, DAILEY JARS, HYD. DISCONNECT, 2.2" RUPTURE DISK SUB W/ 5200# DISC., AND 2.5" GS) AND PULLED "XX" 01/13/02 ATTEMPTED TO SET BAKER 2-1/8" IBP; 1ST ATTEMPT UNABLE TO PASS NIPPLE AT 3730' RKB (SUSPECT TEL FAILURE). 2ND ATTEMPT, REMOVED TEL AND HUNG UP IN 4-1/2"X3-1/2" X-O @ 3626', PARTIALLY SETTING IBP. WORKED PLUG FREE & FOUND ELEMENT PARTLY "ROLLED". 3RD ATTEM 01/14/02 BAILED BRIDGES & TAGGED @ 4360' WLM. DRIFTED W/ 2-1/8" X 10' STEM TO 4100' WLM. [TAG] 01/15/02 2-1/8" BAKER IBP SET @ 3996' RKB (TOP OF PLUG), PLACING CENTER ELEMENT @ 4002' RKB; P/T'D TO 500 PSI FOR 10 MINS-- HELD SOLID. 1000# OF 20/40 SAND PLACED ON TOP OF IBP (UNABLE TO GET INTO SCREEN ASSBLY W/ NOZZLE --PUMPED FROM 9-5/8" PKR TOP); LET SETTLE/G 01/16/02 TAGGED BTM @ 393T RKB W/ 2.20" GAUGE RING. COMPLETE [TAG] 01/17/02 PLACE 1600# 20/40 SAND WITH CTU. WAIT 6 HOURS FOR SAND TO SETTLE. TAG SOFT SAND TOP AT 3904' MD (25' ABOVE LINER TOP), WILL ALLOW 6 MORE HOURS SETTLING TIME BEFORE CIRCULATING WELL. LEAVE DIESEL IN TUBING TO 3100'. _ 01/18/02 CIRCULATED 425 BBLS OF 100 DEG DIESEL DOWN THE TBG AND OUT IA TO REMOVE HEAVY CRUDE. DISPLACED THE TBG & IA TO SEAWATER W/ 2500' DIESEL CAP ON BOTH. PT'D THE IBP & SAND PLUG TO 500 PSI, GOOD TEST. DEPRESSURE BOTH TBG AND IA TO 0 PSI. UNABLE TO FLUSH OUT T 02/10/02 PUMPED 600 BBLS OF DIESEL AT 2.5 BPM DOWN INNER ANNULUS TO WASH LINER SCREEN. Page 1 of 1 2/22/2002 MICROFILMED 7/30/02 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Saved as M:/weepie/microfilm_marker.doc PHILLIPS PHILLIPS Alaska, Inc. W A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. R. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 January 7, 2002 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 71h Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 2T-209 Application for Sundry Approval (APD 198-243) Dear Commissioner: Phillips Alaska, Inc. hereby files this Application for Sundry Approval to workover the Tabasco 2T-209 well. If you have any questions regarding this matter, please contact Todd Mushovic at 265-6974. Sincerely, C. R. Mallary Drilling Engineering Supervisor PAI Drilling CRM/skad RECEI QED AlJAN 0 8 2002 OilA r3as Cons. Ante Commission ORIGINAL V-j(-tA I / ql0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _X Variance— Perforate _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X Exploratory_ RKB 111 feet 3. Address 7. Unit or Property name P. O. Box 100360 Stratigraphic Anchorage, AK 99510-0360 Service_ Kuparuk River Unit 4. Location of well at surface 8. Well number 4623' FNL, 4723' FEL, Sec. 1, T11 N, R8E , UM (asp's 498945, 5970635) 2T-209 At top of productive interval 9. Permit number / approval number 2803' FSL, 143' FWL, Sec. 1, T11N, R8E, UM 198-243 At effective depth 10. API number 50-103-20281 At total depth 11. Field / Pool 1991' FNL, 5169' FEL, Sec. 1, T11 N, R8E , UM (asps 498497, 5973267) Kuparuk River Field / Tabasco Oil Pool 12. Present well condition summary Total depth: measured 4690 feet Plugs (measured) XX plug @ 3730' MD true vertical 3318 feet Effective depth: measured 4500 feet Junk (measured) true vertical 3222 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 112' 16" 9 cu yds High Early 112' 112' SURF/PROD 3971' 9-5/8" 505 sx AS III & 760 sx Class G, 4082' 3001' 60 sx AS 1 4" gravel pack screen 4678' Perforation depth: measured none RECEIVED true vertical none JAN 0 8 2002 A'Ska Oii d"r Gas Cons. CO(nl►i' Tubing (size, grade, and measured depth 4-1/2", 12.6#, L-80 Tbg @ 3626' MD; 3-1/2", 9.3#, L-80 Tbg @ 3727' MD. Lwon Anchorage Packers & SSSV (type & measured depth) gravel pack packer @ 3929' No SSSV 13. Attachments Description summary of proposal _X Detailed operations program _ Schematics X 14. Estimated date for commencing operation 15. Status of well classification as: January 18, 2002 Oil _X Gas _ Suspended 16. If proposal was verbally approved Name of approver Date approved Service 17. 1 hereby certify that e foregoing is true an C rrect to the best of my knowledge. Questions? Call Todd Mushovic 265-6974 Signed ,r^% I/ �i.X - Title: Drilling Engineering Supervisor Date C. Ma/la Pre ared b Sharon Allsu - r263-4612 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no. Plug integrity _ BOP Test,? Location clearance _ ^ fD Mechanical Integrity Test _ Subsequent form required 10- / �/ t L o riginal Signed By io Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 ORIGINAL SUBMIT IN TRIPLICATE Workover Procedure 2T-209 1. MIRU Nordic Rig U. RU hardline and flowback tanks. Circulate seawater. Wait until well is static and read tbg and annulus pressures. Calculate brine weight and circulate kill weight brine around. 2. Ensure that the well is dead. ND tree. NU BOPE. Function test BOPE. Pull BPV. Install test plug. Test rams and choke manifold to 5000 psi / Test annular to 3500 psi (Minimum 24 hours notification to AOGCC is required prior to nippling up and testing). 3. Screw into tubing. BOLDS, pull hanger to floor. 4. POOH standing back 4-1/2" tbg. Spool heat trace and ESP cable onto drums. 5. TIH with reverse junk basket and cleanout wellbore to liner top. TOH. J 6. Pull wear bushing and re -run 4-1/2" tbg and ESP completion. 7. Pull landing joint. Install BPV. ND BOP stack and NU tree. Pull BPV. Install test plug. Test tree to 250 and 5000 psi. Test packoff to 5000 psi. Pull test plug. 8. Displace well to seawater by pumping down annulus thru dump kill valve. Take returns thru the choke, holding back pressure as necessary to maintain constant BHP. Continue circulating until clean seawater returns to surface. 9. Freeze protect well by pumping diesel down annulus taking returns from tubing, holding back pressure as necessary to maintain constant BHP. Shut down pumps. Put tubing and annulus into communication across choke manifold and allow diesel to swap over to tubing, equalizing at approximately 2000' TVD. Be sure to allow sufficient time for diesel to fully swap. 10. Shut in well. Monitor and record SICP and SITP. 11. Set BPV and RDMO Nordic Rig U. Pull BPV and turn well over to Production via handover form. 9/24/01 1 Version 1 Conductor :0 Weatherford Gemoco 9-5/8" DV Stage Collar Stnd. Grade BTC Threads (+/- 1801' MD / 1745' TVD) Cannon Single -channel Clamps ESP power cable splice above Y-block B. 1 it, 3-1/2" 9.3# L-80 EUEBRD tubing A. Centrifilt Series 562 ESP assembly w/ power cable, 5.62" OD LaSalle Protectorlizers 9-5/8" Surface Casing 40.0# L-80 BTCM (4082' MD / 3004' TVD) Tabasco Producer 2T-209 (A, Producer Completion Proposed N. FMC Tabasco Producer horizontal wellhead/hanger system w/ 125 amp penetrators Nordic 3 RKB to LDS = 28.37' L. 114 its 4-1/2" 12.6# L-80 BTCM tubing to surface 31.56' MD K. XO sub, L-80 4-1/2" BTCM box x 3-1/2" BTCM Special Clearance pin 3626'MD J. 3 jts, 3-1/2" 9.3# L-80 BTCM tubing 3.865" Special Clearance couplings 3628' MD I. Baker'Sentry' gauge, 3-1/2", w/ 1-wire, Clamp -on style H. 3-1/2" x 4' Landing pup, 9.3#, L-80, BTCM 3.865" Special Clearance couplings@ 3724'MD G. 3-1/2" Trico Y-Block (OD 8.6") w/ couplings, 3-1/2" EUEBRD pin on motor leg, 2-7/8" EUEBRD pin on 1-tube leg, 3-1/2" BTCM Special Clearance box up@ 3728' MD F. 2-7/8" Trico 'X' landing nipple w/ 2.312" profile, EUEBRD box x Hydrill 511 pin@ 3731' MD E. 3-11/16" x 2' L-80'Swivel Sub', 2.875" ID Hydrill 511@ 3736'MD D. 3 its, 2-7/8" 6.5# L-80 Hydrill 511 flush it tubing@ 3740' MD C** 0.184" planned clearance as per Centrilift (drift) - (ESP OD) - (I tube OD) = 8.679" - 5.62" - 2.875' C. 2-7/8" Wireline Entry Guide, Hydrill 511 BTM@ 3842'MD Gravel Pack Assembly (run on drillpipel IIIIIII Baker SC-1 Gravel Pack packer, 9-5/8" x 4.75"ID 3929' IIIIIII Upper Ext, 6.625"OD x 5.75" ID 3934' Top of Tabasco Sand @ 4127' MD, 302T TVD IIIIIII IIIIIII GP Sld Sleeve, 70D x 4.875"ID 3939' IIIIIII Lower Sealbore, 6.63"OD x 4.75"ID 3941' IIIIIII GP Lower Ext, 6.625" x 5.75"ID 3942' IIIIIII X-over sub, 7.25"OD x 4.25"ID 3961' IIIIIII Model "B" ceramic KOIV, 5.13"OD x 2.88"ID 3962' X-over sub, 5.55"OD x 3.428"ID 3964' 2 its 4" Blank Pipe, 4"OD x 3.428"ID 3965' 17 its 4" GP Screen, .020" ga 4.63"OD x 3.428"ID 4039' IIIIIII IIIIIII O-ring/Flapper Assby, 5.5"OD x 2.375"ID 4668' 1 1 1 1 1 1 1 4" Pup JT., 4"OD x 3.428"ID 4672' Bottom of Tabasco Sand @ 4670' MD, 3309' TVD 1 1 1 1 1 1 1 IIIIIII 4" V Set Shoe, 4.47OD x 0"ID 4678' 1111111 End of Assby, 4680' Open Hole Gravel Pack IIIIIII 34,000# of 12-20 US mesh gravel pack sand TD < 10' below Tabasco base (4680' MD / 3019' TVD) TJM,1/7/02 ver4 Tabasco Producer 2T-209 (A, Producer Completion Current N. FMC Tabasco Producer horizontal wellhead/hanger system w/ 125 amp penetrators Conductor @) :0 Weatherford Gemoco 9-5/8" DV Stage Collar Stnd. Grade BTC Threads (+/- 1801' MD / 1745' TVD) 4-1/2" Nova Clamps 3-1/2" Nova Clamps ESP power cable splice above Y-block B. 1 jt, 3-1/2" 9.3# L-80 EUEBRD tubing A. Centrifilt Series 562 ESP assembly w/ power cable, 5.62" OD Super -Bands to top of Y-block +/- 3' intervals 9-5/8" Surface Casing 40.0# L-80 BTCM (4082' MD / 3004' TVD) IIIIIII N IIIIIII IIIIIII Top of Tabasco Sand @ 4127' MD, 302T TVD I I I I I I I IIIIIII IIIIIII IIIIIII IIIIIII IIII IIIIIII IIIIIII IIIIIII 1111111 Bottom of Tabasco Sand @ 4670' MD, 3309' TVD 1111111 Open Hole Gravel Pack TD < 10' below Tabasco base (4680' MD / 3019' TVD) LM. Heat Trace, Raychem, 3000' Nordic 3 RKB to LDS = 28.37' L. 114 jts 4-1/2" 12.6# L-80 BTCM tubing to surface 31.56' MD K. XO sub, L-80 4-1/2" BTCM box x 3-1/2" BTCM Special Clearance pin 3626'MD J. 3 jts, 3-1/2" 9.3# L-80 BTCM tubing 3.865" Special Clearance couplings 3628' MD I. Baker'Sentry' gauge, 3-1/2", w/ 1-wire, Clamp -on style H. 3-1/2" x 4' Landing pup, 9.3#, L-80, BTCM 3.865" Special Clearance couplings@ 3724'MD G. 3-1/2" Trico Y-Block (OD 8.6") w/ couplings, 3-1/2" EUEBRD pin on motor leg, 2-7/8" EUEBRD pin on 1-tube leg, 3-1/2" BTCM Special Clearance box up@ 3728' MD F. 2-7/8" Trico 'X' landing nipple w/ 2.312" profile, EUEBRD box x Hydrill 511pin@ 3731' MD E. 3-11/16" x 2' L-80'Swivel Sub', 2.875" ID Hydrill 511@ 3736'MD D. 3 jts, 2-7/8" 6.5# L-80 Hydrill 511 flush jt tubing@ 3740' MD C" 0.184" Planned clearance as per Centrirft (drift) - (ESP OD) - (I tube OD) = 8.679" - 5.62" - 2.875" C. 2-7/8" Wireline Entry Guide, Hydrill 511 BTM@ 3842'MD 1 4 Gravel Pack Assembly (run on drillpipe) Baker SC-1 Gravel Pack packer, 9-5/8" x 4.75"ID Upper Ext, 6.625"OD x 5.75" ID GP Sld Sleeve, 7"OD x 4.875"ID Lower Sealbore, 6.63"OD x 4.75"ID GP Lower Ext, 6.625" x 5.75"ID X-over sub, 7.25"OD x 4.25"ID Model "B" ceramic KOIV, 5.13"OD x 2.881D X-over sub, 5.55"OD x 3.428"ID 2 jts 4" Blank Pipe, 4"OD x 3.428"ID 17 jts 4" GP Screen, .020" ga 4.63"OD x 3.428"ID O-ring/Flapper Assby, 5.5"OD x 2.375"ID 4" Pup JT., 4"OD x 3.428"ID 4" V Set Shoe, 4.47"OD x 0"ID End of Assby, 34,000# of 12-20 US mesh gravel pack sand 3929' 3934' 3939' 3941' 3942' 3961' 3962' 3964' 3965' 4039' 4668' 4672' 4678' 4680' TJM,1/7/02 ver4 3-30 -01 198-243-0 KUPARUK RIV U TABS 2T-209 50- 103-20281-00 PHILLIPS ALASKA INC Roll #1: Start: Stop Roll #2: Start Stop MD 04690 TVD 03318 Completion Date: _ t2l!�7/99 Completed Status: I -OIL Current: T Name Interval D 9149 1-3 SPERRY GR/EWR4 L DGR/EWR4-MD 6_-�FINAL 117-4690 L DGR/EWR4-TVD FINAL 117-3319 L PEX-3DD/CN FINAL 4074-4518 L PEX-HALS ✓ FINAL 4074-4518 L PEX-HALS/TLD/CNL 1, [ AL 4074-4518 L PEX-MCFL ✓ FMAL 4074-4518 L PROD-SPIN/PSP/D u`�FINAL 4000-4645 6/17/99 R SRVY RPT SPERRY 0-4087. R SRVY RPTo SPERRY 4020.26-4690. T 9004 /� 1 SCHLUM PEX-HALS Sent Received T/C/D OH 5/20/99 5/21/99 OH 5/21/99 5/21/99 OH 5/21/99 5/21/99 OH 3/3/99 3/3/99 OH 3/3/99 3/3/99 T OH 3/3/99 3/3/99 OH 3/3/99 3/3/99 CH 5 7/27/99 8/13/99 OH 1/11/99 1/13/99 OH 3/9/99 3/11/99 OH 3/3/99 3/3/99 Thursday, February 01, 2001 Page I of I E E 0 U N O > N M 0 (D Y otS � c Q a _ � y O `o i co to J ao `o Y _ M C O U c Q Q M Q co o c ty O. T c a)O a N o Z U ll. CO '2 C— CM G2 coo J m d R 0 C O a U 0 N rn 0 J a L O d T T T T T T a N of N N N et N w N r lD O to O tD O O O O O t0 O T O T 01 O T cc w } w J -iU. J =i CC J F p M M O N = M oC Q O a s C7 w a w Z J O O O U. wwy�awa o a I-- O to N to M to M co Q> O M M M f7 N N Z Z Z Z H N N N N N N CO I- p so�T v 0 49 .i a � ry p i8 T^ !tS M T n O w Q Q K Z O V) sperry-sun DRIL-LING SERVICES WELL LOG TRANSMITTAL To: State of Alaska 114ay 21 r 1999 Alaska Oil and Gras Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr_ Anchorage, Alaska 99501 RE: MWp Formation Evaluation Logs 2T-209, AK-MW-90040 The technical data listed below is being submitted herewith_ Please address any problems or �s to the attention of: Tim Galvin, Sperry -Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2T-209: 2" x 5" MD Resistivity& GammaRayLoW 50-103-20281-00 2" x 5" TVD-Resistivity & Gamma Ray Logs: 50-103-20281-00 1 bore 1 Folded Sepia 1 Blueline 1 Folded Sepia MAY ? 1 1999 Alaska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G • Anchorage, Alaska 99518 • (907) 273-3500 • Fax (907) 273-3535 A Halliburton Company sperry-sun DRILLING SERVICES WELL LOG TRANSMITTAL To: State of Alaska May 20, 1999 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2T-209, AK-MW-90040 1 LDWG formatted Disc with verification listing. API#: 5 0-103 -202 81-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Service Attn: Jun Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 REUENE Date: AY 21 1999 Aaska Oil & Gas Cons. Commission Anchorage SignecCk 5631 Silverado Way, Suite G • Anchorage, Alaska 99518 • (907) 273-3500 • Fax (907) 273-3535 A Halliburton Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ❑2 Gas ❑ Suspended ❑ Abandoned ❑ Service ❑ 2. Name of Operator ARCO Alaska, Inc. 7. Permit Number 98-243 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 - - ----.- -- 8. API Number 50-103-20281 4. Location of well at surface i `` `"'' 655' FSL, 556' FWL, Sec. 1, T11N, R8E, UM p2V�' At Top Producing Interval (` _I 2803' FSL, 143' FWL, SEC 1, T11 N, R8E, UM At Total Depth 1993' FNL, 111' FWL, SEC 1, T11N, R8E, UM 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2T-209 11. Field and Pool Kuparuk River Field Tabasco Oil Pool (proposed) 5. Elevation in feet (indicate KB, DF, etc.) 31 feet 6. Lease Designation and Serial No. I ADL 25569 ALK 2667 12. Date Spudded December 15, 1998 13. Date T.D. Reached February 17, 1999 14. Date Comp., Susp. Or Aband. February 27, 1999 15. Water Depth, if offshore N/A feet MSL 16. No. of Completions 1 17. Total Depth (MD + TVD) 4690' MD / 3318' TVD 18. Plug Back Depth (MD + TVD) 4678' MD / 3312' TVD 19. Directional Survey YES ❑J No ❑ 20. Depth where SSSV set N/A feet MD 21. Thickness of Permafrost 1534' (approx) 22. Type Electric or Other Logs Run GR/Res, Platform Express( HAILS, Den, CNL, GR, MCFL) 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H 40 28' 112' 24" 9 cu yds High Early 9.625" 40# L-80 28' 4,082 12.25" 505 sx AS III & 760 sx Class G, 60 sx AS 1 4" 32# L-80 3941' 4039' 8.5" gravel pack screen 4" 11.6# L-80 4039' 4678' 8.5" gravel pack screen 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 4038'-4668' MD gravel pack 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" x 3.5" 362673727' 3929' (gravel pack pkr) 26, ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production March 31, 1999 Method of Operation (Flowing, gas lift, etc.) Flowing Date of Test 4/22/1999 Hours Tested 12.0 Production for Test Period > OIL-BBL 1213 GAS-MCF 351 WATER-BBL 645 CHOKE SIZE 176 GAS -OIL RATIO 348 Flow Tubing Press. 342 Casing Pressure 0 Calculated 24-Hour Rate > OIL-BBL 2314 GAS-MCF 806 WATER-BBL 1290 OIL GRAVITY - API (corr) 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. This 10-407 is submitted as directed per the 10-401 form approved (Permit #98-243) ORIGINAL Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Top Tabasco 11 4121' 11 3023' Base Tabasco 11 4662' 11 33047 31. LIST OF ATTACHMENTS Summary of Daily Operations and Directional Survey 32. 1 hereby certify that the following is true and correct to the best of my knowledge. SignedY144JO24C. Title Drilling Team Leader Paul Mazzolini 0 INSTRUCTIONS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. Date 4 j2Z/g!J Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in -situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other -explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 4/13/99 ARCO ALASKA INC. Page: 1 WELL SUMMARY REPORT -------------------------------------------------------------------------------- WELL:2T-209 RIG:NORDIC 3 WI: 0% SECURITY:O WELL_ID: AK9685 TYPE: AFC: AK9685 STATE:ALASKA API NUMBER: 50-103- 20281-00 AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:12/16/98 START COMP:02/19/99 FINAL: 12/14/98 (D1) MW: 8.3 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD: 117'( 117) P/U BHA SUPV:FRED HERBERT Move rig to 2T-209. Accept @ 2200 hrs. 12/14/98. 12/15/98 (D2) MW: 9.1 VISC: 170 PV/YP: 34/33 APIWL: 7.7 TD: 1037'( 920) DRILLING @ 1500' SUPV:FRED HERBERT Function test diverter. Drilling 12.25" hole from 117, to 1037'. Ream out doglegs from 938' to 1037'. 12/16/98 (D3) MW: 9.4 VISC: 160 PV/YP: 26/43 APIWL: 5.2 TD: 2408'(1371) DRILLING AHEAD @ 3000' SUPV:FRED HERBERT Drilling 12.25" hole from 1037' to 1732'. Back ream thru doglegs @ 1605', 1636'. Drilling 12.25" hole from 1732' to 2014'. Circ & cond for short trip. POH. Monitor well, thaw out elevators. Ream thru doglegs @ 973' & 1032'. Ream thru doglegs @ 1065' & 1630'. Drilling 12.25" hole from 2014' to 2408'. 12/17/98 (D4) MW: 9.5 VISC: 100 PV/YP: 29/41 APIWL: 4.6 TD: 3822'(1414) CIRC @ 4087', FAX LOGS TO GEOLOGIST SUPV:FRED HERBERT Drilling 12.25" hole from 2408' to 38221. Control drill from 32551. POOH to 19221, tight @ 33191, 2334', swabbed slightly from 2176' to 2017'. 12/18/98 (D5) MW: 9.6 VISC: 100 PV/YP: 30/40 APIWL: 4.6 TD: 4087'( 265) RIG UP TO RUN CASING SUPV:FRED HERBERT Drilling 12.25" hole from 3822' to 4087'. TOH, swabbed for first 6 stds. RIH Whole opener. 12/19/98 (D6) MW: 9.7 VISC: 51 PV/YP: 1/ 0 APIWL: 5.2 TD: 4087'( 0) RIG DOWN CEMENTING EQUIPMENT SUPV:FRED HERBERT Run 9-5/8" casing. Cement first stage cement. Date: 4/13/99 ARCO ALASKA INC. Page: 2 WELL SUMMARY REPORT 12/20/98 (D7) MW: 9.7 VISC: 47 PV/YP: 19/13 APIWL: 5.6 TD: 4087'( 0) DRILLING ON STAGE COLLAR SUPV:FRED HERBERT Displace cement w/rig pump. Pump 2nd stage cement job. ND diverter. NU BOPE. 12/21/98 (D8) MW: 8.5 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD: 4087'( 0) RIG RELEASED FROM 2T-209 @ 0500 HRS 12/22/98 SUPV:FRED HERBERT Drill cement, stage collar from 1753' to 1810'. Drill cement and stringers from 3773' to 3960'. Freeze protect well. 12/22/98 (D9) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 4087'( 0) RIG RELEASED FROM 2T-209 @ 0500 HRS 12/22/98 SUPV:FRED HERBERT ND BOPS. NU tree and test to 250/5000 psi. Secure well and release. 02/12/99 (D10) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 4087'( 0) N/U BOP - INSTALL 5" RAMS , UPPER & LOWER SUPV:DEARL W. GLADDEN Move rig off 2T-207. 02/13/99 (D11) MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 4087'( 0) P/U 3 1/2" DP AND STANDBACK IN DERRICK(43 STDS TOTAL 4164') SUPV:DEARL W. GLADDEN Accept rig 2/13/99 @ 01:30 hrs. N/D tree, N/U BOPE, attempt to screw landing joint into hanger, no go. Reset BOP. Test BOPs. 02/14/99 (D12) MW: 9.7 VISC: 44 PV/YP: 12/16 APIWL: 0.0 TD: 01( 0) DRLG OUT SHOE @ 4076' (NORDIC RKB) SUPV:D. GLADDEN/M. WHITELEY RIH w/3.5" DP. Displace well with 9.7 ppg LSND mud. Drill out baffle collar @ 3960' and cement to 39681. 02/15/99 (D13) MW: 9.7 VISC: 52 PV/YP: 12/20 APIWL: 3.8 TD: 4305'(4305) TOH - C/O MWD SUPV:D. GLADDEN/M. WHITELEY Clean out mud, float collar @ 40011, and shoe @ 40821. Drill new hole from 4087'. Performed LOT, EMW - 15.2 ppg. Drill from 4107'. Gas to surface, shut in. Open and monitor well. Static. Drill from 4155'. Date: 4/13/99 ARCO ALASKA INC. Page: 3 WELL SUMMARY REPORT 02/16/99 (D14) MW: 9.7 VISC: 55 PV/YP: 13/22 APIWL: 3.6 TD: 4576'( 271) DRILLED F/ 4576' TO 4690' MD 3319' TVD TD 20' BELOW TABASCO SUPV:DONALD L.WESTER Working with MWD attempt to restart. Tool failed @ 4305' POOH pumping to 9-5/8" shoe @ 4082'. CBU. RIH to 4225'. Ream last 80' to bottom. No fill. Continue drilling 8.5" hole from 4305' to 4576'. 02/17/99 (D15) MW: 9.7 VISC: 51 PV/YP: 12/21 APIWL: 3.0 TD: 4690'( 114) CONTINUE TEST BOPE, PULL TEST PLUG & SET WEAR RING, M/U SCRA SUPV:DONALD L. WESTER Continue drilling 8.5" hole from 4576' to 4690'. RIH w/logging tools. Unable to get below 4515' w/logging tools. 02/18/99 (D16) MW: 9.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 4690'( 0) CONTINUE RIH TO 4650' PIPE PLUGED. FLUID LOSS 15 TO 20 BPH. SUPV:DONALD L. WESTER Circulating and washing to bottom @ 4690'. Reverse circulate hi-vis pill ahead of brine. Started plugging bit. Lost full returns. Tight while pulling up 50' off bottom. Secure well due to diesel spill. Clean up spill. Date: 4/13/99 ARCO ALASKA INC. Page: 4 WELL SUMMARY REPORT REMEDIAL AND COMPLETION OPERATIONS WELL:2T-209 RIG:NORDIC 3 WI: 0% SECURITY:O WELL ID: AK9685 TYPE: AFC: AK9685 STATE:ALASKA API NUMBER: 50-103-20281-00 AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:12/16/98 START COMP:02/19/99 FINAL: 02/19/99 (C17) TRYED TO REVERSE FLUID LO MW: 9.8 KCL TD: 4690' SUPV:DONALD L. WESTER PB: 0' Continue to filter brind and mix HEC LCM pill. RIH w/3.5" mule shoe to 4600'. Pipe plugged. Work pipe try to break circulation. Try to reverse and to clear pipe. No go. POOH drop plastic rabbit through each joint. At 9-5/8" casing shoe monitor well & blow down lines. Continue to POOH wet. RIH w/3.5" DP to 4082' 9-5/8" casing shoe. Pump LCM pill. Circulated out pea size gravel cleared up. POOH to 9-5/8" csg shoe. Pipe plugged. Worked pipe and try to unplug. Unable to clear pipe. POOH wet to 1153'. Drop plastic rabbit. Looking for plugged pipe. Clean out 5 joint of plugged 3.5" DP. Pea gravel to large river rocks. 02/20/99 (C18) LOAD TANK FARM W/ 9.8 PPG MW: 9.8 KCL TD: 4690' SUPV:DONALD L. WESTER PB: 0' Continue RIH w/3.5" mule shoe. After cleanout plugged DP @ 11531. Tagged fill @ 4640'. Wash to bottom @ 46901. Fluid loss. Start reversing @ 4640'. Fluid loss. Pipe plugging go long way clear pipe. Pump and spot HEC LCM pill across open hole. Squeeze LCM. Pull up to 4600' started to reverse pipe plugged. Pulled 2 stands came unplugged pumped long way clear pipe. Spot HEC pill across open hole squeeze in place. Continue reversing and clean out hole from 4651' to 4690'. Fluid loss continues to be 1 bpm. Pump HEC LCM pill and squeeze in place. POOH to 9-5/8" csg shoe @ 4082, Monitor fluid loss without pumping 12 bph. 02/21/99 (C19) P/U BAKER SCREENS & GRAVE MW: 9.8 KCL TD: 4690' SUPV:DONALD L. WESTER PB: 0' Pump caustic wash and displace w/brine. Spot HEC pill across open hole. Pump HEC followed by HC1 acid. 02/22/99 (C20) PULL OUT OF BAKER SC-1 PA MW: 9.8 KCL TD: 4690' SUPV:DONALD L. WESTER PB: 0' RIH w/Baker screen assembly. Wash from 4550' to 4680'. Drop ball set Baker 9-5/8" gravel pack packer. Pump formic acid, spotted over open hole 4082' to 4680'. Try to reverse out with no returns lost 50 bbls. Gravel packed screens. Date: 4/13/99 ARCO ALASKA INC. Page: 5 WELL SUMMARY REPORT 02/23/99 (C21) CIRC 9.2PPG 15% KCL BRINE MW: 9.8 KCL TD: 4690' SUPV:DEARL W. GLADDEN PB: 0' Hole taking fluid. Spot HEC pill. Hole still taking fluid. Pump LC pill. Hole taking fluid. 02/24/99 (C22) P/U "Y" BLOCK ASSY MW: 9.8 KCL TD: 4690' SUPV:DEARL W. GLADDEN PB: 0' Displace well w/brine. Well showed slight flow. Shut in well. CBU, a few small spots of oil. Raise mud wt to 9.3 ppg- 02/25/99 (C23) CIRCU W/CHARGE PUMP @ 359 MW: 9.8 KCL TD: 4690' SUPV:DEARL W. GLADDEN PB: 0' Start to run completion. Centrilift P/U "Y" block assy, at the point the top pump was picked up it was discovered that the two pumps would not flange up together. Pumps not compatible. TIH w/4.5" tubing t/3591'. 02/26/99 (C24) I RUN COMPLETION @ 1664'- E MW: 9.8 KCL TD: 4690' SUPV:DEARL W. GLADDEN PB: 0' Continue circ w/charge pump @ 3591', waiting on new ESP pump. Run "Y" block assy. Run completion. 02/27/99 (C25) S/U SPILL BERM FOR RIG ON MW: 9.8 KCL TD: 4690' SUPV:DEARL W. GLADDEN PB: 0' TIH w/"Y" block ESP completion assy. N/U tree and test to 250/5000 psi. 02/28/99 (C26) RIG RELEASED OFF 2T-209 @ MW: 9.8 KCL TD: 4690' SUPV:DEARL W. GLADDEN PB: 0' Freeze protect well. Rig released @ 0900 hrs. 2/28/99. o Ul r r13 'r10 m� <N nC M. :1 rm n, O �O O 0 C Z r oil �m 0 0 Qn �• cn y V �= o c O am= cco C n zmc C o r O O C Sn' oa�v n c o� rn -i t3 to � '� NNE CD �yoo O a N O ~' p CD CD o� _ m ,Zo co oy0 o00 00 co v to Crn .� rn 7h o, M 0 -� — .C! �� < �v w y o. 1 0 0 0 0 N CO Cn 0 (0 CO CO O 00 (n A 0 co CO J J J J N CO O) CA O O O (n A W V A Cn O O N 1 -+ 00 w m y "T Q W N j O N J j 1 A A A A W A W O 90 A O) O O .,,. 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N W V (O W OD A (D N N A A O Cn CD O C)) W A (3) 0) O (d z z z z z z z z z z z z z z z ZZZzz z z z z z n O O A A A A A A A A A A A A A A A A A A A A A A A A A Q: CO (D co (O co (D CO CO CO co co W CO co CD CO (D CO CO co co CO co co co m 3 CD CD CD OD OD 0(b O CD CO Oo CO 00 00 00 ao m CD O CO (D OD OD CD (D Gl W CO CD OD OD CO Oo OD OD OD W CD CD CO CD CO OD CD CO OD OD OD OD OD 00 1 A A Cn (n Cn Cn (;) O C) j J V J J J V J V V V V CO OD OD m A Oo -+ W 9) 00 O N OD W A Ui 9) O 9) O) �4 V OD CD -+ W 9 Q y CO co O 1 c0 A V 0) J O) -+ N (n Cn N O) CD c0 O W A W O) (J W W 00 O O CO 00 (n N N V OD O W OD O O CO CO O Cn W A (W y m m m m m m m m m m m m m m m m m m m m m m m m m 0 W Cn A Cn Cn Cn A A A Gi O) CJI Cn Ui (n W W A W A A W Cn W A m O O) W W Cn J CA O 0) (3) N OD O O -i Cn A W (O N CA 1 O) s O rt (o O N N W O W W V V OD Cn CO CD Cn O V O V V A V W W O fP (D W N O W N J O W W A n N ( OD O OD Cr) O N CO CD Cn J (A CD D 0) N C (n W CO W tD A W CO 00 V (A CJi Cn A W W n Q V V OD 90 1 W Cn 1 CO W V N W J Cn A A A Cn O) 0o O W CA O i CD N CD O V CO A N -+ CO N A J CO A -+ O N J N CD A O) A Q n i O) W N N O co A W V W W CO O) V CO -+ W J V o 0 CO Cn Q m rh n O M N c 3 -: N c o O m a 'O CL w co N N N N N N N N N N N N N N N N N N_ NM N 1 (D CDO CD co (D CD N 0)CO W V -1 m 0 1 J O A (D A A W W N (n N a) N (O _N N N N 1 m W O W O O O CO O V V (D y O C) J CO (O m N J CT m A N C, J m o A N f0 i N A O (O '� '0 C m 1 0 bD OD (D m N j .pp, V Ut W W CO m 4D J (n N =r O CA A OD A J O O J N A A A Cn UC V O A V W W m J mCL W m m O) Cn Ut (n m m m (3) Cn Cn (n Cn Cn Cn Cn Cn Cn Cn A A A A A O O O CO O CO O 0 1 m CD CO OD O Ut A W 1 0 CD m Ut W 1 C N m Cn A J m m O m O m O A N Cn A A N (O N V co -+ 1 Cn 0 0 0 0 0 O O O O O O O O O C)O O O O O 0 0 0 0 0 rF Cl) W W W W Cn Cn Cn Cn Cn W W W W W Cn Cn U1 A A W W W W W Cn A Cn Cn (n W W W W W Cn Cn 1 1 Cn W W co W W M Cn Cn Cn Cn n PPP. 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Post ' ` Post Office Box 10036v Anchorage, Alaska 99510-0360 March 23, 1999 Lori Taylor AOGCC 3010 Porcupine Drive Anchorage, AK 99501 Dear Lori: Enclosed in this envelope should be 2 bluelines and 2 folded Sepia's. One blueline and 1 sepia for well 2T-09 and 1 blueline and 1 sepia for well 2T-220. Please sign one of the two enclosed transmittals and return to me at the following address, letting me know that you have received the information as stated above. The second transmittal is for your records. Bethany Lilly ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Thank you, Bethany Lilly vjL) I received 1 blueline epia for well 2T-09, and 1 blueline, 1 sepia for 2T-220. C Signature: EC E-N 261999 Alaska OR & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany sperry-sun DRILLING SERVICES AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 9-S. aLA':s Re: Distribution of Survey Data for Well 2T-209N3 Dear Lori Taylor: Enclosed are two survey hard copies. Tie -on Survey: Window / Kickoff Survey Projected Survey 4,020.26' MD 'MD (if applicable) Y 1 11 IlIffi Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 09-Mar-99 tIAR 11 1999 Alasks OU Gas Cons. CommiWmn Anohc W 5631 Silverado Way, Suite G • Anchorage, Alaska 99518 • (907) 273-3500 • Fax (907) 273-3535 A Halliburton Company sperry-sun DRILLING SERVICES "ENT11011061 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2T-209 Dear Lori Taylor: Enclosed are two survey hard copies. Tie -on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD (if applicable) 4,087.00' MD Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G • Anchorage, Alaska 99518 • (907) 273-3500 • Fax (907) 273-3535 A Halliburton Company AI<ASKA OIL AND GAS CONSERVATION CO10IISSION November 25. 1998 Tom JlcKav Drilling Team Leader ARCO Alaska. Inc. P 0 Box 100360 Anchorage, AK 995 10-0 360 Re: Kuparuk River Unit 2T-209 ARCO Alaska. Inc. Permit No: 08-243 Sur Loc: 1,55'FSL. 556TWL. Scc. i. TI 1N. R8E. UNI Btmholc Loc. 1897'FNL. 65TWL. Sec. 1. TI IN. R8E. UNI Dear Mr. NlcKav: -JNY KN0WLES, GOVERNOR 3001 PCRCUPINE DRIVE -NCHOR.AGE. ALASKA 99501-3192 PHONE: ]o07) 279-1433 =AX: :07) 276-7542 Enclosed is the approved application for permit to drill the abo�c referenced Nell. The permit to drill does not exempt you from obtaining additional permits required by lm% from other governnicntal agencies. and does not authorize conducting drilling operations until all other required permitting, determinations are made. MON\out prevention equipment (BOPS) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approxiniately 24 hours) must be given to allo\\ a representative of the Commission to witness a test of BOPE installed urior to drilling ne« hole. Notice may be Liven ly contacting the Con-Imisslon DC[roleulll fiCid Insllcctor on the \crth Slope La<gcr '-50-3607 David W. johnstoll Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish &- Game. Habitat Section w; o encl. Department of Environmental Conservation wio encl. STATE OF ALASKA ALAz:.)r<A OIL AND GAS CONSERVATION COMIvnSSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work Drill X Redrill Type of Well Exploratory Stratigraphic Test Development Oil X Re -Entry Deepen Service Development Gas Single Zone X Multiple Zone 7 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 88' feet Kuparuk River Field Tabasco Oil Pool (Proposed) 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25569, ALK 2667 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 655' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Ku aruk River Unit Statewide At top of productive interval (Q TARGET ) Number 8. Well number 2476' FNL, 147' FWL, Sec. 1, T11N, R8E, UM 2T-209 #U-630610 At total depth 9. Approximate spud date Amount 1897' FNL, 65' FWL, Sec. 1, T11N, R8E, UM 11/28/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2T-30 4682' MD 65' @ TD feet 54.5' @ 1030' feet 2560 3383' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum hole angle 55.33o Maximum surface 2063 psig At total depth (TVD) 2428 psig 18. Casing program Setting Depth size S ecifications Top Bottom Quantity of cement Hole Casing Weight Grade Couplinq I Length MD TVD MD TVD include stage data 24" 16" 62.5# H-40 Weld 82' 28' 28' 110, 110, ±200 CF 12.25" 9.625" 40# L-80 BTC 3987' 28' 28' 4015' 3003' 499 Sx Arcticset III & 744 Sx Class G & 60 sx AS I 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet w v 18 1998 Effective depth: measured feet Junk (measured) true vertical feet Alaska Oil & Gas Cons. Commissi Anchorage Casing Length Size Cemented Measured depth True Ve ical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured ORIGINAL true vertical 20. Attachments Filing fee X Property plat ❑ BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot ❑ Refraction analysis ❑ Seabed report ❑ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and Corr ct to the best of my knowledge Z6 / D / Cx �. Signed G Title Drilling Team Leader Date to Co mission Use Only Permit umber API number 5 0 - l0 ? — 0 2 8 / Approval date G p / / -o�J — / D I See cover letter for other requirements Conditions of approval Samples required ❑' Yes 9 No Mud log required ❑ Yes ❑C No Hydrogen sulfide measures ❑ Yes IX No Directional survey required JZ Yes ❑ No Required working pressure for BOPE ❑ 2M ❑ 3M ❑ 5M ❑ 10M ❑ 15M Other: t}rigln3i 51grlea t3y David W. Johnston by order of f1 Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate Drill, Case and Completion Plan for Tabasco 2T-209 (A) Drr%rh itnr General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up Doyon Rig 19. Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/ 4015') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, POOH. 5. Run and cement 9-5/8" 40.0# L-80 BTC casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. 6. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 psi. Record results. 7. Pick up 8-1/2" bit and BHA. Trip in and drill out stage collar. Clean out to top of float collar. 8. Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. 9. Freeze protect well. Install BPV. Nipple down BOP stack and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. 10. Secure well. Release rig. 11. Move in / rig up Nordic Rig 3. Nipple up BOPE and test to 3000 psi. Test casing to 3000 psi. Record results. 12. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 13. Drill 8-1/2" hole to well total depth (+/- 4682') according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH 14. Run open hole wireline logs as needed. 15. RIH with clean out BHA. Scrape casing. Displace well to completion brine. 16. Pump caustic wash. Pump pickle job. Circulate brine. 17. Pump acid pill across formation. Reverse out with brine. POOH 18. Run in hole with 4" Gravel Pack screen assembly. Set gravel pack packer. 19. Pressure test lines. Pump gravel pack sand and pack screens. 20. Reverse out excess sand. Circulate well to non-freezing, clean completion brine. POOH 21. Pick up Centrilift ESP motor, seal assembly, Y-block, and 2-7/8" tubing 1-tube on 4-1/2" 12.6# L-80 BTCM production tubing. 22. Run in well with ESP motor assembly with power cable and data gathering information wire attached to tubing. 23. Attach Raychem heat trace cable to tubing at pre -determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 24. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. 2T-209 (A) Page 1 TAB, 11 /13/98, v.1 25. Make surface electrical connections as required. 26. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up horizontal production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 27. Freeze protect well. Make final conductivity check of ESP cable and instrumentation wire. Set BPV. Release rig and turn well over to production. 2T-209 (A) Page 2 TAB, 11 /13/98, v.1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Well Tabasco 2T-209 (A) Drilling Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel API Filtrate pH % Solids Drilling Fluid System: Doyon Rig 19 Triple Derrick Shale Shakers Centrifuge, Mud Cleaner Desander, Degasser Pit Level Indicator (Visual / Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Flow Line Cleaner Doyon Rig 19 Spud to 9-5/8" surface casing 8.5-9.6 16-26 25-50 150-250* 10-20 10-30 8-15 8-10 4-6% Nordic Rig 3 Drill out to TD 10.2 4-7 15-30 60-120 2-4 4-8 8-15 8.0-8.5 4-7% Nordic Rig 3 Tandem Geolograph/Swaco Shale Shakers Mud Cleaner, Degassers Pit Level Indicator (Visual / Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 200-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using an expected surface casing leak -off of 14.1 ppg EMW (0.73 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2193 psi. The leak off EMW was chosen based on an open hole FIT on 2T-202 taken to 14.1 ppg at 2829' TVD (0.73 psi/ft). Therefore, Arco Alaska, Inc. will test the BOP equipment to 3000 psi. MASP = (3326 ft)(0.73 — 0.11) = 2063 psi Based on offset well data, reservoir pressures in the Tabasco sands in the vicinity of 2T pad are expected to be 1500 psi (0.50 psi/ft). Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.2 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 3003'. Well Proximitv Risks: The nearest existing well to 2T-209 is 2T-30. As designed, the minimum distance between the two wells would be 54.5' at 1030' MD. Drillinq Area Risks: Risks in the 2T-209 drilling area are limited to lost circulation and potential borehole instability in the Tabasco formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous IDS 2T drilling results, 10.1 ppg mud should be adequate to control both the West Sak and Tabasco formation pressures without resulting in lost circulation. The 9-5/8" casing shoe will be tested to leak off or a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well on 2T Pad. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2T-209 4-1/2" x 9-5/8" tubing annulus will be filled with kill weight brine and diesel after setting the 4-1/2" production tubing string and prior to the drilling rig moving off of the well. ANNUL.f�R X+SP S^— ►�� n�Es7E ►=o� 7H S wE.c� }7z�r� ToM �jac�cY l,aY,AA) 16" Conductor @ 80' Weatherford Gemoco 9-5/8" DV Stage Collar Stnd. Grade BTC Threads (+/- 1781' MD / 1696' TVD) 4-1/2" Nova Clamps All Depths RKB Nordic 3 3-1/2" Nova Clamps ESP power cable splice above Y-block B. 1 it, 3-1/2" 9.3# L-80 EUEBRD tubing A. Centrifilt Series 562 ESP assembly w/ power cable, 5.62" OD Super -Bands to top of Y-block +/- 3' intervals 9-5/8" Surface Casing 40.0# L-80 BTCM (+/ 4015' MD / 3003' TVD) Tabasco Producer 2T-209 (A) Producer Completion N. FMC Tabasco Producer horizontal wellhead/hanger system w/ 125 amp penetrators M. Heat Trace, Raychem, 3000' L. 4-1/2" 12.6# L-80 BTCM tubing to surface K. XO sub, L-80 4-1/2" BTCM box x 3-1/2" BTCM Special Clearance pin J. 3 its, 3-1/2" 9.3# L-80 BTCM tubing 3.865" Special Clearance couplings I. Baker Dual 'Sentry' gauges, 3-1/2", w/ 1-wire, Clamp -on style (suction) and Sidemount kit (discharge) H. 3-1/2" x 10' Landing pup, 9.3#, L-80, BTCM 3.865" Special Clearance couplings G. 3-1/2" Trico Y-Block w/ couplings, 3-1/2" EUEBRD pin on motor leg, 2-7/8" EUEBRD pin on 1-tube leg, 3-1/2" BTCM Special Clearance box on uphole end F. 2-7/8" Trico 'X' landing nipple w/ 2.312" profile, EUEBRD box x Hydrill 511 pin E. 3-11/16" x 2' L-80 'Swivel Sub', 2.875" ID Hydrill 511 D. 3 its, 2-7/8" 6.5# L-80 Hydrill 511 flush it tubing •* 0.184" planned clearance as per Centrili ft C(drift) - (ESP OD) - (I tube OD) = 8.679" - 5.62" - 2.875" C. 2-7/8" Wireline Entry Guide, Hydrill 511 -� Gravel Pack Assembly (run on drillpipe) Baker SC-1 Gravel Pack packer, 9-5/8" 4 its, Baker 4" blank tubing, Hunting Seal Lock threads Baker ceramic flapper valve Baker 4" Gravel Pack screen, Hunting Seal Lock 20 gauge (0.02") screen 12-20 US mesh gravel pack sand TAB, 10/28/98, v1 Created by finch For: BROCKWAY Date platted : 3—Nav-98 Plat Reference is 209 Version J5. Coordinates are in feet reference slot H2O9. True Vertical Depths are reference RKB (Dayen #19). d-.n rrrrr,Q RC® Alaska, Inc® Structure : Pad 2T Well : 209 Field : Kuparuk River Unit Location : North Slope, Alaska <— West (feet) 600 400 200 0 200 I I TD LOCATION: 1897' FNL, 65' FWL 2800 SEC. 1, T1 1 N, R8E 12091vTD — Csg Pt Base Tabasco 2600 0 RKB ELEVATION: 116' 2400 349.23 AZIMUTH 2188' (TO TARGET) 200 ***Plane of Proposal*** Target — Top Tabasco 2200 9 5/8 Casing 400 2000 w an 0 600 TARGET LOCATION: c, 1800 2476' FNL, 147' FWL N KOP TVD=700 TMD=700 DEP=O SEC. 1 , T1 1 N. R8E 4.00 TARGET Base West Sak Sands A Boa BEGIN BUILD/TURN TO TARGET TVD=825 TMD=825 DEP=3 TVD=3026 1500 i TMD=4055 6.87 DEP=2188 NORTH 2149 Z 1000 10.23 EAST 409 t400 U �_ 13.93 DLS 4.00 deg per 100 ft 3 Q) N 1200-1200 1 7.76 Q7 — 21.65 a) 1400 25.57 Top West Sak Sands 1000 29.51 B/ PERMAFROST TVD=1496 TMD=1534 DEP=204 � 33.47 1600 37.43 T/ UGNU SNDS TVD=1651 TMD=1722 DEP=311 K-13 800 41.40 U i 800 45.37 EOC 600 N 49.35 53.33 EOC TVD=1943 TMD=2150 DEP=622 N 2000 400 AVERAGE ANGLE K-13 TVD=2082 TMD=2395 DEP=823 Top Ugnu Sands F— 2200 55.33 DEG T/ W SAK SNDS TVD=2217 TMD=2632 DEP=1018 Base Permafrost 200 V 2400 Begin Build/Turn to Target 0 290 A2 2600 B/ W SAK SNDS TVD=2656 TMD=3404 DEP=1653 200 SURFACE LOCATION: 2800 655' FSL, 566' FWL SEC. 1, T11N, RBE 9 5/8'' CSG PT TVD=3003 TMD=4015 DEP=2155 3ooa TARGET — T/ TABASCO TVD=3026 TMD=4055 DEP=2188 3200 B/ TABASCO TVD=3326 TMD=4582 DEP=2621 TD — CSG PT TVD=3383 TMD=4682 DEP-2703 3400 09 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 280C Vertical Section (feet) —> Azimuth 349.23 with reference 0.00 N, 0.00 E from slot ##209 Created by arch For: BROCKWAY Date platted : 3—Nov-98 PIOI Reference is 209 Version #5. Coordinates are in feel reference slot #29. True Vertical Deptha are reference RKB (Dayan #19). 111111111M INTEQ 320 300 280 260 240 22C 200 180 160 140 120 L O Z 100 80 6C 40 20 0 20 40 60 i� rARCO Alaska, InC.l Structure : Pad 2T Well : 209 Field : Kuparuk River Unit Location : North Slope, Alaska <— West (feet) 180 160 140 120 100 80 60 40 20 0 20 40 60 80 100 120 140 320 300 280 260 240 220 200 180 A 160 Z 140 O0 s 120 + CD (D 100 80 60 40 20 0 20 40 60 180 160 140 120 100 80 60 40 20 0 20 40 60 80 100 120 140 <— West (feet) Created by finch For: BROCKWAY Dale plotted : 3—Nov-98 Plot Reference is 209 Version }5. Coardinales are in feel reference slot #209. True Vertical Depths are reference RK9 (Day- #19). KI-12 affism iNl'EQ 1000 960 920 880 840 800 760 720 n 680 CU 640 (U 600 L O Z 560 520 480 440 400 360 320 280 240 ARC® Alaska, Inc- Structure : Pad 2T Well : 209 Field : Kuparuk River Unit Location : North Slope, Alaska <— West (feet) 400 360 320 280 240 200 160 120 80 40 0 40 80 120 160 200 <— West (feet) 1000 960 920 880 840 800 760 720 A 680 Z 640 O0 600 (D CD 560 520 480 440 400 360 320 280 240 C—ted by re,ah For: BROCKWAY Date platted : 3—Nov-98 Plot Referents is 209 Version Coordinates are in feel reference slot #209. true Vertical Depth, are reference RKB (Day,, #19). wd-m INTEQ rA'RCO Alaska, Inc. Structure : Pad 2T Well : 209 Field : Kuparuk River Unit Location : North Slope, Alaska <— West (feet) 1100 1000 900 800 700 60C 500 400 300 200 100 0 100 200 300 400 500 2800 2700 2600 2500 2400 2300 2200 2100 2000 1900 N N 1800 s O 1700 z 1600 150C 1400 1300 1200 1100 1000 900 2800 2700 2600 2500 2400 2300 2200 2100 2000 A 1900 z O 1800 m 1700 C( 1600 1500 1400 1300 1200 1100 1000 900 1100 1000 900 800 700 600 500 400 300 200 100 0 100 200 300 400 500 n. <— West (feet) ARCO Alaska, Inc. Pad 2T 209 slot #209 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref 209 Version #5 Our ref prop3051 License Date printed 3-Nov-98 Date created 14-Jul-98 Last revised : 3-Nov-98 Field is centred on n70 16 18.576,wl50 5 56.536 Structure is centred on n70 19 45.172,w150 0 47.034 Slot location is n70 19 51.614,w150 0 30.800 Slot Grid coordinates are N 5970635.070, E 498945.191 Slot local coordinates are 655.00 N 556.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Object wellpath PMSS <469-10632'>„ 18,Pad 2T MSS <4046-44271>„ 202,Pad 2T PMSS <0-59241>„ 32,Pad 2T PMSS <4850 - 5918'>„ 32A,Pad 2T PMSS <5497-13787'>„ 32B,Pad 2T PMSS <0-4749'>„ 30,Pad 2T PMSS <4627 - 10686'>„ 30A,Pad 2T PMSS <12144-133601>„ 38A,Pad 2T PGMS <0-6370'>„ 9,Pad 2T PGMS <0-6975'>„ 7,Pad 2T PGMS <0-82081>„ 6,Pad 2T PGMS <0-76701>„ S,Pad 2T PGMS <0-8160'>„ 4,Pad 2T PGMS <0-8445'>„ 17,Pad 2T PGMS <0-78681>„ 13,Pad 2T PGMS <0-67891> „ 11,Pad 2T PMSS <3115 - 3645'>„ 12,Pad 2T PGMS <0-67251> „ 12B,Pad 2T PMSS <4757-68001>„ 12A,Pad 2T PMSS <1287-1725'>„ 2,Pad 2T PGMS <0-88901> „ 2A,Pad 2T PMSS <0-10570'>„ 29,Pad 2T PMSS <0-98451>„ 19,Pad 2T PMSS <380 - 114001>„ 31,Pad 2T PGMS <0-8250'>„ l0,Pad 2T PGMS <0-76501>„ 8,Pad 2T PMSS <5917-79571>„ 16A,Pad 2T PGMS <0-89471>„ 16B,Pad 2T Reference North is True North Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 21-Oct-98 689.7 500.0 500.0 26-Aug-98 136.6 1020.0 1020.0 24-Feb-98 57.5 1040.0 1040.0 24-Feb-98 57.5 1040.0 1040.0 24-Feb-98 57.5 1040.0 1040.0 16-Jul-98 54.5 1030.0 1030.0 16-Jul-98 54.5 1030.0 1030.0 23-Jan-98 590.0 100.0 100.0 23-Jan-98 427.6 710.0 710.0 23-Jan-98 376.7 720.0 720.0 23-Jan-98 303.3 970.0 970.0 23-Jan-98 325.3 730.0 730.0 23-Jan-98 300.6 740.0 740.0 23-Jan-98 677.9 200.0 200.0 23-Jan-98 577.3 720.0 720.0 23-Jan-98 527.9 300.0 710.0 23-Jan-98 546.7 770.0 770.0 23-Jan-98 546.7 770.0 770.0 23-Jan-98 546.7 770.0 770.0 26-Aug-98 201.4 1040.0 1040.0 26-Aug-98 201.4 1040.0 1040.0 23-Jan-98 121.6 1020.0 1020.0 23-Jan-98 703.4 750.0 750.0 23-Jan-98 83.8 700.0 700.0 23-Jan-98 496.3 780.0 780.0 23-Jan-98 400.8 730.0 730.0 23-Jan-98 653.0 0.0 0.0 23-Jan-98 653.0 0.0 0.0 PMSS <1604-36251>„ 16, 2T 23-Jan-98 653.0 0.� 0.0 PGMS <0-76251>„ 15,Pad 2T 23-Jan-98 627.4 710.0 710.0 PGMS <0-82621>„ 14,Pad 2T 23-Jan-98 598.8 730.0 730.0 PMSS <650 - 11080'>„ 37,Pad 2T 23-Jan-98 743.9 600.0 600.0 PMSS <918' - 10890'>„ 28,Pad 2T 23-Jan-98 111.2 1000.0 1000.0 PMSS <921-102351>„ 20,Pad 2T 23-Jan-98 619.2 1460.0 1460.0 PMSS <0-12821'>„ 21,Pad 2T 23-Jan-98 737.9 200.0 200.0 PMSS <0 - 9210'>„ 26,Pad 2T 23-Jan-98 173.3 881.2 881.2 PMSS <741-154711>„ 36,Pad 2T 23-Jan-98 640.0 100.0 100.0 PMSS <918 - 101931>„ 22,Pad 2T 23-Jan-98 229.0 808.3 808.3 PMSS <0-41751>„ 201,Pad 2T 26-Aug-98 415.5 100.0 100.0 PMSS <0-9298'>„ 27,Pad 2T 23-Jan-98 135.8 1060.0 3420.0 PGMS <0-78971>„ 3,Pad 2T 26-Aug-98 277.7 720.0 720.0 PMSS <893 - 12977'>„ 23,Pad 2T 25-Aug-98 199.1 1060.0 1060.0 16" Div( ter Schematic -- Doyc Rig 19 Kuparuk River Unit Tabasco Operations u 1' C/W PLUG 21 1/4' 2000 PSI. LISP HYDRIL BOP/0MYTER, MOOED TOP/FLANGED BOTTOM 4' THRZ CONNECTION C/W PLUG (TYPICAL BOTH SIDES) 21.1/4' 2000 PSI FLANGE 16' 150 PSI HYOR. OPERATED KNIFE GATE VALVE 5' rLG'D VENT LINE SURFACE DIVERTER CONFIGURATION 13-5/8" 5( 0 psi BOP Stack -- Dc _ on Rig 19 Kuparuk River Unit Tabasco Operations - Producer Wells i 13 5/8', 5000 PSI HYDRIL ANNULAR BOP, I STUDDED TOP/FLANGED BOTTOM , I -------------------,--- FUwCE/FLANGE I SINGLE 13 5/8% 5000 PSI, 10' MPL OPERATORS, ]' 0 t/4' i HYDRIL PIPE RAM 3/r -------------------- FLANGE BOTTOM/STUDDED TOP SINGLE 13 5/8', 5000 PSI, 14' MPL OPERATORS, 3- 0 1/4' i BLIND SHEAR RAM 3/a" ---------- -------- Q ' FLANGE/FLANGE 3 1/8' 5000 PSI HCR VALVE 3' CHOKE LINE f -- 2' KILL LINE t• to t/e' 3 1/8' 5000 PSI HCR VALVE J i 3 1/8' 50DO PSI GATE VALVE 3 1/8' 5000 PSI GATE VALVE FLANGEBOTTOM/STUDDED TOP 3/e, -------------------- 1' to t/!' ' SINGLE 13 5/8% 5000 PSI, 10' MPL OPERATORS HYDRIL PIPE RAM 3/e'--------------------- FLANGE/FLANGE 1Y 10' BOP SACK ADAPTER SPOOL HUB x FLANGE WEUl1EAD BOP STACK ELEVATION 11 " 50'1 psi BOP Stack -- Nor 'ic Rig 3 Kuparuk River Unit Tabasco Operations - Producer Wells Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock -down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi low and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 low and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 11" 5000 psi Horizontal Tubing Head 3. 11" 5000 psi Double Flange Adapter/Spacer Spool 4. 11" 5000 psi Hydril Type V Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ manual locks 5. 11 " 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves - each are 3" 5000 psi gate 6. 1 1" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/ Manual Locks 7. 11" 5000 psi Hydril Annular Preventer TAB, 09/30/98, v.1 1 1 19/16/981 MRT I JM PE' 38# K98075ACS J4 16'. No PMv lKhOR1. I I 17A- 'HIP SEE SHEET 2 FOR NOTES AND LOCATION INFORMATION 0 Cr 0 a Q (NO SCALE) LEGEND o NEW CONDUCTOR LOCATIONS LOUNSBURY ® EXISTING CONDUCTORS 9 1% & ASSOCIATES, INC. ENGINEERS PLANNERS SURVEYORS AREA: 2T MODULE: XX UNIT: D2 ARCO Alaska, Inc. ,Nr WELL CONDUCTORS 207-210,215,218 & 220 DRILL SITE 2-T Subsidiary of Atlantic Richfield Company AS -BUILT LOCATION CAD LK6220 2 9 16 98 DRAWING N0: CEA-D2TX-622OD1 2 SHE 001 OF 2 REV: 1 1 1 9/16/981 MRT I JM I I PER 3# K98075ACS NOTES 1. BASIS OF LOCATION AND ELEVATION ARE DRILLSITE 2-T MONUMENTS PER LHD & ASSOCIATES. 2. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. ALL DISTANCES ARE TRUE. 3. ELEVATIONS SHOWN ARE B.P.M.S.L. 4. WELLS ARE LOCATED WITHIN PROTRACTED SECTION 1, T. 11 N., R. 8 E., UMIAT MERIDIAN, ALASKA, 5. DATE OF SURVEY: 9/13/98, FIELD BK. L98-71 pg. 14-23. 6. DRILL SITE 2-T GRID NORTH IS ROTATED 179' 59' 40" WEST FROM A.S.P. ZONE 4 GRID NORTH. 7. SEE REFERENCE DRAWINGS: CEA-D2TX-866, FOR CONDUCTOR 2-17 LOCATIONS, CEA-D2TX-622OD7 FOR CONDUCTOR 18-23, 26-32, 36-38 & TA8ASCO LOCATIONS, AND CEA-D2TX-622OD9 FOR CONDUCTOR 202, LOCATED IN SECTION 1, T 11 N, R 8 E, U.M. WELL NO. Y X LATITUDE LONGITUDE SEC. LINE O/S SEC. LINE O/S O.G. ELEV. PAD ELEV. 207 5,970,610.10 498,945.02 70'19'51.368" 150'00'30.805" F.S.L. 630' F.W.L. 556' 75.2' 80.4' 208 5,970,622.69 498,944.87 70" 9'51.492" 150,00,30.810" 642' 556' 75.2' 80.4' 209 5,970,635.10 498,944.90 70*19'51.614" 150'00'30.809" 655' 556' 74.9' 80.4' 210 5,970,647.69 498,944.73 70*19'51.738" 150'00'30.814" 667' 556' 74.7' 80.4' 215 5,970,709.72 498,944.99 70'19'52.348" 150'00'30.807" 729' 556' 74.2' 80.4' 218 5,970,747.74 498,944.97 70*19'52.722*' 150'00'30.807" 768' 556' 74.1' 80.4' 220 5,970,772.57 498,944.90 70'19'52.966" 150'00'30.810" 792' 556' 74.1' 80,4' SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT 1 AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF SEPTEMBER 16, 1998. LOUNSBURY & ASSOCIATES, INC. ENGINEERS PLANNERS SURVEYORS '` AREA: 2T MODULE: XX UNIT: D2 ARCO Alaska Inc DRILL SITE 2-T �� Subsidiary of Atlantic Richfield Company WELL CONDUCTORS 207-210,215,218 & 220AS-BUILT LOCATION CAD LK6220 2 9 16 98 DRAWING N0: CEA-D2TX-622OD12 SHE002 OF 2 REV: 1 ARCO Alaska, Inc. ' ` Kuparuk Drillsite Development " Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor November 13, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill Tabasco 2T-209 Tabasco Producer, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well to the prospective Tabasco interval from 2T Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the Tabasco sands in the vicinity of 2T pad. The well is designed as a producer using an open hole gravel pack completion technique for sand control purposes. The surface hole will be drilled and cased using Doyon Rig 19. After this rig moves off the well, Nordic Rig 3 will move onto location to drill out the production interval and run the completion. Completion plans call for running a 4-1/2" production tubing string with an ESP and Y-block assembly, 2-7/8" 1-tube, and heat trace. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $ 100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the Tabasco sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the Tabasco sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at 2T-209, such as shallow gas. 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. Please note that the anticipated spud date for this well is November 28, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Sincer _ Thomas A. Brockway Operations Drilling Engine Attachments: cc: Tabasco 2T-209 Well File Tom McKay ATO-1060 Jack Walker ATO-1200 Steve Kranker ATO-1252 Lewis Ledlow ATO-1063 ru Ln Ep Ln ru w L1J O r ru m ry D n m Z c m m 37 N O cn O W rn Ln J N 0—+-0 mo> m� X. m O n wDD 0DD cn(n X 0DD n � m r :2 m00 z N m <n momZ yC mm 33 D O Z } } n m n z c co m m A r0 o O m 00 c m Ul N N I� W 00 lw CD w A O N v Ln v I ADMINISTRATION 5 6 7. 8 9 tO 11. 12. 13. . l'e~ nfil lee attached ...... I ease ~umber appropriate ............ Unique well name and numbe~. ........... Well Io(:aled in a defined pool ............... Well Iocaled proper dislance fi'om drilling Emil botHKlary. . Well Io(:ated proper distance from other wells . . . S~dticienl acreage available in drilling unit . . If deviated, is wellbore plat included . . Operator only affected pady ........... Operator has appropriate bond in force ........... Permit can be issued wilhout conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING 14 15 16 18 19. 20. 21. 22. 23. 24. 25. API)I~ I)AIE 26. 28 29 GEOLOGY 30 31. 32 33 API~I'~ I.')A 1 l..i ,34 APPI? I)A'I Conductor string provided ................ StHface casing protects all known USDWs ......... CM I' vol adequale to circulate on conduclo~ & surf csg .... ¢:M I vol adequale Io lie-in long siring to surf csg ....... CMI will cover all known produclive horizons ........ Casi~g designs adequate for C, 1, B & pem~ahosl ...... Adequate lankage or reserve pil ................. It a re-drill, has a 10-403 for abandonme~fl been approved.. Adequate wellbore separation proposed ............. If diveder required, does il meet regulalions .......... Drilling fluid program schematic & equip Iisi adequale .... BOPEs, do they meet regulation ................ B()PE press rating appropriate; tesl to ....~___O'_C.~ ......................... psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur wilhout operalion st'mldow~ ........ Is p~esence of H:S gas probable ................. Pe~nHt can be issued w/o hydrogen sulfide measures ..... Dala presenled on potential overpressme zones ...... Seismic analysis of shallow gas zones ..... ' ........ Seabed condition survey (if off-shore) ............ Contact name/phone for weekly progress mp(.)~ts ...... lexploratory only] " (A) will contain waste in a suitable receiving zone; ....... (R) will not contaminate freshwaler; or cause drilling wasle... lo s~rface; (C) will nol impair mechanical integrity ol tile well used for disposal; (I)) will ~1ol dan'lage prod[icing fonrlalion o[ i~Iu)cfir recovery from a [,'}()OI ', ~]lld ...... .~.'~.,) will Hol circumvent 20 AAC 25.252 or 20 AAC 25.412. M ~:h,,I, II!;I r,'v ()!.g2fllHH GEOl. AREA Y N NNY N Y N Y N GEOI OGY: ENGINEERING: UlC/Annular COMMISSION: JDIt ~ RNC CO ~{~_~,..~..jq~' '~-i~ ~ ............... Y N Y N N Comments/Instructions: dlf (: \Hm, dh{ ,,\w<uJh;Hl\rh, Uhl\ lu,, Ih, I Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon May 17 15:05:05 1999 Reel Header Service name ............. LISTPE Date ..................... 99/05/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/05/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER TABASCO MWD/MAD LOGS WELL NAME: API NLTMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 1 AK-MW-90040 J. MARTIN F. HERBERT 2T-209 501032028100 ARCO ALASKA, INC SPERRY-SUN DRILLING SERVICES 17-51AY-99 MWD RUN 2 AK-MW-90040 G. TOBIAS D. WESTER MWD RUN 3 AK-MW-90040 G. TOBIAS D. WESTER 1 lin 08E 655 556 110.90 110.90 80.40 RECEIVED ;/ AY 21 1999 Alaska Oil & Gas Cons. Co sion WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 24.000 16.000 110.0 12.250 9.625 4076.0 8.500 4690.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL, DUAL GAMMA R3kY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . THIS HOLE SECTION WAS COMPLETED BY RIG DOYON 19 WITH KBE OF 117.5' AMSL. 3. RUNS 2 & 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , UTILIZING GEIGER MUELLER TUBE DETECTORS. THIS HOLE SECTION WAS COMPLETED BY RIG NORDIC 3 WITH KBE OF 110.9' AMSL. 4. DEPTH SHIFTING OF MWD DATA IS WAIVED AS PER THE E MAIL FROM D. SCHWARTZ OF ARCO ALASKA, INC. ON 12/29/98. MWD DATA IS PDC. MWD RUN 1 IS DEPTH CORRECTED UPWARD 6.6' AND MERGED WITH RUNS 2 AND 3. 5. MWD RUNS 1-3 REPRESENT WELL 2T-209 WITH API#: 50-103 -20281-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4690'MD, 3319 ' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM S PACING ). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 118 0 RPD 127 5 RPM 127 5 RPS 127 5 RPX 127 5 FET 165 5 ROP 166 5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: STOP DEPTH 4679 5 4042 5 4042 5 4042 5 4042 5 4042 5 4689 5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 110.0 4081.0 2 4081.0 4305.0 3 4305.0 4690.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 118 4689.5 2403.75 9144 118 Last Reading 4689.5 GR 9.4984 148.395 78.5283 8636 ROP 0 2046.09 177.72 9047 RPX 0.1794 153.122 22.0947 7831 RPS 0.0632 2000 32.4622 7831 RPM 0.1535 2000 57.9114 7831 RPD 0.1114 2000 115.033 7831 FET 0.1077 6.4384 0.634318 7755 118 166 5 127 5 127 5 127 5 127 5 165 5 4679.5 4689.5 4042 .'5 4042.5 4042.5 4042.5 4042.5 First Reading For Entire File .......... 118 Last Reading For Entire File ........... 4689.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 118 0 127 5 127 5 127 5 127 5 165 5 166 5 STOP DEPTH 4032.0 4042 5 4042 5 4042 5 4042 5 4042 5 4080 5 18-DEC-98 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 ISC 5.07 ISC 5.07 MEMORY 4087.0 117.0 4087.0 .8 61.1 TOOL NUMBER Pl158CRG8 Pl158CRG8 12.250 12.3 SPUD 9.50 100.0 9.0 200 4.6 5.000 3.967 8.000 5.000 32.2 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD 1 FT/H 4 1 GR MWD 1 API 4 1 RPX MWD 1 OHMM 4 1 RPS MWD 1 OHMM 4 1 RPM MWD 1 OHMM 4 1 RPD MWD 1 OHMM 4 1 FET MWD 1 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 118 4080.5 2099.25 ROP 11.3704 2046.09 191.64 OR 9.4984 148.395 78.6305 RPX 0.1794 153.122 22.0947 RPS 0.0632 2000 32.4622 RPM 0.1535 2000 57.9114 RPD 0.1114 2000 115.033 FET 0.1077 6.4384 0.634318 First Last Nsam Reading Reading 7926 118 4080.5 7829 166.5 4080.5 7829 118 4032 7831 127.5 4042.5 7831 127.5 4042.5 7831 127.5 4042.5 7831 127.5 4042.5 7755 165.5 4042.5 First Reading For Entire File ........... 118 Last Reading For Entire File ........... 4080.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ........ 99/05/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4032.5 ROP 4081.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ STOP DEPTH 4294.0 4305.0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPER3~TURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 15-FEB-99 ISC 5.07 ISC 5.07 MEMORY 4305.0 4081.0 4305.0 56.6 57.0 TOOL NUMBER P1250CG6 8.500 8.5 KCL DRILL-IN 9.70 57.0 8.5 3.2 .000 .000 .000 .000 -17.7 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 4032.5 4305 4168.75 546 4032.5 GR 43.99 135.53 81.2985 524 4032.5 ROP 0 1496 94.6036 449 4081 Last Reading 4305 4294 4305 First Reading For Entire File .......... 4032.5 Last Reading For Entire File ........... 4305 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4295.5 ROP 4305.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ STOP DEPTH 4679.5 4689.5 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 17-FEB-99 ISC 5.07 ISC 5.07 MEMORY 4690.0 4305.0 4690.0 56.6 60.5 TOOL NUMBER P1251CG6 8.500 8.5 KCL DRILL-IN 9.70 54.0 8.7 3.4 .000 .000 .000 .000 -17.7 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 4295.5 4689.5 4492.5 789 4295.5 GR 47.13 145.75 78.6602 769 4295.5 ROP 2 2013 84.5358 769 4305.5 Last Reading 4689.5 4679.5 4689.5 First Reading For Entire File .......... 4295.5 Last Reading For Entire File ........... 4689.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/05/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/05/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File * ~SKA COMPUTING CENTER . ....... SCHLUMBERGER * COMPANY NAME : BP EXPLORATION (ALASKA), INC. WELL NAME : B-4 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292007200 REFERENCE NO : 99057 R C VED ;,,4AR 0 3 1999 Alaska Oil & Gas Cons. Commission LIS Tape VeriEhC~tion Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33~_~- PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/02/19 ORIGIN : FLIC REEL NAME : 99057 CONTINUATION # : PREVIOUS REEL : CO~4MENT · BP EXPLORATION, B-04, PRUDHOE BAY, 50-029-20072-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/02/19 ORIGIN : FLIC TAPE NAME · 99057 CONTINUATION # : 1 PREVIOUS TAPE : CO~ff~ENT · BP EXPLORATION, B-04, PRUDHOE BAY, 50-029-20072-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: B-4 API NUMBER: 500292007200 OPERATOR: BP EXPLORATION (ALASKA), INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 19-FEB-99 JOB NUMBER: 99057 LOGGING ENGINEER: DECKERT OPERATOR WITNESS: KRIEGER/KOES SURFACE LOCATION SECTION: 31 TOWNSHIP: 1 IN RANGE: 14E FNL: 741 FSL: FEL: 1598 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 59.60 DERRICK FLOOR: 58.60 GROUND LEVEL: 33.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (iN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 12.250 9.625 10784.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASO~ED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33"~~ BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: il-AUG-70 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 10596.0 10594.5 10591.0 10578.0 10575.0 10573.5 10565.5 10565.0 10557.0 10555,0 10553.0 10552.5 10548.5 10546,5 10545,5 10535.0 10534,0 10525,0 10514 5 10509 5 10492 0 10488 5 10480 5 10472 5 10469 5 10468 0 10465 5 10460 5 10457 0 10445 5 10444 5 10429 0 10424.0 10416.0 10403.0 10378.5 10367.0 10359.5 10351.5 10344.0 10343.5 10339.0 10327.0 10322.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88887.5 10595.5 10593.0 10575.0 10571.0 10562.5 10552.5 10551.0 10546.0 10543.0 10534.0 10525.5 10517.0 10509.0 10490.0 10481.5 10468.5 10459.5 10445.0 10418.5 10405.0 10380.0 10351.0 10346.0 88888.0 10591.0 10573.5 10564.0 10555.5 10551.0 10543.0 10534.0 10509.0 10490.5 10474.0 10468.5 10464.0 10455.0 10445.0 10428.5 10424.0 10367.0 10360.0 10343.0 10338.5 10327.0 10324.5 PAGE: LIS Tape Verifz't-~tion Listing Schlumberger Alaska Computing Center 10321.0 10315.0 10313.0 10312.5 10310.5 10304.0 10300.5 10299.5 10294.5 10293.0 10289.5 10281.5 10278.0 10266.0 10258.0 10253.5 10248.0 10247.0 10239.0 10238.0 10233.0 10229.0 10225.5 10218.0 10214.5 10212.0 10202.0 10200.0 10197.0 10196.5 10195 5 10194 0 10187 5 10185 0 10183 0 10182 0 10180 0 10174 5 10169 5 10168 0 10164 0 10162 0 10156 5 10148 5 10133 5 10128 5 10127 0 10120 0 10119 5 10118 5 10113.0 10101.0 1 OO98.5 10097.0 1 0096.0 10092.5 10323.0 10314.0 10312.0 10301.0 10294.0 10248.0 10239.0 10231.0 10220.5 10201.0 10196.5 10194.0 10186.0 10183.0 10181.0 10170.0 10164.5 10151.0 10133.0 10129.0 10121.0 10117.5 10111.5 10099.0 10093.5 10314.0 10310.5 10303.5 10300.5 10294. 0 10289.5 10282.5 10279.0 10267.0 10258.0 10254.0 10248.5 10239.0 10234.0 10224.5 10214.5 10210.5 10202.5 10198.5 10196.5 10189.0 10183.0 10176.0 10169.0 10160.5 10156.0 10129.0 10121.0 10102.0 10099.5 10097.0 19-FEB-1999 14:33''~' PAGE: LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33'~'~-''~ 10090.0 10083.5 10082.0 10077.0 10074.0 10069.0 10064.0 10058.5 10056.5 10054.0 10048.0 10045.5 10041.0 10035.0 10029.5 10028.0 10027.5 10025.5 10019.5 10016.5 10015.5 10004 0 10003 5 10002 0 10001 5 9999 0 9994 5 9993 5 9987 0 9981.0 9977.5 9975.0 9971.5 9964.5 9962.5 9948.5 9933.5 9926.5 100.0 $ REMARKS: 10090.5 10083.5 10077.0 10075.0 10069.0 10065.0 10057 0 10055 0 10049 0 10046 0 10041 0 10036 0 10030 5 10028 0 10025.0 10017.0 10005.0 10002.0 9999.0 9993.0 9981.5 9979.0 9977.5 9972.0 9963.0 9950.0 9926.5 100.0 10083.5 10061.0 10048.5 10030.5 10023.0 10017.0 10005.0 10002.0 9995.0 9989.0 9963.5 9931.5 98.0 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST DATA AQUIRED ON BP EXPLORATION'S B-04 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWUEEN GRCH BASE PASS #1 AND THE BASE GAiVk4A RAY, ALSO BASE PASS #1 SIGMA AND THE BASE GAM~WlA RAY, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ PAGE: LIS Tape Verifi~a~tion Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33~'~ .... PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS AUJMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10599.5 9892.0 RST 10611.0 9890.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33'-~'' PAGE: TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NTJM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 SBNA FIL CU 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 IRAT FIL 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 CIRNFIL 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 BSALRST PPK 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 SIBF RST CU 1267903 O0 000 O0 0 1 1 I 4 68 0000000000 TPHI RST PU-S 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 SFNC RST CU 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM RST CU 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 DSIG RST CU 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 FBEF RST UA 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 CRRA RST 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH RST GAPI 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 TENS RST LB 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 CCL RST V 1267903 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10611.000 NBAC.RST 1921.663 FBAC.RST 3355.363 SBNA.FIL SFNA.FIL 23.377 SBFA.FIL 48.831 SFFA.FIL 21.627 TR~T. FIL IRAT. FIL 0.737 CIRN. FIL 0.780 CIRF. FIL 1.325 BSAL.RST SIBF. RST 47.214 TPHI.RST 10.742 SFFC.RST 15.850 SFNC.RST SIGM. RST 15.840 DSIG.RST -4.294 FBEF. RST 33.407 CRRA.RST 61.411 0.785 70.257 11.542 1.393 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33'~'' PAGE: GRCH.RST -999.250 TENS.RST 1619.000 CCL.RST DEPT. 9890.000 NBAC.RST SFNA.FIL 37.448 SBFA.FIL IRAT. FIL 0.721 CIRN. FIL SIBF.RST 64.728 TPHI.RST SIGM. RST 33.818 DSIG.RST GRCH.RST -999.250 TENS.RST 2096.079 FBAC.RST 59.468 SFFA.FIL 0.410 CIRF. FIL 26.610 SFFC.RST -4.098 FBEF. RST 1473.000 CCL.RST -0.005 3657.329 SBNA.FIL 39.106 TRAT. FIL 0. $ 85 BSAL. RST 33. 815 SFNC.RST 29. 683 CRRA. RST O. 015 63. 706 O. 972 116.118 29. 419 1.341 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION · O01CO1 DATE : 99/02/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 99/02/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEA2~ER FILE ~BER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS IvTJMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUM~J~?Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10598.0 9892.5 RST 10611.5 9892.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 LIS Tape Verifm..~ion Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33 PAGE: BASELINE DEPTH 88888.0 10596.5 10586.5 10577.5 10575.0 10574.5 10571.5 10569.0 10568.5 10564.0 10557.5 10553.0 10552.0 10548.5 10545.0 10532.5 10524.5 10520.0 10519.0 10510.0 10509.5 10503.5 1O500 5 10493 5 10493 0 10490 0 10484 0 10483 0 10474 5 10472 5 10469 5 10465 0 10458 5 10449 5 10445 0 10436.5 10431. 0 10428.5 10404. $ 10390.5 10375.5 10374.0 10360.0 10348.0 10343.5 10340.5 10328.0 10322.5 10320.5 10314.5 10313.0 10310.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH RST 88886.0 88888.5 10575.5 10571.0 10566.5 10562.5 10556.0 10551.0 10546.0 10533.0 10519.0 10509.0 10501.0 10494.5 10489.5 10482.5 10471.0 10457.5 10429.5 10374. 0 10346.0 10322.0 10314.0 10597.0 10585.5 10573.5 10570.5 10567. 0 10551.0 10543.0 10524.0 10519.5 10509.0 10503.5 10491.0 10483.0 10474.0 10468.5 10464. 0 10448.0 10445.0 10436.5 10428.5 10405.0 10391.0 10374.0 10360.0 10343.5 10339.5 10328.0 10324.0 10314.0 10311.0 LIS Tape Verifi't~tion Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33'-~''~ PAGE: 10303.5 10300.0 10293.5 10293.0 10282.0 10280 5 10268 0 10263 5 10258 5 10253 5 10248 5 10246 0 10241 0 10234 5 10233 0 10225 5 10221 5 10215 0 10212 5 10201.5 10198.5 10195.5 10194.5 10193.0 10188.0 10184.0 10183.0 10182.0 10181.0 10177.5 10169.5 10168.5 10166.5 10160.5 10158.0 10152.5 10149.0 10145.5 10134.0 10127.5 10120.0 10117.5 10117.0 10114.0 10111.0 10105.0 10101.5 10098.0 10096.0 10093 5 10091 0 10087 0 10083 0 10065 0 10061 0 10303.5 10290.0 10278.0 10248.0 10235.0 10220.5 10201.5 10194.0 10188.5 10183.5 10181.0 10170.0 10159.0 10150.5 10145.5 10117.5 10111.5 10100.0 10095.0 10090.5 10064.5 10061.5 10300.5 10294.0 10283. 0 10269.0 10264.0 10258.0 10254.0 10247.0 10241.5 10233.5 10224.5 10214.5 10211.0 10200.0 10196.5 10194.5 10185.5 10182.5 10178.5 10169.0 10165.0 10157.0 10149.0 10135.0 10129.5 10121.5 20118.0 10114.5 10105.5 !0100. 0 10096.5 10088.0 10084.0 LIS Tape Verif~-J~tion Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33'~-~ PAGE: 10 10060.0 10058.5 10056.0 10049.0 10048.5 10041.5 10031.0 10028.5 10019.5 10016.0 10006.0 10003.5 10003.0 10001.5 10001.0 9995.5 9990 0 9987 5 9982 5 9978 5 9976 5 9972 0 9963 5 9962 5 9955 5 9948.0 9934.0 9918.5 9916.5 9911.5 9903.5 9894.5 9893.0 100.0 $ 10055.5 10049.5 10041.0 10031.0 10017.5 10005.0 10002.0 9999.0 9988.0 9981.5 9979.0 9977.0 9972.0 9963.0 9956.5 9949.5 9917.5 9910.5 9904.5 9893.5 100.5 10062.0 10060.5 10049.0 10031.0 10017.5 10005.0 10002.0 9995.0 9989.0 9963.5 9933.5 9917.0 9895.0 100.5 REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33~-~ PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SkT~YPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 CIRN FIL 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 BSALRST PPK 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1267903 O0 000 O0 0 2 t 1 4 68 0000000000 SFFC RST CU 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 CRRA RST 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1267903 O0 000 O0 0 2 i 1 4 68 0000000000 TENS RST LB 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1267903 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33 PAGE: 12 ** DATA ** DEPT. 10611.500 NBAC.RST SFNA.FIL 23.829 SBFA.FIL IRAT. FIL 0.730 CIRN. FIL SIBF. RST 46.435 TPHI.RST SIGM. RST 15.698 DSIG.RST GRCH.RST -999.250 TENS.RST DEPT. 9892.500 NBAC.RST SFNA.FIL 37.810 SBFA.FIL IRAT. FIL 0.731 CIRN. FIL SIBF.RST 60.825 TPHI.RST SIGM. RST 33.533 DSIG.RST GRCH. RST 41.163 TENS.RST 2132.977 FBAC.RST 46.527 SFFA.FIL 0.768 CIRF. FIL 10.888 SFFC.RST -3.844 FBEF.RST 1650.000 CCL.RST 2061.555 FBAC.RST 65.449 SFFA.FIL 0.407 CIRF. FIL 24.336 SFFC.RST -3.915 FBEF. RST 1482.000 CCL.RST 3511.351 SBNA.FIL 21.517 TRAT. FIL 1.331 BSAL.RST 15.716 SFNC.RST 34.219 C~.RST 0.000 3653.345 SBNA.FIL 38.920 TRAT. FIL 0.578 BSAL.RST 33.534 SFNC.RST 30.361 CRRA.RST 0.001 58.773 0.789 68.160 11.888 1.425 66. 392 O. 956 106.110 29.273 1.371 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION . O01CO1 DATE : 99/02/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 99/02/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUMFiARY LDWG TOOL CODE START DEPTH GRCH 10597.5 RST 10611.0 STOP DEPTH 9878.0 9878.0 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:3~~ PAGE: 13 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASSNUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH RST 88888.0 88885.5 88888.0 10609.0 10609.0 10596.0 10596.5 10590.0 10587.5 10583.0 10581.5 10575.5 10573.5 10574.5 10571.0 10568.5 10567.0 10568.0 10567.5 10565.0 10564.0 10552.5 10551.0 10549.5 10546.0 10545.0 10543.0 10536.5 10536.0 10536.0 10534.0 10524.5 10523.5 10514.0 10512.5 10510.5 10509.0 10509.5 10509.0 10506.0 10506.5 10504.0 10503.5 10501.5 10499.0 10495.5 10494.0 10485.5 10484.5 10476.0 10475.0 10472.5 10474.5 10468.5 10468.5 10456.5 10454.5 10449.5 10448.0 10447.0 10445.5 10444.0 10445.0 10437.5 10436.0 10428.5 10428.5 10422.0 10423.0 10421.0 10422.0 10410.5 10411.0 10408.5 10407.5 10392.5 10391.0 10391 . 5 10391 . 0 10383 . 0 10383.0 10381 . 0 10380.5 10374 . 5 10374.0 10373.5 10374.5 10360.5 10362.0 10360.0 10360.0 LIS Tape Verif~'tion Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33 PAGE: 14 10357.5 10346.5 10343.5 10339.5 10332.0 10327.0 10322.0 10310.0 10304.5 10301.0 10299.5 10296.0 10282.0 10279.0 10273.0 10266.0 10263.0 10257.5 10255.5 10253.0 10249.0 10240.5 10233 0 10229 0 10225 0 10220 5 10212 5 10205 0 10198 0 10195 5 10188.0 10186.0 10183.0 10182.0 10174.0 10169.5 10162.0 10156.5 10150.5 10148.0 10135.5 10131.5 10130.0 10129.0 10119.0 10117.0 10110.5 10104.5 10100.5 10097.5 10096.0 10093.0 1 OO90.5 10087.0 10082.5 10346.5 10327.5 10301.0 10273.0 10249.0 10220.5 10186.0 10183.5 10170.0 10158.5 10151.0 10132.5 10129.0 10111.0 10100.5 10090.5 10358.5 10343.5 10338.5 10332.5 10324.5 10310.5 10303.5 10300.5 10297. 0 10282.5 10280.5 10266.5 10264.0 10258.0 10255.5 10254.0 10241.5 10234. 0 10228.5 10224.5 10211. 0 10205. 0 10199.5 10196.5 10189. 0 10183. 0 10176. 0 10169. 0 10161.0 10148.5 10136.5 10132. 0 10121. 0 10118.0 10105.5 10099.5 10096.5 10094.5 10088.5 10083.5 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33 PAGE: 15 10077.0 10069.5 10067.0 10059.0 10058.0 10056.5 10054.0 10048.0 10044.0 10040.5 10035.0 10031 . 0 10028.5 10026.5 10025.0 10020.5 10017 5 10015 5 10009 0 10005 0 10003 5 10002 5 10001.0 9993.0 9992.0 9988.5 9986.5 9983.5 9976.5 9975.0 9973.0 9971.5 9962.5 9949.0 9939.0 9938.0 9925.5 9918.0 9916.0 9913.5 9908.0 9906.0 9895.0 100.0 $ 10069.5 10061.0 10057.0 10055.0 10047.5 10041.0 10030.5 10025.5 10017.5 10005.0 10002.0 9993.0 9983.5 9979.0 9976.0 9972.0 9963.0 9950. 0 9939.0 9925.5 9917.5 9915.5 10079. 0 10069.5 10060.5 10049.0 10046.0 10037.5 10031.0 10029.0 10022.5 10017.5 10009.0 10005.0 10002.0 9992.5 9990.5 9989.0 9973.0 9940.5 9913.5 9909.5 9905.5 9895.0 9895.0 100.0 100.0 REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #3 AND GRCH BASE PASS #!, ALSO SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Veri£;c~tion Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33 .... PAGE: 16 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NURiB SAMP ELEM CODE (HEX) DEPT FT 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA FIL CU 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA FIL CU 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA FIL CU 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA FIL CU 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT FIL 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT FIL 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 CIRN FIL 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 CIRF FIL 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 BSAL RST PPK 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RST CU 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RST PU-S 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RST CU 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RST CU 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RST CU 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RST CU 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RST UA 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 CRRA RST 1267903 O0 000 O0 0 3 1 i 4 68 0000000000 GRCH RST GAPI 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 TENS RST LB 1267903 O0 000 O0 0 3 1 ! 4 68 0000000000 CCL RST V 1267903 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:3~~ .... PAGE '. 17 ** DATA ** DEPT. 10611.000 NBAC.RST 2196.078 FBAC.RST 3765.947 SBNA.FIL SFNA.FIL 23.041 SBFA.FIL 55.396 SFFA.FIL 21.551 TRAT. FIL IRAT. FIL 0.736 CIRN. FIL 0.777 CIRF.FIL 1.320 BSAL.RST SIBF. RST 46.775 TPHI.RST 11.955 SFFC.RST 15.888 SFNC.RST SIGM. RST 15.960 DSIG.RST -3.742 FBEF.RST 33.230 CRRA.RST GRCH. RST -999.250 TENS.RST 1666.000 CCL.RST 0.001 DEPT. 9878.000 NBAC.RST 2128.811 FBAC.RST 3630.007 SBNA.FIL SFNA.FIL 39.669 SBFA.FIL 60.533 SFFA.FIL 39.223 TRAT. FIL IRAT. FIL 0.728 CIRN. FIL 0.391 CIRF. FIL 0.559 BSAL.RST SIBF.RST 63.574 TPHI.RST 25.755 SFFC.RST 33.882 SFNC.RST SIGM. RST 33.854 DSIG.RST -3.012 FBEF.RST 30.000 CRRA.RST GRCH. RST 39.991 TENS.RST 1485.000 CCL.RST -0.028 54.817 0.801 69.077 11.755 1.376 75.618 0.966 113.171 31.533 1.334 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE · 99/02/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION · O01CO1 DATE . 99/02/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass i Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33~ PAGE: 18 RST $ REMARKS 1, 2, 3, THIS FILE CONTAINS THE ARITH~fETIC AVERAGE OF BASE PASSES 1,2, & 3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NQ?/iB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD AK]FiB SAMP ELEM CODE (HEX) DEPT FT 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA RSAV CU 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA RSAV CU 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA RSAV CU 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA RSAV CU 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 T~T RSAV 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT RSAV 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNRSAV 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF RSAV 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL RSAV PPK 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF RSAV CU 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verif~¥Htion Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:3~. PAGE: 19 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUN~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) TPHI RSAV PU-S 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC RSAV CU 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC RSAV CU 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM RSAV CU 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG RSAV CU 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF RSAV UA 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 CRRA RSAV 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI 1267903 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10580.000 NBAC.RST 1818.531 FBAC.RST 3377.094 SBNA.RSAV 62.216 SFNA.RSAV 23.954 SBFA.RSAV 52.606 SFFA.RSAV 21.526 TRAT.RSAV 0.807 IRAT. RSAV 0.698 CIRN. RSAV 0.732 CIRF.RSAV 1.300 BSAL.RSAV 79.549 SIBF. RSAV 50.686 TPHI.RSAV 13.413 SFFC.RSAV 16.278 SFNC.RSAV 13.478 SIGM. RSAV 16.188 DSIG.RSAV -3.010 FBEF.RSAV 33.006 CRRA.RSAV 1.436 GRCH.RST 11.812 DEPT. 9890.000 NBAC.RST 2096.079 FBAC.RST 3657.329 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT.RSAV -999.250 IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF.RSAV -999.250 BSAL.RSAV -999.250 SIBF.RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF.RSAV -999.250 CRRA.RSAV -999.250 GRCH.RST -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verif~i~-ation Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33 r. PAGE: 20 FILE HEADER FILENO?~BER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~94ARY VENDOR TOOL CODE START DEPTH RST 10642.0 $ LOG HEADER DATA STOP DEPTH 9862.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G) : SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEC): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE 02-DEC-98 8C1-205 10693.0 10631.0 9878.0 10611.0 1800.0 TOOL NUMBER CGRS-A RST-A 12.250 10784.0 PRODUCED FLUIDS 223.0 THERMAL SANDSTONE 2.65 LIS Tape Verif~8~'tion Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33~-'' PAGE: 21 TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS BHCS DATED Il-AUG-1970. WELL TEST DATA: 11-13-98-1.78 MBPD, 1.72 MBOPD, .06 MBWPD, 32.62 f4MSCFD, 0 LIFT GAS, CHOKE 55.5, 2169 PSI MAN, 131 DEGF MAN. GR SCALE X10. LOGGED AT REDUCED CHOKE SETTING TEST DATA DURING LOG:554 BPD, 552 BOPD, 2.5 BWPD, MAN 2353 PSI, MAN 126 DEGF, CHOF~E 48, GAS LIFT O, FORM GAS14. 78 ~SCFD. 7" 29# LINER FROM 6706-10784 OTHER SERVICES RUN: FSPL/CNL. THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 224 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Veri£_ ~ion Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:3~'~'~ PAGE: 22 ** SET TYPE - CHAN ** N~'VlE SERV UNIT SERVICE API API API API FILE ~ Nr31vlB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUAiB SAMP ELEM CODE (HEX) DEPT FT 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 CS PS1 F/HR 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1267903 O0 000 O0 0 $ 1 1 4 68 0000000000 NPHV PS1 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 NPDE PS1 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 NSCE PS1 S 1267903 O0 000 O0 0 $ 1 1 4 68 0000000000 CRRA PS1 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 NSCR PS1 S 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 AQTMPS1 UA 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 CHV PS1 UA 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 CPSV PS1 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 CP2V PS1 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 CM2V PS1 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 RCFR PS1 PPK 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 RCLC PS1 PPK 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 RCRC PS1 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 RCAK PS1 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 RTDF PS1 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 FPHV PS1 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 FPDE PS1 CU 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 FSCE PS1 CPS 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 FSCR PS1 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 AQTF PS1 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 SF6P PS1 CPS 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 HVPV PS1 CU 1267903 O0 000 O0 0 5 1 ! 4 68 0000000000 BMCU PS1 CU 1267903 O0 000 O0 0 $ 1 1 4 68 0000000000 GDCU PS1 CU 1267903 O0 000 O0 0 $ 1 1 4 68 0000000000 EXCU PS1 CU 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 NBEF PS1 CU 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF PSi CU 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 NPGF PS1 CU 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 FPGF PS1 CU 1267903 O0 000 O0 0 $ 1 i 4 68 0000000000 BSTR PSI CU 1267903 O0 000 O0 0 5 1 ! 4 68 0000000000 BSPR PS1 CU 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 MARC PS1 CU 1267903 O0 000 O0 0 5 i 1 4 68 0000000000 XHV PS1 CU 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 XPSV PS1 CU 1267903 O0 000 O0 0 5 1 ! 4 68 0000000000 XP2V PSI CU 1267903 O0 000 O0 0 5 1 ! 4 68 0000000000 XM2V PS1 CU 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 RXFR PS1 CU 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 RXLC PS1 CU 1267903 O0 000 O0 0 5 1 i 4 68 0000000000 RXRC PS1 CU 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 RXAK PS1 1267903 O0 000 O0 0 5 1 t 4 68 0000000000 SHCU PS1 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL PS1 1267903 O0 000 O0 0 5 1 ! 4 68 0000000000 BSAL SIG GAPI 1267903 O0 000 O0 0 5 1 i 4 68 0000000000 CIRN PS1 1267903 O0 000 O0 0 5 1 ! 4 68 0000000000 CIRF PS1 KHZ 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 CIRN FIL K_HZ 1267903 O0 000 O0 0 $ 1 1 4 68 0000000000 CIRF FIL DEGC 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33~ PAGE .. 23 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DSIG PS1 DEGC 1267903 FBAC PS1 1267903 IRAT PS1 PU 1267903 IRAT Fib PU 1267903 NBAC PS1 V 1267903 SFNA PS1 1267903 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10642.000 CS,PS1 2743.902 TENS. PS1 NPDE. PS1 0.299 NSCE, PS1 0.661 CRRA.PS1 AQTM. PS1 23.802 CHV, PS1 34.494 CPSV. PS1 CM2V. PS1 0.000 RCFR~PS1 -999.250 RCLC. PS1 RCAK. PS1 -999.250 RTDF, PSl -999.250 FPHV. PS1 FSCE. PS1 -999.250 FSCR,PS1 -999.250 AQTF. PS1 HVPV. PS1 -999.250 BMCU, PS1 -999.250 GDCU. PS1 NBEF. PS1 -999.250 FBEF, PS1 -999.250 NPGF. PS1 BSTR.PS1 -999.250 BSPR,PS1 -999.250 MARC. PSi XPSV. PS1 -999.250 XP2V. PS1 -999.250 XM2V. PS1 RXLC. PS1 -999.250 RXRC.PS1 -999.250 RXAK. PS1 BSAL.PS1 -999.250 BSAL.SIG 0.000 CIRN. PS1 CIRN. FIL 315.798 CIRF,FIL 97.168 DSIG.PS1 IRAT. PS1 -999.250 IRAT, FIL -999.250 NBAC. PS1 DEPT. 9862.000 NPDE. PS1 0.388 AQTM. PS1 21.825 CM2V. PS1 0.000 RCAK. PS1 0.556 FSCE. PS1 3641.383 HVPV. PSl 35.580 NBEF. PS1 1.557 BSTR.PS1 37.500 XPSV. PS1 64.496 RXLC. PS1 1.117 BSAL. PS1 0.973 CIRN. FIL 339.339 IRAT. PS1 26.442 CS.PS1 NSCE. PS1 CHV, PS1 RCFR,PS1 RTDF, PS1 FSCR,PS1 BMCU PS1 FBEF PSi BSPR PSi XP2V PS1 RXRC PS1 BSAL SIG CIRF, FIL IRAT.FIL 1179.000 -0 139 0 996 -999 250 -999 250 -999 250 -999 250 -999.250 -999,250 -999.250 -999,250 85023,000 96,191 0,029 1915.657 TENS.PSi 1473,000 1.102 CRRA.PS1 -0,269 29.674 CPSV. PS1 1,008 115.526 RCLC. PS1 2,848 0.400 FPHV. PS1 0,548 0.738 AQTF. PS1 0,739 39.843 GDCU. PS1 65,850 1.002 NPGF. PS1 5,860 39.985 MARC. PSi 66,859 29.443 X~I2V. PS1 34,730 1.014 RXAK. PS1 0,983 32.159 CIRN. PS1 107164,000 98.145 DSIG. PS1 95,494 1.573 NBAC. PS1 -999,250 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC. PS1 FPDE.PS1 SF6P. PS1 EXCU. PS1 FPGF. PSl XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 NPHV. PS1 NSCR,PS1 CP2V. PS1 RCRC.PS1 FPDE. PS1 SF6P.PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS! SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 1.449 0.661 1,005 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 457.669 8878.000 8459.000 l. 360 O. 661 O. 994 O. 401 -4. 698 2027. 629 61 627 3 453 60 583 34 690 0 030 461 367 8878 000 8463 000 ** END OF DATA ** LIS Tape Veri£r~ation Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:3~~/ PAGE: 24 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUNk~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10641.0 9862.0 RST $ LOG HEADER DATA DATE LOGGED: 02-DEC-98 SOFTWARE VERSION: 8Cl-205 TIME LOGGER ON BOTTOM: TD DRILLER (FT) : 10693.0 TD LOGGER (FT) : 10631.0 TOP LOG INTERVAL (FT) : 9878.0 BOTTOM LOG INTERVAL (FT) : 10611.0 LOGGING SPEED (FPHR): 3400.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAIV~CA RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER ........... CGRS-A RST-A 12. 250 LIS Tape Veri£~tion Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:3~~/ PAGE: 25 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 10784.0 PRODUCED FLUIDS 223.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 3 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS BHCS DATED Il-AUG-1970. WELL TEST DATA: 11-13-98-1.78 MBPD, 1.72 MBOPD, .06 ~WPD, 32.62 I4MSCFD, 0 LIFT GAS, CHOKE 55.5, 2169 PSI MAN, 131 DEGF MAN. GR SCALE X10. LOGGED AT REDUCED CHOKE SETTING TEST DATA DURING LOG:554 BPD, 552 BOPD, 2.5 BWPD, MAN 2353 PSI, MAN 126 DEGF, CHOKE 48~GAS LIFT O, FORM GAS14. 78 ~4SCFD. 7" 29# LINER FROM 6706-10784 OTHER SERVICES RUN: FSPL/CNL. THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA LIS Tape VeriflJ~tion Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:32 .... PAGE: 2 6 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 224 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 CS PS2 F/HR 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 NPHV PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 NPDE PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 NSCE PS2 S 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 CRRA PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 NSCR PS2 S 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 AQTM PS2 UA 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 CHV PS2 UA 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 CP5V PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 CP2V PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 CM2V PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 RCFR PS2 PPK 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 RCLC PS2 PPK 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 RCRC PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 RCAK PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 RTDF PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 FPHV PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 FPDE PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 FSCE PS2 CPS 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 FSCR PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 AQTF PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 SF6P PS2 CPS 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 HVPV PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 BMCU PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Veri£1~tion Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33 PAGE: 27 NAME SERV UNIT SERVICE API API API API FILE NUM~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CI~SS MOD ~ SAMP ELi~I CODE (HFS) GDCU PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 EXCU PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 NBEF PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 FBEF PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 NPGF PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 FPGF PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 BSTR PS2 CU 1267903 O0 000 O0 0 6 I 1 4 68 0000000000 BSPR PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 MARC PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 XHV PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 XPSV PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 XP2V PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 X~2V PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 RXFR PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 RXLC PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 RXRC PS2 CU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 RXAK PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 SHCU PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL SIG GAPI 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 CIRN PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF PS2 KHZ 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 CIRN FIL KHZ 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF FIL DEGC 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 DSIG PS2 DEGC 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT PS2 PU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT FIL PU 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 NBAC PS2 V 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA PS2 1267903 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 10641.000 CS.PS2 2085.748 TENS.PS2 NPDE. PS2 0.023 NSCE.PS2 0.441 CRRA.PS2 AQTM. PS2 24.119 CHV. PS2 34.496 CP5V. PS2 CM2V. PS2 0.000 RCFR.PS2 -999.250 RCLC. PS2 RCAK. PS2 -999.250 RTDF.PS2 -999.250 FPHV. PS2 FSCE. PS2 -999.250 FSCR.PS2 -999.250 AQTF. PS2 HVPV. PS2 -999.250 BMCU. PS2 -999.250 GDCU. PS2 NBEF.PS2 -999.250 FBEF. PS2 -999.250 NPGF. PS2 BSTR.PS2 -999.250 BSPR.PS2 -999.250 MARC. PS2 XP5V. PS2 -999.250 XP2V. PS2 -999.250 X~2V. PS2 RXLC. PS2 -999.250 RXRC. PS2 -999.250 RXAK. PS2 BSAL.PS2 -999.250 BSAL.SIG 80.752 CIRN. PS2 CIRN. FIL 309.865 CIRF.FIL 97.168 DSIG.PS2 IRAT. PS2 -999.250 IRAT.FIL -999.250 NBAC. PS2 1089.000 0.014 1.008 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 112587 000 95 703 0 029 NPHV. PS2 NSCR . PS2 CP2 V. PS2 RCRC. PS2 FPDE.PS2 SF6P.PS2 EXCU. PS2 FPGF.PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 1.430 0.441 0.998 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 443.188 8878.000 8459.000 LIS Tape Veri~x~ation Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33 PAGE: 28 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUFmD%RY VENDOR TOOL CODE START DEPTH STOP DEPTH 10640.0 9846.5 RST $ LOG HEADER DATA DATE LOGGED: 02-DEC-98 SOFTWARE VERSION: 8Cl-205 TIME LOGGER ON BOTTOM: TD DRILLER (FT) : 10693.0 TD LOGGER (FT) : 10631.0 TOP LOG INTERVAL (FT) : 9878.0 BOTTOM LOG INTERVAL (FT): 10611.0 LOGGING SPEED (FPHR): 3400.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:33 PAGE: 29 GR RST $ GA~g~A RAY RESERVOIR SATURATION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) '. FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG): CGRS-A RST-A 12.250 10784.0 PRODUCED FLUIDS 223.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS BHCS DATED !l-AUG-1970. WELL TEST DATA: 11-13-98-1.78 MBPD, 1.72 MBOPD, .06 MBWPD, 32.62 Rff~SCFD, 0 LIFT GAS, CHOICE 55.5, 2169 PSI MAN, 131 DEGFMAN. GR SCALE XiO. LOGGED AT REDUCED CHOKE SETTING TEST DATA DURING LOG:554 BPD, 552 BOPD, 2.5 BWPD, MAN2353 PSI, MAN 126 DEGF, CHOKE 48, GAS LIFT O, FORM GAS 14.78 Nk4SCFD. 7" 29# LINER FROM 6706-10784 OTHER SERVICES RUN: FSPL/CNL. THIS FILE CONTAINS THE RAW DATA FOR PASS #3. $ LIS FORMAT DATA LIS Tape Veri~t=~ation Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:~b PAGE: 30 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 224 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 CS PS3 F/HR 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 NPHV PS3 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 NPDE PS3 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 NSCE PS3 S 1267903 O0 000 O0 0 7 i 1 4 68 0000000000 CRRA PS3 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 NSCR PS3 S 1267903 O0 000 O0 0 7 ! 1 4 68 0000000000 AQTMPS3 UA 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 CHV PS3 UA 1267903 O0 000 O0 0 7 ! 1 4 68 0000000000 CPSV PS3 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 CP2V PS3 1267903 O0 000 O0 0 7 t 1 4 68 0000000000 CM2V PS3 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 RCFR PS3 PPK 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 RCLC PS3 PPK 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 RCRC PS3 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 RCAK PS3 1267903 O0 000 O0 0 7 t 1 4 68 0000000000 RTDF PS3 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 FPHV PS3 1267903 O0 000 O0 0 7 i 1 4 68 0000000000 FPDE PS3 CU 1267903 O0 000 O0 0 7 ! 1 4 68 0000000000 FSCE PS3 CPS 1267903 O0 000 O0 0 7 ! 1 4 68 0000000000 FSCR PS3 1267903 O0 000 O0 0 7 ! i 4 68 0000000000 AQTF PS3 1267903 O0 000 O0 0 7 1 i 4 68 0000000000 SF6P PS3 CPS 1267903 O0 000 O0 0 7 1 I 4 68 0000000000 LIS Tape Veri'~J~ation Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:3~~ PAGE: 31 NAME SERV UNIT SERVICE API API API API FILE NUMB NUA~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) HVPV PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 BMCU PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 GDCU PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 EXCU PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 NBEF PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 FBEF PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 NPGF PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 FPGF PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 BSTR PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 BSPR PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 MARC PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 XHV PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 XPSV PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 XP2V PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 X~2V PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 RXFR PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 RXLC PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 RXRC PS3 CU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 RXAKPS3 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 SHCU PS3 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL PS3 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL SIG GAPI 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 CIRN PS3 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF PS3 KHZ 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 CIRN FIL KHZ 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF FIL DEGC 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 DSIG PS3 DEGC 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT PS3 PU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT FIL PU 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC PS3 V 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA PS3 1267903 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. PS3 AQTM. PS3 CM2V. PS3 RCAK. PS3 FSCE. PS3 HVPV. PS3 NBEF. PS3 BSTR.PS3 XPSV. PS3 RXLC. PS3 BSAL.PS3 CIRN. FIL IRAT. PS3 10640 000 1 040 24 144 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 312.778 -999.250 CS.PS3 1355.422 TENS. PS3 984.000 NPHV. PS3 NSCE.PS3 0.661 CRRA.PS3 -0.527 NSCR.PS3 CHV. PS3 34.098 CPSV. PS3 1.008 CP2V. PS3 RCFR.PS3 -999.250 RCLC. PS3 -999.250 RCRC.PS3 RTDF. PS3 -999.250 FPHV. PS3 -999.250 FPDE. PS3 FSCR.PS3 -999.250 AQTF. PS3 -999.250 SF6P. PS3 BMCU. PS3 -999.250 GDCU. PS3 -999.250 EXCU. PS3 FBEF. PS3 -999.250 NPGF. PS3 -999.250 FPGF. PS3 BSPR.PS3 -999.250 MARC. PS3 -999.250 i~V. PS3 XP2V. PS3 -999.250 X~2V. PS3 -999.250 RXFR.PS3 RXRC. PS3 -999.250 RXAK. PS3 -999.250 SHCU. PS3 BSAL.SIG 73.470 CIRN. PS3 129327.000 CIRF. PS3 CIRF. FIL 97.168 DSIG. PS3 95.703 FBAC.PS3 IRAT. FIL -999.250 NBAC. PS3 0.029 SFNA.PS3 t 412 0 661 1 007 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 441 717 8878 000 8459.000 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 19-FEB-1999 14:~ PAGE: 32 DEPT. 9846. 500 CS. PS3 NPDE. PS3 -0.286 NSCE. PS3 AQTM. PS3 22. 384 CHV. PS3 CM2V. PS3 0.000 RCFR . PS3 RCAK. PS3 O. 535 RTDF. PS3 FSCE. PS3 3620. 053 FSCR. PS3 HVPV. PS3 39.171 BMCU. PS3 NBEF. PS3 1.402 FBEF. PS3 BSTR. PS3 39. 331 BSPR. PS3 XPSV. PS3 64 . 169 XP2V. PS3 RXLC. PS3 1 . 336 R3fRC. PS3 BSAL. PS3 O. 981 BSAL. SIG CIRN. FIL 335.630 CIRF. FIL IRAT. PS3 26. 921 IRAT. FIL 3523 . 600 TENS. PS3 0.661 CRRA.PS3 30. 109 CPSV. PS3 114. 693 RCLC. PS3 O. 371 FPHV. PS3 O. 708 AQTF. PS3 41. 414 GDCU. PS3 1 . 470 NPGF. PS3 40. 695 MARC. PS3 31. 435 XM2V. PS3 1. 047 RXAK . PS3 54 . 384 CIRN. PS3 97. 168 DSIG. PS3 1 . 924 NBAC. PS3 1473.000 NPHV. PS3 -0.585 NSCR.PS3 0.995 CP2V. PS3 3.410 RCRC. PS3 0.526 FPDE. PS3 0.711 SF6P.PS3 64.249 EXCU. PS3 4.662 FPGF. PS3 66.070 XHV. PS3 35.467 RXFR.PS3 0.991 SHCU. PS3 141707.000 CIRF. PS3 95.703 FBAC. PS3 -999.250 SFNA.PS3 1.345 0.441 1. 002 O. 363 -3. 227 2104.322 63.882 4.763 62.614 35.395 0.036 451.463 8878.OOO 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE . FLIC VERSION · O01CO1 DATE : 99/02/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 99/02/19 ORIGIN : FLIC TAPE NAME : 99057 CONTINUATION # : 1 PREVIOUS TAPE : COf4~ENT · BP EXPLORATION, B-04, PRUDHOE BAY, 50-029-20072-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/02/19 ORIGIN : FLIC REEL NAME : 99057 CONTINUATION # : PREVIOUS REEL : COMMENT · BP EXPLORATION, B-04, PRUDHOE BAY, 50-029-20072-00 16" Conductor Tabasco Producer 2T-209 Producer Completion Current N. FMC Tabasco Producer horizontal wellhead/hanger sys[em w/125 amp penetrators M; Heat Trace, Raychem, 3000' Weatherford Gemoco DV Stage Collar Stnd. Grade BTC Threads (+/- 1801' MB / 1745' TVD) 4-1/2" Nova Clamps Nordic 3 RKB to LDS = 28.37' L. 114 jts 4-1/2" 12.6# L-80 BTCM tubing to surface 31.56' MD K. XO sub, L-80 4-1/2'~ BTCM box x 3-1/2" BTCM Special Clearance pin 3626'MD 3-1/2" Nova Clamps ESP power cable splice above Y-block B, 1 jr, 3-1/2" 9.3# L-80 EUE8RD tubing J. 3 its, 3-1/2" 9.3# L-80 BTCM tubing 3.865" Special Clearance couplings 3628' MD I. Baker 'Sentry' gauge, 3-1/2", w/I-wire, Clamp-on style H. 3-112" x 4' Landing pup, 9.3#, L~80, BTCM 3.865" Special Clearance couplings@ 3724'MD G. 3-1/2" Trico Y-Block (OD 8.6") w/couplings, 3-1/2" EUE8RD pin on motor leg, 2-7/8" EUE8RD pin on I-tube leg, 3-1/2" BTCM Special Clearance box up@ 3728' MD F. 2~7/8" Trico 'X' landing nipple w/2.312" profile, EUE8RD box x Hydril1511pin@ 3731' MD E, 3-11/16" x 2' L*80 'Swivel Sub'. 2.875*' ID Hyddl1511@ 3736'MD A. Centrifilt Series 562 ESP assembly w/power cable, 5.62" OD Super-Bands to top of Y-block D. 3 its, 2-7/8" 6.5# L-80 Hyddt1511 flush jt tubing@ 3740' MD ** 0.184" olanned clearance as D,e,r Cent,r, iliff ~ ,, (drift) - (ESP OD) - (I tube OD) = 8.679 - 6.62 - 2.875"! ./ 9-5/8" Surface Casing 40.0¢ L-80 BTCM (4082' MD / 3004' TVD) Top of Tabasco Sand @ 4127' MD, 3027' TVD Bottom of Tabasco Sand @ 4670' MD, 3309' TVD Open Hole Gravel Pack TD < 10' below Tabasco base (4680' MD / 3019' TVD) C. 2-7/8" Wireline Entry Guide, Hydril1511 BTM@ 3842'MD Gravel Pack Assembly (run on ddlfi~iDe~ Baker SC-1 Gravel Pack packer, 9-5/8" x 4.75"1D 3929' Upper Ext, 6.625"OD x 5.75" ID 3934' GP SId Sleeve, 7"OD x 4.8751'1D 3939~ Lower Sealbore, 6.63"OD x 4.75"1D 3941' GP Lower Eh(t, 6.625" x 5.75"1D 3942' X-over sub, 7.25"OD x 4.25"1D 3961' Model 'lB" ceramic KOIV, 5~13"OD x 2.88"1D 3962' X-over sub, 5.55"OD x 3.428"1D 3964' 2 its 4" Blank Pipe, 4"OD x 3.428"1D 3965' 17 its 4" GP Screen, ,020" ga 4,63"OD x 3.428"1D 4039' O-ring/Flapper Assby, 5.5"OD x 2.375"1D 4668' 4" Pup JT. 4!~OD x 3.428"tD 4672' 4" V Set Shoe, 4.47"OD x 0"ID 4678' End of Assby, 4680' 34,000# of 12~20 US mesh gravel pack sand TJM,1/7/02 ver4 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 February 22, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2T-209 (198-243 / 302-008) Dear Commissioner Oechsli Taylor: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover on the KRU well 2T-209. If there are any questions, please contact Skip Coyner at 265-6074. Sincerely, C. Mallary Drilling Engineering Supervisor Phillips Drilling CM/skad RECEIVED FEB g g 2002 Alaska 0il & Gas Co~s. Commission A~c~ao~e OR!81 AL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _ Pull tubing _X Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X Nordic 3 RKB 28' 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 4623' FNL, 4723' FEL, Sec. 1, T11 N, R8E, UM (asp°s 498945, 5970635) 2T-209 At top of productive interval 9. Permit number / approval number 2803' FSL, 143' FWL, Sec. 1, T11N, R8E, UM 198-243/302-008 At effective depth 10. APl number 50-103-20281 At total depth 11. Field / Pool 1991' FNL, 5169' FEL, Sec. 1, T11 N, R8E, UM (asp's 498497, 5973267) Kuparuk River Field / Tabasco Oil Pool 12. Present well condition summary Total depth: measured 4690 feet Plugs (measured) XX plug @ 3730' MD true vertical 3318 feet Effective depth: measured 4678 feet Junk (measured) true vertical 3312 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 112' 16" 9 cu yds High Early 112' 112' SURF/PROD 3971' 9-5/8" 505 sx AS Ill & 760 sx Class G, 60 4082' 3001' Liner 4" gravel pack screen 4678' 3312' Perforation depth: measured none RECEIVED true vertical none FEB Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 3754' MD Alaska Oil & Gas Co~s. Commission Packers & SSSV (type & measured depth) gravel pack packer @ 3929', Baker Model F pkr @ 3915' with KOIV below Anchorage No SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation SI Subsequent to operation SI 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil __ X Gas _ Suspended__ Service 17. I hereby certify that the foregoing is true_and correct to the best of my knowledge. Questions? Call Todd Mushovic 265-6974 Signed (~. ~, ,, Title: Ddlling Engineering Supervisor Date C. Malla~ -- ~ Prepared b,V Sharon Al/sup-Drake 263-4612 OP, 1611 AL Form 10-404 Rev 06/15/88- SUBMIT IN DUPLICATE ti S:! Report Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 :DeScripti°n of Operations Code..~ 1/20/2002 18:00-00:00 6.00 MOVE MOVE MOVE Moving rig from 1M pad to 2T pad 20.6 miles 1/21/2002 00:00-14:00 14.00 MOVE MOVE MOVE Moving rig from 1M pad to 2T pad 20.6 miles -temp 37 below-hydraulic oil thick & blowed breakers-replace one breaker-pull out for cr ew change @ 0600 @ X pad. (Note) Camp on 2T pad @ 1800 hrs. 01-20-2002. Rig on pad @ 1300 hrs. Spot rig over well. (Accept rig @ 1400 hrs. 01/21/2002.) 14:00-17:00 3.00 MOVE MOVE MOVE Load 'A' frame-guards & esp spool on rig fie or w/ crane. 17:00-20:00 3.00 WELLSROTHR WRKOVR Pull VR plug & BPV. 20:00-21:00 1.00 WELLSROTHR WRKOVR Rig up circ. equipment test hard lines w/ air 21:00-23:30 2.50 WELLSFIClRC WRKOVR PJSM-displace well w/ 350 bbls. seawater. 23:30-00:00 0.50 WELLSROTHR WRKOVR Rig down kill manifold-install BPV-break do wn hardline. 1/22/2002 00:00 - 01:00 1.00 WELLSFI NUND WRKOVR N i p p I e d o w n t r e e. 01:00-06:00 5.00 WELLSRNUND WRKOVR Nipple up bope-install 4 1/2" rams. 06:00-07:00 1.00 WELLSROTHR WRKOVR Function test rams. Pull bpv & install 2 way check. 07:00-10:30 3.50 WELLSRSEQT WRKOVR Test bope 250-3500# ok. 10:30-13:30 3.00 WELLSRPULD WRKOVR Pull 2 way check-install landing jt.-bolds-pu / II hanger loose @ 160k-pull to floor slow-kn otty all the way pulling from 80k to 150k-es p electric cable missing. POH laying down 4 1/2' tbg. tight & knotty. Layed down 9 jts.- 35 raychem bands missing & 5 flat guards m ssing-18 centralift bans missing. 13:30-15:00 1.50 WELLSFCIRC WRKOVR Rig up & circ. while waiting on orders. 15:00-16:30 1.50 WELLSFPULD WRKOVR Lay down 11 its. 4 1/2' tbg. Pulling tight. 16:30-00:00 7.50 WELLSFOTHR WRKOVR Pipe stuck w/ Bottom motor leg @ 3170'. We rk same-change out bails to run free point & chemical cutter. (Load pipe shed w/ dc,s-d p & fishing tools while waiting on sws. Schl umberger running late due to rigging unit fo r free point & cutter.) 1/23/2002 00:00-06:00 6.00 WELLSROTHR WRKOVR Waiting on ewe-make up free point. 06:00-10:30 4.50 WELLSF~OTHR WRKOVR PJSM-rig up sws E-line & sheaves-pick up fr ee point. 10:30-22:00 11.50 WELLSROTHR WRKOVR Rih w/ freepoint-free pointing several depth s from 1600' to 3100'. POH w/ free point & r ig down same. 22:00-00:00 2.00 WELLSFiOTHR WRKOVR PJSM-pick up-make up string shot-rih & fire string shot @ 3035' to 3045'-poh & lay down string shot. 1/24/2002 00:00-08:00 8.00 WELLSROTHR WRKOVRiPJSM-RIH w/ chemical cutter to top of 2 7/8 "@ 3061'-Iog up-hung up in 4.5" X 3.5" XO- work same loose-pump capacity of tbg. & po h-check tool-clean debrie out of bottom cent ralizer & point spring-rih & cut 3.5" tbg. @ 3040'. (pump capacity of tbg. while running n hole-90k up wt. prior to cutting-50k up wt Printed: 2/14/2002 1:24:27PM Report Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 ~ii Hb~rs.!~ :::DesCription of Operations 1/24/2002 00:00 - 08:00 8.00 WELLSR OTHR WRKOVR . a f t e r c u t t i n g. ) 08:00-12:00 4.00 WELLSFIPULD WRKOVR POH Laying down tbg.-recovered 1708' heat trace w/ bands & flat guards-heat trace gon e & all bands guards & clamps gone after he at trace. 12:00-15:00 3.00 WELLSFIOTHR WRKOVR Change out bails & floor equipment-rig down ewe-send out heat trace,bands, & flat guar ds-test lower pipe rams to 250-3500#-set we ar ring. 15:00-17:00 2.00 WELLSROTHR WRKOVR Pick up bha-rope spear & rih-tag esr cable @ 110'-Iatch fish-poh to rotary table w/ cabl e-5k over string wt.. 17:00-00:00 7.00 WELLSROTHR WRKOVR Fabricate handling tools for esp cable w/ we =lder-clean & inspect derrick. 1/25/2002 00:00-06:00 6.00 WELLSFOTHR WRKOVR Fabricate clamps & handling tools for retrie ving esp cable. 06:00-00:00 18.00 WELLSFOTHR WRKOVR Fishing for esp cable w/ rope spear-recover ed 635" of cable-19 flat guards & several b ands w/ cable. (circ. well to hot seawater @ 750'.) Recovered 876' By 0600) 1/26/2002 00:00-00:00 24.00 WELLSFOTHR WRKOVR Continue making trips w/ rope spear recover ng esp cable & various metal pieces includi ng flat guards & bands.(recovered-2229' esp cable-300' heat trace-82 flat guards & bun ch of bands & pieces. (Total since starting 2864' esp cable-lO1 flat guards-300' heat tr ace & bunch of bands) 1/27/2002 00:00-00:00 24.00 WELLSI=OTHR WRKOVR Retrieving esp completion w/ rope spear (pi ck up 7- 4 3/4' dc,s) Retrieved=984' Heat tr ace-127 flat guards-162 bands+-. (Total retri eved-2864' esp cable-228 flat guards-1284' heat trace-Approx. 200 bands.) Circ. hot se awater complete circ. @ 1934'. Fishing @ 22 40'. @ midnight. Stacked out on bands. 1/28/2002 00:00-12:00 12.00 WELLSROTHR WRKOVR Tripping w/ spear & retrieving esp completio n. (circ. hole @ 2240') 12:00-00:00 12.00 WELLSROTHR WRKOVR Make up washpipe w/ 'E' claw tool & disk-di sk sheared 3 stands off bottom-rih & rig up- reverse & clean out from 2250' to 2265'-rec overed 25 gals. corrosion & scale-3' esp ca hie & bucket full of band pieces-rih w/ same -clean out from 2265' to 2283' Poh recover ed 5 gals. scale & corrosion-1 flat guard & bucket full of band pieces-5' esp cable.. ( t otal recovered today-23' esp cable- 30 gals. corrosion-2 flat guards & 2 buckets band pi eces. 1/29/2002 00:00-01:00 1.00 WELLSFiOTHR WRKOVR Lay down washpipe assembly. 01:00-12:30 11.50 WELLSFOTHR WRKOVR Tripping & fishing w/ spear from 2283' to 23 05' recovered 180' esp cable-32 flat guards- 1 bucket band pieces & 2 nova clamps. 12:30-13:00 0.50 WELLSI;OTHR WRKOVR Clean metal from stack & function rams. 13:00-00:00 11.00 WELLSFISEQT WRKOVR Test bope-change element in annular preven Printed: 2/14/2002 1:24:27 PM :i !.i.i: i Report: Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 i :'::-::! :~i~:.i: !'Fr°~::;:~TM :' iR~;s!,t ::~:.: i~ :.i~: ~::: :' : i DeScriPtion of Operations 1/29/2002 13:00-00:00 11.00 WELLSFSEQT WRKOVR ter-repair-outside kill line valve-top drive d ouble ball sub-Test same to 250-3500# OK. 1/30/2002 00:00-02:30 2.50 WELCTLBOPE WRKOVR Complete testing bope 3500 / 350 psi / 5 mi n, annular 3000 / 350 psi. Set wear bushing. 02:30-03:30 1.00 WELLSFOTHR WRKOVR Slip & cut drlg line. 03:30o04:00 0.50 WELLSFTRIP WRKOVR Make up fishing assmby: od Ingth Spear 8.375' x 13.45' xo 5.75 x 2.03 lubricated Bump. Sub 4.75 x 7.86 Bowen F. Jars 4.75 x 12.53 Pump out cir sub 4.75 x 1.48 9 dc 4.625 x 279.30 Total = 31 6.65' 04:00-05:00 1.00 FISH TRIP WRKOVR Rih to tag @ fish 2483' 05:00-05:30 0.50 FISH FISH WRKOVR Work spear down to 2487' 05:30-06:30 1.00 FISH TRIP WRKOVR Pooh, recovered 6 flat guards. 06:30-07:30 1.00 RIGMNTRSRV WRKOVR Rig service & clean floor. 07:30-08:30 1.00 FISH TRIP WRKOVR Rih w/ spear assmby to tag fish @ 2487' 08:30-09:00 0.50 FISH FISH WRKOVR Work spear down to 2505'. Work spear @ td , pulled up to 70k lbs off bottom. Weight dr opped back to 6 k over when 30' off bottom. 09:00-10:30 1.50 FISH TRIP WRKOVR Pooh dragging 6k lbs over - when pulled int o stack heard debris fall off spear. When o ut of the hole recover 2 ea 1/8" x 3/4 x 6" banding material. Ld spear assmbly. 10:30-11:30 1.00 FISH PULD WRKOVR Pu / Mu reverse cir assmby: Reverse Cir b asket 5.75" 7.3' 2 Jts wash pipe 5 .75 62.25 Top sub 1.87 Bumper sub 4.75 7.86 Bowen Oil Jar 4.75 12.53 Cir - c ontrol sub 4.75 1.48 9 dc 4.625 279.30 xo 1.2 Stop Sub 4.75 I .8 xo 2.03 Rupture Sub 4.75 I .45 total 3 35' 11:30-13:00 1.50 FISH TRIP WRKOVR Rih to tag debris @ 2495'. 13:00-14:30 1.50 FISH OTHR WRKOVR Work rev cir sub to 2506' @ 9.7 bpm / 600 p si. Rotate slowly w/ max torque to 8k ft-lbs Recovered heavy rust & black sand size i ron debris @ shaker for ? 7 minutes. 14:30-15:30 1.00 FISH TRIP WRKOVR Pooh w/ reversing assmby. 15:30-16:30 1.00 FISH PULD WRKOVR Recovered 2 mangled flat guards [estimated ] from reversing assmby. Ld reverse assm bly. 16:30-18:00 1.50 FISH TRIP WRKOVR Rih w/ spear assmbly as above. 18:00-19:00 1.00 FISH OTHR WRKOVR Work spear on bottom & down to 2522' w/ ov er pulls to 60k lbs over string wt. Pull up 6 0' off td, wt dropped to 6k lbs over. 19:00-20:00 1.00 FISH TRIP WRKOVR Pooh w/ spear assembly. Printed: 2/14/2002 1:24:27 PM :.:'!i'.i' Report : Legal Well Name: 2T-209 Common Well Name: 2-1'-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 Hours?-: Code..~: ::.~:Phase: :: :::::: :::~ DeSCriptiOn of Operations 1/30/2002 20:00-20:30 0.50 FISH OTHR WRKOVR Recovered approx. 2 complete Nova clamps & 30 lbs of flat guard material which = 710 f lat guards. 20:30-21:~ 0.50 FISH OTHR WRKOVR Clean floor & repair spear 21:00-22:00 1.00 FISH TRIP WRKOVR Rih w/ spear assmby as above. Tag up ~ 2 522', push down 4' to 2526' w/ light wt. 22:00-00:00 2.00 FISH OTHR WRKOVR Rotate / circulate down 3 singles. Continue to rotate down singles [not circulating] to 2850' where started taking weight. Mu tds f or circulation, & prepare to rot - cir string d own . 1/31/2002 00:00-00:30 0.50 FISH OTHR WRKOVR Continue to circulate [300 psi / 5.2 bpm] & r orate down to 2932' where torque built to 55 00 ft-lbs. 00:30-01:30 1.00 FISH CIRC WRKOVR Circulate 2 x bottoms up. Very light corrosi on material on shakers. 01:30-03:30 2.00 FISH TRIP WRKOVR Pooh 10 stands slowly to 2000', dragging 12 0k lbs over string & swabbing 18 bbl per 5 s tands. Ok for flow each 5 stands [15 mins]. 03:30-06:00 2.50 FISH TRIP WRKOVR Weight dropped backed to calculated string wt plus some light drag. Continued to pooh w/ correct hole fill. Recovered 1 Nova cl amp, part of a flatguard & 30' of esp cable. 06:00-07:00 1.00 RIGMNT RSRV WRKOVR Rig Service 07:00-08:00 1.00 FISH TRIP WRKOVR Rih w/ spear assmby to tag debris ~ 2934' Dailey planning meeting held 0700 hrs [too pushers, ppco,brine engineer] 08:00-08:30 0.50 FISH FISH WRKOVR Work spear down to 2942'. Difficult to get a good catch & hole same. Got one good ov er pull of 100k lbs & started out w/ slight dr ag. 08:30-10:00 1.50 FISH TRIP WRKOVR Pooh dragging 1500 - 2500 lbs. Recovered 6' of ESP line. 10:00-11:00 1.00 RIGMNT RGRP WRKOVR Replace hydraulic cylinders on TDS compens ator. 11:00-12:00 1.00 FISH PULD WRKOVR Ld spear bha. 12:00-14:00 2.00 FISH PULD WRKOVR Pick up & make up wash pipe bha: 8.375" Wash Pipe shoe 2.35' XO & Dragon Tooth Extension 4.88 1 jt 8.125' wash pipe 32.05 xo junk basket 5.69 2 each junk baskets 9.24 Bit sub 70 Bumper Sub 7.86 B owen Oil Jars[4.75"] 12.53 9 x 4.7 5" dc 279.30 Cir pump o ut sub 2. I 2 Total 358.72 14:00-15:00 1.00 FISH TRIP WRKOVR Rih on 3.5" dp to tag debris ~ 2935'. 15:00-20:00 5.00 FISH WASH WRKOVR Washing over junk / debris from 2935' to 29 90.5'. 1st 7' slow, then broke through & wa shed ahead. 7.8 bpm / 550 - 660 psi, wts 2 Printed: 2/14/2002 1:24:27 PM Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/REOOMP Start: 1/21/2002 End: 2/1012002 Contractor Name: NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 ::::::::: : : DesCription of Operations 1/31/2002 15:00-20:00 5.00 FISH WASH WRKOVR - 12 k lbs, 60 - 70 rpm, torque 1500 - 6500 f t lbs. Shakers 25% coverage w/ hi percenta ge of rust - corrosion material, not much "fr esh steel material' NOTE - SIMULTANEO US CPS: During this time block cleaned hol e w! hi-vis sweep, 50 bbl hot diesel pill & di splaced w/ 580 bbl warm clean sea water tre ated w/ KCI to 2%. 20:00-21:00 1.00 FISH (:;IRC WRKOVR Cir / cond sweep hole. 21:00-23:00 2.00 FISH TRIP WRKOVR Pooh w/ washover string. Ld jars [will repla ce] . 23:00-00:00 1.00 FISH PULD WRKOVR Shoe in good shape, wash pipe in good cond ition. Clean out string recovering 4?' of ste el & copper, weight = ?50 lbs. Junk baskets full of steel & copper [1.5 gallons]. 2/1/2002 00:00-01:00 1.00 FISH OTHR WRKOVR Continue to clean out washover assembly. Note: recovery on previous rpt [# 12]. 01:00-02:30 1.50 FISH TRIP WRKOVR Trip in hole w/ washover string, tag up on d ebris @ 2990' [previous depth was 2990.0']. 02:30-06:00 3.50 FISH WASH WRKOVR Wash over debris from 2990 to 3011'. 8' of washover was accomplished in first hour, aft er that the rate decreased gradually to .5 - 1' foot per hour. No increase in pump press ure due to all recovery below slots cut in "d ragon tooth" catch sub. Parameter 350 - 45 0 psi @ 6 - 7 bpm, torque 1500 to average o f 3800 w/ peaks to 6500 ft-lbs [to make any head way near the end w/ 15k lbs on the sho e]. RPMs in the 65 to 75 range dependent o n weight. Weight 5 to max of 15k lbs near e nd of run. 06:00-07:00 1.00 FISH (:;IRC WRKOVR Circulate cond, prep for trip. Held dailey cps meeting [ppco, 2 x pushers, brine engin eer] 07:00-09:30 2.50 FISH TRIP WRKOVR Pooh w/ washover assembly. 09:30-10:00 0.50 FISH WRKOVR Clean out wash pipe, rec 4.5', recover @ Io wer dragon tooth. 10:00-12:30 2.50 FISH TRIP WRKOVR!Trip in hole w/ wash-over assembly, tag pre vious td on depth of 301 1' Did not run "dr agon tooth" sub in wash - over assembly. 12:30-14:00 1.50 FISH WASH WRKOVR Wash over debris from 3011 to 3024'. Pump press increased from 650 to 1000 psi. Nec essary to increase weights from 2K lbs to 1 OK + lbs to to make assembly cut @ end of r un. Torque mild @ 2500 - 3500 ft-lbs. Sha kers yielding fine black steel / copper / rub ber & not much. 14:00- 16:00 2.00 FISH TRIP WRKOVR P o o h 16:00-17:00 1.00 FISH OTHR WRKOVR Break off shoe, recover estimated 4 Nova cl amps & 30 + feet of esp cable. Junk basket s full, 1.5 gallons. 17:00-18:30 1.50 FISH TRIP WRKOVR Rih w/ wash over assembly to include "drago Printed: 2/14/2002 1:24:27 PM i" l a :Report Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 Fr°~:..}?:TO:': ::~t~.' '.::-CO~:: ~iI i:i: :~ : DeSCriptiOn of Operations 2/1/2002 17:00-18:30 1.50 FISH TRIP WRKOVR n tooth sub. Tag up @ 3024'. 18:30-22:00 3.50 FISH WASH WRKOVR Wash over fish from 3024 to 3029'. Slow en tire way. Torque in the 3500 - 4500 ft-lb r ange, not definitive [to pump pressure or we ight on shoe]. 22:00-23:30 1.50 FISH TRIP WRKOVR:Pooh, incomplete @ rpt time. 2/2/2002 00:00-02:30 2.50 FISH TRIP WRKOVR Complete Tih to tag @ 3029' [previous td = same]. 02:30-05:00 2.50 FISH WASH WRKOVR Wash over fish from 3029 - 3035', no progre ss last hr. 05:00 - 06:30 1.50 FISH TRIP WRKOVR P o o h 06:30-08:00 1.50 FISH OTHR WRKOVR Recover 60 lbs asp cable & Nova clamps ma ngled & compressed together by milling act on W/ a 1.5' X 3.875' CENTER CORE. Ju nk baskets full. Noted that recover was s hort of 1st dragon tooth. 08:00-09:30 1.50 FISH TRIP WRKOVR Rih w/ washing assembly to tag debris @ 30 34' [previous td 3035']. 09:30-15:00 5.50 FISH WASH WRKOVR Work pipe to insure over 3.5' stick up. Wor k over 3.5' cut off to 3050', based on the 1. 5' core on the previous run this will place t he shoe several inches above the "Y' block. During washing eps picked up several time s to 25k lbs over to engage debris well. 15:00-16:00 1.00 FISH CIRC WRKOVR Pump hi viscosity {120 sec +} 8.7 ppg 30 bb I pill. Some minor increase in material @ s haker. 16:00-17:30 1.50 FISH TRIP WRKOVR Pooh w/ wash string. Rotate slowly off 3.5' stem. Very little drag / wt increase on trip out. 17:30-19:00 1.50 FISH OTHR WRKOVR Recover 6' of mangeled debris [50 lbs] from wash pipe, lower dragon teeth were engaged , debris exibited a ? 3.8' core through the recovery. Bottom piece of debris was the in tact "Sentry Gage" clamp which sits on top of the 'Y" block. 19:00-20:30 1.50 FISH TRIP WRKOVR Rih w/ wash pipe assembly, did not run "Dr agon' tooth sub. 20:30-22:30 2.00 FISH WASH WRKOVR Precautionary wash ream over fish: Anticip ate & tag top of 3.5" as per tally, rotate eve r same & 3 '. Wash to bottom of 3049'+. 22:30-00:00 1.50 FISH ClRC WRKOVR Cir condition one bottoms, pump 30 bbl hi vi s sweep, continue to circulate sweep down [ sweep - circulation incomplete @ rpt time]. 2/3/2002 00:00-00:30 0.50 FISH ClRC WRKOVR Complete cir 30 bbl hi vis sweep, continue to circulate sweep down for bottoms up + on e additional bottoms up. Set down 5k lbs du ring eps, fish did not move. Very little mat ariel to surface. 00:30-03:00 2.50 Pooh, Id tools not required for grapple run, clean out wash over string, recovering some minor material from lower junk basket. Printed: 2/14/2002 1:24:27PM i!iii:: ii i:- ti0ns_!summary RePOrt'. Legal Well Name: 2T-209 Common Well Name: 2T-209 Spud Date: 1/1/1999 Event Name: WORKOVER/RECOMP Start: 1/21/2002 End: 2/10/2002 Contractor Name: NORDIC 3 n1433@ppco.com Rig Release: 2/10/2001 Group: Rig Name: Nordic 3 Rig Number: 3 !":.i'i-:-::Date'.:.i:_:::::: :.-i .i:~:T~.::_~Ui, s:. ::::C~d~i} !i~u~:. _p~S~-" ' ' ' Description of Operations i-:::-:-::::::.-..: ._. :.:.::~:.:--:: .:;...?....._..:.:.:_-..:_ ::: :_: ..... ....~.:.. ..: .::~- :-- :. ..:._: .... :~:.-Code:.: ....... .:.:...-:-.-.":..:.' : .'.:- · 2/3/2002 03:00-05:00 2.00 FISH PULD WRKOVR Completing making up grapple bha assembly Item length 8.125" shoe 2.68 w/ 3.5" id internal dressin g mill xo to wash pipe 1.45 8.125" over shot 1.75 dressed w/ 3.5" baske t grapple 8.125" extension 3.30 8.125" top sub 1.14 Bumper Sub 8.98 Oil jar 11.54 xo 2.67 7 6.25" dc 11.04 xo 1.30 9 4.7 5" dc 279.30 pump out sub 2.12 total 527.27 05:00-06:00 1.00 FISH TRIP WRKOVR Complete rih w/ grapple assmby to tag top o f 3.5' tbg as per tally @ 3034'. Rotate over fish & swallow a total of ?9', 4.5' of 3.5 tb g above grapple. No circulation - fish plugg ed. Fish will move down hole w/ 6k lbs over , pull [smooth] w/ no jarring @ 25k lbs over string. 06:00-07:00 1.00 FISH SFTY WRKOVR Crew change / eps meeting / rig service 07:00-12:00 5.00 FISH PULL WRKOVR Pooh slowly w/ fish, string wet. Dragging 2 0-25k over string. 12:00-15:30 3.50 FISH PULL WRKOVR Break out fish from fishing string. Ld pump & pump assemble. Noted severe corrosion ncreasing w/ depth. 15:30-18:00 2.50 WELLSFtTRIP WRKOVR Make up reversing assemby. Item length Rev Basket 8.5" o d 7.3' 2 jts 5.75' wash Pipe 62.25 top sub 1.87 XO 1 .05 Bit s bv 1.7 Bumper sub 6 .25" 8.98 Oil jar 6.25" I 1 .54 xo's 2.31 Stop sub 1.08 xo 2.03 Cir nt jt 1.48 9 4.75 dc 279.30. otal 350.89 blank sub [w/ disk insta lied] in dp 20 stands from surface. 18:00-20:30 2.50 WELLSFTRIP WRKOVR RIH w/ reversing assembly. Rupture disk fa lied @ 710 stands {900'} in hole. Taged up solid @ 3725', [top of Y block originally · 20:30-21:30 1.00 WELLSFCIRC WRKOVR annular w/ 350 psi closing pressure, start reverse circulation, work down to conn ection @ 3735', string taking no weight. Ru n in to 3745' not circulating when tagged up Start reverse circulating, pressure increa sed gradually to 450 as rate was brought to 6 bpm work down to 3768' when string plug ged off after 6 minutes. Work w/ string - u nable to reverse circulate. Line up & pump out pump out plug @ 320 psi. Printed: 2/14/2002 1:24:27 PM Depth P~ssum