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197-099
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 18-16B PRUDHOE BAY UNIT 18-16B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 18-16B 50-029-21749-02-00 197-099-0 N SPT 8134 1970990 2500 129 2758 2637 2584 0 4 1 2 OTHER P Sully Sullivan 12/1/2025 MIT-TxIA per Sundry #325-451 for future sidetrack. Guy Cook witnessed CMT Tag on 11-25-25 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 18-16B Inspection Date: Tubing OA Packer Depth 129 2754 2634 2581IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS251203191441 BBL Pumped:3.9 BBL Returned:2.6 Friday, January 16, 2026 Page 1 of 1 1-Oil Producer MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:19 Township:11N Range:15E Meridian:Umiat Drilling Rig:Rig Elevation:Total Depth:11370 ft MD Lease No.:ADL0028321 Operator Rep:Suspend:P&A:X Conductor:20"O.D. Shoe@ 119 Feet Csg Cut@ Feet Surface:13 3/8"O.D. Shoe@ 2517 Feet Csg Cut@ Feet Intermediate:9 5/8"O.D. Shoe@ 7824 Feet Csg Cut@ Feet Production:O.D. Shoe@ Feet Csg Cut@ Feet Liner:7"O.D. Shoe@ Feet Csg Cut@ Feet Liner:4.5"O.D. Shoe@ Feet Csg Cut@ Feet Tubing:4.5"O.D. Tail@ 8565 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Perforation Retainer 8540 ft 8001 ft 15.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Tagged top of cement with Pollard Wireline at 7998 ft MD. Tool string was approximately 240 pounds with a 4-foot long drive down bailer fitted with a mule shoe with a flapper valve. Drove the bailer down to 8001 ft MD and came to surface with a cement sample. The sample was good cured cement. No test. October 18, 2025 Guy Cook Well Bore Plug & Abandonment PBU 18-16B Hilcorp North Slope LLC PTD 1970990; Sundry 325-451 None Test Data: Casing Removal: Nathan Williams Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-1018_Plug_Verification_PBU_18-16B_gc 10233, 10483, Unknown By Grace Christianson at 10:20 am, Jul 31, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.07.31 07:44:57 - 08'00' Bo York (1248) 325-451 X A.Dewhurst 11AUG25 AOGCC witness pressure test and tag TOC of both cement plugs. DSR-8/13/25 10-407 JJL 8/5/25 X *&: 8/14/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.14 10:04:35 -08'00' RBDMS JSB 081825 RST Res P&A Sundry Well: 18-16B PTD: 197099 API: 50-029-21749-02 Well Name:18-16B Permit to Drill:197099 Current Status:Producer, Not Operable API Number:50-029-21749-02 Estimated Start Date:8/15/2025 Estimated Duration:6days Regulatory Contact:Carrie Janowski 907-575-7336 First Call Engineer:Dave Bjork 907 440-0331 Second Call Engineer:Jerry Lau 907 360-6233 Current Bottom Hole Pressure:3,400 psi @ 8,800’ TVD (average BHP at DS18) Max. Anticipated Surface Pressure:2,520 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:400 psi Min ID:3.812” @ 2,216’ MD (Camco Bal-O) Max Angle:>70deg at 9,433’MD 98 deg at 10,635’ MD Well History: 18-16 was drilled in Oct 1987 and rotary sidetracked in ’92 and ’98. In 2018 a PC was identified at 6,307ft. An IA cement job was pumped to remedy the leak. Late in 2024 the well failed a TIFL. Subsequent diagnostics indicated another PC leak at 5,220ft and 5,340ft and a tubing leak between 3,000ft to 5,220ft. The PC leaks at 0.5pm at 2,500-psi and the tubing leaks at 0.7bpm at 2,380-psi. We would like to abandon the reservoir section, cement up the production casing and cut the tubing in preparation for a rotary sidetrack with a high kick off point at ~3,000ft. The sidetrack will be the subject of a different sundry. Justification for Reservoir P&A: In 2024, 18-16 was identified as a donor candidate for a CTD sidetrack. Unfortunately, it failed pre rig screening due to multiple PC leaks. A rotary sidetrack with a high kick out will now exploit the target. A reservoir P&A is required in preparation for the Hilcorp Innovation rig to drill a rotary sidetrack. Objectives: The intent of this program is to perform a reservoir P&A of the well per 20 AAC 25.112, isolate the PC leaks and cut TBG in preparation for a rotary sidetrack with planned KOP @ ~3,000’ MD. The original wellbore was drilled in 1987 utilizing a 3 string casing design. The 9-5/8” production casing was sidetracked in the CM1 (7,824’) when the A lateral was drilled. The estimated TOC with 30% washout was calculated at 6,339ft. The 7” drilling liner was fully cemented in ’92 while completing the A sidetrack. The ’98 B sidetrack was milled out of the 7” liner at the top of the Ivishak (8718ft). The subsequent 4-1/2” production liner was fully cemented. Procedure: AOGCC Witness: All AOGCC witnessed operations require a minimum of 24-hour notice to AOGCC inspectors of the timing of the operation so they can be available. RST Res P&A Sundry Well: 18-16B PTD: 197099 API: 50-029-21749-02 Wellhead: 1. PPPOT-T to 5000 psi 2. PPPOT-IC to 3500 psi Slickline: 1. Pull PX plug from 8,543ft. Service Coil: 1. Set one trip cement retainer at 8,540ft. 2. Pump Reservoir Abandonment plug by bullheading cement thru the retainer. TOC is planned at ~7,500’ MD. Bullhead into the reservoir as follows: x 5 bbls MeOH x 10 bbls fresh water x 50 bbls 15.3 class G cement (6.8 bbls excess) x 2 bbls freshwater x After ~ 30bbls thru the retainer, unsting and lay in remaining cement to ~ 7,500ft. x Displace with diesel. x Max pressure 2650 psi Cement Type/weight: Class G 14-15.8 ppg Bottom hole temp: 209°F Fluid Loss: 20-200cc/30 min Thickening Time: Minimum 8 hours Cement Volumes: cap top btm vol size bpf MD' MD bbls Above retainer 4-1/2" 0.0152 7500 8540 15.8 Below retainer 4-1/2" 0.0152 8540 10360 27.4 Excess - - - 6.8 Total ---50.0 Fullbore 1. WOC 3 days, MIT-T to 2500 psi target pressure, verify leak rate is similar to prior MIT-T 0.7bpm at 2,380-psi Slickline 1. Drift and tag to TOC –AOGCC Witnessed. Eline: 1. Punch 4-1/2” tubing at ~5,000ft. A. Apply 1,000 psi to 4-1/2” prior to punching, record before/after pressures. B. Circulate ~ 20bbls to verify punches are successful. Note any pressure changes. RST Res P&A Sundry Well: 18-16B PTD: 197099 API: 50-029-21749-02 Service Coil: 1. Set onetrip cement retainer at 4,980’. 2. Pump Abandonment plug, TOC is planned at ~3,500’ MD in tubing and IA. x 5 bbls MeOH x 10 bbls fresh water x 110 bbls 15.3 class G cement (6.9 bbls excess) x 2 bbls freshwater x After 80bbls thru the retainer, unsting and lay in cement plug to 3,500’. x Displace with diesel. x Max pressure 2650 psi Cement Type/weight: Class G 14-15.8 ppg Bottom hole temp: 145°F Fluid Loss: 20-200cc/30 min Thickening Time: Minimum 8 hours Cement Volumes: cap top btm vol size bpf MD' MD bbls 4-1/2" 0.0152 3,500 5,000 22.8 4-1/2” annulus 0.0535 3,500 5,000 80.3 Total -- -103.1 Displacement: cap top btm vol size bpf MD' MD bbls 4-1/2" 0.0152 0 3500 53.2 A. Wait 3 days and pressure Test TxIA to 2,500 psi for 5 minutes.AOGCC Witnessed. E-Line: 2. Jet Cut 4.5” tubing @ ~3,200’. Adjust depth to cut 2’ below a tubing collar. A. Use cutter rated for 4.5”, 12.6, L-80 tubing. Fullbore: 3. Circout 1.5 wellbore volumes with 8.6ppg 2%KCl with soap pill. Freeze protect to 2,000ft TxIA RST Res P&A Sundry Well: 18-16B PTD: 197099 API: 50-029-21749-02 Current Wellbore Schematic RST Res P&A Sundry Well: 18-16B PTD: 197099 API: 50-029-21749-02 Proposed Reservoir P&A with TBG cut, TBG punch, and cement detail included RST Res P&A Sundry Well: 18-16B PTD: 197099 API: 50-029-21749-02 Casing and Liner Tallies RST Res P&A Sundry Well: 18-16B PTD: 197099 API: 50-029-21749-02 RST Res P&A Sundry Well: 18-16B PTD: 197099 API: 50-029-21749-02 RST Res P&A Sundry Well: 18-16B PTD: 197099 API: 50-029-21749-02 RST Res P&A Sundry Well: 18-16B PTD: 197099 API: 50-029-21749-02 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Operations Manager Date Operations Engineer Date Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer PBU 18-16B A.Dewhurst 11AUG25 325-451197-099 A.Dewhurst 11AUG25 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, April 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 18-16B PRUDHOE BAY UNIT 18-16B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/17/2023 18-16B 50-029-21749-02-00 197-099-0 N SPT1970990 2300 2189 2525 2455 2420 0 0 0 0 OTHER P Adam Earl 3/3/2023 MIT-T tested as per CO 736 to 2300psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 18-16B Inspection Date: Tubing OA Packer Depth 61 90 127 139IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230306132923 BBL Pumped:0.3 BBL Returned:1.3 Monday, April 17, 2023 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9 2RLOSURGXFHU ,$UHPHGLDOFHPHQW MIT-T CO 736 James B. Regg Digitally signed by James B. Regg Date: 2023.04.17 15:40:18 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, April 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 18-16B PRUDHOE BAY UNIT 18-16B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/17/2023 18-16B 50-029-21749-02-00 197-099-0 N SPT1970990 2300 24 2550 2454 2410 0 0 0 0 OTHER P Adam Earl 3/3/2023 CMIT-Tubing and IA tested as per CO 736 to 2300psi cemented IA @5490' 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 18-16B Inspection Date: Tubing OA Packer Depth 0 2508 2410 2367IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230306132758 BBL Pumped:6.2 BBL Returned:3.5 Monday, April 17, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 999 9 2LO3URGXFHU ,$UHPHGLDOFHPHQW 9 9 CMIT-Tubing and IA CO 736 James B. Regg Digitally signed by James B. Regg Date: 2023.04.17 15:37:41 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Austin McLeod Petroleum Inspector Well Name PRUDHOE BAY UNIT 18-16B Insp Num: mitSAM210306065320 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, March 16, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 18-168 PRUDHOE BAY UNIT 18-16B Src: Inspector Reviewed B P.I. Sup" Comm API Well Number 50-029-21749-02-00 Inspector Name: Austin Mcleod Permit Number: 197-099-0 Inspection Date: 3/5/2021 Tuesday, March 16, 2021 pa -e I of Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 18-16B - Type lnJ I N -TVD 8215 - Tubing 994 2758 -'i 1681' 2645-� PTD 1970990 Type Test SPT Test psi 2500 - IA 994 2763 2685 - 2648 BBL Pumped: 1 43 $BL Returned: 4 OA o 0 0 0 Interval OTHER PIF 1 P Notes: Producer. Combo MITT -IA to 2500 per Sundry 318-468. Plug in tubing TVD -8160; TOC TVD in IA -5388' Tuesday, March 16, 2021 pa -e I of MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, March 16, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 18-16B PRUDHOE BAY UNIT 18-16B Sre: Inspector Reviewed By: P.L Suprym�n Comm Well Name PRUDHOE BAY UNIT 18-16B API Well Number 50-029-21749-02-00 Inspector Name: Austin McLeod Insp Num: mitSAM210306063705 Permit Number: 197-099-0 Inspection Date: 315/2021 Rel Insp Num: Notes: Producer. MITT to 2500 per Sundry 318-468. Plug in tubing TVD -8160`, TOC TVD in IA -5388' k)a( ti tic I �q1 A plz�111.ICe- Tuesday, March 16, 2021 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 18-16B ''Type Inj N -TVD 8215 Tubing 1042 2749 268T-1092 649 2622 PTD 1970990 ''Type Test SPT ,Test psi 2500 IA 1047 1097 109 - 1089BBL Pumped: 15 1BBL Returned: 1 5 - OA o0 0 _ Interval OTHER P/F P Notes: Producer. MITT to 2500 per Sundry 318-468. Plug in tubing TVD -8160`, TOC TVD in IA -5388' k)a( ti tic I �q1 A plz�111.ICe- Tuesday, March 16, 2021 Page I of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL nPFRATInlil 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown- ❑ Suspend ❑ Perforate 21 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Set Straddle Packers 21 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work 1 Development 0 Exploratory ❑ 5. Permit to DnII Number: 197-099 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 6. API Number: 50-029-21749-02-00 7. Property Designation (Lease Number): ADL 0283218. Well Name and Number: PBU 18-16B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 11370 feet Plugs measured 10499 feet true vertical 8680 feet Junk measured—_T0233 10483 feet Effective Depth: measured 10499 feet Packer measured 8510 feet true vertical 8654 feet Packer true vertical 8134 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 39-119 39-119 1530 520 Surface 2478 13-3/8" 39-2517 39-2517 3450/5380 1950/2670 Intermediate 7789 9-5/8" 36-7824 36-7539 6870 4760 Liner 1073 7" 7646-8719 7370-8298 7240 5410 Liner 2805 4-1/7' 8560-11365 8175-8680 8430 7500 Perforation Depth: Measured depth: 8600-11240 feet True vertical depth: 8206-8674 feet Tubing (size, grade, measured and true vertical depth) 4-1/2' 12.6# L-80 34-8565 34-8179 Packers and SSSV (type, measured and 4-1/7' Baker S-3 Perm Packer 8510 8134 true vertical depth) No SSSV Insstalled 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: 118 0 403 1017 397 Subsequent to operation: 290 4951 729 0 491 14. Attachments: (required per20 MC 25070.25.071, s 25.2113) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development m Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil RI Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ 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: N/A Authorized Name: Oestgaard, Finn Contact Name: Oestgaartl Finn Authorized Title: Production Engineer C allenger Contact Email: Finn.Oestgaard0bp.com Authorized Signature: o Date: W Z i'lCj Contact Phone: +1 907 564 5026 Form 10-404 Revised 04/2017 (� //� 1BDMS W,1-4cT 0 7 2019 Submit Original Only Daily Report of Well Operations PBU 18-16B ACTIVITYFATF ***WELL S/I UPON ARRIVAL*** (profile modification) PULLED 4 1/2" DREAM CATCHER FROM 8,761' MD (small pieces of debris) RAN 30' DUMMY PATCH DRIFT (3.70" max od) TO 9,351' SLM 7/14/2019 ***WELL S/I ON DEPARTURE*** ***CONT WSR FROM 8/11/19*** (profile modification) DRIFT W/ 3.86" GAUGE RING TO SVLN @ 2,216' MD LRS LOADED TUBING W/ 175bbls CRUDE SET 4 1/2" DB -P SSSV PLUG @ 2,216' MD LRS CURRENTLY TESTING PLUG 8/12/2019 ***CONT WSR ON 8/13/19*** ***CONT WSR FROM 8/12/19*** (profile modification) LRS PERFORMED PASSING PRESSURE TEST ON TUBING TO 2609psi (see Irs log for details) 8/13/2019 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** ****WELL SHUT IN ON ARRIVAL**** (Post Tree C/O) PULLED 4-1/2" DBP PLUG FRMO SVLN @ 2,216' MD 8/26/2019 ***WELL LEFTSHUT IN, DSO NOTIFIED*** ""*WELL SHUT IN ON ARRIVAL*** T/I/0= 2000/150/0 PERFORATE INTERVAL=8600'-8605' WITH 5'2906 POWERJET OMEGA, CCL TO _DEP T=8596.5. RIH WITH BAKER 10 SETTING TOOL/ 45 FLOGAURD STRADDLE PACKER OAL=10.6', MIN I D=2.45". 45 FLOGAURD STRADDLE PACKER SET DEPTH=8624' ME,TOP OF PACKER @ 8620' MD. CCL STOP DEPTH=8612.8, CCL TO TOPSHOT=11.2'. 9/10/2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** ***WELL S/I ON ARRIVAL*** (Profile Mod) SET 4-1/2" UPPER 45 FLO-GUARD PACKER, NS BLAST JOINT, SLCMD (open), 2.313" BX PROFILE W/ RIF CE IN T INSTAL X 0.188") 8619' SLM (top of patch at 859 ') SET 4-1/2" X -LOCK W/ DREAM C TCHE 9/13/2019 ***CONT. ON 09/14/19 WSR*** ***CONT. FROM 09/13/19 WSR*** (Profile Mod) RAN 4-1/2" CHECK SET TO DREAM CATCHER @ 8543' MD ... CONFIRMED GOOD SET 9/14/2019 ***JOB COMPLETE, WELL LEFT S/I*** TREE = 4-1/16' FMC 1928' KOP = WELLHEAD = ACTUATOR= FMC OTIS 18-16 FORT OKB. ELEV = 55' 55' 3020 3020 REF ELEV = WAS - BF. ELEV = 1928' KOP = 3600' M=A k= 98' @ 1063V 20• CONDUCTOR -101 91.5#, H40, D= 19.124' rL 757 Daum TVD = 8800' SS 13-3/8" CSG, 251T 72#, L-80, D = 12.347" 141/2- CAMCO BA L -O SSSV N. D = 3.812' "OC LOGGED w/SCMT ON r_AA r F Ment PQ ST MD TVD DEV TYFE VLV LATCH FORT DATE 1 3020 3020 1 MdGM DOME Po( 16 03/05/19 2 5265 5184 21 %r M SO RK 20 8666' 4-12' WLEG, D = 3.958' TOP OF BKR TIEBACK SLV, D = 5250' 8660' 7219 6969 22 M G -M DMY RK 0 [03=/05/1913 0/07/034 45 KB FLOGUARD STRADDLE PKR, ID =2.45' (09/10119) $624• 8359 8013 35 KBG2-LSEM'TY 0311198 - - 30/19 Minimum ID = 1.25" @ 8613' REV BY COMMENTS DATE 10490' 45 KB PK /646' 70POF BKR7EBACK SLV, D=7.50' ORIGINAL COMPLETION ORIFICE INSERT SET INSLCMD D = 2.38' 1011492 SIDETRACK 18-1 7663' 958'X7 BKR LNRFKRD=6.218' FSH: G FISHING NECK 10483• 0311398 REF 7658' 9-5/8' X 7• BKR LNR HGR, D = 6.250' 9-5/8" CSG, 47#, L -BO, D = 8.681' 7824' 03107/19 RCB/JMD SET DREAMCATCHER 03/06/1 9-518' MLLOUT WINDOW (18-16A) 7824' - 7841' TS/JMD SETSTRDLPKR/SLDSLEEVEIDREAMCATCHE 8610' 7' X 4-1/2' BKR S3 PKR, D = 3.875' MWJMD UPDATED TOC wSCMT ON 02/18/19 8643' 4-12• HES X NP, D = 3.813' P137D 11278' 8543' 4-12'_DREAMCATCHER (09113/19) SIZE 8666' 4-12' WLEG, D = 3.958' TOP OF BKR TIEBACK SLV, D = 5250' 8660' 8666' 7' X 4-1/2' BKR ZXP PKR D = 4438- 4-1/2' TBG, 12.6#, L-80,.0152 bpf, D = 3_958;7 8664' 8674' 7' X 4-112-BKR HMC HGR, D = 4.371 45 FLOWGUARD UPPER STRADDLE PKR (09113/19) 8692' 6 2.313'BX PROFILE wl SLCMD,D=1.25'(OPEN) 8613' O 7- MLLOUT WINDOW (18-16B) 8719' - 8731' 45 KB FLOGUARD STRADDLE PKR, ID =2.45' (09/10119) $624• 8761' 4-112• HES X NP. D = 3.813• ra FSH: ID = 6.276' D = 3.813' AS JT (291 DATE REV BY COMMENTS DATE 10490' 45 KB PK 10101187 ORIGINAL COMPLETION 08/20/19 D = 2.38' 1011492 SIDETRACK 18-1 PERFORATION SUMMARY FSH: G FISHING NECK 10483• 0311398 REF LOG: SPERRYSUN GRIRESST VrrYON 03/08/98 (05/17/14) 03107/19 RCB/JMD SET DREAMCATCHER 03/06/1 ANGLE AT TOP PERF: 38'@ 8600' TS/JMD SETSTRDLPKR/SLDSLEEVEIDREAMCATCHE w, MWJMD UPDATED TOC wSCMT ON 02/18/19 Note: Refer to Production DB for historical perf data P137D 11278' MTHIJMD PULLED DREAMCATCHER 07/14/19 SIZE I SPF INTERVAL I OprVSqz SHOT SQZ 2-718' 6 8600-8605 O 09/10/19 2-314' 4 9590-9800 O 0311198 2-3/4' 4 9820-10090 O 03/11/98 4-1/2' LNR 12.69, L-80, .0152 bpf, 1 = 3.958' 11366' 2-7/8' 6 10090-10360 O 05/03/99 2-314' 4 10625 -11010 C 03/11/98 23/4' 4 11025 -11075 C 03/11/98 2-7/8' 6 11110-11240 C 05/03/99 DATE REV BY COMMENTS DATE REV BY COMMENTS 10101187 ORIGINAL COMPLETION 08/20/19 JB/JMD SETDB-P SSSV PLUG 08/12/19) 1011492 SIDETRACK 18-1 08/28/19 LLG/JMD PULLED DB -P SSSV PLUG 7/19 0311398 SIDETRACK (18-16B) 10/02/19 NXW/JMD SETFLOGUARD PKR &ADPERFS 03107/19 RCB/JMD SET DREAMCATCHER 03/06/1 I 10/02/19 TS/JMD SETSTRDLPKR/SLDSLEEVEIDREAMCATCHE 0327/19 MWJMD UPDATED TOC wSCMT ON 02/18/19 07/16/19 MTHIJMD PULLED DREAMCATCHER 07/14/19 PLUG PRUDHOE BAY UNIT WELL 18-168 PERMIT No: 1970990 API No: 50-029-21749-02 t SEC 19, T11N, R15E, 69TSNL&281' BP Exploration (Alaska) rs��,cevCu STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAR 2 8 ?074 1. Operations Performed Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations y� of %� Plugs Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Appprroved Program ❑ 8680 Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: IA Cement Squeeze 0 2. Operator Name: SP Exploration (Alaska), Inc 4, Well Class Before Work feet 5. Permit to Drill Number 197-099 3. Address: P.O. Box 196612 Anchorage, Development 0 Exploratory ❑ 8654 feet Packer AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-21749-02-00 7. Property Designation (Lease Number). ADL 028321 8. Well Name and Number: PBU 18-16B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Total Depth: measured 11370 feet Plugs measured 10499 feet true vertical 8680 feet Junk measured 10233, 10483 feet Effective Depth: measured 10499 feet Packer measured 6510 feet true vertical 8654 feet Packer true vertical 8135 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Conductor 80 20" 39-119 39-119 1530 520 Surface 2478 13-3/8" 39-2517 39-2517 3450 / 5380 1950 / 2670 Intermediate 7789 9-5/8" 36-7824 36-7540 6870 4760 Liner 1073 7" 7646-8719 7370-8298 7240 5410 Liner 2805 4-1/2" 8560-11365 8175-8680 8430 7500 Perforation Depth: Measured depth: 9590-11240 feet True vertical depth: 8705-8675 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 34-8565 334-8179 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Penn Packer 8510 8135 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Pump 124 We 15.8 Class G cement into IA through retainer. Shut down pump, unsting, lay in remaining 1.2 bbls cement above retainer. ETOC in tubing = 8255'. ETOC in IA = 5650'. Intervals treated (measured): 5650 - 8379 Treatment descriptions including volumes used and final pressure: 125.2 bbls Class G Cement Final Pressures: OA = 10 psi, IA = 100 psi, Tbq = 0 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 437 2818 721 0 330 Subsequent to operation: No Test Available 100 0 14. Attachments: pewm r20 MC 25.070.25.011, a 25201 Daily Report of Well Operations 0 Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 15. Well Class after work: Exploratory ❑ Development 0 Service ❑ Stratigrephic ❑ 16. Well Status atter work: Oil m Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ 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: 318.468 Authorized Name: Hibbert, Michael Contact Name: Hibbert, Michael Authorized Title: Well lnterventi finer Contact Email: Michael.Hibbert(MBP.com G !i Authorized Signature: \�\\� yam- Date: g/�_j1/16} Contact Phone: +1 907 564 4351 Form 10-404 Revisatl 04/2017r�11�� `7 7 RBDMS�w MAR 2 9 2019 Submit Original Only Daily Report of Well Operations PBU 18-16B ACTIVITYDATE SUMMARY "`WELL S/I ON ARRIVAL"' (Cement squeeze) SET 4-1/2" WHIDDON CATCHER SUB ON 4-1/2" PX PLUG AT 8,543' MD. 1129/2019 "'JOB IN PROGRESS, CONTINUED ON 1/30/19 WSR'" "'CONTINUED FROM 1/29/19 WSR"' (Cement squeeze) PULL INT-DGLV (Extended packing) FROM ST #4 (8,359' MD). PULL RK-DGLV FROM ST #2 & RK-LGLV FROM ST #1. SET RK-DGLV'S AT ST #1 (3,020' MD) & ST #2 (5,265' MD). PULL EMPTY 4-1/2" WHIDDON C -SUB FROM 8,543' MD PULL P -PRONG & 4-1/2" PX PLUG BODY FROM 8,522' SLM / 8,543' MD. DRIFT TO DEVIATION AT 9,420' SLM W/ 2-7/8" x 1 O' DUMMY GUN. RAN PDS 40 ARM CALIPER FROM 9,488' SLM TO SURFACE (Good data). "'WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS"' 1/30/2019 NOTE: STATION #4 LEFT AS AN OPEN POCKET FOR UPCOMING CEMENT SQUEEZE. ***WELL S/I ON ARRIVAL"' (CEMENT SQUEEZE) HES RELAY UNIT #46 INITIAL TWO = 900/0/0. MIRU HES & LRS. LRS PUMPED 175 BBLS OF CRUDE DOWN TBG RUN 1: SET 4-1/2" HES CBP @ 8380' MD MID-ELEMENT(top of plug - 8379' md). LRS ESTABLISH LLR DOWN TXIA - 1.3 GPM (plug holding). RUN 2: SET 4-1/2" HES FAS DRILL SVB @ 8335' MD MID -ELEMENT (top of plug - 8334' md). PERFORM PASSING 5 MIN 1500 PSI PIT ON SVB (retainer holding, no pressure seen on IA). ALL LOGS TIED INTO TUBING TALLY DATED 11 -MARCH -1998. RDMO. WELL LEFT S/I ON DEPARTURE. FINAL TWO = 90010/0. 2/2/2019 "'JOB COMPLETE ON 02 -FEB -2019"' CTU 9 1.75" CT Job Objective Cement IA to repair PC leak IRU. Make up and RIH with HES Fas Drill cement stinger assembly. Roll coil over to diesel and tag retainer at 8329. PT backside of coil to confirm being stung in. Establish circulation with diesel down the coil taking returns from the IA.Pump 124 bbls 15.8 Class G cement into IA through retainer. Shut down pump, unsting, lay in remaining 1.2 bbls cement above retainer. ETOC in tubing = 8255'. ETOC in IA= 5650'.POOH pumping pipe displacement 2/12/2019 "'Job in Proress" CTU 9 1.75" CT "'Continue from 2/12/19'" Job Objective Cement IA to repair PC leak Complete rig down 2/13/2019 ...Complete... ."'WELL SHUT IN ON ARRIVAL"" (Cement Squeeze) DRIFTED W/ 30'x 1-3/4" D.D. BAILER, S/D @ 8,280' SLM (Recovered cement) RAN SLB MEMORY SCMT LOG PER PROGRAM 2/17/2019 ""CONT JOB ON 2/18/19'*** ""CONT. JOB FROM 2/17/19' (Cement squeeze) COMPLETE SLB MEMORY SCMT LOG (Good data) 2/18/2019 ""WELL LEFT S/I & PAD -OP NOTIFIED OF STATUS UPON DEPARTURE"" CTU 9 1.75" 0.156WT HS -90 Objective mill -push cement retainer/composite to KB packer MI U. -MU RIH with 2 7/8" motor and 3.80" 5- bladed junk mill and 3.80" String Mill. Mill retainer and CBP and begin to push downhole. 2/25/2019 ...Continued on WSR 2-26-19... CTU #9 - 1.75" Coil *-Cont from WSR 2-25-19"' Job Objective: Mill retainer and CBP Push CBP to 10248' CTMD (10252' RIH). Unable to push deeper due to obstruction. Detained at 10233'. See log for details. Unable to free tools from 10233'. Paint yellow/red flag at 12230'CTM. Drop 3/4" In-telic disconnect ball. Ball is dissolvalble after-100hrs. Disconnected from tools, POOH with CTC/DBPV/Jars/half the disco. FP coil, surface and well to 2500'. Trim coil, change pack offs and perform chain insp. 2/26/2019 ...Continued on WSR 2-27-19.... Daily Report of Well Operations PBU 18-16B CTU #9 - 1.75" Coil ""Cont. from WSR 2-26-19`" Job Objective: Mill Retainer and CBP Make up Venturi BHA with 3.66" mule shoe and RIH. Venturi from 9400' down to FN at 10215' CTMD. POOH. Venturi was half full of mostly fine shavings, some plug slips/chunks. MU/RIH with fishing bha (accel/wt bars/jar/disco/GS spear). RIH. latch fish, on 5th up jar had it moving north. Very grabby through perfs and approximately at each collar all the way up to lowest XN at 9152', had to work fish through XN at 8761' as well. Once past upper XN it was smooth sailing (see log for details). FP well to 2500' with 60/40. Tag up and confirm fish. Fish was retrieved TJ disco/3.80" string reamer/3.80" 51blade junk mill CAL: 16.54' OAL) Perform Weekly bop test on location. 2/27/2019 ...Continued on WSR 2-28-19... CTU #9 - 1.75" Coil "'"Cont. from WSR 2-27-19"' Job Objective: Mill retainer and CBP Complete weekly BOP test. RDMO CTU. 2/26/2019 "'Job Complete'"" ""'WELL S/I ON ARRIVAL""`(post ctd) DRIFT TO 9,275' SLM W/ 3.80 GUAGE RING & 4-1/2" BRUSH 3/4/2019 ""CONT WSR ON 3/5/19""' '"'CONT WSR FROM 3/4/19'" (cement squeeze) LRS LOADED TUBING W/ 180bbls OF CRUDE SET 4 1/2" PX -PLUG IN X -NIPPLE @ 8,543' MD LRS PERFORMED PASSING MIT -T see Irs Io LRS PERFORMED FAILING CMIT-IA (see Irs log) LRS PERFORMED PASSING STATE WITNESSED CMIT-TxIA& MIT -T see Irs 12 9) SET 4 1/2" WHIDDON ON PX -PLUG @ 8,510' SUM PULLED RK-DGLVS FROM STA#2 @ 5,265' MD & STA#1 @ 3,020' MD SET RK-LGLV IN STA#1 @ 3,020' MD & RK-S/O IN STA#2 @ 5,265' MD PULLED EMPTY 41/2" WHIDDON FROM 8,510' SUM PULLED P -PRONG FROM PX -PLUG @ 8,515' SUM 3/5/2019 "'CONT WSR ON 3/6/19'" '"Continued from 3/4/19'" (LRS Unit 42 - Assist Slickline: Load Tubing, AOGCC CMIT-TxIA, AOGCC MIT -T) Loaded tbg with 180 bbls 10'F crude. Tested prong set with 1.3 bbls crude. Conducted Pressure test using MIT -T guidelines, Tbg lost 90 psi in 1st 15 minutes, and fell below 2500 psi differential with IA 4 minutes into 2nd Segment. Bled IAP down Pre-AOGCC MIT -T to 2698 psi —'*PASS"" per E. Dickerman. (Target of 2500 psi, max applied of 2750 psi) Tbg lost 26 psi in 1st 15 min and lost 13 psi in 2nd 15 for total loss of 39 psi in a 30 minute test. Pumped 0.12 bbls to reach test pressure. Did not bleed back, rolled into next test. Pre-AOGCC CMIT TxIA ""'Inconclusive"" (Target of 2500 psi, max applied of 2750 psi) Pressured up TBG and IA with 8.35 bbls crude. 4th 15 min T/IA lost 10/26 psi. 5th 15 min. T/IA lost 8/22 psi. for a total loss of 18/48 psi. Test showing stabilization. Bled back 1.4 bbls AOGCC CMIT TxIA to 2609 psi ""PASS" (AOGCC Rep Bob Noble) (Target of 2500 psi, max applied of 2750 psi) 4th 15 min Tbg/IA lost 8/21 psi, and Final 15 min T/IA lost 7/19 for a total loss of 15/40 psi in a 30 min. test. (E. Dickerman) Bled back 2.6 bbls. AOGCC MIT -T to 2687 "`PASS"' (AOGCC Rep Bob Noble). (Target of 2500 psi, max applied of 2750 psi) Pumped 0.91 bbls crude to reach test pressure. Tbg lost 57 psi in 1 at 15 and lost 17 psi in 2nd 15 for total loss of 74 psi in a 30 min. test. Bled back —0.9 bbls. Continued to bleed TBG/IA down for SL. IA/OA-OTG. SL in control of well at LRS departure. AFE sign and caution tags hung. 3/5/2019 FWHP-98/99/0 ""'CONT WSR FROM 3/5/19"' (cement squeeze) PULLED 4 1/2" PX -PLUG BODY FROM 8,543' MD SET 4 1/2" DREAM CATCHER IN X -NIPPLE @ 8,761' MD (verified w/ check set) 3/6/2019 ""WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS"' TRSE= 4-1!16" FMC VVELLHEAD= FRC ACTUATOR= OTIS KB. ELEV = 55' BF. ELEV = SHOT KOP= 3600' M1x Angle = 98" @ 10635 Datum ND= WA Oaten TVD = 880(r SS 1 8 — 1G BSAFETY NOTES: WELL SDTRK WELLBORES NOT SHOWN ON DIAGRAM PRE - BELOW MILLOUT WINDOWS. 91.5#, H40, I O 2216' 4-1/2" CAMCO BAL-O SS D = 19.124" J 13-3/8' CSG, 2517' 113 = LSO, 6660' V1 TOC (02/12/19) D- 12.347' GAS LET MOMRLLS Minimum ID = 3.812" @ 2216' 4-1/2" CAMCO BAL-0 SSSVN SHOWN) I 8718' I FISH: MLLEDIFUSHE0 FASDRL CMT RET & CBP (02/26/19) PERFORATION SUMARY REF LOG: SPERRY-SUN GRIRESISMI Y ON 03(08/98 ANGLE AT TOP PERF: 93 @ 9590' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 2-3/4" 4 9590-9800 O 03/11/98 RK 2-3/4" 4 9820-10090 0 03/11/98 5184 2-718" 6 10090 - 10360 O 05/OM9 03/05119 2-314" 4 10625 - 11010 C 03/11/98 DW 2-314" 4 11025-11075 C 03117/98 8359 2-71W 6 11110-11240 C 05!03/99 - NECK ST RU I TVD I DEV I TYPE I VLV I LATCH FORT DATE 1 3020 3020 1 MVIG-M DOME RK 16 03/05119 2 5265 5184 21 NMC+M SO RK 20 03/05119 3 7219 6969 22 MMGM DW RK 0 10/07/03 4 8359 8013 35 KBG2-LS BYPIY - - 01/30/19 7646' HTOPOFBKRTEBACKSLV,D=7.50" 7663' 9-5/8" X 7" BKR LNR PKR D = 6218" 7668' 9-5/8" X 7" BKR LNR HGR ID = 6.250' 9-5/8" MLLOUT VVNOOW (18-16A) 7824'- 7841' I 8610' H 7• X 4-1/2" BKR S-3 PKR ID = 3.875' 8666' H4-1/2• VVLEG,D=3958- SHOWN ) 958" 8666• H7-X4-112•BKRZXPPKR,D=4.438• 6674' 7"x4 -y2" BKR HMC HGR D = 4.375• 7" MLLOUi VVNOOW (18-18B) 8719' - 8731' 8�6� 4-12•HPS X NP. D=3.813' D = 3.958" 14-1/2" HES X NP. D = 3.813" 1 I45 KB PKR (10.25•), D = 2.38' (05/17/14) PLUG PRU]HDE BAY UNIT WELL 18-168 PERT No. 11970990 AR No 50-029-2174302 SEC 19, T11N, R15E, 697' SPL & 281' EWL DATE REV BY I COMVEQIS DATE REV BY COMVENTS 10101187 ORIGINAL COMPLEnON 02/13/19 JTMJM) SET CMr RET&RAN W&TBG CMf 10)14192 SIOEFRACK(18-16A) 03/07/19 lTC1JKU FISH MIJPUSH CMf RET&CBP 03113198 SIDETRACK (18-16B) 03/07/19 RCE/JNU GLV 00 (03105/19) 02107/19 CJWJM) PULED FA RUG (01/30/19) 03/07/19 RCB1JM) SET OREAMOATCHHR(03/06/19) 02/07/19 MS/JKU SET CMT RET&CBP(02((12119) BP Exploration (Alaska) 02/07/19 CJPYJM) GLV CIO (01IM19) Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: iI AOGCC \ ATTN: Natural Resources Technician It Alaska Oil & Gas Conservation Commision .+ 333 W. 7th Ave, Suite 100 > Anchorage, AK 99501 197099 30452 TRANSMITTALDATE14-Mar-19 TRANSMITTAL # 74Mar19JW02 WELL NAME API # SERVICE ORDER # FIELD NAMEPRUDHOE BAY PRUDHOE BAY SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPES COLOR DATE LOGGED PRINTS CDs PRUDHOE BAY nt Nanri f lI Signature return via courier or sign/scan and email a copy Date Schlumberger and BP Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Auditor - MEMORANDUM ITO: Jim Regg i< e93 2t 1 L9 P.I. Supervisor FROM: Bob Noble Petroleum Inspector Section: 19 Drilling Rig: Operator Rep: Township: Rig Elevation: Eric Dickerman Casing/Tubing Data (depths ai Conductor: 20" - O.D. Shoe@ Surface: 13 3/8" " O.D. Shoe@ Intermediate: 9 5/8" - O.D. Shoe@ Production: Cut@ O.D. Shoe@ Liner: 7" x 4 1/2" O.D. Shoe@ Tubing: 41/2" O.D. Tail@ Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 5, 2019 SUBJECT: Plug Verification - IA Squeeze PBU 18-16B BPXA PTD 1970990; Sundry 318-468 11N Range: 15E Meridian: Umiat NA Total Depth: 11370 ft MD Lease No.: Suspend: NA P&A: NA 119 Feet 2517 Feet 7824 Feet Csg Feet 11365 Feet 8565 Feet MITT Initial 15 min 30 min 45 min Result Tubing 2761 2704 2687 Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet MITT Initial 15 min 30 min 45 min Result Tubing 2761 2704 2687 Initial IA 1550 1558 1557 - TE P OA 0 0 0 Tubing CMIT TxIA Initial 15 min 3U min 45 min Tubing 2726 2710, 1 2702 2695 IA 2739 2669 2672 - 2649 OA 0 0 0 0 CMIT cont'd 60 min 75 min 90 min Result Tubing 2687 2680 " IA 2628 2606 P OA 0 0 Remarks: I traveled to PBU 18-16B to witness a MIT -T and a combination MIT TxIA. When I arrived I met with BPXA rep. Eric Dickerman. We went over what we were going to do. Eric told me that they had a tubing tail plug set at 8543 ft MD. These pressure tests were to evaluate the integrity of an inner annulus cement squeeze to repair a leak in the 9 5/8" intermediate casing before ✓ allowing the well to return to production. No details provided about the IA cement squeeze. The CMIT TxIA was held for 75 minutes per BPXA, not Attachments: none rev 11-28-18 2019-0305_Plug_Verification_IA-Squeeze_PBU_18-16B_bn STATE OF ALASKA REC t • AL ,CA OIL AND GAS CONSERVATION COMMISSION • REPORT OF SUNDRY WELL OPERATIONS '( 1 8 2014 1.Operations Abandon❑ Repair WelC Plug Perforations ❑ Perforate❑ Othe 40rice Vit.,/y� pj,)CIPerformed: Alter Casing Pull TubinU Stimulate-Frac LI Waiver❑ Time Extensioi❑ Change Approved Program❑ Operat.Shutdowi❑ Stimulate-Other ❑ Re-enter Suspended Wel] 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: BP Exploration(Alaska),Inc Name: Developmen0 Exploratory❑ 197-099-0 3.Address: P.O.Box 196612 StratigraphiG Service❑ 6.API Number: Anchorage,AK 99519-6612 50-029-21749-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028321 PBU 18-16B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 11370 feet Plugs measured None feet true vertical 8680.34 feet Junk measured 10483 feet Effective Depth measured 11278 feet Packer measured See Attachment feet true vertical 8675.92 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 37-117 37-117 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 7794 9-5/8"47#L-80 35-7829 35-7544.54 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9590 9800 feet 9820-10090 feet 10090-10360 feet 10625-11010 feet 11025 11075 feet 11110-11240 feet True Vertical depth 8704.94-8711.06 feet 8712.56-8714.46 feet 8714.46-8708.68 feet 8699.8-8687.64 feet 8687.92-8686.6 feet 8683.45-8675.07 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 30-8565 30-8179.24 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED JUL 1 0 2014 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 27982 0 0 643 Subsequent to operation: 0 13695 0 0 608 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run ExploratorD Development❑ Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas ❑ WDSP❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP ❑ SPLUC] 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Garry.Catron( BP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564-4424 Date 6/18/2014 7 vi-f- /"" i / RBGMS JUN 19 2016\- 040 6f4e Form 10-404 Revised 10/2012 Submit Original Only • , Packers and SSV's Attachment ADL0028321 SW Name _ Type MD TVD Depscription 18-16B PACKER 7659 7382.49 7" Liner Top Packer 18-16B PACKER 8510 8135.19 4-1/2" Baker S-3 Perm Packer 18-16B _ PACKER 8566 8180.03 4-1/2" Baker ZXP Packer 18-16B PACKER 10490 8708.74 2-7/8" Baker KB Packer • w � CD T- o CD N- o Ns v cn o) CD Ir) C LO Ns T- N Ns -) • T-- (DNsO0OMTr0000 • N Is- o) NI- LO N- O CO N r rl• • O• OCDo) Nt CD CO T- O N CO O '- 1- 0000 N00 0 O C) N Ns 01 Ul 001 0Ni vi 07 Ns M M � Is- CO CDC) N- In N M OIO Ul Ns CO N CO 03 ,t a 1 1 1 1 1 1 1 � N Q c0 N � n � rncno ON ch ch ChD r) I- r) co = � 1-- O O O O w C) o ao �n ao O N Z (5OD NCNI .N N O N U) � _ 8 = - 0Q - corn V - M N 6 h- TT Ch M TT Nr t C 00 N- O 00 V, O J Ps s- N NCO W os OC 0 C W W W 0 0 Ce uZ Z W W W ce • Z Z O _.iC/) C/) F- I \ o 00 E I - ® 2 [ c o I k 2 ® 2 7 ? � / - \ � o � ) 6 / f % 7 / : 3 � e O I ±2 ® ° '- � � 0 © • k Ta- u) % \ � E2 � a k / •e E a ? \ / 0 0 2 9 2 0_2 / 2 a c \ r % k \ 2 0 o L 7 » o - \ 2 b 0) » -0 2 / / cl co � 2 c a / / - ƒ a / °Tzt a / / m / S C• - co CD E \ � kk .E = Ac a 2 3 2 2 $ $ \ 0)- - Z o a) 0200 aI / ƒ < x :17, » 'e 5 m / E 2 I sv C / N E \ % ƒ 0 / $ o o m Er) ) + ® - O• _ 0 -C1 S » ? 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FMC 18-16 B SAF. ,TOTES:WELL ANGLE>70"@ 9433'"'PRE- W� AC,Zt�ATOR= OTS SDTRK WELLBORES NOT SHOWN ON DIAGRAM ��_ BELOW MILLOUT WINDOWS. KB.BF.E LEEV= KOP= 3600' Max Angle= )8 oft 10635' Datum MD= NA ( 2216' H4-1/2"CAMCO BAL-O SSSVN,D=3.812" Datum ND= 8800'SS ` GAS LET IM 13-3/8"CSG,72#,L-80,D=12.34r H 2517' 'lkST MD ND DEV TYPE VLV LATCH PDRT DATE - 1 3020 3020 1 MMG-M DOME RK 16 06/10/08 2 5265 5184 21 MMG-M SO RK 20 06/10/08 3 7219 6969 22 MMGM DW RK 0 10/07/03 Minimum ID =3.812" 2216' 4 8359 8013 35 KBG2-LS DMY NT 0 10/07/03 4-1/2" CAMCO BAL-0 SSSVN l 7646' H TOP OF BKR TEBACK SLV,D=7.50" q Fr 7653' H9-5/8"X 7"BKR LNR PKR,D=6218" 7658' H9-5/8"X 7"BKR UR HGR,D=6.250" 9-5/8"CSG,47#,L-80,D=8.681" H 7824' 9-5/8"MLLOUT WINDOW (18-18A)7824'-7841' ;�--I 8610' H7"X 4-1/2"BKR S-3 PKR,D=3.875" 44% ` 8543' H4-112"HES X NP,D=3.813" 8565' H4-1l2" YVLEG,D=3.958' I TOP OF BKR TIEBACK SLV,D=5.250" —I_ 8560' Nt 8566' H7"X 4-1/2"BKR ZXP PKR,D=4.438' 4-1/2"TBG, 12.6#,L-80,.0152 bpf,D=3.958" —i 8564' $ 8574' 7"X 4-1/2"BKR HMC HGR,D=4.375" 7"LNR,26#,NT-80S,0.383 bpf, 13=6.276" 7"MLLOUT Wf'DOW(18-168)8719'-8731' TOP OF 7"BKR WHPSTOCK(NOT SHOWN) H 8718' 8761' H4-1/2'HES X NP,D=3.813" —I 9152 H4-1/2"I-ES X NP,0=3.813' 10232 4-1/2"MLAS JT(29') • a , 10490' 145 KB PKR(10.25'), PE32FOFtAT10N SUMMARI' =2.38"(05/17/14) F�LOG: SPERRY-SU N GR/RESSTNfTY ON 03/08/98 FISH:G FISHNG NECK — 10483' ,y,�� D ANGLE ATTOP FERF: 93 a+9590' (05/17/14) * 10499' —2-7/8"X NIP, Note:Refer to Production DB for historical pert data 5 w I PLUG SIZE SPF INTERVAL Opn/Sqz SHOT SOZ • • 2-3/4" 4 9590-9800 0 03/11/98 /. 2-3/4" 4 9820- 10090 0 03/11/98 PB113 H. 11278' W 2-7/8" 6 10090-10360 0 05/03/99 2-3/4" 4 10625-11010 C 03/11/98 4-1/2"LM,12.6#,L-80,.0152 bpf,0=3.958" H 11365' 2-3/4" 4 11025-11075 C 03/11/98 2-7/8" 6 11110- 11240 C 05/03/99 DATE REV BY COMuENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/01/87 ORIGINAL COMPLETION 03/29/12 PJC DRAWING CORRECTIONS WELL: 18-16B 10/14/92 SIDETRACK(18-16A) 05/20/14 CJS/PJC SE KB FKR ASSY (05/17/14) WRIST No:'1970990 03/13/98 SIDETRACK (18-16B) AR No: 50-029-21749-02 01/18/07 CJN/PAG GLV C/O SEC 19,T11N,R15E,697'SNL&281'EWL 06/24/07 KSB/PJC GLV C/O 06/25/08 KSB/PJC GLV CIO(06/10/08) BP Exploration(Alaska) Well Jo # LOR escnptlOn ate alar W-25 10980555 RST(REDO) 05/02/05 1 N··07A 11296715 RST 09/11/06 1 1 F-06A 11258688 RST 03/03/06 1 1 18-16B 11588702 MCNL 12/27/06 1 1 06-09 11320999 RST 08/02/06 1 1 X-15A 10928631 MCNL 05/11/05 1 1 06-09 11223132 RST 08/02/06 1 1 3-17F/K-30 10728392 MCNL 03/12/04 1 1 SChlUlÙupgeP Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, At{ 99503-2838 ATTN: Beth b 04/05/07 SCANNED APR 1 () 2007 NO. 4210 1l11- -cAq t!- Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 '4~~+ Field: Prudhoe Bay D D BL C CD . . PLEASE ACKI~OWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: ~ RECEIVED Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 A""""". AK '''''U ATTN: Beth ê. Received by:, Î'--_ APR 0 (3 7007 /\lasM Oil & Gas Cons, Cornm\ssíon AnçhOfagE~ THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03,2001 M PL ATE IA L U N D W E R ~ H IS M ARK E R C:LORIkMFILM.DOC Well Compliance Report File on Left side of folder 197-099-0 MD 11370 TYD 08680 pRUDHoE BAYMiT i82i'6B 5°~'029~2i749]02 ~CO ~ompletionDate: 3/13/98 Completed Status: 1-OIL Cnrrent: T Name Interval D 8446..~~''''~ 2-4 -~ SPERRY MPT/GR/EWR4 -,/- L NGP/DGR/EWR4-MD ~5;~AL 8635-11370 L NGP/DGR/EWR4-TVD ~Z/~AL 8322-8685 R DIR SRVY ~Y 8647.78-11370. Daily Well Ops fl~/~oZ ~ .3f/J/c4r2 Was the well cored? yes ~_.~ Sent Received T/C/D OH 5/20/98 5/28/98 OH 5/28/98 5/28/98 OH 5/28/98 5/28/98 OH 4/15/98 4/22/98 Are Dry Ditch Samples Required? yes (~..And Received? Analysis Description Receiv, gf!2__y, as-.n~,.-~ Comments: Tuesday, April 04, 2000 Page 1 of 1 STATE OF ALASKA '- " ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operators performed: Operation shutdown _ Stimulate_ Plugging_ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 55 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 695' FNL, 4670' FEL, Sec. 19, T11 N, R15E, UM 18-16B At top of productive interval 9. Permit number / approval number 222' FNL, 2725' FWL, Sec. 19, TllN, R15E, UM 97-99 At effective depth 10. APl number 50-029-21749-02 At total depth 11. Field / Pool 4652' FNL, 612' FEL, Sec. 18, T11N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 11370 feet Plugs (measured) PBTD tagged @ 11272 (5/03/1999) true vertical 8680 feet Effective depth: measured 11272 feet Junk (measured) true vertical 8676 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 109' 20" 168o Sx Poleset 109' 109' Surface 2462' 13-3/8" 2500 sx cs m & 600 sx cs ~ 2517' 2517' Production 7769' 9-5/8" 70o sx C~ass G & 30O Sx CS ~ 7824' 7540' Liner 1073' 7" 444 Sx Class G 8719' 8298' Liner 2806' 4-1/2" 375 Sx C~ass G 11365' 8680' Perforation depth: measured 9590'- 9800'; 9820'- 10360'; 10625'- 11010'; 11025'- 11075'; 11110'- 11240'. true vertical 8705' - 8711'; 8712' - 8709'; 8700' - 8688'; 8688' - 8687'. 8683' - 8675'. ,j ~] ,i._ ,..~ Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 8565' MD. /~,I~qSi(~ 0JJ & GaS Co~(~, Anchorage Packers & SSSV (type & measured depth) 7" X 4-1/2" BAKER S-3 PACKER @ 8511' MD; 7" X 4-1/2" BAKER ZXP LINER TOP PACKER @ 8567' MD. 4-1/2" CAMCO BAL-O SSSV @ 2217' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached)0RIpolNAL Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 912 18168 0 1151 Subsequent to operation 928 19812 123 1180 15. Attachments 16. Status of well classification as: 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. Signed -'~~ ~4~ ~ Title Arco Well Group Supervisor Date "7- 2 oo' - ~' Erin Oba ° Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICAT 18-16B DESCRIPTION OF WORK COMPLETED PERFORATION Date Event Summary 5/02/1999: 5/03/1999: 6/15/1999: 6/26/1999' 7/10/1999: 7/13/1999: 7/22/1999: 7/25/1999: MIRU CTU. PT'd equip. RIH & ran GR-CCL Log. POOH w/logging tools. Fluid packed IA w/KCL. FP w/Crude. Flushed tbg w/KCL Water. Spotted FIo Pro across perfs. RIH w/perf guns & tagged PBTD @ 11272' MD. Shot 400' of Add perforations as follows: 10090' - 10360' MD (Zone 1 B) 11110' - 11240' MD (Zone 1 B) Used 2-7/8" carriers. All shots @ 6 SPF & overbalanced. POOH w/guns. ASF. RD. D&T to 470' MD (paraffin). RIH & performed a Hot Oil Tubing Wash. Jetted Paraffin from tbg & hot oiled IA. 550 bbls Hot Crude. RIH & performed a Hot Oil Tubing Wash. Pumped 100 bbls of 180° F Crude down flowlines. Pumped 60 bbls of hot Crude down tbg & flushed w/Diesel. RIH & performed a Hot Oil Tubing Wash. RIH & performed a Hot Oil Tubing Wash. RIH & performed a Hot Oil Tubing Wash. Pumped 100 bbls hot Crude down tbg & 75 bbls down flowlines. Returned well to production & obtained welltest data. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3 001 Porcupine Dr. Anchorage, Alaska 99501 May28,1998 RE: MWD Formation Evaluation Logs D.S. 18-16B, AK-MM-80141 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' ,Mi Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, .4/42 99518 cl' . o g h D.S. 18-16B: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-21749-02 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-21749-02 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax 907) 563-7252 A Division of Dresser Industries, Inc. WELL LOG TRANSM1TFAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. ~)~¢t~ (~ Anchorage, Alaska 99501 ~. MWD Formation Evaluation Logs - D.S. 18-16B, AK-MM-80141 May20,1998 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, 'Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. ,M>I#: 50-029-21749-02. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Inc. · , STATE OF ALASKA ._ . ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 97-99 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21749-02 4. Locationofwellatsurface!i~ ....... ~ ,:, ! _ - _ -~ 9. UnitorLeaseName 697' SNL, 281' EWL, SEC. 19, TllN, R15E, UM i ~ . . Prudhoe Bay Unit At top of productive interval ! ~',/~:~' i ~IilIBI~II~ [ 10. Well Number 222' SNL, 2725' EWL, SEC. 19, T11 N, R15E, UM i ' '~~ 18-16B 626' NSL, 4334' EWL, SEC. 18, T11N, R15E, UM - . i .~' 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 55.08'I ADL 028321 12. Date Spudded 113. Date T.D. Reached I 14. Date Comp., Susp., or Aband.115. Water depth, if off~hore 116. i~o. of Completions 3/1/98 3/7/98 3/13/98 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11370 8680 FTI 11278 8676 FTI [~Yes F-INoI (Nipple) 2216' MD 1900' (Approx.) '22. Type Electric or Other Logs Run MWD, LWD, GR, RES 23. CASING, LINER AND CEMENTING RECORD U ! I I CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 109' 26" 1680# Poleset 13-3/8" 72# L-80 Surface 2515' 17-1/2" 2500 sx Coldset III, 400 sx Coldset II 9-5/8" 47# L-80 Surface 7824' 12-1/4" 700 sx Class 'G', 300 sx Coldset I 7" 26# NT80S 7646' 8719' 8-1/2" 444 sx Class 'G' 4-1/2" 12.6# L-80 8560' 11365' 6" 375 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 8565' 8510' MD TVD MD TVD 9590' - 9800' 8705' - 8711' 9820' - 10090' 8712' - 8714' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 10625' - 11010' 8700' - 8688' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11025' - 11075' 8688' - 8687' Freeze Protect with 150 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) March 19, 1998 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE IGAS-O~'I~-¢~,~i'(~" TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Zone 3 8862' 8388' Zone 2 8982' 8456' Zone 1 9303' 8632' Base of Sadlerochit 10364' 8709' 31. List of Attachments Summary of Daily Drilling ~ports, S/~p~ys 32. I hereby certify that(th oi nd correct to the best of my knowledge Signed / '1"- ~ / '~d ,~ TimA. Burns ~ ,~'~ \//~k~,~ /-/' I,,' ~ Title Senior Drilling Engineer Date 18-16B '--/ 97-99 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Progress Report Facility PB DS 18 Well 18-16B Rig Doyon # 9 Page 1 Date 02 April 98 Date/Time 24 Feb 98 12:00-12:30 12:30-19:00 19:00-20:30 20:30-21:00 21:00-22:00 22:00-22:30 22:30-02:45 25 Feb 98 02:45-03:00 03:00-04:00 04:00-06:00 06:00-06:05 06:05-06:20 06:20-10:00 10:00-12:00 12:00-12:30 12:30-16:00 16:00-17:00 17:00-18:00 18:00-18:30 18:30-20:30 20:30-20:45 20:45-22:15 22:15-22:45 22:45-23:00 23:00-00:00 26 Feb 98 00:00-00:30 00:30-03:00 03:00-03:30 03:30-06:00 06:00-10:30 10:30-11:00 11:00-11:15 11:15-12:00 12:00-12:30 12:30-13:30 13:30-14:00 14:00-14:15 14:15-14:30 14:30-16:00 16:00-16:30 16:30-19:30 19:30-21:00 21:00-23:00 23:00-00:00 27 Feb 98 00:00-00:30 00:30-03:00 03:00-03:30 03:30-04:00 04:00-04:15 04:15-04:30 04:30-06:00 06:00-06:30 06:30-07:15 07:15-07:30 Duration 1/2 hr 6-1/2 hr 1-1/2 hr 1/2 hr 1 hr 1/2 hr 4-1/4 hr 1/4 hr lhr 2 hr 0 hr 1/4 hr 3-1/2 hr 2 hr 1/2 hr 3-1/2 hr 1 hr 1 hr 1/2 hr 2 hr 1/4 hr 1-1/2 hr 1/2 hr 1/4 hr 1 hr 1/2 hr 2-1/2 hr 1/2 hr 2-1/2 hr 4-1/2 hr 1/2 hr 1/4 hr 3/4 hr 1/2 hr 1 hr 1/2 hr 1/4 hr 1/4 hr 1-1/2 hr 1/2 hr 3 hr 1-1/2 hr 2 hr 1 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1-1/2 hr 1/2 hr 3/4 hr 1/4 hr Activity Held safety meeting Rig moved 100.00 % Fill pits with Seawater Held safety meeting Removed Hanger plug Reverse circulated at 8718.0 ft Circulated at 8718.0 ft Flow check Installed Hanger plug Rigged down Xmas tree Rigged down Xmas tree (cont...) Held safety meeting Installed BOP stack Installed Well control Held safety meeting Tested All functions Retrieved Hanger plug Removed Hanger plug Flow check Rigged up Tubing handling equipment Retrieved Tubing hanger Circulated at 8718.0 ft Circulated at 8718.0 ft Flow check Rigged down Tubing hanger Held safety meeting Laid down 2039.0 ft of Tubing Retrieved SCSSSV nipple assembly Laid down Tubing of 2000.0 ft Laid down 6718.0 ft of Tubing (cont...) Rigged down Tubing handling equipment Installed BOP test plug assembly Rigged up All rams Held safety meeting Rigged up All rams Tested All rams Held safety meeting Rigged up Logging/braided cable equipment Conducted electric cable operations Rigged down Logging/braided cable equipment Made up BHA no. 1 R.I.H. to 4733.0 ft Singled in drill pipe to 6700.0 ft Serviced Block line Held safety meeting Singled in drill pipe to 8637.0 ft Circulated at 8637.0 ft Fished at 8713.0 ft Circulated at 8680.0 ft Functioned Circulating sub Circulated at 8318.0 ft Circulated at 8318.0 ft (cont...) Pulled out of hole to 7267.0 ft Circulated at 7267.0 ft Progress Report Facility PB DS 18 Well 18-16B Rig Doyon # 9 Page 2 Date 02 April 98 Date/Time 28 Feb 98 01 Mar 98 07:30-10:00 10:00-10:30 10:30-11:30 11:30-12:30 12:30-14:00 14:00-14:10 14:10-14:30 14:30-16:00 16:00-16:30 16:30-18:00 18:00-19:30 19:30-20:00 20:00-21:00 21:00-22:30 22:30-23:00 23:00-23:15 23:15-23:30 23:30-04:30 04:30-05:00 05:00-05:30 05:30-05:45 05:45-05:55 05:55-06:00 06:00-06:30 06:30-07:00 07:00-07:15 07:15-07:30 07:30-07:45 07:45-07:50 07:50-07:55 07:55-08:10 08:10-08:25 08:25-09:00 09:00-09:30 09:30-09:45 09:45-10:00 10:00-11:00 11:00-13:00 13:00-13:30 13:30-15:00 15:00-19:00 19:00-21:30 21:30-22:00 22:00-00:30 00:30-01:15 01:15-01:30 01:30-05:00 05:00-06:00 06:00-10:00 10:00-12:00 12:00-13:30 13:30-14:00 14:00-15:30 15:30-17:30 Duration 2-1/2 hr 1/2 hr 1 hr 1 hr 1-1/2 hr 0 hr 1/4 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1 hr 1-1/2 hr 1/2 hr 1/4 hr 1/4 hr 5 hr 1/2 hr 1/2 hr 1/4 hr 0 hr 0 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/4 hr 0 hr 0 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1 hr 2 hr 1/2 hr 1-1/2 hr 4 hr 2-1/2 hr 1/2 hr 2-1/2 hr 3/4 hr 1/4 hr 3-1/2 hr 1 hr 4 hr 2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 2 hr Activity Pulled out of hole to 400.0 ft Pulled BHA Laid down fish Made up BHA no. 2 R.I.H. to 4271.0 ft Held drill (Kick while tripping) Rigged up Drillstring handling equipment R.I.H. to 8656.0 ft Washed to 8743.0 ft Circulated at 8743.0 ft Pulled out of hole to 4721.0 ft Rigged up Drillstring handling equipment Pulled out of hole to 400.0 ft Pulled BHA Serviced Drillfloor / Derrick Held safety meeting Rigged up sub-surface equipment - Cement retainer Ran Drillpipe in stands to 8370.0 ft Singled in drill pipe to 8743.0 ft Functioned Cement retainer Held safety meeting Tested High pressure lines Injectivity test - 5.000 bbl injected at 1200.0 psi Injectivity test - 5.000 bbl injected at 1200.0 psi (cont...) Tested Casing - Via annulus and string Held safety meeting Rigged up High pressure lines Pumped Water spacers - volume 5.000 bbl Mixed and pumped slurry - 5.000 bbl Mixed and pumped slurry - 19.000 bbl Displaced slurry - 64.000 bbl Displaced slurry - 46.000 bbl Displaced slurry - 10.000 bbl Reverse circulated at 8739.0 ft Tested Casing Rigged down High pressure lines Laid down 900.0 ft of 5in OD drill pipe Pulled out of hole to 4337.0 ft Rigged up Drillstring handling equipment Pulled out of hole to 0.0 ft Made up BHA no. 3 R.I.H. to 5729.0 ft Rigged up Handling equipment R.I.H. to 8700.0 ft Took MWD survey at 8620.0 ft Functioned Other sub-surface equipment Milled Liner at 8731.0 ft Drilled to 8740.0 ft Drilled to 8749.0 ft (cont...) Circulated at 8749.0 ft Pulled out of hole to 5730.0 ft Rigged up Drillstring handling equipment Pulled out of hole to 901.0 ft Pulled BHA Facility Date/Time 02 Mar 98 03 Mar 98 04 Mar 98 05 Mar 98 06 Mar 98 07 Mar 98 08 Mar 98 Progress Report PB DS 18 Well 18-16B Page 3 Rig Doyon # 9 Date 02 April 98 17:30-18:30 18:30-20:00 20:00-20:15 20:15-23:00 23:00-00:00 00:00-02:00 02:00-02:30 02:30 06:00-03:15 03:15-04:15 04:15-04:45 04:45-05:30 05:30-05:45 05:45 06:00-09:00 09:00-09:30 09:30-12:30 12:30-13:30 13:30-14:00 14:00-17:30 17:30-18:00 18:00-21:00 21:00-03:30 03:30-04:00 04:00-04:45 04:45-06:00 06:00-06:05 06:05-06:00 06:00-23:00 23:00-01:00 01:00-05:30 05:30-06:00 06:00-11:00 11:00-12:00 12:00-14:30 14:30-22:00 22:00-22:30 22:30-06:00 06:00-16:00 16:00-18:00 18:00-20:00 20:00-21:30 21:30-23:00 23:00-02:30 02:30-06:00 06:00-07:30 07:30-07:45 07:45-10:30 10:30-11:30 11:30-12:30 12:30-13:00 13:00-13:30 13:30-17:00 17:00-22:00 Duration 1 hr 1-1/2 hr 1/4 hr 2-3/4 hr 1 hr 2 hr 1/2 hr 21-1/4 hr 1 hr 1/2 hr 3/4 hr 1/4 hr 3hr 1/2 hr 3 hr 1 hr 1/2 hr 3-1/2 hr 1/2hr 3 hr 6-1/2 hr 1/2 hr 3/4 hr 1-1/4 hr 0 hr 23-3/4 hr 17hr 2 hr 4-1/2 hr 1/2 hr 5 hr 1 hr 2-1/2 hr 7-1/2 hr 1/2 hr 7-1/2 hr 10 hr 2 hr 2 hr 1-1/2 hr 1-1/2 hr 3-1/2 hr 3-1/2 hr 1-1/2 hr 1/4 hr 2-3/4 hr 1 hr 1 hr 1/2 hr 1/2 hr 3-1/2 hr 5 hr Activity Circulated at 25.0 fl Made up BHA no. 4 Functioned Survey instruments R.I.H. to 6600.0 ft Serviced Block line R.I.H. to 8685.0 ft Logged hole with LWD: DIR/FE from 8670.0 fl to 8688.0 fl Drilled to 8920.0 ft Drilled to 9590.0 fl (cont...) Circulated at 9560.0 ft Drilled to 9603.0 ft Circulated at 9603.0 ft Flow check Pulled out of hole to 9300.0 ft Pulled out of hole to 5068.0 fl (cont...) Rigged up Drillstring handling equipment Pulled out of hole to 193.0 ft Pulled BHA Installed BOP test plug assembly Tested All functions Retrieved BOP test plug assembly Made up BHA no. 5 R.I.H. to 8678.0 ft Tested Kelly/top drive hose R.I.H. to 9480.0 ft Reamed to 9480.0 ft Reamed to 9603.0 ft Drilled to 10500.0 ft Drilled to 10964.0 ft Circulated at 10964.0 fl Logged hole with LWD: DIR/DD from 10927.0 ft to 9520.0 ft Pulled out of hole to 9000.0 ft Pulled out of hole to 185.0 ft Pulled BHA Made up BHA no. 6 R.I.H. to 9260.0 ft Logged hole with LWD: DIR/DD from 10954.0 ft to 10964.0 ft Drilled to 11163.0 ft Drilled to 11370.0 ft Circulated at 11370.0 ft Logged hole with LWD: DIR/DD from 11280.0 ft to 10800.0 ft Pulled out of hole to 8731.0 ft R.I.H. to 11370.0 ft Circulated at 11370.0 fl Pulled out of hole to 7000.0 ft Pulled out of hole to 5060.0 ft Rigged up Drillstring handling equipment Pulled out of hole to 161.0 ft Pulled BHA Downloaded MWD tool Pulled BHA Rigged up Casing handling equipment Ran Liner to 2805.0 ft (4-1/2in OD) Ran Tubing to 2690.0 ft (2-7/8in OD) Facility Date/Time 09 Mar 98 10 Mar 98 11 Mar 98 12 Mar 98 13 Mar 98 PB DS 18 Progress Report Well 18-16B Rig Doyon # 9 Duration Activity 22:00-23:30 23:30-02:00 02:00-02:30 02:30-05:30 05:30-06:00 06:00-06:30 06:30-08:30 08:30-11:00 11:00-12:30 12:30-17:00 17:00-21:00 21:00-22:30 22:30-01:30 01:30-04:30 04:30-05:00 05:00-06:00 06:00-08:30 08:30-09:00 09:00-10:00 10:00-01:00 01:00-02:30 02:30-03:00 03:00-06:00 06:00-08:30 08:30-10:00 10:00-13:30 13:30-17:30 17:30-18:30 18:30-19:30 19:30-20:00 20:00-21:00 21:00-06:00 06:00-11:00 11:00-14:00 14:00-15:30 15:30-17:30 17:30-20:30 20:30-00:30 00:30-03:00 03:00-04:00 1-1/2 hr 2-1/2 hr 1/2 hr 3 hr 1/2 hr 1/2 hr 2 hr 2-1/2 hr 1-1/2 hr 4-1/2 hr 4 hr 1-1/2 hr 3 hr 3 hr 1/2 hr 1 hr 2-1/2 hr 1/2 hr 1 hr 15hr 1-1/2 hr 1/2 hr 3 hr 2-1/2 hr 1-1/2 hr 3-1/2 hr 4 hr 1 hr 1 hr 1/2 hr 1 hr 9 hr 5 hr 3 hr 1-1/2 hr 2 hr 3 hr 4 hr 2-1/2 hr 1 hr / Page Date Rigged up Drillstring handling equipment Ran Drillpipe to 2313.0 ft (3-1/2in OD) Rigged up Drillstring handling equipment Ran Drillpipe in stands to 8670.0 ft Circulated at 8670.0 ft Circulated at 8670.0 ft Ran Liner to 11370.0 ft (4-1/2in OD) Circulated at 11370.0 ft Mixed and pumped slurry - 77.000 bbl Circulated at 11220.0 ft Pulled Drillpipe in stands to 5125.0 ft Commissioned Block line Pulled Drillpipe in stands to 2668.0 ft Laid down 1400.0 ft of Tubing Retrieved Wear bushing Tested BOP stack Tested BOP stack Installed Wear bushing Tested Liner Ran Tubing to 1485.0 ft (2-3/4in OD) Perforated Flow check Laid down 1800.0 ft of 5in OD drill pipe Pulled out of hole to 5193.0 ft Pulled Drillpipe in stands to 2783.0 ft Laid down 1245.0 ft of Tubing Laid down 1486.0 ft of Tubing Retrieved Wear bushing Installed BOP stack Tested BOP stack Rigged up Completion string handling equipment Ran Tubing to 6400.0 ft (4-1/2in OD) Ran Tubing to 8559.0 ft (4-1/2in OD) Reverse circulated at 8559.0 ft Set packer at 8509.0 ft with 4000.0 psi Rigged down Completion string handling equipment Rigged down BOP stack Installed Xmas tree Freeze protect well - 150.000 bbl of Diesel Tested Xmas tree 4 02 April 98 sp ,r r -sun 0 F! I I_/I I~J I:~ SEFI~/I I- E S 15-Apr-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 18-16B Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,647.78' MD 8,731.00' MD 11,370.00' MD (if applicable) 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) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company prudhoe Bay Unit Alaska State Plane Zone 4 PBU EOA DS ~8 18-16B SURVEY REPORT April, 1998 Your Ref: API-500292174902 JOB Number- AKMMS0141 Last Day of Survey - March 9, 1998 KBE- 55.08 DRILLING SERVICE=; ORIGINAL Survey Ref: svy2819 Prudhoe Bay Unit Measured Depth (ft) 8647.78 8719.00 8731.00 8766.15 8797.87 8829.58 8860.96 8892.69 8924.43 8957.04 8989.20 9020.69 9052.19 9083.79 9115.52 9147.29 9179.89 9210.40 9241.86 9274.07 9306.00 9337.53 9369.18 9400.58 9432.70 9464.39 9496.61 9528.32 9547.82 9587.05 39.650 43.140 43.810 49.140 52.580 55.020 56.370 56.270 55.640 54.620 54,180 54,980 58.310 61.550 61.040 58.390 55.800 54.940 54.390 53.320 54.710 58.550 60.870 65.140 71.120 77.690 83,020 92.460 92.740 93.540 Azim. 73.860 75.740 76.040 81.000 85.030 88.830 92.470 96.110 99.800 98.060 96.270 92.790 88.790 88.480 88.540 87.480 86.950 86.670 86.160 85.770 87.04O 89.970 92.520 96.300 97.770 98.050 97.410 99.940 99.900 95.660 Sub-Sea Depth (ft) 8189.18 8242.60 8251.31 8275.51 8295.54 8314.27 8331.96 8349.56 8367.33 8385.98 8404.70 8422.95 8440.28 8456.11 8471.35 8487.37 8505.08 8522.41 8540.61 8559.61 8578.37 8595.71 8611.68 8625.93 8637.89 8646.4O 8651.80 8653.05 8652.16 8650.01 Vertical Depth (ft) 8244.26 8297.68 8306.39 8330.59 8350.62 8369.35 8387.04 8404.64 8422.41 8441.06 8459.78 8478.03 8495.36 8511.19 8526.43 8542.45 8560.16 8577.49 8595.69 8614.69 8633.45 8650.79 8666.76 8681.01 8692.97 8701.48 8706.88 8708.13 8707.24 8705.09 Sperry-Sun Drilling Services Survey Report for 18-16B Your Ref: API-500292174902 Alaska State Plane Zone 4 PBU EOA DS 18 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) Comment 456.97 N 1923.27 E 5961684.50 N 693945.05 E 1924.71 469.29 N 1968.71 E 5961697.97 N 693990.17 E 5.201 1970.86 471.30 N 1976.72 E 5961700.19 N 693998.12 E 5.842 1978.93 476.32 N 2001.68 E 5961705.85 N 694022.95 E 18.284 2003.50 479.29 N 2026.09 E 5961709.44 N 694047.27 E 14.650 2026.66 480.65 N 2051.63 E 5961711.45 N 694072.77 E 12.356 2050.12 480.35 N 2077.55 E 5961711.81N 694098.68 E 10.502 2073.16 478.37 N 2103.87 E 5961710.51N 694125.05 E 9.551 2095.83 474.74 N 2129.91E 5961707.54 N 694151.17 E 9.835 2117.50 470.58 N 2156.34 E 5961704.06 N 694177.70 E 5.380 2139.28 467.32 N 2182.28 E 5961701.46 N 694203.72 E 4.728 2161.03 465.30 N 2207.85 E 5961700.09 N 694229.33 E 9.357 2183.00 464.95 N 2234.15 E 5961700.42 N 694255.63 E 14.972 2206.37 465.60 N 2261.49 E 5961701.77 N 694282.94 E 10.288 2231.12 466.33 N 2289.31 E 5961703.21 N 694310.73 E 1.616 2256.33 467.28 N 2316.72 E 5961704.86 N 694338.12 E 8.825 2281.28 468.60 N 2344.06 E 5961706.88 N 694365.41 E 8.061 2306.32 470.00 N 2369.12 E 5961708.92 N 694390.43 E 2.918 2329.37 471.61N 2394.74 E 5961711.18 N 694415.99 E 2,192 2353.00 473.44N 2420.68 E 5961713.67 N 694441.89 E 3.463 2377.03 475.05 N 2446.47 E 5961715.94 N 694467.62 E 5.414 2400.81 475.72 N 2472.78 E 5961717.29 N 694493.91 E 14.439 2424.65 475.12 N 2500.10 E 5961717.39 N 694521.23 E 10.105 2448.82 472.96 N 2527.98 E 5961715.93 N 694549.16 E 17.317 2472.79 469.30 N 2557.55 E 5961713.03 N 694578.81 E 19.095 2497.61 465.10 N 2587.77 E 5961709.61 N 694609.13 E 20.750 2522.76 460.83 N 2619.23 E 5961706.14 N 694640.69 E 16,658 2549.00 456.05 N 2650.51 E 5961702.17 N 694672.08 E 30.816 2574.85 452.70 N 2669.70 E 5961699.30 N 694691.35 E 1.450 2590.52 447.40 N 2708.50 E 5961694.99 N 694730.28 E 10.983 2622.85 <-Window point / Tie-on Survey at 8,647.78' MD Continued... 15Apdl, 1998 - 11:56 - 2 - DdllQuest Prudhoe Bay Unit Measured Depth (ft) 9618.92 9650.70 9682.55 9714.60 9746.01 9777.73 9809.61 9841.59 9873.43 9904.88 9936.63 9968.26 10000.00 10031.81 10063,52 10095.29 10126.78 10159.02 10190.25 10222.07 10253.84 10285.66 10317.53 10349.32 10381.20 10413.11 10~,~.67 10476.48 10508.18 10539.83 92.030 89.140 88.060 87.780 86.610 84.700 85.620 87.310 90.220 9O.460 90.030 89.780 89.850 89.600 89,94O 90.710 91.790 92.070 94.100 93.630 92.830 89.510 87.280 88.370 90.990 91.290 89.750 88.090 88.610 92.930 Azim. 94.830 93.890 93.920 94.040 93,270 91.150 88.290 86.610 85.880 85.050 82.480 78,890 75,630 73.060 69,630 67.180 66.040 66,840 66,350 66.120 66.160 65.030 64.380 64,570 65.450 64.960 64,360 64.350 64.570 64.210 Sub-Sea Depth (ft) 8648.47 8648.14 8648.92 8650.08 8651.62 8654.02 8656.71 8658.69 8659.37 8659.19 8659.05 8659.10 8659.20 8659.36 8659.48 8659.30 8658.62 8657.53 8655.85 8653.71 8651.92 8651.27 8652.16 8653.37 8653,54 8652.91 8652.62 8653.22 8654.13 8653.71 Vertical Depth (ft) 8703.55 8703.22 8704.00 8705.16 8706.70 8709.10 8711.79 8713.77 8714.45 8714.27 8714.13 8714.18 8714.28 8714.44 8714.56 8714.38 8713.70 8712.61 8710.93 8708.79 8707.00 8706.35 8707.24 8708.45 8708.62 8707.99 8707.70 8708.30 8709.21 8708.79 Sperry-Sun Drilling Services Survey Report for 18-16B Your Ref: API-500292174902 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 444.49 N 2740.20 E 5961692.89 N 694762.04 E 5.405 2649.91 442.07 N 2771.88 E 5961691.29 N 694793.77 E 9.563 2677.17 439.90 N 2803.65 E 5961689.93 N 694825.58 E 3.392 2704.62 437.68 N 2835.60 E 5961688.53 N 694857.58 E 0,950 2732,21 435.68 N 2866.91 E 5961687.33 N 694888.93 E 4,458 2759.32 434.46 N 2898.51E 5961686.92 N 694920.55 E 8.981 2787.04 434.62 N 2930.27 E 5961687.88 N 694952.30 E 9.393 2815.53 436.04 N 2962.16 E 5961690.12 N 694984.14 E 7,444 2844.68 438.12 N 2993.92 E 5961693.01N 695015.84 E 9,422 2874.03 440.61 N 3025.27 E 5961696.30 N 695047.11 E 2.747 2903.18 444.06 N 3056.83 E 5961700.55 N 695078.57 E 8.207 2932.95 449.17 N 3088.04 E 5961706.47 N 695109.64 E 11.377 2963.16 456.17 N 3118.99 E 5961714.26 N 695140.41E 10.273 2993.98 464.76 N 3149.62 E 5961723.62 N 695170.80 E 8.117 3025.21 474.90 N 3179.66 E 5961734.52 N 695200.57 E 10.870 3056.62 486.59 N 3209.20 E 5961746.97 N 695229.80 E 8.083 3088.26 499.09 N 3238.09 E 5961760.20 N 695258.37 E 4.986 3119.70 511.97 N 3267.63 E 5961773.83 N 695287.57 E 2.628 3151.87 524.35 N 3296.24 E 5961786.94 N 695315.86 E 6.686 3183.01 537.15 N 3325.30 E 5961800.47 N 695344.58 E 1.644 3214.72 549.98 N 3354.31 E 5961814.04N 695373.25 E 2.521 3246.41 563.12 N 3383.27 E 5961827.92 N 695401.87 E 11.021 3278.19 576.73 N 3412.07 E 5961842.26 N 695430.31E 7.288 3310.04 590.42 N 3440.74 E 5961856.68 N 695458.62 E 3.480 3341.80 603.89 N 3469.63 E 5961870.88 N 695487.16 E 8.669 3373.67 617.26 N 3498.59 E 5961885.00 N 695515.77 E 1,800 3405.55 630.77 N 3527.12 E 5961899.23 N 695543.94 E 5.237 3437,10 644.54N 3555.79 E 5961913.72 N 695572.25 E 5.219 3468.90 658.20 N 3584.38 E 5961928.11 N 695600.48 E 1.781 3500.59 671.87 N 3612.91 E 5961942.51 N 695628.65 E 13.697 3532.22 Comment Alaska State Plane Zone 4 PBU EOADS 18 Continued,., 15 April, 1998 - 11:56 - 3 - DrillQuest Prudhoe Bay Unit Measured Depth (ft) 10571.40 106O2.95 10635.06 10666.86 10698.63 10730.66 10762.40 10794.30 10826.13 10857.99 10889.69 10912.66 10951.56 10983.39 11014.87 11046.68 11078.60 11110.34 11142.19 11205.67 11237.55 11269.44 11300.92 11315.27 11370.00 Incl. 95.980 97.280 98.150 96.350 92.280 91.690 91.200 90.030 91.110 95.370 91.450 90.580 88.220 87.910 88.650 91.140 94.090 96.540 96.380 91.940 88.740 88.770 87.600 86.920 86.920 62.630 61.620 58.150 55.420 53.950 52.110 48.090 46.890 44.630 40.810 38.140 37.430 34.460 33.550 31.710 28.960 25.870 23.110 18.880 11.910 10.430 7.340 6.060 6.470 6.470 Sub-Sea Depth (ft) 8651.26 8647.61 8643.30 8639.29 8636.90 8635.79 8634.99 8634.65 8634.33 8632.53 8630.64 8630.24 8630.64 8631.72 8632.66 8632.72 8631.27 8628.32 8624.74 8620.13 8619.94 8620.63 8621.63 8622.32 8625.26 Vertical Depth (ft) 8706.34 8702.69 8698.38 8694.37 8691.98 8690.87 8690.07 8689.73 8689.41 8687.61 8685.72 8685.32 8685.72 8686.80 8687.74 8687.80 8686.35 8683.40 8679.82 8675.21 8675.02 8675.71 8676.71 8677.40 8680.34 Sperry-Sun Dril#ng Services Survey Report for 18-16B Your Ref: API-500292174902 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 685.95 N 3641.05 E 5961957.30 N 695656.42 E 10.873 3563.69 700.60 N 3668.75 E 5961972.66 N 695683.74 E 5.205 3595.02 716.57 N 3696.27 E 5961989.32 N 695710.85 E 11.046 3626.77 733.85 N 3722.66 E 5962007.26 N 695736.78 E 10.225 3658.10 752.16 N 3748.51E 5962026.23 N 695762.15 E 13.616 3689.40 771.41N 3774.08 E 5962046.13 N 695787.22 E 6.029 3720.88 791.75 N 3798.42 E 5962067.09 N 695811.03 E 12.755 3751.75 813.31N 3821.93 E 5962089.24 N 695833.99 E 5.254 3782.42 835.51N 3844.73 E 5962112.02 N 695856.21E 7.869 3812.74 858.87 N 3866.30 E 5962135.92 N 695877.18 E 17.945 3842.48 883.29 N 3886.41 E 5962160.84 N 695896.66 E 14.953 3871.38 901.44 N 3900.48 E 5962179.35 N 695910.27 E 4.888 3892.08 932.93 N 3923.31E 5962211.41N 695932.28 E 9.751 3926.58 959.30 N 3941.11E 5962238.22 N 695949.39 E 3.019 3954.28 985.79 N 3958.07 E 5962265.15 N 695965.68 E 6.297 3981.30 1013.24 N 3974.13 E 5962293.00 N 695981.03 E 11.662 4007.94 1041.54 N 3988.81E 5962321.66 N 695994.98 E 13.376 4033.72 1070.30 N 4001.91 E 5962350.74 N 696007.35 E 11.599 4058.29 1099.84N 4013.25 E 5962380.56 N 696017.92 E 13.206 4081.63 1160.83 N 4030.03 E 5962441.96 N 696033.14 E 12.992 4123.91 1192.10 N 4036.21E 5962473.38 N 696038.52 E 11.059 4143.41 1223.60 N 4041.13 E 5962504.99 N 696042.63 E 9.688 4161.89 1254.84N 4044.80 E 5962536.32 N 696045.50 E 5.507 4179.14 1269.09 N 4046.37 E 5962550.61 N 696046.70 E 5.532 4186.91 1323.39 N 4052.52 E 5962605.05 N 696051.47 E 0.000 4216.69 Comment Projected Survey Alaska State Plane Zone 4 PBU EOADS 18 Continued... 15 April, 1998 - 11:56 - 4 - DrillQuest Prudhoe Bay Unit Sperry-Sun Drilling Services Survey Report for t8-16B Your Ref: API.500292174902 Alaska State Plane Zone 4 PBU EOA DS 18 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. ii'he Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 63.450° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11370.00ft., The Bottom Hole Displacement is 4263.13ff., in the Direction of 71.915° (True). 15 April, 1998 - 11:56 - 5 - DdllQuest MEMORANDUM TO: David Johnston' Chairman ~.~' THRU' Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: March I0, 1998 FILE NO: AEFJCIFE.DOC FROM' Lou Grimaldi, ~ ~- SUBJECT: Petroleum Inspector BOP test Doyon CF2 Arco DS18o16B Prudhoe Bay Field PTD #97-99 Tuesday, March 10,, 1998; I witnessed the weekly BOP test on Doyon rig #9 redrilling Arco well #DS18-16B in the Prudhoe Bay Field. I arrived to find the rig ready to test. The test went well, All BOPE were tested and one failure was observed. The inside valve for the hydraulic choke failed, was greased and retested but failed again. This valve was changed out and tested "OK". The Accumulator test time of 2 minutes and 45 seconds is normal for this rig and average for this type accumulator. The Gas detectors had just been checked and were logged properly in the dgs logbook. I waived the check on this system due to the late hour. The rig and its surrounding area were very clean. This is normal for this rig and the hands work hard to keep it sO. SUMMARY: The weekly BOPE test I witnessed on Doyon dg ¢F2 revealed the following; Test time 3.5 hours, One choke valve failure. Attachments: AEFJCIFE.XLS CC; Steve Walls/John Raui (Shared Services Drilling) NON-CONFIDENTIAL STATE OF ALASKA ...... OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: Doyon Rig No. g PTD # ARCO Rep.: DS18-t6B Rig Rep.: Set @ Location: Sec. Weekly X Other DATE: 3/10/98 97-99 Rig Ph.# 659-4831 Gefii Hohman Tim Krupa t 9 T. 1tN R. 15E Meddian Umiat MISC. INSPECTIONS: Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted (Gen) Well Sign P Drl. Rig P Hazard Sec. P Test Quan. Pressure I 5O0/5, O00 1 I 5O0/5,000 1 5OO/5,0O0 500/5,000 FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly/IBOP Ball Type Inside BOP P/F P P P P , , BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. I 250/300O I 500/5,000 P/F P P P 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P N/A MUD SYSTEM: V'~ual Alarm Tdp Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P CHOKE MANIFOLD: No. Valves 15 No. Flanges 38 Manual Chokes 1 Hydraulic Chokes I Test Pressure 5O0/5,000 Functio~ Func#oned P/F ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: Five Bottles 2150 Average 3,000 J.P. 1,750 P minutes 45 sec. minutes 3~' sec. P Remote: P Psig. Number of Failures: I ,Test Time: 3.5 Hours. Number of valves tested 21 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I I I I REMARKS: Inside hydraulic choke valve (#3) leaked, repair and retest. Distribution: odg-Well File c - Oper./Rig c - Database c - Tdp Rpt File c -Inspector F1-021L (Rev.12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Aef]cife Louis R. Grimaidi TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 20. 1998 Jamcs Smith Engineering Supcr¥isor ARCO Alaska Inc. P O Box 196612 Anchorage, AK 99519-6612 ae~ Prudhoc Bay 18-16B ARCO Alaska Inc. Permit No 97-99 Sur Loc: 697'SNL, 281'EWL, Scc. 19, TI 1N, RI5E, UM Btmholc Loc. 924'NSL. 756'WEL, Scc. 18, TI IN. RI5E, UM Dcar Mr. Smith: Encloscd is thc approvcd revised application for permit to drill the above rcfcrcnccd xvcll. cd permit datcd Ma.',' 30. 1997, arc in cffcct for this revision. Chairman ~ BY ORDER OF TIlE COMMISSION dlf/Enclosurcs CC; Dcpartmcnt of Fish 8,: Gamc. Habitat Scction W/o cncl Departmcnt of Environmcntal Conscrvation w/o cncl STATE OF ALASKA. AD-,SKA Ch'L AND GAS CONSERVATIO'~¢COMi~ISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill [lb. Type of well [] Exploratory [] Stratigraphic Test [] Development oil I-I Re-En. tr¥ .. [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) ~10. Field and Pool ARCO Alaska Inc. Plan RKB = 67.90' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028321 4. Location of well at surface ,7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 697' SNL, 281' EWL, SEC. 19, T11N, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 5128' NSL, 1738' WEL, SEC. 19, T11N, R15E, UM 18-16B Attotal depth 19. Approximate spud date Amount $200,000.00 924' NSL, 756' WEL, SEC. 18, T11 N, R15E, UM 02/23/98 121 Distance to nearest property line113. Distance to nearest well 14. Numbe'~' of'acres in' property 15. Proposed depth (MD and TVD)" ADL 028307, 4189'I No Close Approach 2560 11562' MD / 8630' TVD 16. To be completed for deviated wells '17. AniicipatecJ' pre'ssu~'e {see 20 AAC 25.035 (e) (2)} .... KickOff Depth 8715' Maximum HoleAngle 92° Maximurnsurface 2595 psig, At total depth (TVD) 8800'/3475 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement H01e Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 IBT-Mod 2997' 8565' 8236' 11562' 8630' 347 sx Class 'G' ....... 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth' truemeasuredvertical 108348700 feetfeet Plugs(measured) 0 R 161NAL Effective depth: measured 10834 feet Junk (measured) true vertical 8700 feet Casing Length Size Cemented MD TVD Structural Conductor 109' 20" 1680# Poleset 109' 109' Surface 2515' 13-3/8" 2500 sx CS Ill, 400 sx CS II 2515' 2515' Intermediate 7824' 9-5/8" 700 sx Class 'G', 300 sx CS I 7824' 7539' Production 2235' 7" 444 sx Class 'G' 7646' - 9881' 7369' - 8705' Liner 899' 4-1/2" Uncemented Slotted Liner 9519' - 10418' 8674' - 8706' PeRoration depth: measured Slotted Liner Intervals: 9878' - 10394' '. ,7 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diver~r' Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements ............ Contact Engineer Name/Number: J. Aflen Sherritt, 564-4809 Matt Scheuring, 564-4809 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify t~t the foregoing is true/af~ correct to the best of my knowledge Signed ~' '~ ' ~¢'~/'4'--1' Title Engineerin, Supervisor Date~//~~. /// Commission Use Only Permit Number ~/ I APl Number I Ap_..proval Date_ _ letter ~'~;;'- ?~' I 50-029-21749-02 I ,-~ "~)"'~'7 I See cover for other requirements Conditions of Approval: Samples Required []Yes ,J~ No Mud Log Required []Yes J~No Hydrogen Sulfide Measures J~Yes I--INo Directional Survey Required ]~Yes I'-INo Required Working Pressure for BOPE []2M; ~3M; []SM; [--I 10M; I--i 15M Other: 0rigi,ai orderer !Approved By David W. J0hnsi:0r, Commissioner the commission Datec~ ' Form 10-401 Rev. 12-01-85 Submit In Triplicate Well Name: I 1 8-16B I Sidetrack Plan Summary Type of Redrill (producer or injector)' Surface Location: X=692034.09 IPr°ducer I Y=5961178.53 697' FNL, 281' FEL, Sec. 19, T11N, R15E, UM Target 1 Location: X=694950 Y=5961800 5128' FSL, 1738' FEL, Sec. 19, T11N, R15E, UM Bottom Hole Location: X=695900 Y=5962900 924' FSL, 756' FEL, SEC. 18, T11N, R15E, UM I AFE Number: 14J0385 I I Rig: I Doyon 9 Estimated Start Date: I 2/23/98 I I Operating days to complete: I MD: 111,562' I ITvD: I8630' I I Well Design (conventional, slimhole, etc.): 117 IRKB ~67.90' I Ultra-slimhole Horizontal Side-track Objective: I Access Zone lB reserves and maximize standoff from GOC. Mud Pro ram Production Mud Properties:I Solids Free Quikdriln Density Viscosity LSR LSRV Filtrate pH (PPG) YP 8.7-8.8 50-65 14-24 35000-55000 NC 8.5-9.0 Keep Sand content at less than 0.25% in the production interval Directional KOP: Maximum Hole Angle: Close Approach Well: 8,715' MD 92° N/A Formation Markers Formation Tops MD TVD (SS) Zone 4 - KOP 8715' 8242' Zone 3 8870' 8340' Zone 2 9022' 8407' Zone 1 /Romeo 9516' 8589' CGOC 9545' 8600' Target Polygon Start 9788' 8655' TD 11562' 8630' BSAD 8665' Casinc/Tubinc Proc ram Hole Size Csg Wt/Ft Grade Corm Length Top Btm MD/TVDss MD/TVDss Existing 13-3/8" 72# L-80 BTC 2,517' Surface 2,515'/2,515' Existing 9-5/8" 47# L-80 BTC 7,824' Surface 7,824'/7594' Existing 7" 26# NT-80S NSCC 2,235' 7,646'/7,425' 8,715'/8,242' 6" 4.5" 12.6# L-80 iBT-MOD 2,997' 8,565'/8,236' 11,562'/ 8,630' Tubing 4.5" 12.6# L-80 IBT-MO D 3,017' Surface 8,565'/8,236' Cement Lead Cement Tail Cement Casing/Liner Sx / Wt / Yield Sx / Wt / Yield Comments P&A 119/15.8/1.15 Bullhead cement and displace to place TOC @ 9700'. 4-1/2" 347/15.8/1.15 Solid Cemented Liner, Class "G", TOC to 200' above liner top Volume assumptions: Gauge hole + 50% excess; 80' shoe joints; TOC as listed. Logging Program ILogs: 6" Hole DPC Logs: MWD/GR from KOP to horizontal, MWD/GR/RES in horizontal section. N/A Well Control Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling maximum potential surface pressures. Bottom hole pressure is expected to be 3475 psi. Maximum expected surface pressure at 8800' tvdss is 2595 psi (assuming gas column of 0.1 psi/fi) Diverter, BOPE and mud fluid system schematics on file with AOGCC. Hazards DS 18 is not an H2S drillsite. Stuck pipe/lost circulation has been reported. Shallow gas (Ugnu, W. Sak) and Put River (gas) will not be penetrated. Kingak will not be penetrated. (ST below) Close approach with existing 18-16A. Disposal Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: Haul all drilling and completion fluids and other class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC-2A for disposal. 18-16B Short Well Summary Pre-Rig Operations: The objective of the pre-rig work is to ascertain the condition of the 9 5/8" casing presently in the hole; P&A all open perforations; and test the 9 5/8" pack offs. 1. Notify AOGCC of initiation prior to commencing any P&A operations. 2. NU on Well. 3. Bullhead seawater down tubing to kill well and verify injectivity. 4. Set plug @ 8800' MD (3-1/2" SWN Parker nipple ID=2.75") 5. Pressure test tubing to 2000 psi for 30 minutes. 6. Pull plug. 7. Make GR/JB run on 3~,~'' tubing. 8. Bullhead 119 sks. (24 bbls.) of class G, 15.8 ppg cement down tubing, and displace to place TOC @ 9700'. 24 bbls is hole volume calculated, plus 5 bbls. Note: If the tubing fails pressure test or there is Iow injectivity, the weft will have to be P&Ad with Coiled Tubing. 9. Pressure test cement P&A and pressure test 9-5/8"casing to 3000 psi. 10. Rig up chemical cutter and chemically cut tubing at 8741' MD. 11. Freeze protect tubing. 12. Test packoffs on tubing and 9 5/8" annulus, and carefully cycle Iockdown screws. 13. Set BPV. 14. Clear location, dig out cellar, remove electrical lines, flow lines, and well house. RDMO Rig Operations 1. MIRU 2. Pull BPV 3. Circulate out freeze protection and circulate well with seawater. 4. ND tree. NU BOP. 5. Test BOP 6. Change packoff if failed in Pre-rig 7. Pull tbg. 8. Make GR/JB with CCL run on wireline. 9. Run 7" casing scraper if there is any indication of debris. 10. Set 7" whipstock assembly 25° right of highside @ 8,715' MD. 11. Displace to 4% KCI Quikdriln mud. 12. Mill window 13. MU BHA#1 for build w/MWD/GR & drill to horiz ,-,9,782' MD. 14. MU BHA#2 for horizontal section W/MWD/GR/RES and drill to TD @--,11,562' MD. 15. POOH 16. Run 4-1/2" L-80 liner with 2 MLAS subs. 2 X nipples, and set w/7"x4-1/2" packer @ ,-,8,565' MD. 17. Cement via inner string to 8415' MD 18. Perf as per asset direction. 19. Complete with 4 GLMs, an X nipple and a SSSV on 4-1/2" tubing. 20. Freeze protect well. 21. RDMO DS 18-16B Sidetrack PROPOSED COMPLETION DESIGN SIDETRACK OUT OF 7" LINER '~-~- 4-1/2" L-80, 12.6#, IBT-MOD Tubing 13-3/8" 72# , L-80 BTC I O +_2200' SSSV Landing Nipple 2517' MD ~' ~. --b~ Gas Lift Mandrels- Depth Below 7" Production packer @ +8415' MD ] [ "X" only completion (future CT sidetrack) i ~ Top of 4-1/2" L-80, 12.6#, IBT-MOD ,, , , - Liner @ +8565' MD 7 TeL 7646 MD --~1 ~ - 9-5/8" 47# ~ ~. ~ ~2 X nipples; one across a Tango Shale ~ ~ and one 50 belowTSAD · Whipstock/Bridge ,, , plug Assembly (~~~Solid cemented linerto TD @ 11,562 MD +8715' MD ~ ~ ~ I %MLAS Jts. (2) I Depth TBA 7", 29# L-80 Liner~JI il:.i:~:~i~i~' TOC- 9,700' MD 9,881' MD ~, i!i.f .i,.i. /i' ii' ess Lift Mandrels set @; 4.5, 13.5# L-80 ii;! ii' Slotted liner 3000', 5200', 6900', 8080' TVDss "Cemented 3000', 5287', 7144', 8440' MD Slotted Liner10,418' MD~i:! i'li' ::~ Date Revised by Comments 2/17/98 MCS PRUDHOE BAY UNIT WELL: DS 18-16B APl #: 50-029-21756-02 well: 18-16A Spud Date: 09-17-87 Original RKBE: 47' Top of Formation: 8710' Annular Fluid:6.4 Diesel/8.5 SW Reference LoG:BHCS Date: 09-28-87 '.~l< k~-aska, Inc. - Prudhoe Bay · APT $: 50-029-21749-01 Completion: 10-15-92 Hanger Type: FMC Gert .IV.. Max Hole Angle: 91°~'~ X4D: 10765' Tie In: Type: PRODUCER Status:Sidetrack Hanger: 34' Angle @ TS: Angle @ %73:91° Date: 00.-00-00 ALL DEPTHS 2L~ 1%~CB DRILLING ~XD TO TO1~ OF EQ~P2~E~ ]~XC~PT WHERE NOTED. t l Jewelry "-' ...... '4 7653' 5 8660' · 2 6 8747' 7 8800' G-1 8 9474' ,~ / 9 9478' 10' 9489' 11 9519' · 12 9529' 13 9538' ' Description 4-1/~" C~u~co ~ ~ N~le ]33=3.812" C:~x)ssover 4-1/2" x 3-1/2" 7-.1/2" Baker Tieback Sleeve ' '- 9-518' x 7' Baker ~An. er ~ac~ . 3-1/2" Otis X ~ipple ID=2.8~3" 7' x 3-1/2' ~T~ 3-112' Parker S~ Uf~ole-ZD=2.75".- Crossover 3-1/2' x 4-1/2" - .- '4-112' ~W 6-~i~ Overset Seal Assembly 4-1/2' TIW SS Horizontal 4-112" L{ner ~3q. 6 Unit ~t' .S~.al'Asse=bly 4-1/2' 4-1/2" ~o:~ced Joint (O.31'1 ' '- ~:L~ ZO: 3-1/2" Parker ~ Nipple 1! i Fwr./T:L'W ~BBP pkze hmve =e~uce~ test p=eaauxe l~m{ts i~ some cases. Comtact ACE (13X02) p~io~ to p~essu~e .testi~. Casino an4 Tuhinc (C) Size Weight ~rade 1 13-3/8- 72t ~-80 2 9-5/8' 471 I,-80 9-5/8' :WinOow '8. ~824' - 7841' 3 7" 26t ~T~-80S 4 4-1/2- 12.6~ 13cR-80 5 4-1/2- 12:6~ 13~-80 6 4-1/2- 12.6~ t3~-80. . .4-t/2- -- ~2.6{ · 3'~/2" 9.2{ ~80 ToD Bottom Descriptiom 2517' C~in~ o, 7B24. · 7646' 9881' Liner 9519' 9878' CR Liner 9878' 1.0.395' CR.Liner-Slotted 10395' 10418' CR Liner 0' ' 3017' 3017' · 9476" ~b~ 9476' 9487' Tubing Oas T. ift Information (~) ~D TVD Stn ~el Valve Type L~tch Port 3216' (3216') 1 CA-M~3-2 ~' RD T~ 5689' (5570;) 2 CA-~G-2 CA RD TG 7409' (7146') 3 CA-~4G-2 TE D-14R TG 8505' (8149') 4 CA-MMG-2 TE D-14R TG . 8630' (8248') 5 CA-MMG-2 CA RD TG Perforation Data {ELM DEPTHS) (P) Interval Zone FT SPF Date Comments 1 9878-10395 517 N/A 10-16-92 SLOTTED LINER Datum 8600' SS= 9364' MD PBTD=10392, 8700' SS= 9687' MD TD=10834' TRO. Date 10-29-97 10-29-97 11-11-92 10-16-92 10-31-97 Revision Date: 11-0A-97 by ENH Reason: GLV C/O Sta{1,2,5 Previous Reason: 04-12-95 Well 18-16A · Shared Services Drillif I DrillQuestTM 1400 11200.£ 8696.23 m 1 ooo o z 6OO 9259.60 9123.45 8600.0( 9700.00 8703.1( 10000.00 8710.26 10300.00 8709.97 10600.00 8709.25 I 1800 I 2200 Scale: linch = 400ft p~gon 871o.6o 36o.5o N. 3oo3.71 E I I I I I 2600 3000 3400 3800 4200 Fasfinns Reference is True North Scale: linch = 400ft Vertical Section Section Azimuth: 59.437° (True North) 1800 2200 2600 3000 3400 3800 4200 I I I I I I I 8400 - 8800 -- II · ~ 9200 - I 1800 2200 Scale: linch = 400ft 8000 t ~. ~O0 ..................................... ................ .....'_'_'_'_'_'_'_%~.. ~..~? ..................................................................................... : ...................................................... '~ ~,~,'- _ 4 1/2" Liner -,¢;,~ -~.,,,~ oo 11562.30 ~~ 8685.60 .......................................... ~;%o ,oo°~,. ,o;'~i°;;.o ,o¢?Z~_. _,o¢?-- :"¢-~-~" BSA£ 18-16B T1N 18-16A 18-16B T3N Poinl Porn! 8710.60 16-16B T2N 8685.6O 546.75 N, 2930.84 E Po[n! 1622.12 N, 39O8.64 E 8705.6O 922.35 N. 389O.75 E I I I I 1 2600 3000 3400 3800 4200 Vertical Section Section Azimuth: 59.437° (True North) Sperry-Sun Drilling Services Proposal Report for 18-16B - 18-16B Wp2 PREL Shared Services Drilling Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 8715.00 42.921 75.647 8242.41 8298.01 8720.00 43.332 76.065 8246.06 8301.66 8740.00 44.988 77.676 8260.41 8316.01 8755.00 46.244 78.823 8270.90 8326.50 8760.00 46.842 78.884 8274.34 8329.94 8780.00 49.236 79.118 8287.71 8343.31 8800.00 51.630 79.336 8300.45 8356.05 8820.00 54.024 79.540 8312.53 8368.13 8840.00 56.419 79.732 8323.94 8379.54 8860.00 58.814 79.914 8334.65 8390.25 8869.90 60.000 80.000 8339.69 8395.29 8870.52 60.030 80.025 8340.00 8395.60 8880.00 60.495 80.403 8344.70 8400.30 8900.00 61.478 81.189 8354.40 8410.00 8920.00 62.466 81.961 8363.80 8419.40 8940.00 63.458 82.719 8372.89 8428.49 8960.00 64.455 83.464 8381.67 8437.27 8980.00 65.454 84.196 8390.14 8445.74 9000.00 66.458 84.917 8398.29 8453.89 9020.00 67.464 85.627 8406.12 8461.72 9022.31 67.581 85.708 8407.00 8462.60 9030.62 68.000 86.000 8410.14 8465.74 9038.35 68.000 87.000 8413.04 8468.64 9040.00 68.112 87.176 8413.65 8469.25 9044.01 68.385 87.602 8415.14 8470.74 9500.00 68.385 87.602 8583.11 8638.71 Q -'~99515.99 68.385 87.602 8589.00~,0 8644.60' ¢02.84 68.385 87.602 8620.99"' 8676.59 9620.00 70.416 87.238 8627.03 8682.63 9640.00 72.784 86.825 8633.34 8688.94 470.64 N 1958.69 E 471.48 N 1962.00 E 474.64 N 1975.57 E 476.82 N 1986.07 E 477.52 N 1989.63 E 480.36 N 2004.23 E 483.24 N 2019.37 E 486.16 N 2035.04 E 489.12 N 2051.19 E 492.10 N 2067.82 E 493.59 N 2076.21E 493.68 N 2076.74 E 495.08 N 2084.85 E 497.88 N 2102.11E 500.46 N 2119.58 E 502.84 N 2137.23 E 505.00 N 2155.07 E 506.94 N 2173.09 E 508.68 N 2191.27 E 510.19 N 2209.61E 510.35 N 2211.74 E 510.91N 2219.41E 511.35 N 2226.56 E 511.43 N 2228.09 E 511.59 N 2231.81E 529.33 N 2655.37 E 529.96 N 2670.22 E 533.34 N 2750.89 E 534.06 N 2766.94 E 535.04 N 2785.89 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5961699.07 N 693980.11 E 5961699.99 N 693983.41 E 10.000 5961703.50 N 693996.89 E 10.000 5961705.95 N 694007.32 E 10.000 5961706.74 N 694010.87 E 12.000 5961709.95 N 694025.39 E 12.000 5961713.22 N 694040.45 E 12.000 5961716.54 N 694056.04 E 12.000 5961719.90 N 694072.12 E 12.000 5961723.31 N 694088.66 E 12.000 5961725.01 N 694097.01 E 12.000 5961725.12 N 694097.53 E 6.000 5961726.72 N 694105.61 E 6.000 5961729.96 N 694122.80 E 6.000 5961732.99 N 694140.19 E 6.000 5961735.82 N 694157.78 E 6.000 5961738.43 N 694175.55 E 6.000 5961740.84 N 694193.51E 6.000 5961743.04 N 694211.64 E 6.000 5961745.02 N 694229.94 E 6.000 5961745.24 N 694232.07 E 6.000 5961745.99 N 694239.72 E 6.000 5961746.61 N 694246.86 E 12.000 5961746.72 N 694248.39 E 12.000 5961746.99 N 694252.10 E 12.000 5961775.55 N 694675.06 E 0.000 5961776.55 N 694689.90 E 0.000 5961781.99 N 694770.45 E 0.000 5961783.12 N 694786.48 E 12.000 5961784.59 N 694805.40 E 12.000 Vertical Section (ft) 1925.89 1929.16 1942.46 1952.60 1956.02 1970.04 1984.54 1999.52 2014.93 2030.76 2038.74 2039.25 2046.94 2063.23 2079.58 2095.99 2112.45 2128.95 2145.49 2162.05 2163.97 2170.86 2177.24 2178.60 2181.88 2555.62 2568.73 2639.90 2654.09 2670.91 Comment TZ3 TZ2 TZ1 14 January, 1998 - 20:10 -1- Sperry-Sun Drifting Services Proposal Report for 18-16B - 18-16B Wp2 PRELl Shared Services Drilling Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 9660.00 75.153 86.423 8638.86 8694.46 9680.00 77.522 86.030 8643.59 8699.19 9700.00 79.892 85.644 8647.50 8703.10 9720.00 82.263 85.263 8650.61 8706.21 9740.00 84.633 84.887 8652.89 8708.49 9760.00 87.004 84.513 8654.35 8709.95 9780.00 89.375 84.141 8654.98 8710.58 9787.61 90.278 84.000 8655.00 8710.60 9800.00 90.238 82.514 8654.94 8710.54 9820.00 90.174 80.115 8654.87 8710.47 9840.00 90.109 77.716 8654.82 8710.42 9856.48 90.055 75.739 8654.80 8710.40 10000.00 90.055 75.739 8654.66 8710.26 10480.54 90.055 75.739 8654.20 8709.80 10500.00 90.123 73.404 8654.17 8709.77 10520.00 90.193 71.005 8654.11 8709.71 10540.00 90.263 68.606 8654.03 8709.63 10560.00 90.332 66.207 8653.93 8709.53 10580.00 90.401 63.808 8653.80 8709.40 10600.00 90.469 61.409 8653.65 8709.25 10620.00 90.536 59.010 8653.47 8709.07 10640.00 90.602 56.611 8653.28 8708.88 10660.00 90.667 54.211 8653.05 8708.65 10680.00 90.731 51.812 8652.81 8708.41 10700.00 90.794 49.413 8652.54 8708.14 10720.00 90.855 47.013 8652.26 8707.86 10740.00 90.915 44.614 8651.95 8707.55 10760.00 90.973 42.214 8651.62 8707.22 10780.00 91.029 39.814 8651.27 8706.87 10800.00 91.084 37.414 8650.90 8706.50 536.17 N 2805.08 E 537.45 N 2824.47 E 538.88 N 2844.03 E 540.44 N 2863.72 E 542.15 N 2883.52 E 543.99 N 2903.38 E 545.97 N 2923.27 E 546.75 N 2930.84 E 548.21N 2943.14 E 551.23 N 2962.91E 555.07 N 2982.53 E 558.86 N 2998.57 E 594.21 N 3137.67 E 712.59 N 3603.40 E 717.77 N 3622.16 E 723.88 N 3641.20 E 730.78 N 3659.97 E 738.47 N 3678.43 E 746.92 N 3696.56 E 756.12 N 3714.31E 766.05 N 3731.67 E 776~70 N 3748.59 E 788.06 N 3765.05 E 800.09 N 3781.03 E 812.78 N 3796.48 E 826.10 N 3811.39 E 840.04 N 3825.73 E 854.56 N 3839.47 E 869.65 N 3852.59 E 885.28 N 3865.07 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/lOOft) 5961786.21N 694824.55 E 12.000 5961787.98 N 694843.90 E 12.000 5961789.91N 694863.42 E 12.000 5961791.98 N 694883.07 E 12.000 5961794.19 N 694902.81E 12.000 5961796.54 N 694922.62 E 12.000 5961799.02 N 694942.45 E 12.000 5961800.00 N 694950.00 E 12.000 5961801.77 N 694962.26 E 12.000 5961805.29 N 694981.94 E 12.000 5961809.64 N 695001.47 E 12.000 5961813.83 N 695017.40 E 12.000 5961852.73 N 695155.55 E 0.000 5961982.97 N 695618.10 E 0.000 5961988.62 N 695636.72 E 12.000 5961995.22 N 695655.60 E 12.000 5962002.60 N 695674.19 E 12.000 5962010.75 N 695692.45 E 12.000 5962019.66 N 695710.35 E 12.000 5962029.31N 695727.87 E 12.000 5962039.69 N 695744.96 E 12.000 5962050.77 N 695761.61E 12.000 5962062.54 N 695777.78 E 12.000 5962074.98 N 695793.44 E 12.000 5962088.06 N 695808.56 E 12.000 5962101.76 N 695823.13 E 12.000 5962116.06 N 695837.10 E 12.000 5962130.93 N 695850.47 E 12.000 5962146.35 N 695863.20 E 12.000 5962162.28 N 695875.28 E 12.000 Vertical Section (ft) 2688.01 27O5.35 2722.92 2740.67 2758.59 2776.62 2794.75 2801.68 2813.01 2831.56 2850.42 2866.16 3003.90 3465.12 3483.91 3503.41 3523.08 3542.89 3562.79 3582.76 3602.76 3622.74 3642.69 3662.56 3682.32 3701.94 3721.37 3740.59 3759.56 3778.25 Comment Target: 18-16B T1 N, Geological 14 January, 1998 - 20:10 -2- Sperry-Sun Drilling Services Proposal Report for 18-16B - 18-16B Wp2 PREL Shared Services Drilling Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 10820.00 91.137 35.015 8650.51 8706.11 10840.00 91.187 32.615 8650.11 8705.71 10845.12 91.200 32.000 8650.00 8705.60 10860.00 91.236 30.215 8649.68 8705.28 10880.00 91.283 27.814 8649.24 8704.84 10900.00 91.328 25.414 8648.79 8704.39 10920.00 91.371 23.014 8648.32 8703.92 10940.00 91.411 20.614 8647.83 8703.43 10960.00 91.448 18.213 8647.33 8702.93 10980.00 91.483 15.813 8646.82 8702.42 11000.00 91.516 13.412 8646.30 8701.90 11020.00 91.545 11.011 8645.76 8701.36 11040.00 91.573 8.611 8645.22 8700.82 11060.00 91.597 6.210 8644.67 8700.27 11080.00 91.618 3.809 8644.10 8699.70 11100.00 91.637 1.408 8643.54 8699.14 11120.00 91.653 359.007 8642.96 8698.56 11140.00 91.666 356.606 8642.38 8697.98 11160.00 91.676 354.205 8641.80 8697.40 11174.10 91.681 352.513 8641.39 8696.99 11500.00 91.681 352.513 8631.83 8687.43 11562.30 91.681 352.513 8630.00 8685.60 901.41 N 3876.89 E 918.02 N 3888.01E 922.35 N 3890.75 E 935.08 N 3898.43 E 952.57 N 3908.13 E 970.44 N 3917.09 E 988.68 N 3925.29 E 1007.24 N 3932.72 E 1026.09 N 3939.36 E 1045.21 N 3945.21 E 1064.56 N 3950.26 E 1084.09 N 3954.48 E 1103.79 N 3957.89 E 1123.62 N 3960.47 E 1143.53 N 3962.22 E 1163.50 N 3963.12 E 1183.49 N 3963.20 E 1203.47 N 3962.43 E 1223.39 N 3960.83 E 1237.39 N 3959.20 E 1560.37 N 3916.75 E 1622.12 N 3908.64 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5962178.71N 695886.68 E 12.000 5962195.60 N 695897.37 E 12.000 5962200.00 N 695900.00 E 12.000 5962212.93 N 695907.36 E 12.000 5962230.65 N 695916.60 E 12.000 5962248.75 N 695925.10 E 12.000 5962267.19 N 695932.83 E 12.000 5962285.93 N 695939.79 E 12.000 5962304.95 N 695945.95 E 12.000 5962324.21N 695951.31E 12.000 5962343.68 N 695955.85 E 12.000 5962363.32 N 695959.58 E 12.000 5962383.10 N 695962.48 E 12.000 5962402.99 N 695964.55 E 12.000 5962422.94 N 695965.79 E 12.000 5962442.92 N 695966.19 E 12.000 5962462.91N 695965.75 E 12.000 5962482.86 N 695964.48 E 12.000 5962502.74 N 695962.37 E 12.000 5962516.69 N 695960.38 E 12.000 5962838.48 N 695909.69 E 0.000 5962900.00 N 695900.00 E 0.000 Vertical Section (ft) 3796.63 3814.65 3819.21 3832.30 3849.54 3866.35 3882.68 3898.51 3913.82 3928.58 3942.76 3956.34 3969.29 3981.59 3993.22 4004.15 4014.38 4023.88 4032.63 4038.35 4166.03 4190.44 Comment Target: 18-16B T2N, Geological 4 1/2" Liner Target: 18-16B T3N, Geological 14 January, 1998'- 20:10 - 3 - Sperry-Sun Drilling Services Proposal Report for 18-16B - 18-16B Wp2 Shared Services Drilling Prudhoe Bay Unit All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 59.437° (True). Based upon Minimum Curvature'type calculations, at a Measured Depth of 11562.30ft., The Bottom Hole Displacement is 4231.87ft., in the Direction of 67.461 © (True). 14 January, 1998 - 20:10 - 4 - Sperry-Sun Drilling Services Proposal Report for 1'8-16B - 18-16B Wp2 Shared Services Drilling Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_EOA DS 18 Measured Vertical Depth Incl. Azim. Depth Northings Eastings (ft) (ft) (ft) (ft) Vertical Dogleg Section Rate (ft) (°/100ft) 8715.00 42.921 75.647 8298.01 470.64 N 1958.69 E 8755.00 46.244 78.823 8326.50 476.82 N 1986.07 E 8869.90 60.000 80.000 8395.29 493.59 N 2076.21 E 9030.62 68.000 86.000 8465.74 510.91 N 2219.41 E 9038.35 68.000 87.000 8468.64 511.35 N 2226.56 E 9044.01 68.385 87.602 8470.74 511.59 N 2231.81 E 9602.84 68.385 87.602 8676.59 533.34 N 2750.89 E 9787.61 90.278 84.000 8710.60 546.75 N 2930.84 E 9856.48 90.055 75.739 8710.40 558.86 N 2998.57 E 0480.54 90.055 75.739 8709.80 712.59 N 3603.40 E 0845.12 91.200 32.000 8705.60 922.35 N 3890.75 E 1174.10 91.681 352.513 8696.99 1237.39 N 3959.20 E 1562.30 91.681 352.513 8685.60 1622.12 N 3908.64 E 1925.89 1952.60 10,000 2038.74 12.000 2170.86 6.000 2177.24 12.000 2181.88 12.000 2639.90 0.000 2801.68 12.000 2866.16 12.000 3465.12 0.000 3819.21 12.000 4038.35 12.000 4190.44 0.000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well, The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 59.437° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11562.30ft., The Bottom Hole Displacement is 4231.87ft., in the Direction of 67.461 o (True). Formation Tops Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) 8870.52 8395.60 8340.00 9022.31 8462.60 8407.00 9515.99 · 8644.60 8589.00 Northings Eastings Formation Name (ft) (ft) 493.68 N 2076.74 E TZ3 510.35 N 2211.74 E TZ2 529.96 N 2670.22 E TZ1 Casing details From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) <Surface> <Surface> 11562.30 Vertical Depth Casing Detail (ft) 8685.60 4 1/2" Liner PRELIMINARY Targets associated with this wellpath Target Name 18~16B POLY 18-16B T1N 18-16B T2N 18-16B T3N Target Entry Coordinates TVD Northings Eastings Target Target (ft) (ft) (ft) Shape Type 8710.60 360.50 N 3003.71 E Polygon Geological 8710.60 546.75 N 2930.84 E Point Geological 8705.60 922.35 N 3890.75 E Point Geological 8685.60 1622.12 N 3908.64 E Point Geological TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 27'9-1433 FAX: (907) 276-7542 May 30, 1997 Erin Oba Engineering Supervisor ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Prudhoe Bav Unit 18-16B ARCO Alaska, Inc. Permit No 97-99 Sur. Loc.: 691'SNL. 281'EWL. Sec. 19, TllN. R15E. UM Btmhole Loc: 4415'FNL, 457'FEL, Sec. 18, T11N. R15E, UM Dear Ms. Oba: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made: Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice max' be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/enclosures cc: Department of Fish & Game. Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. STATE OF ALASKA ALAsKa-DIE AND GAS CONSERVATION COMMIS-~'IoN PERMIT TO DRILL 2O AAC 25.005 I la. Type of Work Ddlt _ Redrill X I lb. Type of Well Exploratow._ Stratigraphic Test _ Development Oil _~X Re-Entry__ Deepen ~I Service_ Development Gas_ Single Zone X Multiple Zone_ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 50' 3. Address 6. Property Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 28321 Prudhoe Bay Oil Pool 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 691' SNL, 281' EWL, Sec 19, T11N, R15E, UMo Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number N/A 18-16B #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 4415' FNL, 457' FEL, Sec 18, T11N, R15E, UM. June, 1997 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) properly line No Close Approach 11255' MD / 8687' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth N/A Maximum hole angle 93° Maximum surfa~ 2800 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth Size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2-3/4" 2-3/8" 4.6 L-80 FL4S 1000' 10300' 8701' 11255' 8687' Slotted Liner (uncemented) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary0RI61NAL Totaldepth: measured 10834 feet Plugs(measured) true vertical 8700 feet Effective depth: measured 10834 feet Junk (measured) true vertical 8700 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 109' 20" 1680 # Poleset 109' 109' Surface 2465' 13-3/8" 2500 Sx CS III & 400 Sx CS II 2515' 2515' Production 7774' 9-5/8" 700 Sx CIG & 300 Sx CS I 7824' 7539' Liner 2235' 7" 444 Sx CIG 9881' Slotted Liner 899' 4-1/2" U ncemented 10418' Perforation depth: measured Slotted Liner: 9878-10395' true vedical Slotted Liner: 8702- 8703' knchors~e 20. Attachments Filing fee _~X Property plat_ BOP Sketch __X Diverter Sketch _ Ddlling program Drilling fluid program __ Time vs depth plot_ Refraction analysis ~ Seabed report _ 20 AAC 25.050 requirements ~1. Ihereby cedify that the foregoing is true and correct to the best of my knowledge (~*¢B~'t"f~o,~,~ Signed ~'~~ '~. t/'~ Titlle Engineering Supervisor Date Commission Use Only ~ermit Number APl number . ~ Approval date I See cover letter for ¢--~ I Sam-les I 5o-o ?' / :TZ/¢- o.~ I other requirements_ ?? Cond~ions of approva IJ required _'Yes ~No Mud Icg required_ Yes )('No Hydrogen sulfide measures ,,~'Yes _ No Directional survey required ~'Yes _ No Required working pressure for BOPE _2M; _3M; _5M; _10M; _15M __X 3500 psi for CTU Other: by order of Approved by Commissioner the commission Date :orm 10-401 Rev. 7-24-89 Submit in triplicate DS 18-16~ CT Extension and Completion Intended Procedure Objective: Directionally drill -1000', 2-3/4" horizontal extension from the existing wellbore. Complete with 2-3/8" slotted liner. Intended Procedure: · RU CTU/Nabors 3S. RIH and mill out shoe in 4-1/2" slotted liner. · Plugback existing 6" open hole with cement to - 10420' MD. · Load well with +8.9 ppg polymer mud. Directionally drill -~1000' of 2-3/4" horizontal hole to access Romeo reserves. · Run 2-3/8" slotted liner to TD. · RD CTD, return well to production. May 21, 1997 DS 18-16,~ Proposed Wellbore Sketch Extension of Wellbore & Completion 4-1/2" Camco TRSV SSSV 3.812" ID 2039' 4-1/2" Production Tubing 4-1/2" x 3-1/2" xo 3015' 3-112" Camco GLMs 7" Liner top 7646' 3-1/2" Otis "X" Nipple 8660' 7" TIW HBBP 8747" 3-1/2" Parker 8800' "SWN' NIpPle ~.,,~ 2.375" Slotted 9-~8" 7824- Window 7841' 7" Liner Shoe 9881' TIW Overshot Seal Assy, SS Packer @ 9478' & 9529' 4-1/2" Slotted Liner to 10395' Lin 2.375" TOL -1O3O0' er 2.75" Openhole +/-1000' -1 ID +/- 11300' 1 .~ .~., 5/11/97 6:04 PM VERTICAL SECTION USED RKB .OTE Ec. I I , ~..e~ M:~ Inc. ~ ~ DE,H :~ ~J ~:~ Bu~ Turn ~,~ ASP YJ ASP X , ~.3[ 0.0 1. TIP 6° DLS ~0~ TFC 1~21.0 89.0 71.6 ~.5 ~75.3 0.0~ 5~152.0~ ~18.0 1~.0 ~.0 ~.9 ~.0 ~.7 ~.8 ~.9 0.0~ ~.0 6.0~ 5~1~.5~ ~.~ 1~.0 ~.0 ~.1 ~.6 ~.2 ~.6 ~.9 0.0 ~.0 6.0~ 5~173.5~ ~72.8 ~.1 ~.9 918.2 ~.5 ~.0 6.0~ 5~1~.01 ~.2 1~.0 89.0 ~.5 ~.6 ~m.7 ~.7 3517.8 0;0 ~.0 6.0 5~1~.5~1 6~527.1 1~70.0 ~.O ~.7 ~7.1 ~ ~22.6 ~.1 ~.6 0.O~ ~.0 ~2213.5 ~53.6 1~.0 ~.0 ~.9 ~7.6 ~2.6 ~.3 ~71.0~ 0.0' ~.0 5~228.0~ ~579.7 1~.0 ~.0 ~.1 ~.1 ~2.6 973.3 ~7.0 0.0 ~.0 6.0 ~2~.0 ~.3 1~.0 89.0 57.3 ~.7 ~12.6 ~.1 ~.5 0.0~ ~.0 6.0 5~.5 ~.3 1~.0 ~.0 ~.5 ~.2 ~2.5 1~.7 ~7.5 0.0~ ~.0 6.0 ~277.5 ~.9 1~.0 ~.1; 51.9 ~.2 3702.2 1~1.3 ~.8 ~.0 6.0 5~314.5 ~7~.3 ~ 1~.0 ~.1 ~.1 ~.6 37~.0 1~.2 3719.1 ~.0 6.0 ~.0~ ~725.1 10710.0 ~.1 ~.3 ~1.1 3761.5 1079.8 3741.8 ~.0 6.0~ 5~.0 ~747.3 2. 6~ DLS 60° TFC 10721.0 ~.1 47.6 ~1.3 3772.3 1~7.2 3749.9. 0.0 ~.0 6.0J ~1.5 ~755.2 107~.0 ~.7 ~.6 ~1.5 3791.0 1~.91 37~.1 3.0 5.2 .6.0 ~374.5~ ~7~.0 10770.0 ~.6 ~.1 ~.5 ~.~ ~1~9.41 37~.8 3.0 5.2 6.0J 5~.5{ ~791.3 1~.0 91.5 51.7 ~.9 ~.3 11~.3~ ~10.1 3.0 5.2 6.0~ ~414.0j ~14.1 1~.01 ~.4 53.3 ~9.9 ~.1 11~.6~ ~.9 3.0 5.2 6.0~ 5~.0 ~7.4 3. 3.20~ DLS 92.1~ TFC 1~.0 ~.0 ~.3 ~9.0 ~.0 11~.4 ~.0 3.0 5.2 6.0, ~2~.5 ~.2 { 3.2~ ~1.5 ~1.2 1~.0 ~.9 ~.6 ~.5 ~.9 1174.2 ~.1 ~ ~.1 3.2 1 ~.0 ~.9 ~.6 ~7.0 ~.8 1191.3 ~.7~ ~.1 3.2 32 ~ 5~.0 ~.3~ { 1 ~0.0~ ~.9 ~.5 ~.5 ~.7 12~.0 ~7.6,~ ~. 1 3.2 3.2{ ~.5 ~.7 J 111~.0 ~.6 ~.2 ~.1 42~2 1326.4 4115.8 ~.1 32' 3.21 5~610.01 ~114.9 111~.0 ~.5 ~.2 ~2.8 42~.0 1~.2 4142.9 ~.1 3.2 · - 3.2~ 5~3.5~ ~141.6 11220.0 ~.5 ~.2 ~1.5 42~.8 1~1.6 4170.2 ~.1~ 3.2 3.2[ ~.5~ ~1~.6 ~.1 112~.0 ~.4 ~.1 ~.2 4~.5 1~.5 4197.7 3~ 3.2 5~9.0 6~1~.8 4. TD 112~.8 ~.4 ~.3 ~.0 ~.2i 1~.3 4~.2 ~ 3.2, 3.2 5~1.0 ~.2 /-66 I, ' I. I, ),,VIN ' =J.LVO O~J. NdIQVH O~la ' ,&lB N/VW~IQ 7.,/V~Q' I, V9LgI,\V91,-91,\YI-IVOO~IV~:O' 31NVN =1"114 HI,ON ::IN,J/Ol :IAIIV-Iq~! o68'8~ u/O::IS I~I::iA -IO :::lNVqd lJ 00~' qou! I, eleoS uo!loes leO!l~eA O O O O O O O O O O O O O O O O O O O O ~r c~ o co (o ~l' 04 o 0o ~1' ~1' ~l' 03 co cO 03 03 oq SS 0'0t798 O/t7 91,'81, o [,'69 ~EZO~ 009 J.L 001,/o9 IO ~ i i iii I i i ii iii i iiii _ iii 00'68 I,~COI, OR o0'C60g80~ Ola dO>1006- Il_ 001,/o9 ICI I, o I, 7:6 Jl O0 I,/oE'£ Id C _ 0088 ~ - g - ~ _-'-"00~8 ~ _ ~ .. = 8 '' OOff8 ~J 00~:' 4OUl t eleOS NV~I O O O O O O O O O O O O ~ O~ O eO (O ~1' 'ONI VHSVlV ODdlY (I, 9'9~+) 6e~ (0+) emi 3na± O± HI,ION V)ISVIV AW8 30HOfl~ '9NI VYlSV-IV OOUV Drilling Wellhead Detail ~ CT Injector Head %~_.~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure r- -- 7" Riser Methanol Injection Otis 7" WLA Quick I' ' Connect ------ I Alignment Guide Flange 7-1/16", 5M Ram Type Dual ~ Gate BOPE Flanged Fire Resistant Man Kelly Hose to Dual HCR Choke Manifold \ Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure ,) Cutters or Combination CuttedBlinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M am Type Dual Gate BOPE anua/over Hydraulic 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus Mu, Tanks 6O/4O I TrplxI Ext. Fuel Shop Boilers Water Pump Fire Ext. Ext. ,~Pipe ra,~ I--CO D°Wement Trailer Equipll Drilling Preferred Major Equipment Layout for CT Drilling WELL PERMIT CHECKLISToo. .Y F~E~.D ~ POO~, ~/~I,_Co ~N~T c~,Ass GEOL AREA PROGRAM: expr~ dev~redrl~serv[] wellbore segO ann disp para reqO ~ UNIT# //~ ._~c3_ ON/OFF SHORE ~ ~j ADMINISTRATION 1. 2. 3 4 5 6 7 8 9 10 11. 12. 13. Permit fee attached .................. N Lease number appropriate ............... N Unique well name and number .............. N Well located in a defined pool ............. N Well located proper distance from drlg unit boundary. . N Well located proper distance from other wells ...... N Sufficient acreage available in drilling unit ...... N If deviated, is wellbore plat included ......... N Operator onl~ affected party .............. N Operator has appropriate bond in force ......... N Permit can be issued without conservation order ..... N Permit can be issued without administrative approval. . N Can permit be approved before 15-day wait ........ N REMARKS ENGINEERING 14. Conductor string provided ................ Y N 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg. . Y N 17. CMT vol adequate to tie-i~ long string to surf csg... Y N 18. CMT will cover all known productive horizons ....... Y 19. Casing designs adequate for C, T, B & permafrost .... _~ ~ /~ 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. '-~~~-r--~ 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... --~Y-----N-~//~ 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to 5~-~'~ psig..~ N 27. Choke manifold complies w/API RP-53 (May %4) ...... ~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/'__ Data presented on potential overpressure zones ..... Y /~/ . 31. Seismic analysis of shallow gas zones .......... Y/ N /~J. 32. 33. Seabed condition survey (if off-shore) ........ /Y N ' 4 34. Contact name/phone for weekly progress reports . . . /. Y N [exploratory only] ~ GEOLOGY: ENGINEERING: COMMISSION: HOW/dlf- A:\FORMS\cheklist rev 01197 · WELL PERMIT CHECKLIST COMPANY//';-'~..~ FIELD & POOL INIT CLASS /"-~.~ Y GEOL AREA PROGRAM: exp [] dev,/~'redrll~serv [] wellbore seg E] ann. disposal para reqH ~:>.'.'.~c--~j UNIT# ..... //,,'/,~, ~"'t'~ ON/OFF SHORE F"~A 2 ADMINISTRATION ~TE~ 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ....................... Y Lease number appropriate ................... Y Unique well name and number .................. Y Well located in a defined pool .................. Y N Well located proper distance from drilling unit boundary .... Y N Well located proper distance from other wells .......... Y N Sufficient acreage available in drilling unit ............ Y N If deviated, is wellbore plat included ............... Y N Operator only affected party ................... Y N Operator has appropriate bond in force ............. Y N Permit can be issued without conservation order ........ Y N Permit can be issued without administrative approval ...... Y N Can permit be approved before 15oday wait ........... Y N ENGINEERING REMARKS ,/ 14. Conductor string provided ................... Y N "~ 15. Surface casing protects all known USDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... N 19. Casing designs adequate for C, T, B & permafrost ....... (?'2 N 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. (_~ N , ~./~_ 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to _'~~ psig. ~1~-----~ 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... (_~ N 29. Is presence of H2S gas probable ................. N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... ~N//~/YY N ./'~,,,/,,~.t 31. Data presented on potential overpressure zones ........ 32. Seismic analysis of shallow gas zones ............. -33. Seabed condition survey (if off-shore) ............ .//Y N 34. Contact name/phone for weeklyproqress reports ..... /. Y N [ex~lora'tory only] ~ GEOLOGY: ENGINEERING: COMMISSION: RPC~ JDH ~ RNC__ "'" CO ~ Commentsllnstructions: HOW/lit - A:\FORMS\cheklist rev 09/97 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 18 09:56:20 1998 Reel Header Service name ............. LISTPE Date ..................... 98/05/18 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 ..................... 98/05/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-80141 R. MCNEILL T. MAUNDER 18-16B 500292174902 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 18-MAY-98 MWD RUN 3 AK-MM-80141 R. MCNEILL T. MAUNDER MWD RUN 3 AK-MM-80141 R. MCNEILL T. MAUNDER JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 4 AK-MM-80141 J. FOLEY T. MAUNDER MWD RUN 4 AK-MM-80141 J. FOLEY T. MAUNDER 19 liN 15E 691 281 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 55.10 52.10 17.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 11370.0 6.000 11370.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP) . 4. MWD RUNS 3 AND 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 5. TWO MEASUREMENT AFTER DRILLING (MAD) PASSES WERE PERFORMED AFTER MWD RUNS 3 AND 4. THIS DATA IS PRESENTED AS A TAIL TO THIS LOG. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF l1370'MD, 8685'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. 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 SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. CURVES WITH THE EXTENSION "M" ARE MEASURED AFTER DRILLING (MAD). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR ROP FET RPD RPM RPS RPX $ BASELINE CURVE FOR SHIFTS: 8672 5 8733 5 9542 0 9542 0 9542 0 9542 0 95~2 0 CURVE SHIFT DATA (MEASURED DEPTH) 1 8674 8675 8676 8680 8684 8686 8688 8689 8690 8692 8693 8696 8698 8700 8702 8704 8708 8713 8715 8717 8724 8727 1368 BASELINE DEPTH GR 8672.5 8674 · 0 8675 · 0 8676 .5 8678 .5 8682 .5 8686 5 8687 5 8689 5 8691 5 8693 5 8694 5 8695 5 8698 5 8702 5 8703 5 8704 5 8707 0 8711 0 8715 5 8716 5 8719 0 8725 0 8728 5 11370 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: Dat .5 .5 .5 .5 .5 .0 .0 .0 .0 .0 .5 .5 .0 0 0 5 5 0 0 5 5 0 5 0 11330.0 11368.5 11337.0 11337.0 11337.0 11337.0 11337.0 EQUIVALENT UNSHIFTED DEPTH a 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 MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 2 8735.0 9607.0 3 9607.0 10965.0 4 10965.0 11370.0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD FT/H 4 1 GR MWD API 4 1 RPX MWD OHMM 4 1 RPS MWD OHMM 4 1 RPM MWD oHMM 4 1 RPD MWD OHMM 4 1 FET MWD 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 8672.5 11368.5 10020.5 ROP 7.0177 2418.75 130.724 GR 17.6692 301.593 60.375 RPX 5.7857 2000 58.329 RPS 5.7901 132.539 52.7626 RPM 5.6138 2000 102.926 RPD 6.4393 2000 166.099 FET 0.3386 29.344 2.5264 First Last Nsam Reading Reading 5393 8672.5 11368.5 5271 8733.5 11368.5 5316 8672.5 11330 3591 9542 11337 3591 9542 11337 3591 9542 11337 3591 9542 11337 3591 9542 11337 First Reading For Entire File .......... 8672.5 Last Reading For Entire File ........... 11368.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/18 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 ....... 98/05/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FET 9365.0 11304.5 RPX RPD RPM RPS GR RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 9365.0 11304.5 9370.5 11304.5 9371.5 11304.5 9372.5 11304.5 9389.0 11297.0 9427.0 11336.0 MAD RUN NO. MAD PASS NO. 3 4 MERGED MAD 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 MERGE TOP 9607.0 10965.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RAT MAD FT/H 4 1 68 GR MAD API 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHMM 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OHMM 4 1 68 FET MAD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 MERGE BASE 10965.0 11370.0 Name Min Max Mean DEPT 9365 11336 10350.5 RAT 152.693 6901.17 922.258 GR 27.0313 164.496 64.7505 RPX 6.2739 94.9263 39.0997 RPS 6.462 89.2017 42.9388 RPM 6.4325 236.584 58.9275 RPD 7.5064 2000 93.7639 FET 0.0074 20.8413 2.87774 Nsam 3943 3819 3518 3880 3865 3867 3869 3761 First Reading 9365 9427 9389 9365 9372.5 9371.5 9370.5 9365 Last Reading 11336 11336 11297 11304.5 11304.5 11304.5 11304.5 11304.5 First Reading For Entire File .......... 9365 Last Reading For Entire File ........... 11336 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/18 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 ....... 98/05/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8674.5 9545.5 ROP 8735.0 9607.0 $ LOG HEADER DATA DATE LOGGED: 03-MAR-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9607.0 TOP LOG INTERVAL (FT): 8735.0 BOTTOM LOG INTERVAL (FT): 9607.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 42.8 MAXIMUM ANGLE: 92.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: ISC 5.06 & 5.07 PCG 3.00/DEP2 2.22a/SP4 TOOL NUMBER PCG 61 6.000 6.0 QUICKDRIL-N 8.70 47.0 9.0 MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MzAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: M~TRIX 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 19000 8.0 .000 .000 .000 .000 .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 3 108.0 First Name Min Max Mean Nsam Reading DEPT 8674.5 9607 9140.75 1866 8674.5 GR 17.6692 301.593 42.157 1743 8674.5 ROP 12.3969 1257.5 108.176 1745 8735 Last Reading 9607 9545.5 9607 First Reading For Entire File .......... 8674.5 Last Reading For Entire File ........... 9607 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/18 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 ....... 98/05/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW 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 FET 9543.5 RPD 9543.5 RPM 9543.5 RPS 9543.5 RPX 9543.5 GR 9545.0 ROP 9605.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10931.5 10931.5 10931.5 10931.5 10931.5 10924.5 10965.0 05-MAR-98 ISC 5.06 & 5.07 PCG 3.00/DEP2 2.22a/SP4 MEMORY 10965.0 9607.0 10965.0 84.7 98.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0935SP4 P0935SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.000 6.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : QUIKDRIL-N 8.80 48.0 9.0 18000 7.8 Dat 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: a 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 .220 .220 .220 .250 .5 DE?T GR RPX RPS RPM RPD ROP FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD 3 API 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 FT/H 4 1 68 MWD 3 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 120.0 Name Min Max Mean Nsam DEPT 9543.5 10965 10254.2 2844 GR 34.1992 141.486 67.4295 2760 RPX 7.5188 2000 63.5849 2777 RPS 7.5757 120.361 55.3679 2777 RPM 7.0355 2000 67.4348 2777 R?D 7.587 2000 91.7509 2777 ROP 11.7345 2253.52 152.913 2721 FET 0.4114 29.344 2.21841 2777 First Reading 9543.5 9545 9543.5 9543.5 9543.5 9543.5 9605 9543.5 Last Reading 10965 10924.5 10931.5 10931.5 10931.5 10931.5 10965 10931.5 First Reading For Entire File .......... 9543.5 Last Reading For Entire File ........... 10965 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10924 0 FET 10924 5 RPD 10924 5 10924 10924 10924 10965 RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5.03 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 EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 11331.5 11338.5 11338.5 11338.5 11338.5 11338.5 11370.0 06-MAR-98 ISC 5.06 & 5.07 PCG 3.00/DEP2 2.22a/SP4 MEMORY 11370.0 10965.0 11370.0 86.9 96.5 TOOL NUMBER P0935SP4 P0935SP4 6.000 6.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 QUIKDRIL-N 8.80 50.0 9.0 18000 6.2 .250 .250 .250 .230 129.0 .5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 RPX MWD 4 OHMM 4 1 68 8 3 RPS MWD 4 OHMM 4 1 68 12 4 RPM MWD 4 OHMM 4 1 68 16 5 RPD MWD 4 OHMM 4 1 68 20 6 ROP MWD 4 FT/H 4 1 68 24 7 FET MWD 4 HOUR 4 1 68 28 8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 10924 43.747 5 7857 5 7901 5 6138 6 4393 7 0177 0 3386 First Max Mean Nsam Reading 11370 11147 893 10924 145.427 75.433 816 10924 110.58 40.2048 829 10924.5 132.539 43.8016 829 10924.5 2000 221.054 829 10924.5 2000 413.726 829 10924.5 2418.75 105.413 811 10965 25.4095 3.9658 829 10924.5 Last Reading 11370 11331.5 11338.5 11338.5 11338.5 11338.5 11370 11338.5 First Reading For Entire File .......... 10924 Last Reading For Entire File ........... 11370 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 ' Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: FILE SUMMARY .5000 3 VENDOR TOOL CODE START DEPTH STOP DEPTH FET 9366.5 10896.0 RPX 9366.5 10896.0 RPD 9372.0 10896.0 RPM 9373.0 10896.0 RPS 9374.0 10896.0 GR 9391.0 10888.5 RAT 9428.5 10927.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5.03 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: 05-MAR-98 ISC 5.06 & 5.07 PCG 3.00/DEP2 2.22a/SP4 MEMORY 10965.0 9607.0 10965.0 84.7 98.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY 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 TOOL NUMBER P0935SP4 P0935SP4 6.000 6.0 QUIKDRIL-N 8.80 48.0 9.0 18000 7.8 .220 .220 .220 .250 120.0 .5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MAD 3 API 4 1 68 4 2 RPX MAD 3 OHMM 4 1 68 8 3 RPS MAD 3 OHMM 4 1 68 12 4 RPM MAD 3 OHMM 4 1 68 16 5 RPD MAD 3 OHMM 4 1 68 20 6 RAT MAD 3 FT/H 4 1 68 24 7 FET MAD 3 HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading Last Reading DEPT 9366.5 10927.5 10147 3123 GR 27.0313 164.382 62.7584 2696 RPX 7.0252 94.9263 40.9844 3060 RPS 7.9283 89.2017 44.637 3045 RPM 7.4256 133.377 59.3345 3047 RPD 8.1495 288.308 84.3416 3049 RAT 152.693 690'1.17 1081.61 2999 FET 0.0074 4.2482 0.28857 3060 9366.5 9391 9366.5 9374 9373 9372 9428.5 9366.5 10927.5 10888.5 10896 10896 10896 10896 10927.5 10896 First Reading For Entire File .......... 9366.5 Last Reading For Entire File ........... '10927.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 10748.0 11306.0 RPM 10748.5 11306.0 RPS 10748.5 11306.0 RPX 10749.5 11306.0 GR 10749.5 11298.5 RAT 10776.5 11337.5 FET 10956.0 11306.0 $ LOG HEADER DATA DATE LOGGED: 06-MAR-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 & 5.07 DOWNHOLE SOFTWARE VERSION: 5.03 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 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 PCG 3.00/DEP2 2.22a/SP4 MEMORY 11370.0 10965.0 11370.0 86.9 96.5 TOOL NUMBER P0935SP4 P0935SP4 6.000 6.0 QUIKDRIL-N 8.80 50.0 9.0 18000 6.2 .250 .250 .250 .230 129.0 .5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MAD 4 API 4 1 68 4 2 RPX MAD 4 OHMM 4 1 68 8 3 RPS MAD 4 OHMM 4 1 68 RPM MAD 4 OHMM 4 1 68 RPD MAD 4 OHMM 4 1 68 RAT MAD 4 FT/H 4 1 68 FET MAD 4 HOUR 4 1 68 12 16 20 24 28 Name Min Max Mean Nsam DEPT 10748 11337.5 11042.8 1180 GR 31.6327 164.496 67.5231 1099 RPX 6.2739 84.5488 35.9469 1114 RPS 6.462 70.9426 40.4221 1116 RPM 6.4325 236.584 59.2407 1116 RPD 7.5064 2000 117.142 1117 RAT 221.88 6278.91 544.511 1123 FET 6.1322 20.8413 14.1799 701 First Reading 10748 10749.5 10749.5 10748.5 10748.5 10748 10776.5 10956 Last Reading 11337.5 11298.5 11306 11306 11306 11306 11337.5 11306 First Reading For Entire File .......... 10748 Last Reading For Entire File ........... 11337.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/05/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/05/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
