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198-106
Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2025 InspectNo:susSTS250729155610 Well Pressures (psi): Date Inspected:7/26/2025 Inspector:Sully Sullivan If Verified, How?Other (specify in comments) Suspension Date:8/16/2011 #311-248 Tubing:73 IA:250 OA:75 Operator:Hilcorp North Slope, LLC Operator Rep:Andy Ogg Date AOGCC Notified:7/25/2025 Type of Inspection:Subsequent Well Name:PRUDHOE BAY UN PBU L2-18A Permit Number:1981060 Wellhead Condition Clean, valves operated okay, no signs of leaks Surrounding Surface Condition Clean and debris free Condition of Cellar No sign of contaminents or subsidence Comments Location verified by plot map Supervisor Comments Photos (4) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, September 15, 2025 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 2025-0726_Suspend_PBU_L2-18A_photos_ss Page 1 of 2 Suspended Well Inspection – PBU L2-18A PTD 1981060 AOGCC Inspection Rpt # susSTS250729155610 Photos by AOGCC Inspector S. Sullivan 7/26/2025 2025-0726_Suspend_PBU_L2-18A_photos_ss Page 2 of 2 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU L2-18A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-106 50-029-21766-01-00 14070 Conductor Surface Intermediate Liner Liner 8659 80 4083 8262 3012 3127 10500 20" 13-3/8" 9-5/8" 7" 4-1/2" 7747 39 - 119 38 - 4121 36 - 8298 8112 - 11124 10941 - 14068 39 - 119 38 - 3599 36 - 6113 6001 - 8218 8077 - 8659 13968 470 1950 4760 5410 7500 10500, 12015 1490 3450 6870 7240 8430 12065 - 13960 4-1/2" 12.6# L-80 34 - 10949 8702 - 8662 Structural 4-1/2" Baker S-3 Packer 10894 8042 Dave Bjork for Bo York Operations Manager Andy Ogg andrew.ogg@hilcorp.com 907.659.5102 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028321, 0028322 34 - 8083 N/A N/A 250 250 0 73 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 10894, 8042 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Gavin Gluyas at 1:08 pm, Aug 14, 2025 Digitally signed by David Bjork (3888) DN: cn=David Bjork (3888) Date: 2025.08.14 12:27:23 - 08'00' David Bjork (3888) J.Lau 11/4/25 RBDMS JSB 081825 ACTIVITY DATE SUMMARY 7/26/2025 T/I/O = 75/250/75. Temp = SI. AOGCC SU well inspection (AOGCC witnessed by Sully Sullivan). Pictures taken. SV = C. WV = LOTO. SSV = C. MV = O. IA, OA = OTG. 09:45 Daily Report of Well Operations PBU L2-18A Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:198-106 6.API Number:50-029-21766-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028322 & 0028321 Property Designation (Lease Number):10. N/A 8. PBU L2-18A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspended Well Rene Op Shutdown GAS GSTOR WAG SPLUG Abandoned Oil WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 14070 Effective Depth MD: L-80 11. Commission Representative: 15. Suspended 5 Contact Name: Oliver Sternicki Contact Email: oliver.sternicki@hilcorp.com Authorized Name: Bo York Authorized Title:Sr Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8659 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend 5 Plug for Redrill Perforate Perforate New Pool 10894/8042 , 10949/8083 No SSSV Installed Date: Liner 3127 4-1/2" 10941 - 14068 8077 - 8659 8430 7500 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 38 - 4121 38 - 3599 14. Estimated Date for Commencing Operations: BOP Sketch 39 - 119 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" BKR S-3 PKR, 4-1/2" BKR ZXP None None 4-1/2" 12.6# L-80 34 - 10949 Liner 10500 7747 10500 13968 39 - 119 470 13-3/8" 9-5/8" Contact Phone:(907)564-4891 Date: 4760 80 149020"Conductor 1950 / 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 4083 3450 / 5380 Intermediate 8262 36 - 8298 36 - 6113 3012 7" 8112 - 11124 6001 - 8218 7240 5410 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 3:08 pm, Jun 28, 2021 321-318 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.06.28 14:50:29 -08'00' Bo York MGR02JUL21 X DLB 06/28/2021 DSR-7/23/21 dts 7/23/2021 JLC 7/23/2021 10-404 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.23 12:25:19 -08'00' RBDMS HEW 7/26/2021 Hilcorp North Slope, LLC Bo York, PBE Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 06/09/2021 Mr. Jeremy Price Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Well L2-18 (PTD #198106) Application for Renewal of Existing Suspension (10-403) Dear Mr. Price, An AOGCC witnessed suspended well inspection of Prudhoe Bay well L2-18 was conducted on 06/09/2020 (20 AAC 25.110 (h)). The submitted suspended well inspection reflects the current condition of the well (reference 20 AAC 25.110 (f)) and supports the request for renewal of suspension. Recent events from this well indicate that this well is mechanically sound. Specific attachments include: x Wellbore diagram illustrating the current configuration of the well. x Suspended Well Site Inspection form documenting the pressures and site condition. Prudhoe Bay well L2-18 was suspended on 09/07/2011. It is located on a pad with active wells and/or service wells. The strata through which the well was drilled is neither abnormally geopressured or depleted. The well is mechanically sound and secured with a passing MIT-T on 09/07/2011. Based on these conditions and the inspection on 06/09/2020 Prudhoe Bay well L2- 18 meets the provisions required in 20 AAC 25.110 (a)(1). Hilcorp North Slope, LLC requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10-403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h)). In summary, Hilcorp believes Prudhoe Bay well L2-18 is mechanically sound and secure and meets the requirements for renewal of suspended status. If you have any questions, please call me at 907-777-8345 or Ryan Holt/ Andy Ogg at 659- 5102. Sincerely, Bo York PBE Operations Manager Attachments Technical Justification 2020 Suspended Well Site Inspection form Wellbore Schematic Prudhoe Bay Well L2-18 (PTD #198106) Technical Justification for Renewal of Suspended Status 06/09/2021 Well History and Status Prudhoe Bay well L2-18 (PTD #198106) was a not operable, LTSI well with TxIA communication at 10824’, a PC leak at ~3300’ and a tubing restriction also at ~3300’. In 2011 the well was suspended due to it needing to be secured for anti-collision purposes when drilling the production hole for well 18-12C (PTD #210092). L2-18 was suspended on 09/07/2011 with the TOC in the tubing at 10500’ and TOC in the IA at 10286’. The well is mechanically sound and secured with a passing MIT-T on 09/07/2011 proving the integrity of the cement top at 10500’ MD and the 4-1/2” tubing. The well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, and is secure, safe and not a threat to public health. The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of the Wellhead and Surface Location Prudhoe Bay well L2-18 is located on an active, well maintained pad with clean gravel. The pit and surrounding area are in good condition. There is no discoloration and no sheens on the pad, pits, or in nearby water. The well pressure readings are T/I/O = 0/250/50 psi. Request Hilcorp North Slope, LLC requests approval for renewal of the existing suspension status for L2- 18. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:198-106 6.50-029-21766-01-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 14070 10500 7747 10894 13968 10500, 12015 8042 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 39 - 119 39 - 119 1490 470 Surface 4083 13-3/8" 38 - 4121 38 - 3599 3450 / 5380 1950 / 2670 Intermediate 8262 9-5/8" 36 - 8298 36 - 6113 6870 4760 Liner 3012 7" 8112 - 11124 6001 - 8218 7240 5410 Perforation Depth: Measured depth: None feet True vertical depth: feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 34 - 10949 34 - 8083 10894 8042Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Liner 3127 4-1/2" 10941 - 14068 8077 - 8659 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Suspended Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Sternicki, Oliver R Oliver.Sternicki@bp.com Authorized Name:Lastufka, Joseph N Authorized Title: Authorized Signature with Date:Contact Phone:+1 907 564 4301 Treatment descriptions including volumes used and final pressure: 13. SIM Specialist Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP 5 SPLUG 16. Well Status after work:Oil Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8659 Sundry Number or N/A if C.O. Exempt: N/A Junk Packer Printed and Electronic Fracture Stimulation Data 5 Suspend Inspection Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 0028322 PBU L2-18A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Jody Colombie at 3:12 pm, Jun 26, 2020 Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.06.24 10:26:33 -08'00' , ADL 0028321 RBDMS HEW 6/29/2020 SFD 7/2/2020 MGR29JUN20 SFD 7/2/2020DSR-6/26/2020 ACTIVITYDATE SUMMARY 6/4/2020 T/I/O = 20/290/80. Temp = SI. Pre AOGCC SU Inspection. No AL. Area around well is clean, dry, and free of debris. Wellhead and tree are clean. Cellar gravel is dry and free of debris. Well ID sign installed on front of wellhouse. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:50 6/9/2020 T/I/O = 0/250/50. Temp = SI. SU well inspection (AOGCC witnessed by Bob Noble). No AL. Pictures taken. SV, WV, SSV = C. MV = O. IA, OA = OTG. 1030. Daily Report of Well Operations PBU L2-18A Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Prudhoe Bay Unit L2-18A Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 1981060 API Number: Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 9/7/2011 Surface Location: Section: 18 Twsp: T11N Range: 15E Nearest active pad or road: L2 Pad Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: OK Pad or location surface: OK Location cleanup needed: None Pits condition: OK Surrounding area condition: OK Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Photographs taken (# and description): See Folder Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: See pictures in folder Cellar description, condition, fluids: Dry Gravel Rat Hole: None Wellhouse or protective barriers: Yes Well identification sign: Yes Tubing Pressure (or casing if no tubing): 0 Annulus pressures: 250 / 50 Wellhead Photos taken (# and description): See Folder Work Required: None Operator Rep (name and signature): Ryan Moore AOGCC Inspector: Bob Noble Other Observers: Randy Mork / Jeff Curren Inspection Date: 6/9/2020 AOGCC Notice Date: 6/8/2020 Time of arrival: 10:45 AM Time of Departure: 10:55 AM Site access method: Truck 5002921766-01 Re-Inspection Suspended Well Inspection Review Report InspectNo: susRCN200609164207 Date Inspected: 6/9/2020 Inspector: Bob Noble Type of Inspection Well Name: PRUDHOE BAY UN PBU 1-2-18A Permit Number: 1981060 Suspension Approval: Sundry 4 311-248 Suspension Date: 8/16/2011 Location Verified? 2 If Verified, How? Other (specify in comments) — Offshore? ❑ Subsequent , Date AOGCC Notified: 6/8/2020 Operator: BP Exploration (Alaska) Inc. Operator Rep: Ryan Moore Wellbore Diagram Avail?❑ Photos Taken? ❑O Well Pressures (psi): Tubing: 0 Fluid in Cellar? ❑ IA: 250 BPV Installed? ❑ OA: 50 VR Plug(s) Installed? ❑ Wellhead Condition Flow line was attached but locked out on the wing valve. All other lines were blinded. SSV had to be pumped open to get tubing pressure. Condition of Cellar Full of gravel. Surrounding Surface Condition Good clean gravel. - Comments Location was Verified with the use of a pad map. Supervisor Comment, Photos (3) ✓ Friday, June 19, 2020 LU a co �z � 0 - r r o� r Y Q �o 00 x 10 Ci `r 0 '003 C'i Q0 chcv �Z raW �o F- 0, o. 0 Qo Z a UH - w 00 of a J W Z = W M i C M.2 U W W a o a:Q= 0 zuj 2 CD 0(D W Zn �W vU) 3aaMm c d O Q cn p Lnc �i U_Do In �: (D C) C)(V CL O O N o mo Nm cA Q d co N a 4. s. OIL— *41 STATE OF ALASKA ' ',ALASKA OIL AND GAS CONSERVATION COMM N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Suspend Well WI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 198-106 3. Address: P.O.Box 196612 Anchorage, Development I Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21766-01-00 7. Property Designation(Lease Number): ADL 0028322 8. Well Name and Number: PBU L2-18A 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 14070 feet Plugs measured 10500/12015 feet r°Il l7 t, r C r) true vertical 8659 feet Junk measured 13968 feet Effective Depth: measured 10500 feet Packer measured See Attachment feet true vertical 7747 feet Packer true vertical See Attachment feet ! w. ,Jr Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 39-119 39-119 1490 470 Surface 4077 13-3/8"72#L-80 38-4115 38-3596 4930 2670 Intermediate Production 8307 9-5/8"47#L-80 36-8343 36-6140 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 12065-12105 feet 12447-12490 feet 12490-13040 feet 13040-13078 feet 13112-13130 feet 13130-13380 13380-13420 feet 13602-13960 feet True vertical depth: 8702-8706 feet 8699-8697 feet 8697-8688 feet 8688-8687 feet 8686-8685 feet 8685-8679 8679-8681 feet 8675-8662 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 34-10948 34-8082 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): NOVeatment descriptions including volumes used and final pressure: E Y'I NO M� 1 6 201 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 81 1543 0 1530 480 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory ❑ Development m Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP RI SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature feei,l^.''y tet, Phone +1 907 564 4424 Date 8/6/15 / �e- : a,� UG1a2015 Form 10-404 Revised 5/2015 V rL //2-A, A 1 4 Submit Original Only • • Packers and SSV's Attachment PBU L2-18A SW Name Type MD TVD Depscription L2-18A PACKER 8112 6000.64 7" Baker ZXP Packer L2-18A PACKER 10894 8041.57 4-1/2" Baker S-3 Perm Packer L2-18A PACKER 10950 8083.86 4-1/2" Baker ZXP Packer • • Q o O O o c:, .co o � 0 '0 O N LO N- N- U 1 0 0 0 0 0 0 i C7) M N- -4' co M CO r CO h- CO CO • CO O CO C}) N O V r in 00 r r N CO O CO CO CO CO CO a H r � CA 00 CO O I� V M M M O O M CO CO I. co co O co N CO E r - co a- O CA r r 'c C.) o QN 0) CO CO r d' O N CO CO CO CO CO M aO O O O CO O CO CO Q J = d *k NJ CO CO N Al V CU (n _ N t-• OD V o ON LO co r � •c/- 0)O I- O r N = co O M O r O J V cc M Z aO O C .F“-) 00 U 1 U_ O CCEtZ z EtO w w m O D [tz z D 0 O) O J J H • • L Ts U) U co a) v U) }' o C.) co a)• u) II O co ET: C c L O > LL C33 E cv < t E U) O 2 C co U) 2- a N N to O - w _ 2 • d w;.cB 2 E O M i CO o = a) cao eL C a) — N .0 0 -p a) N > -o -o N a) Q- 7 d U N U — 5 O U- O 2 < z LU I- < U) o > o u, N m H U • • Suspended Well Site Inspection Form 5 Year Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT L2-18A Field/Pool: PRUDHOE BAY/PRUDHOE OIL Permit#(PTD): 198106 API Number: 50-029-21766-01 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 9/7/2011 Surface Location: Section: 18 Twsp: 11N Range: 15E Nearest active pad or road L2-Pad Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good, clean active pad Pad or location surface: graded gravel Location cleanup needed' none Pits condition: N/A Surrounding area condition: clean Water/fluids on pad none Discoloration, Sheens on pad, pits or water: none Samples taken: none Access road condition good Photographs taken (#and description). (2) flowline and wellhouse Condition of Wellhead AOGCC requires: 1)a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition. FMC wellhead, CIW tree, clean and functional Cellar description, condition, fluids: back filled gravel, clean Rat Hole: N/A Wellhouse or protective barriers: well house intact Well identification sign: Yes, correct Tubing Pressure(or casing if no tubing): N/A SSV closed Annulus pressures: IA=360 psi, OA=70 psi Wellhead Photos taken (#and description): (2)wellhead and tree Work Required: none Operator Rep(name and signature): Whitney Pettus AOGCC Inspector: Matt Herrera Other rt..- Ryan Hayes Inspection Date: 7/12/2015 AOGCC Notice Date: 7/8/2015 Time of arrival: 9:50 AM Time of Departure: 10:00 AM Site access method: truck • • • wo �° � AoW BWX °: co WW•W wr'NOo1 W+~ 1-, ryI I''r=LJ7r,D�, 0'W i,, OTO0311 'oOh F, O CO N NW]ax, NF. 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'8.---P..-**,1 ;=,.':, -' ,.'..'11..;1441243.4. mj 5 ..4 $ P( ....,41i3n.„.....3.,„„, ,,.. ... ,..,. , , ...... ........... pis L2-18A t WELL: pit ' tat,' . Pmdnoe Bar / t ..}f4. OPEFAOR BP EIp72:76: n(Akukal Inc. '�� API NUM1"5ER 50-026n1-8(:1 -01-00 s igt,R ti ^-' R L�,ynptl $lV 1 4t8sill- RISE .11 &r OFu_W10 PERNlT 1953:'''.18-:°11101:214P 98-706 _ i r F - f 1 ' HaS MAY BE ig r { PRESENT r ¢� iii !1 :4; i )' ani 1._. f x. 1 th ' 4411 i,,, • °•fin.. ~.Icf 71 `) - _ •, _ . • ♦ ^ . k 1 TREE= . 4' CM/ 0 11, SA•NOTES:WELL ANGLE>70°@ 11841 ***PRE- WELLHEAD= FMC SDTRK WELLBORE NOT SHOWN BELOW 8298' (9-5/8" ACTUATOR= BAKER C L2-1 8A CSG WINDOW). ORIG.KB.ELEV = 45' ORIG.BF.ELEV = PRUDHOE BAY KOP= 1500' Max Angle= 95'@ 13582' Datum MD= NA Datum TVD 8800'SS 2234' —14-1/2"CA BAL-0 SSSV NIP, ID=3.813" ( 3355' HRESTRICTION, ID=3.41" 13-3/8"CSG,72#, L-80 BTC, ID=12.347" —I 4115' 1-4 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 3.41" @ 3355' CTM 1 3971 3509 52 MMG DNA' RK 09/22/01 4-1/2" TUBING RESTRICTION 2 8093 5989 53 MMG DMY RK 09/22/01 3 10824 7989 42 KBG-2LS *DMY INT 09/22/01 *GLM#3-DMY COVERED BY CEMENT 9-5/8"X 7"BKR ZXP PKR 1 8112' 10286' —I TOP OF CEMENT-IA (08/27/11) W/6'TIEBACK,ID=7.50" ( , 0 10500' CTMD —I TOP OF CEMENT-TUBING(08/27/11) 9-5/8"X 7"BKR HMC LNR HGR, ID=6.25" — 8126' If • •- •' . ... •,, 9-5/8"MILLOUT WINDOW: START SIDETRACK FROM CMT KO • 'A 4 P• •‘r•-•-•,•,4 PLUG @ 8300'.SEC.WINDOW MILLED FROM 8298'to 8343. 9-5/8"CSG, 47#, L-80,ID=8.681" — 8298' 1— •:Mt n N*:•:44, 2 •:•:.10 10894' —7"X 4-1/2"BKR S-3 PKR, ID=3.875" BKR PKR TIEBACK SLV.ID=5.250" — 10941' '•*•• ••• 10927' 14-1/2"HES X NIP.ID=3.813" 1 1 0,•,• 4-1/2"TBG,12.6#.L80 IBT. 1 10948' •".4-, ••• .0152 bpf. ID=3.958" •••, o••• •••• 1•• ,••• 10949'1-14-1/2"WLEG, ID=3.958" •••• 7"X 4-1/2"BKR ZXP LTP, ID=4.063" 1 10950' I ••• V•••.,' I••• 10949' —I ELMO LOGGED ON??I??/?? •••4 7"X 4-1/2"BKR HMC LNR HGR, ID=4.438" 10955' o•• ••• •• ••• •• ••• ••• ••• o••• ••• o••• ••• o•• ••• •• ••• ••4- 11221' 14-1/2"HES X NIP, ID=3.813" 7"LNR. 26#. L-801ST, .0383 bpf ID=6.276" 1 11124' 1--4 ';a- •• ••• •• ••• ••• ••• o••• ••• •• ••• •• PERFORATION SUMMARY $•••• ••• •••• 11570' —4-1/2" HES X NIP, ID=3.813" REF LOG:NGT 02/27/88 ••••• 0•••••. / ••••••• ••••••• ANGLE AT TOP PERF:83 @ 12065' `•••••< ••••••• . 4,••••••-• Note: Refer to Production DB for historical pen f data 4•••:•••V 12015' CTM —13"BKR IBP SET(06/04/06) SIZE SPEINTERVAL Opn/Sqz DATE ••, ( 13968' —FISH-BOTTOM 9"OF 1" 2-7/8" 4 12065-12105 C 04/16/00 INTERVAL GLV,STA 3, 2-3/4" 4 12447-13078 C 07/28/98 LOST 09/22/01 2-7/8" 4 12490-13040 C 11/27/99 2-3/4" 4 13112-13420 C 07/28/98 2-7/8" 4 13130-13380 C 11/27/99 ft 01 2-3/4" 4 13602-13960 C 07/28/98 1 ..0 PBTD(CTMD) 4-1/2" — 13968' ••• 44 4-1/2"LNR, 12.64. L-80.IBT..0152 bpf, ID=3.958" 1 14068' DATE REV BY COMMENTS DATE REV BY COMMENTS LISBURNE UNIT 04/01/88 ORIGINAL COMPLETION 08/29/11 LLVPJC P&A (08/27/11) WELL: L2-18A 07/30/98 RIG SIDETRACK 01/08/12 PJC DRAWING CORRECTIONS PERIM-No:r1981060 03/25/06 DAV/PJC MIN ID/PERF CORRECTION API No: 50-029-21766-01 05/01/06 JAF/PJC DULL IBP/RESTRICTION©3355' SEC 18,T11N, R15E, 1673'FSL& 1248'FWL 05/31/06 CO/DTM TREE CORRECTION(6/1104) 06/04/06 SRB/PAG SET 3"BKR IBP© 12015' BP Exploration (Alaska) STATE OF ALASKA ALASKA" AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other 0 REPORT OF Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ INSPECTION Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development el Exploratory ❑ .. 198 -1060 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 _ 50- 029 - 21766 -01 -00 8. Property Designation (Lease Number) : 511 9. Well Name and Number: ADLO -c12Sa ) 532 I ( (i'7 Y L2 -18A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 14070 feet Plugs (measured) 12015, 10500 (TOC) feet true vertical 8658.95 feet Junk (measured) 13968 feet Effective Depth measured 10500 feet Packer (measured) 8112 10894 10950 feet true vertical 7746.92 feet (true vertical) 6001 8042 8084 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 30 - 110 30 - 110 1490 470 Surface 4086' 13- 3/8 "72# L -80 29 - 4115 29 - 3596 4930 2670 Production 8315' 9 -5/8" 47# L -80 28 - 8343 28 - 6140 6870 4760 Liner 3012' 7 "26# L -80 8112 - 11124 6001 - 8218 7240 5410 Liner 3127' 4 -1/2" 12.6# L -80 10941 - 14068 8077 - 8659 8430 7500 Liner Perforation depth: Measured depth: SEE ATTACHED - _ , N,,;0 n ,_ 1 _ _ True Vertical depth: _ _ - _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 27 - 10948 27 - 8082 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Packer 8112 6001 4 -1/2" Baker S -3 Perm Packer 10894 8042 4 -1/2" Baker ZXP Packer 10950 8084 RECEIVED 12. Stimulation or cement squeeze summary: OCT 1 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Alaska Oil & Gas Cons. Commission Ancnon p 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SUSPENDED Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ , SUSPD SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na - Joe Lastu Title Petrotechnical Data Technologist Signatu -` Phone 564 -4091 Date 10/13/2011 N RBDMS OCT 1. 7 ZOtt 45 / .0.zo . a Form 10 -404 Revised 10/2010 / Submit Original Only ,moo/ L2 -18A 198 -106 , PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L2 -18A 7/28/98 PER 12,447. 13,078. 8,699.24 8,687.38 L2 -18A 7/28/98 PER 13,112. 13,420. 8,686.37 8,680.91 L2 -18A 7/28/98 PER 13,602. 13,960. 8,675.27 8,661.67 L2 -18A 11/27/99 RPF 12,490. 13,040. 8,697.09 8,687.55 L2 -18A 11/27/99 RPF 13,130. 13,380. 8,685.41 8,678.53 L2 -18A 4/17/00 APF 12,065. 12,105. 8,701.73 8,705.54 L2 -18A 9/16/01 MLK 10,824. 10,825. 7,989.21 7,989.96 L2 -18A 9/16/01 MLK 4,100. 4,101. 3,586.79 3,587.39 L2 -18A 9/16/01 BPS 11,020. 13,960. 8,137.44 8,661.67 L2 -18A 9/21/01 BPP 11,020. 13,960. 8,137.44 8,661.67 L2 -18A 9/24/01 BPS 10,983. 13,960. 8,109.01 8,661.67 L2 -18A 4/5/05 BPP 10,983. 13,960. 8,109.01 8,661.67 • L2 -18A 5/2/05 BPS 12,000. 13,960. 8,692.47 8,661.67 L2 -18A 5/1/06 BPP 12,000. 13,960. 8,692.47 8,661.67 L2 -18A 6/4/06 BPS 12,015. 13,960. 8,695.18 8,661.67 L2 -18A 8/27/11 SPS 10,500. 12,015. 7,746.92 8,695.18 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 1 • L2-18A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 9/22/2011,T/I/0= SSV/350/68. Temp= Si. WHPs (Suspended well). No AL. No floor grating. :SV, WV, SSV= C. MV= 0. IA, OA= OTG. NOVP. 9/23/2011:T/1/0 = 280/350/70. Temp = SI. Suspended well inspection_JAOGCC witnessed tzy M. Herrera). , SV, WV, SSV = C. MV =0. IA & OA = OTG. NOVP. • • Prudhoe Bay Unit L2 -18A, PTD 1981060 Suspended Well Inspection Report BP Exploration Alaska (BPXA) completed a suspended well inspection of PBU well L2- 18A on 9/23/11. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC Inspector Matt Herrara witnessed the inspection. • Wellbore Diagram illustrating the current configuration of the well. • Pad map showing the well location and other wells within '/o mile radius of the surface location. • Photographs showing the condition of the wellhead and surrounding location. Supplemental Information: • L2 -18A was a long term shut in Ivishak horizontal producing well drilled form the Lisburne L2 pad. The well was suspended to secure it for an upcoming sidetrack in the area due to anti - collision concerns. An Application for Sundry Approvals (311 -248) to suspend the well was approved on 8/15/11. A Well Completion or Recompletion Report (10 -407) was submitted 09/15/11 showing the date of suspension to be 09/07/11. • L2 -18A is located on a pad with active producing wells and/or service wells. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • The perforations are isolated with a bridge plug set at 12015' MD with cement placed above to 10500' MD. The tubing passed a pressure test to 2500 psi after the cement plug was set. • L2 -18A has a suspected production casing leak at about 3300'., MLB 9/29/2011 • • Suspended Well Site inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: L2 -18A Field /Pool: Prudhoe Bay /Lisburne Oil Permit # (PTD): 1981060 API Number: 50029217660100 _ Operator: BP EXPLORATION (ALASKA) INC Date Suspended: Surface Location: Section: 18 Twsp: 11N Range: 15E Nearest active pad or road: L2 -Pad T a ke to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good clean gravel pad. Free of standing water, Oil /Chemical sheen and debris Pad or location surface: Clean level gravel -- — Location cleanup needed: No Pits condition: Filled gravel, clean Surrounding area condition: Good Water /fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: N/A —� Access road condition: Good gravel road Photographs taken (# and description): 1 Front of Wellhouse, 1 Back of Wellhouse, 1 Side of Wellhouse w/ Missing Wellhouse sign - -— -- Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: FMC wellhead w/ OCT valves in good condition, function tested. Cameron Tree w/ Cameron vales in good condition. function tested Cellar description, condition, fluids: Clean gravel cellar, 18" depth, fee of fluids. Rat Hole: None Wellhouse or protective barriers: Wellhouse shelter _ Well identification sign: None. Broken off _ Tubing Pressure (or casing if no tubing): 280 psi Annulus pressures: IA = 350 psi, OA = 70 psi Wellhead Photos taken (# and description): 1 wellhead and valves, 1 Tree and valves —__ — Work Required: Replace wellhouse sign Operator Rep (name and signature): Gerald Murphy AOGCC Inspector: Matt Herrara Other Observers: Jon AA Inspection Date: 9/23/2011 AOGCC Notice Date: 9/21/21 1 _ Time of arrival: 12:45 PM Time of Departure: 1:30 PM Site access method: Truck TREE= 4" CIW SAFETY NOOPRE -SDTRK WELL BORE NOT SHOWN WELLHEAD= FMC BELOW DEG. @ 11841' & GOES HORIZONTAL @ 12190'. S ACTUATOR= BAKER C L2-1 8A 70 KB. ELEV = 50.83' BF. ELEV = PRUDHOE BAY KOP = 1500' Max Angle = 95 @ 13582' Datum MD = NA Datum WD 8800' SS I 2234' H4-1/2" CA BAL -O SSSV NIP, ID = 3.813" 3355' H RESTRICTION, ID = 3.41" I 13- 3 /8 "CSG, 72 #, L -80 BTC, ID = 12.347" H 4115' ■ 1 GAS LIFT MANDRELS Minimum ID = 3.41" @3355' CTM ST MD TVD DEV TYPE VLV LATCH PORT DATE TUBING RESTRICTION E 1 3971 3509 52 MMG DMY RK 09/22/01 2 8093 5989 53 MMG DMY RK 09/22/01 3 10824 7989 42 KBG -2LS `DMY INT 09/22/01 9 -5/8" X 7" BKR ZXP PKR -I 8112' * GLM #3 - DMY COVERED BY CEMENT W/ 6' TIEBACK, ID = 7.50" 10286' H TOP OF CEMENT -IA (08/27/11) I 9 -5/8" X 7" BKR HMC LNR -I 8126' ►li 10500' CTMD_I -J TOP OF CEMENT- TUBING (08/27/11) 1 !, HANGER, ID = 6.25" �, ITOP OF 7 "LNR 8133' ■�■ 9 -5/8" MILLOUT WINDOW: START SIDETRACK FROM CMT KO ■•! ►-� �-�'�• / PLUG @ 8300'. SEC. WINDOW MILLED FROM 8298' to 8343'. 9 -5/8" CSG, 47 #, L -80, ID = 8.681 " I 8298' I ►�� ► ►��►�� :*10 I 10894' I -17" X 4 -1/2" BKR S -3 PKR, ID = 3.875" I ITOP OF BKR PKR TIEBACK SLV, ID = 5.250" H 10941' ;���:* ∎•�• 1092 — I4 -1/2" HES X NIP, ID = 3.813" 1 4-1/2" TBG,12.6 #, L80, IBT, 10948' .•••• • 0.0152 bpf, ID = 3.958" ► • � • � • k:•:•: ° 10949' I -14 -1/2" WLEG, ID = 3.958" I 7" X 4-1/2" BKR ZXP LNR TOP PKR, ID = 4.063" H 10950 / ►�•�•�i ■ I 10949' H ELMD LOGGED ON ? ? / ? ? / ?? I V/ 17" X 4 -1/2" BKR HMC LNR HANGER, ID = 4.438" H 10955' TOP OF 4-1/2" LNR H 10963' ►�•�•�• V.� 11221' H4 -1/2" HES X NIP, ID = 3.813" I 7" LNR, 26 #, L -80 , IBT, 0.0383 bpf , ID = 6.276" 1 11124' ►•i•i•i ► ►�OOi I ►�OOi • 1 ►OOi •••■ •j •j •jk 11570' — I4 -1/2 HES X NIP, ID = 3.813" 1 PERFORATION SUMMARY • `�•j•••••••• • < 12015' CTM 1-13" BKR IBP SET (06/04/06) 1 REF LOG: NGT 02/27/88 `•�•�•�•�• �. ANGLE AT TOP PERF: 83 @ 12065' f •'%/' I 13968' I- FISH - BOTTOM 9" OF 1" Note: Refer to Production DB for historical perf data INTERVAL GLV, STA 3, SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 4 12065 -12105 C 04/16/00 LOST 09/22/01 2 -3/4" 4 12447 -13078 C 07/28/98 2 -7/8" 4 12490 -13040 C 11/27/99 '�''' I PBTD (CTMD) H 13968' 2 -3/4" 4 13112 -13420 C 07/28/98 .. .. ..t* 2 -7/8" 4 13130 -13380 C 11/27/99 4. 2 -3/4" 4 13602 -13960 C 07/28/98 1 4-1/2" LNR, 12.6 #, L- 80,IBT,.0152 bpf , ID = 3.958"1—I 14068' I DATE REV BY COMMENTS DATE REV BY COMMENTS LISBURNE UNIT 04/01/88 ORIGINAL COMPLETION 03/25/06 DAV /PJC MIN ID/ PERF CORRECTION WELL: L2 -18A 07/30/98 RIG SIDETRACK 05/01/06 JAF /PJC PULL IBP/ RESTRICTION @ 3355' PERMIT No: 201 -1270 09/22/01 TMN/KK FISH; DMY GLVS; SET IBP 05/31/06 CO /DTM TREE CORRECTION (6/13/04) API No: 50- 029 - 21766 -01 05/03/05 WJH/PJC PULL IBP @ 10990' (4/5/05) 06/04/06 SRB /PAG SET 3" BKR IBP @ 12015' SEC 18, T11 N, R15E, 1672' NSL & 3694' WE_ 05/03/05 SRB /PJC 3" BKR IBP @ 12000' 08/29/11 LLVPJC P&A (08/27/11) 12/13/05 AS/TLH CORRECTION (PRUDHOE WELL) BP Exploration (Alaska) z H --160' o I D 33 32 3p ■ ■° 2g ■ 25 26 • �v 24 • 2 • \ � 21 20 ■ - 1 CO 0 IF o 0.8.11N , v:\ I \\ I 16 • � \\' 13 14 • J. 11 10 • 1 ► \ \ / —8 ■ I I t \ \ t • -/ '� \v - - , 6 O • ■ 3 C I i Co 0 >---11 0 41 ... 1 ,•(,,_ _ail l i r er /Exit ) — 1 'i $ 0 (----'\- \ I 1 1 -N I'........... 4902 -F I • ` Cr) 14 9 ' _ 0 49 -- -' I 08 i - • ; A, WELL PRODUCER • or ❑ WELL INJECTOR • DATE : 12/2/2010 SCALE : 1" = 200' MAP DATE : 2010 PBU - DSL2 WELL SLOT W /CONDUCTOR bs14495.mxd July 6, 2011 I Approximate Scale: 1"=300' 2011- 19c -5 -21 y ' aerometr t r - - �' . mss_: v ,... --.. -- jie r, , ,. , ' p 4. • . y J' `w' t 9 f -�, 1 '" r ;Yf - 4 4 --f. 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Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: _ Zero Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: BP Exploration (Alaska) Inc. Aband.: 9/7/2011 198 -1060 311 -248 3. Address: P.O. Box 196612 6. Date Spudded: 13. API Number: Anchorage, AK 99519 -6612 7/10/1998 50- 029 - 21766 -01 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1673' FSL, 1248' FWL, SEC. 18, T11N, R15E, UM 7/22/1998 L2 -18A Top of Productive Horizon: 8. KB (ft above MSL): 50.83 15. Field /Pool(s): 2712' FSL, 3276' FWL, SEC 17, T11N, R15E, UM GL (ft above MSL): 13.7 Prudhoe Bay Field /Prudhoe Oil Pool Total Depth: 300 f 73 16, 9. Plug Back Depth(MD +TVD): ct � 2 46 SL, 346.9 WL, SEC'teZ T11N, R15E, UM 10500 7747 (• 4b. L cation of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 692690.19 y- 5963572.45 Zone- 4 14070 8659 ADL- 028321 & 028322 TPI: x- 699878.2 y- 5964793.49 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 702045.28 y- 5965148.25 Zone- 4 None 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1900' (Approx) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re- drill /Lateral Top Window MD/TVD: MWD, GR, RES, DIR, DD, RES /AIT, DT /BHC, CNL, LDL, GR, CALIPER, SP, MRES 8298' / 6677' 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 SURFACE 110' SURFACE 110' 30" 1850# POLESET 13 -3/8" 68#/72# K- 55/L -80 SURFACE 4115' SURFACE 3596' 17 -1/2" 300 SX ASIII, 500 SX 'G', TOP JOB W/ 175 SX AS I 9 -5/8" 47# L -80 SURFACE 8298 SURFACE 6112' 12 -1/4" 900 SX CLASS 'G' 7" 26# L -80 8112 11124 6001' 8218' 8 -1/2" 501 SX CLASS 'G' 4 -1/2" 12.6# L -80 10941 14068 8077' 8659' 6" 375 SX CLASS 'G' 24. Open to production or injection? Yes ❑ No 0 If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4 -1/2 ", 12.6# L -80 10949' 10894'/8042' RECEIVE 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ��P ��� DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10500 -12015 33.5 BBL 15.8 PPG CLASS G CEMENT Alaska ©i1 & Gas Cons. Commission Anchor ae 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): NOT ON PRODUCTION N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate . 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No IS If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. g t P '' ;< !"# i ° k. t., tt �r '1 11; RBDMS SEP 19 2011 hl Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE Submi original only • • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? U Yes U No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, Permafrost - Top and submit detailed test information per 20 AAC 25.071. Permafrost - Base Shublik 11108' 8206' Sadlerochit/Zone 4 11166' 8251' Zone 3 11314' 8363' Zone 2C 11394' 8419' Zone 1B 11694' 8593' TDF /Zone 1A 11864' 8661' Base of Sadlerochit 12128' 8707' Formation at total depth: 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Joe Lastufka Printed Na , - •e Last k A, I Title: Petrotechnical Data Technologist Signatu - Phone: 564 -4091 Date: 9/15/2011 I INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 • • L2 -18A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY UT' A 17, frfFrr;fIVS,Wg,Tspb; 8/26/2011; CTU #9 w / 1.75" ct: Job objective P &A: «< Job in progress »> 8/27/2011;CTU #9 w/ 1.75" OD CT. Objective: P &A. Continued from WSR 08/26/11. Wait for well support to RU hardline. MIRU CTU. MU and RIH w/ 2.1" OD BDJSN. Laid in 33.5 bbls of 16 # cement and got 23 bbls of returns. The estimated cment top is @ 10500' Pumped 27 bbls of 50/50 Methanol down BS. RDMO «< Job complete »> 9/7/20111T/I/O= 700/350/180 Temp.= SI MIT -T PASSED to 2500 (P &A For Drillby) First test. -Tbg pressured up to 2550 with 2.5 bbls diesel. Tbg lost 111 psi in the 1st 15 min and ;62 psi in second 15 min for a total pressure loss of 173 psi in 15 mins. Second test - 'Tbg pressured up to 2502 psi with .17 bbls diesel. Tbg lost 42 psi in the 1st 15 mins and 30 psi in 2nd 15 min for a total pressure loss of 72 psi in 30 mins. Monitored additional 15 minutes and lost 21 psi. Third test - Tbg pressured up to 2514 psi with :0.06 bbls diesel. Tbg lost 19 psi in 1st 15 mins and 17 psi in 2nd 15 mins for a total = pressure Toss of 36 psi in 30 mins. Monitored additional 15 minutes and lost 13 psi. Fourth test - Tbg pressured up to 2527 psi with 0.04 bbls diesel. Tbg lost 17 psi in 1st '15 mins and 10 psi in 2nd 15 mins for a total pressure loss of 27 psi in 30 mins. Monitored additional 15 minutes and lost 8 psi. Bled Tbg to 50 psi. Getting gas back at 640 psi. - bled to bleed tank. Fifth test - Tbg pressured up to 2506 psi with 2.16 bbls diesel. Tbg lost 105 psi in 1st 15 mins and 40 psi in 2nd 15 mins for a total pressure loss of 145 psi in 30 mins. Bled Tbg. FWHP's= 450/360/180. Valves in following positions - and operator notified of positions and result of job: Wing closed, Swab closed, SSV open, Master open, IA open, OA open - Well SI FLUIDS PUMPED BBLS 10 1% SLICK KCL 27 50/50 METH 33.5 15.8 PPG CLASS G CEMENT 6 DIESEL 76.5 TOTAL TREE= 4" CIW 0 SAFETY N PRE -SDTRK WELL BORE NOT SHOWN ` WELLHEAD= FMC BELOW 8298 (9 -5/8" CSG WINDOW). WELL EXCEEDS • ACTUATOR= BAKER C L2-1 8 A 70 DEG. © 11841' & GOES HORIZONTAL © 12190'. KB. ELEV = 50.83' BF. ELEV = PRUDHOE BAY KOP = 1500' - Max Angle = 95 @ 13582' Datum MD = NA Datum 6860.5-T I 2234' H4 -1/2" CA BAL -O SSSV NIP, ID= 3.813" I 3355' I — I RESTRICTION, ID = 3.41" 113 -3/8 "CSG, 72 #, L -80 BTC, ID = 12.347" H 4115' LA IL GAS LIFT MANDRELS Minimum ID = 3.41" @3355' CTM ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3971 3509 52 MMG DMY RK 09/22/01 TUBING RESTRICTION 2 8093 5989 53 MMG DMY RK 09/22/01 3 10824 7989 42 KBG -2LS "DMY INT 09/22/01 9 -5/8" X 7" BKR ZXP PKR --I 8112' " GLM #3 - DMY COVERED BY CEMENT W/ 6' TIEBACK, ID = 7.50" 10286' I — I TOP OF CEMENT -IA (08127/11) ( ^ 9 -5/8" X 7" BKR HMC LNR — 8126' �� ∎'' 10500' CTMD I — I TOP OF CEMENT- TUBING (08/27/11) 1 A 4 4 r�.-.� HANGER, ID = 6.25" i . < ►•i i r . J I TOP OF 7 "LNR . 1 - 1 8133 9-5/8" MILLOUT WINDOW: START SIDETRACK FROM CMT KO 41► ♦ � t PLUG @ 8300'. SEC. WINDOW MILLED FROM 8298' to 8343'. (9 518" CSG, 47 #, L -80, ID = 8.681" H 8298' I — ►•� ••••H� CI ��j :*1�e I 10894' H " X 4 -1/2" BKR S -3 PKR, ID = 3.875" 1 'TOP OF BKR PKR TIEBACK SLV, ID = 5.250" H 10941' + � • � • ∎i 10927' — I 4 -1/2" HES X NIP, ID = 3.813" I 4 -1/2" TBG,12.6 #, L80, IBT, — 10948' ' •` • 0.0152 bpf, ID = 3.958" 4., 1Li����� 10949' H4 -1/2" WLEG, ID = 3.958" 1 17" X 4-1/2" BKR ZXP LNR TOP PKR, ID = 4.063" H 10950' •�•�� c . � � * * • * I 10949' I — I ELMD LOGGED ON ? ? / ? ? / ?? 1 17"X 4 -1 /2" BKR HMC LNR HANGER, ID = 4.43$" I- J 10955' �:�:�• ■I TOP OF 4-1/2" LNR I-J 10963' ��* ** 1 1 1221' H4_1/2" HES X NIP, ID = 3.813" I 17" LNR, 26 #, L -80 , BT, 0.0383 bpf , ID = 6.276" H 11124' 44•"t • ♦•♦ •�•j• 11570' —14 -1/2" HES X NIP, ID = 3.813" I PERFORATION SUMMARY •••••••• � 12015' CTM H3" BKR IBP SET (06!04/06) I REF LOG: NGT 02/27/88 ****•:•� ANGLE AT TOP PERF: 83 @ 12065' ''' / / I 13968' I FISH - BOTTOM 9" OF 1" Note: Refer to Production DB for historical perf data INTERVAL GLV, STA 3, SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 4 12065 -12105 C 04/16/00 LOST 09/22/01 2 -3/4" 4 12447 -13078 C 07/28/98 1 PBTD (CTMD) I--I 13968' I 2 -7/8" 4 12490 -13040 C 11/27/99 �11�� • 2 -3/4" 4 13112 -13420 C 07/28/98 •••• •••. 2 -7/8" 4 13130 -13380 C 11/27/99 4. 1 2 -3/4" 4 13602 -13960 C 07/28/98 4-1/2" LNR, 12.6 #, L-80,IBT,.0152 bpf , ID = 3.958" I-I 14068' I DATE REV BY COMMENTS DATE REV BY COMMENTS LISBURNE UNIT 04/01/88 ORIGINAL COMPLETION 03/25/06 DAV /PJC MIN ID/ PERF CORRECTION WELL: L2 -18A 07/30/98 RIG SIDETRACK 05/01/06 JAF /PJC PULL IBP/ RESTRICTION @ 3355' PERMFT No: 201 -1270 09/22/01 TMN/KK FISH; DMY GLVS; SET BP 05/31/06 CO /DTM TREE CORRECTION (6/13/04) API No: 50 -029- 21766 -01 05/03/05 WJH/PJC PULL IBP © 10990' (4/5/05) 06/04/06 SRB /PAG SET 3" BKR IBP @ 12015' SEC 18, T11 N, R15E, 1672' NSL & 3694' WEL 05/03/05 SRB /PJC 3" BKR IBP © 12000' 08/29/11 LLVPJC P&A (08/27/11) 12/13/05 AS/TLH CORRECTION (PRUDHOE WELL) BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. VEC° \I 0 Attn: Well Integrity Coordinator, PRB -20 rt° Post Office Box 196612 10, Anchorage, Alaska 99519 -6612 cti Opp ra dol. August 22, 2011 Co Mr. Tom Maunder ra.. Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA L2 } „ fi 2t)1 S Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA L2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Lisburne 02 Date: 7/7/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal L2 -03A 1980620 500292146501 Top Plate NA NA NA NA NA L2 -06 1830470 500292093000 2" NA 2" NA 0.90 7/7/2011 L2 -07A 2040530 500292291001 14" NA 14" NA 8.50 6/30/2011 L2 -08A 1981400 500292176101 Top Plate NA NA NA NA NA L2 -10 1870850 500292174600 Top Plate NA NA NA NA NA ro.> L2 -11 1980960 500292288500 14" NA 14" NA 6.80 6/30/2011 L2 -13A 1980780 500292144001 Top Plate NA NA NA NA NA L2 -14B 2040950 500292175802 Top Plate NA NA NA NA NA L2 -16 1870970 500292175400 Top Plate NA NA NA NA NA L2 -18A 1981060 500292176601 Top Plate NA NA NA NA NA L2 -20 1851340 500292137600 Top Plate NA NA NA NA NA L2 -21A 2041040 500292148501 Top Plate NA NA NA NA NA L2 -24 1850900 500292134600 Top Plate NA NA NA NA NA L2 -25 1860060 500292152500 Top Plate NA NA NA NA NA L2 -26 1851040 500292135900 Top Plate NA NA NA NA NA L2 -28 1850350 500292129800 62" NA 62" NA 35.70 7/5/2011 L2 -29 1852970 500292150500 Top Plate NA NA NA NA NA L2 -30 1850090 500292127200 Top Plate NA NA NA NA NA L2 -32 1871370 500292177800 Top Plate NA NA NA NA NA L2 -33 1860220 500292153400 Top Plate NA NA NA NA NA • • • stalf,[1 [k SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1'IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Josh Allely Petroleum Engineer Ot fo BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, L2 -18A Sundry Number: 311 -248 AMAX) AUG 1 6 2011 Dear Mr. Allely: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 15 day of August, 2011. Encl. ` • STATE OF ALASKA a t \ cr ALASKA". AND GAS CONSERVATION COMMISSICID eit APPLICATION FOR SUNDRY APPROVALS tao-tt 20 AAC 25.280 As 1. Type of Request: Abandon _i - Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Change Approved Program ❑ Suspend ' Plug Perforations ❑ Perforate0 Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development Exploratory ❑ 198 -1060. 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21766 -01 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ L2 -18A • , -ro :,. 9. Property Designation (Lease Number): 10. Field/Pool(s):° ADLO- 028321 PRUDHOE BAY Field / PRUDHOE OIL Po91, .. 1a °^ , 11. PRESENT WELL CONDITION SUMMARY it � r . �' ; Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): _, , Jun (th tired ' 14070 ' 8658.95- 13968 8661.49 12015 ; r " 13968 Casing Length Size MD TVD Burst 1 ifollapse Structural `# 4,494S`A'i Conductor 80' 20" 91.5# H -40 30 110 30 110 1490 470 4/ Surface 4086' 13 -3/8" 72# L -80 29 4115 29 3596 4930 2670 Production 8315' 9 -5/8" 47# L -80 28 8343 28 6140 6870 4760 Liner 3012' 7" 26# L -80 8112 11124 6001 8218 7240 5410 Liner 3119' 4 -1/2" 12.6# L -80 10949 14068 8083 8659 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# L -80 27 10948 Packers and SSSV Tvoe: 7" Baker ZXP Packer Packers and SSSV MD and TVD (ft): 8112 6001 4 -1/2" Baker S -3 Perm Packer 10894 8042 4 -1/2" Baker ZXP Packer 10950 8084 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 . Service ❑ 14. Estimated Date for 15. Well Status after proposed work: )11_ f` -r Commencing Operations: 8/19/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended 1 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josh Allely Printed Name Josh Allely Title PE Signature Phone Date , c.---'i-t—s---. 564 -5732 8/5/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY ?//2z-/y Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: / 0 - yo7 / APPROVED BY Approved by: i ` COMMISSIONER THE COMMISSION Date: e/ 15/ 1 eDMS AUG 16 N) � � �'ro - n Form 10 -403 Revised 1/2010 M }-(I Submit in Duplicate L2 -18A 198 -106 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L2 -18A 7/28/98 PER 12,447. 13,078. 8,699.24 8,687.38 L2 -18A 7/28/98 PER 13,112. 13,420. 8,686.37 8,680.91 L2 -18A 7/28/98 PER 13,602. 13,960. 8,675.27 8,661.67 L2 -18A 11/27/99 RPF 12,490. 13,040. 8,697.09 8,687.55 L2 -18A 11/27/99 RPF 13,130. 13,380. 8,685.41 8,678.53 L2 -18A 4/17/00 APF 12,065. 12,105. 8,701.73 8,705.54 L2 -18A 9/16/01 MLK 10,824. 10,825. 7,989.21 7,989.96 L2 -18A 9/16/01 MLK 4,100. 4,101. 3,586.79 3,587.39 L2 -18A 9/16/01 BPS 11,020. 13,960. 8,137.44 8,661.67 L2 -18A 9/21/01 BPP 11,020. 13,960. 8,137.44 8,661.67 L2 -18A 9/24/01 BPS 10,983. 13,960. 8,109.01 8,661.67 L2 -18A 4/5/05 BPP 10,983. 13,960. 8,109.01 8,661.67 • L2 -18A 5/2/05 BPS 12,000. 13,960. 8,692.47 8,661.67 L2 -18A 5/1/06 BPP 12,000. 13,960. 8,692.47 8,661.67 L2 -18A 6/4/06 BPS 12,015. 13,960. 8,695.18 8,661.67 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • To: Alaska Oil & Gas Conservation Commission From: Josh Allely bP Wells Group Engineer BP Alaska Date: January 5 2011 Re: PBU L2 -18 Sundry Approval Sundry approval to abandon the production hole interval in well L2 -18 is requested. L2 -18 is a Ivishak horizontal well drilled from L2 (a Lisburne pad). L2 -18 must be secured while the production hole of 18 -12 is drilled during the upcoming sidetrack for anti - collision purposes. L2 -18 is currently a long term SI non - operable well with TxIA communication (via GLM 3 at 10824'), a PC leak at -3300', and a TBG restriction, also at -3300'. L2 -18 currently has an secured with an IBP set above the o•en •erforation 1 ' • • -cause of the current annular communication, can not be pressure tested. We believe the only practical way to secure this well for the drill -by is to lay a cement plug from the IBP up above the leaking GLM 3 at 10824 with CT (TOC at -10,500' MD for total length of 1500' MD and 950' TVD). Independent of the 18 -12 close approach, L2 -18 was already flagged for abandonment, given the integrity issues. 18 -12 is being drilled as a replacement well for L2 -18 giving further justification to abandon the L2 -18 production hole. The final plan for the upper welibore of L2 -18 is still under review. I COW W, gj p !/ Well Information Status: Non Operable Artificial Lift Producer Last Well Test 06/13/2000 (last representative test) Typical Production Rate: 253 bfpd, 0.5 mmscfpd, 3.2% WC at 400 psi WHP and 66F WHT. Max Deviation: 95deg at 13582' and Perf Deviation: 83deg at 12065' md. Min. ID: 3.41: Partially collapsed tubing at 3355' MD Last Downhole Ops: 10/30/09: E -Line RST Log. SIBHP /SIBHT 05/16/06: 3,330 psi and 177degF at 8800' TVD -SS Latest H2S level: N /A; No sample recorded. AnnComm Status: TxIA at GLM 3 at 10824' MD. PC leak at -3500' MD; Not Operable. • • The following describes the work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed cement plug is attached for reference. Planned Work: 1. S — Drift to deviation. Run memory LDL to verify IBP'is holding. 2. C — Lay in 23 BBLS of 15.8 ppg class G cement. Planned TOC at 10500' 3. S — Drift and tag to confirm TOC. 4. F — Pressure test cement 2500 psi. C h[t„,4 - r s f • -'- Josh Allely Wells Group Engineer 564 -5732 (w) C%h t - es 1 350 -7362 (c) PC I e_wc 3 3 At i7 Dan Kara Wells Group Engineering Team Lead 564 -5667 (w) ,/' Y /c 1C 240 -8047 (c) �' . ' • • TREE• 4' CM WELL ..ons SAFETY NOTES: PRISSOTTIK WELLBORE NOT SHOWN FMC \ OnftsvIA S.4.l44t. ACTUATOR- 8AKE1 0 04 a + 6 41% 1_2 - 1 8A SELOW 029r (9-5/r CSO WINDOW). WELL EXCEEDS Ka. ELEV 70 DEG. • 111141' & GOES HORIZONTAL • 121,17. = 50.83' U 1% 13F. EI,EV = PRUDHOE BAY . _ KOP = 1500 Max Anglo • 95 Ci 13587 Datum MD • NA °Mum TVO sa ss 1 223c 1-14-irr CA BAL-0 szsv NF , 0 = 3.813^ I ill r ....---1 3456' HRESTRIC11284 113 =. 3.41• 1 I 13-3/8'CSG. 721, L-80 STC, ID D. 12.347' H 4115' L a. GAS LFT MANDRELS ST OM 1 TVD ter 1W€ VLV LATCM FORT DATE 1 MN ' 3509 52 LIMB ' MY Mt 09/22101 Minimum ID = 341" fj3355° CTM 2 8003 5089 53 IAMG CON MC 00/22/01 ,_,..., TUBING RESTRICTION 1 3 10624 1989 43 IflIG.21.E ow 147 01102,131 9-5/8" X 7" 8KR 2.XP FKR Mir W/ 6 MACK ID = 7.50" 1 9-5/8' X 7' BKR HMG oft ain ■:". f 9 HANGER. D • 6.25" il 940" &CLOUT W91 10118: STAFCT SIDETRACK FROMCIAT KO RUG e bled. 3ED WINDOW /4WD FROM 70P CE rya 6133 7 7 112S6' to 034r. 1 9-5/r CSG, 470, 1-80, ID = 0.681'H 8201 . —I 1084 H 7" X 4-vr NCR 34 p108, r) a 3-a75' I I TOP OF BKR FKR TIEBACK SLV. ID = 5.250' H 10941' 1 1 ---1 ES X NP, ID = 3.81 3' 1 L orr TEIG.12.68, L80. BT. r low 0.0152 bp/, ID .3.9sr i li, 014- 19 WE ir x 4-1/2" BKR 2XP LNR TOPPKR, D • 4.003' 10950' 1 lose' H Eim I 7' X 4-1/2' BKR FRAC LNR PANG. 13 • 4.438' 10165 IMP OF 4.1I? LNR 10063' irlAm.,e,A, -roc- .4. lit Soo 9 o. s • 1 1 — 11221' 1-14-11?Hmx rip, c=3.513- 1 r Lt 261, L-60 , Ea, 0.0383 Dpi, 0 = 6.276" •-1 11124' 11570 H4-1/2" HES X NIRO ...= PERFORATION SUMMARY . 12015' CTM 3' BKR BP SET (06/04/06) REF LOG NOT 02/27/88 , ANGLE AT TOP PEW; 83 • 12065' i I 1 issa. 11F8H- eorro&i r of r Note: Refer to Production CO for historical pen data INTERVAL GLV , STA 3, SEE SFF , INTERVAL Cvn/Sqz DATE 2-710' - 4 12065-12105 C 04/16/00 LOST 09/22/01 2-314" 4 12447.13078 C 07128/98 2-7/0' 4 12400-13040 c 11127/99 ' N. Frac ccrmoll 1396f 74 2-314' 4 1311213420 C 07/28/98 IV ut Io 4, 2-7/8" 4 13130-13380 C 11/27/99 CNA 2-3/4" 4 , 13602-13980 C 07/28/98 q •O 4-11? LNR. 12.6#, L-a0,87,.0152 bpi , ID = 3.958" 14065' I - DATE REV 13Y COMMITS DATE REV DV CONNENTS LISBURNE UNIT . 04101168 ORIGINAL COMPLETION . 03/25/06 DAV/PJC MN ID/ FERF CORRECTION WELL: L218a , D 07130/96 RIG SIDETRACK 05/01/06 JAF/PJC FULL 13P1 RESTRICTION • 3355' RANT Ni : 2_01.-.1211) /1 10(0 09122/01 TNIN/KK FISK OW GLVS; SET EP 05/31/06 C0/CTM TREE 03RRECT)ON (6/13/04) AR No: 50-029-21766-01 06/03/05 W.114TUC PULL BP .i.: 10090' (4/5/05) 06/0406 SRS/PAO SET 3" BKR EIP 6 12015 SEC 18, T1110, RISE, 1672' NM & 3694' WEI. 05/03/05 SFEUPJC r EIKR BP • 12000' 12/13835: AS/R.H ACTION (FRLDHOE WELL' . BP EscplocatIon (Alaska) ' . 1 I Figure 1: Current wellbore schematic as of 08/05/2011 III • TREE= 4 CAN WELLHEAD. FMC SAFETY NOTES: PRE -SOTRK WE LLBORE NOT SHOWN BELOW 029V (e cso WINDOW). ACTUATOR= BAKER 0 Prye'K`A "f'�" N L2 -1 8A 7 OBS. ® 11841' IL GOES HORIZONTAL 0 KB. Eta/ ■ 50.83( BF. B_B/ = PRUDHOE BAY ' M = 1500 . I _ Max (� An81e • 96 1335822' ' Datum MD .1 NA Datum TVD 8800 35 I 2234' 4-1/T CA BAL -O SSSV NIP, D 3.813" RESTRICTION, ID= 3 V 13- 318 "CSG, 729, L-80 BTC, D = 12,34r H 4115' 1-4 GAS UFT MANCRELS ST P.0 1 we ter wee I VLV LATCH' pt71iT DOE 1 3871 3609 52 NAG CA 04/2201 Minimum ID = 3.41" X3355' CTM 2 slow MS • L OW Rx 0002.101 TUBING RESTRICTION iir 3 10824 7989 42 XF10-4LE OW PIT 00(27131 1 x r BE64 ZXF mot el 14' W/ 8' TIEBACK, D= 7.50" 0-5/8' X r BKR FMC LNR BM ..7) 0.1:4 !7-518" MILLDUT WINDOW' START HANGER, D = 6.25" 11 il SDETRACK FROM CMT KO FLUO 8300. SEC. WINDOW MILLED FROM ITOPOF TLNR H 5137 8298' b 8343'. La.ble° eSG, 4T1(!, L-R0. ITJ = 8.4st" 8295' J 1 P Mnru1 TO 4. a. S k � 7 10894' r x a112" BKR 0= 3.875' '1 " : 9 I TOP OF BKR PKR TIEBACK SLV. D = 5.250' 10941' .., 2 ,:, 1092T 4.1 /2'FESXNP, ID = 3.813' I 4. 1/2' 7BG,12,89, L80, ET, 10948' 00152 bpf. ID= 3.D58' ` ' ;'' 1 10045' 4-5/2" V4LEG 17" x4 8KR ZXPLNRTOP PKR D = 4.063' � '� �' r -. '' , - � ' ' 4_ (L i 10949' Km j r X 4 BKR NMC LNR HANGER, D = 4.438' H 10955' ; i 1701 OF 4 -112" LNR Iliallt 4 - -' 11221' 4.1/2" HES X AP, D = 3.813" I r" LNR 264 L -80 , BT, 0,0383 bpf , D • 6,276' 11124' 1, ■. SUMMARY el 1--I4 - 112' ID x NP, D = 3.813' I FERFORATION SLARY '# ( '''. * 12015' CTM I-ILBKR BP SET (06104/06) I REF LOG: MGT 02/27/88 ANGLE AT TOP FERN: 83 re 12065' ' '` (( J I 13158' I✓ FISH- BOTTOM r CFI' Note: Refer to Production CE for histarbaf perf data w NTERVAL Q.V. STA 3. SIZE SPF NTERVAL Opn/Sgz GATE Iii W8T 00/72101 2 -7 /6" 4 12065 -12105 C 04116100 2.3/4" 4 12447 -13078 C 07/18228 6 FBTD(GTbD) 13968' J 2.718" 4 1248013040 C 11/27/99 ` 4 4 2 + 2 -314" 4 13112.13420 C 07f28/98 C i /` •* •� +, 2 -718" 4 13130-13380 G 11/27/99 2 -3/4" 4 13602-13960 C 07/28/88 C37 -C - 5I 4 ) f "Po .p 4-1/2' LNR, 12.54, L- 80.BT..0152 bpf .10 = 1958' 14088' DATE REV BY COMMENTS DATE REV BY COMMENTS LEBLFNE UNIT 04/01f58 ORIGINAL COMPLETION 03/25/06 DAV/PJC MN D/ PERF COFREC110N WELL: L2-18a l 07I30/E18 RIG SIDETRACK 06/01/06 JAF/PJC PULL BR RESTRICTION M 3355' PBEhfT No: 2O1 q / Ip ' / °19 09/22/01_ TMI^YKK FIST{ OMY ewe; 8 TREE bP 05/31/06 CO/DTM TH ECOF3�TL'1N (6/13/04) API No: 50-029-21768-01 06103105 WJWPJC t4JL1 BP 42 10090' (4/5/05) 06/04106 5183/PAG SET 3" BKR BP 42 12015' SEC 18, T11 N. RI5E 1817 NSL S 3694' WE L 05/03/05 SRELPJC 3' 8KR 18P Q 12000' I 12/13/05 AS/11.1-1 XIFIREGTION (PRUDFIOE 11 - BP Exptoretlon (Alaska) Figure 2: Proposed wellbore schematic after placing cement plug in the liner ! • vertical section 6827 — �I b 7327 Planned TOC at 10500' 7827 rK a In T L ` I 8327 IBPat12015 ,mac 40-0 8827 I 5645 6145 6645 7145 7645 8145 8645 9145 vertical section [ft] Figure 3: L2 -18 vertical section view. Page 1 of 2 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, August 11, 2011 3:53 PM To: 'Kara, Danny T'; Allely, Josh (BPXA) Cc: Roby, David S (DOA); Saltmarsh, Arthur C (DOA) Subject: RE: L2 -18A (PTD - 198 -106) Dan, Thank you for the clarification. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Kara, Danny T [mailto:Danny.Kara @bp.com] Sent: Thursday, August 11, 2011 3 :16 PM To: Schwartz, Guy L (DOA); Allely, Josh (BPXA) Cc: Roby, David S (DOA); Saltmarsh, Arthur C (DOA) Subject: RE: L2 -18A (PTD - 198 -106) Guy, most of the L2 -18 well has integrity issues, although there may be some salvage value in the surface casing. We have not yet completed the evaluation of the salvage value of the upper part of this wellbore so we do not yet want to commit to a full P &A to surface. The L2 -18 reservoir abandonment is necessary to protect the close approach drill -by of Prudhoe 18 -12. The L2 -18 reservoir abandonment is a complete separate rig up of equipment from any other work that may be done higher in that well, so there's no lost opportunity at this time. Our intent is to get the reservoir isolated for the sidetrack and address the upper wellbore at a later time. Thanks Dan Danny Kara hitcrcci1tion k- .iuifL•crinc I cam C.citl 564- .5667 (ol ( ice ),-`'_- 1ti- i:U4' i ccli0( --t a -IU (I'a\B lkaradt a.hp co( it From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Thursday, August 11, 2011 11:03 AM To: Allely, Josh (BPXA) Cc: Kara, Danny T; Roby, David S (DOA); Saltmarsh, Arthur C (DOA) Subject: L2 -18A (PTD - 198 -106) Josh, Looking at the procedure for suspending L2 -18A I am curious why you are not going ahead and fully P & A ing the well with cement to the surface since you are already there with Coil tubing? There is a PC leak and you mention that there are no plans for any sidetracks with the well. 8/11/2011 Page2of2 • Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 8/11/2011 �chluanberger NO. 5180 Alaska Data & Consulting Services s y , "' `, � ti, Company: State of Alaska 2526 Gambsll Street, Suite 400 i " =! c v `' ` I Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2538 Attn: Christine Mahnken ATTN: Both 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job M Log Description Date BL Color CD OWDW -SW 83SO -00032 RST/WFL 11/07/09 1 1 L -223 B581 -00014 USIT 10/21/09 1 1 5 -218 85JN -00016 USIT 10/21/09 1 1 L -222 83SO.00031 USIT 11/07/09 1 1 L2 -24 81413 -00079 RST 10*1 109 1 1 1-2 -32 B146-00076 RST 10/30/09 1 1 1.1 -14 AV1H -00029 RST 10127/09 1 1 L2 -18A 8148 -00077 RST 10/30/09 1 1 D-288 AX80-00053 MCNL 10/02/09 1 1 S -228 BBK5 -00008 RST i 10/27/09 1 1 D -24 AWLS -00038 RST 09/27109 1 1 18 -15B AYS4 -00107 RST 10/31/09 1 1 04 -21 ANHY -00115 RST 10/27/09 1 1 1.2-07A AYOO -00047 RST 10/29/09 1 1 OWDW -SW 93SO -00032 RST 11/07/09 1 12- 05APB1 40015441 OH MWOMMD EDIT _ 07/01/07 2 1 06 -21B 08AKA0016 OH MWD/LWD EDIT 07/28/08 2 1 D -16A 09AKA0175 OH M ,-, - EDIT 09/07/09 2 1 L -223 09AKA0081 OH MWD/LWO EDIT 10/10109 2 1 L -223 B581 -00014 CH EDIT PDC USIT 10/21/09 1 S -218 BSJN -00018 CH EDIT POC (USIT) 10/21/09 1 L -222 83So -0003/ CH EDIT PDC (USIT) 11/07/09 1 04 -33A 09AKA0075 OH MWD/LWD EDIT 09/19109 2 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Me. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503.2838 ��f 02/24/09 _~~ ~ ~ SChlu~lbe~g~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~P1~ i ~ i~~~l~' ~~ ~~ N0.5109 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 MPS-43 AZCM-00001 FMI ~+a~r 12/29/08 6L GOIOr 1 GD 1 P2-41 AWL9-00009 SCMT - 01/01/09 1 1 MPS-43 AZCM-00001 SONIC SCANNER / 1y2g/Og 1 1 S-26 AYTU-00014 PRODUCTION PROFILE ~ ~ _~ `~~ 02/16/09 1 1 F-45A AYLF-00018 LDL ~t7?J~ (~~ ~/1~~ 02/24/09 1 1 4-04lf-26 12083416 MEM LDL - (p 02/21/09 1 1 09-34A AZ4D-00005 USIT - ~ 02/07/09 1 1 W-218 11968975 USIT (REVISED) ,•- ~~ / 12/11/08 1 1 L2-18A 11999063 RST ( 11/29/08 1 1 L2-33 11999065 RST 12/07/08 1 1 4-10A/L-28 12017518 RST - 09/26/08 1 1 W-218 11968975 CH EDIT PDC GR (USIT) 12/11/08 1 PLEASE ACKNOWLEDGE RE CEIPT BY SIGNI NG nnln wan lunllmr_ nrac rnnv CA/~Ll TA. -e~.~ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Streel~-$~ite-4i)0'" , Anchorage, AK 995tt8~8 ATTN: Beth Received by: , • i oz/zo/os Schlumberg~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~`1~~~ FED ~ ~O(~~ Wall _In6 dt t nn nncrri nainn NO. 4590 Company: State of Alaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Milne Pt,Endicott,Borealis,Polaris,Lisburne n~ae et r•,.i,.. r•n 18-32A 11968923 SCMT ~ - / 02112/08 1 MPE-12 11978438 MEM INJ PROFILE US. L'-o~US - C3Cc 02/08/08 1 4-14/R-34 11996383 USIT (, 02/12/08 1 V-07 40016096 OH MWD/LWD EDIT '~ - G ~ Lfc 12/04/07 2 1 L1-14 11626482 RST ~ ~- / 1 s"9Y3 05109/07 1 1 L2-18A 11657124 RST ~ 05/10/07 1 1 L2-33 11626484 RST ~ (p - ( `S`[ ~ 05!11107 1 1 G-31A 11962778 RST - V5~( [~ 01!01!08 1 1 V-111 11978439 MEM GLS ~ 02/10/08 1 W-216 12031441 CH EDIT PDC GR (USIT) g 01111/08 1 W-214 40016055 OH MWD/LWD EDIT UZ _ ( 11/15/07 2 1 Y-07A 11962576 USIT ~ 12/18/07 1 C-356 11978432 MEM DDL _ / 01/02/08 1 YLtASt AGRNUWLtUGt KEGEIY I f3Y SIGNING AND RE [~1RNING-UN~.tGOPY EAGN TO: BP Exploration (Alaska) Ina it ~~ Petrotechnical Data Center LRZ-1 '~ 900 E. Benson Blvd. Anchorage, Alaska 99508 ~•a ~~-~ ~~~ ~ ~°,I~~~~ i__ E._3 L, .... _'., CJ ,~ i~4 Date Delivered: ~9 , ,,, ; : ,,: ~~. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by: • ~1 DIViSION OF OiL & GAS . SARAH PA.LiN, GOVERNOR @u&u~ @, &ßÆ@~ DEPARTMENT OF NATURAL RESOURCES 550 WEST 7TH AVENUE, SUITE BOO ANCHORAGE, ALASKA 99501-3560 PHONE: (907) 269-8800 FAX: (907) 269-8938 CERTIFIED MAIL RETURN RECEIPT REQUESTED April 12, 2007 Mark C. Weggeland GPMA Resource Manager BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, AK 99519-6612 Sr;ANNED NOY .0 1 2007 Re: Request to Commingle Production from the Initial Participating Area with Lisburne Participating Area Production ~Cè.<è v,.\~a C.o ~<o ã-~ .~ÖS <>t.Q::. Q.\~O c..a 3>~ \ E . Q't>S Dear Mr. Weggeland: By letter dated April 2, 2007, BP Exploration (Alaska) Inc. (BPXA), as Operator of the Initial Participating Area (IP A) within the Prudhoe Bay Unit (PBU), requested authorization to commingle a portion of the production from the IPA of the PBU with production from the Lisburne Participating Area (LP A) that is processed through the Lisburne Production Center (LPC). r-'"t \ q ¥- \ a <'c Six IPA wells (L2-03A, L2-07A, L2-08A, L2-11, L2-13A, and L2-18A) located on the Lisburne L2 pad are currently connected to DS-18 by a pipeline and processed at FS-I. These six wells are currently cycled on and off, depending on whether their marginal gas oil ratio (GOR) is competitive with lower GOR production at the FS-l processing facility. Because the LPC is not currently gas- constrained, BPXA proposes to re-route this partially shut-in production through the L2 pad to the LPC processing facility and maintain full-time production from these wells. The Division of Oil and Gas (Division) approves BPXA's request to commingle production from the IPA with production ttom the LPA with the following conditions: (a) BPXA shall report production from the six IP A wells at the LPC as IP A production and include it on the 1P A production reports; (b) BPXA shall report these volumes to the Division using selling arrangement number 207002FOOO on the PRUD and PGAS accounting unit oil operator reports (01); (c) production from PBU IPA wells to the LPC shall be determined and allocated in accordance with the GPMA metering and allocation procedures; (d) NGLs removed from gas produced by these PBU ¡PA wells at the LPC shall be accounted for and reported as IPA NGLs; (e) BPXA shall provide the Division the appropriate NGL yield for IP A NGLs produced at the LPC within 10 days of the determination and provide the Division with the mIDual GP~1A NGL allocation update; and (t) the updated Lisburne POD, due in June 2007, shall incorporate a description of operations associated with these six wells. "DeJ'elop, COllserve, alld EIl/UI11Ce Natllral Resources for Presellt alld Fllture Alaskalls. " . . Division of Oil & Gas 4/13/07 ~age 2 of2 A person affected by this decision may appeal it, in accordance with 11 AAC 02. Any appeal must be received within 20 calendar days after the date of "issuance" of this decision, as defined in 11 AAC 02.040 (c) and (d), and may be mailed or delivered to Tom Irwin, Commissioner, DNR, 550 w. th avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1 -907-269-8918, or sent by electronic mail to dnrappeals@dnr.state.ak.us . This decision takes effect immediately. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court. A copy of I] AAC 02 may be obtained from any regional information office of the Department of Natural Resources. If you have any questions regarding this decision, contact Cammy Taylor with the Division at 907- 269-8817. Sincerely, ,/ ~ Kevin R. Banks Acting Director cc: Sherri Gould, BPXA Sam French, BPXA Gary Benson, BPXA Ted Cahalane, BPXA Tim Verseput, BPXA Eric Reinbold, ConocoPhiIlips Gary Forsthoff, Chevron Hank BensmiIler, ExxonMobil John Norman, AOGCC Dave Roby, AOGCC Tom Maunder, AOGCC John Iversen, DOR Cammy Taylor, ONR Jim Stouffer, DNR Jeff Landry, DOL ell Job Log DescriPtion ate B o or 03-36 10831325 CH EDIT PDC GR 08111104 1 MPL-40 98160 OH EDIT MWDILWD (REVISED) 03105/98 4 1 L2-18A 11421036 RST 10114/06 1 1 A-04 11221855 RST 03122106 1 1 06-04A 11320998 RST 08102106 1 1 C-24A 11209609 MCNL 06119106 1 1 P2-57 A 10831796 RST 04129106 1 1 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth W 05/15/07 NO. 4260 ,~<c ··1_-# l L/ u -100 (-:)/3/ Company: State of Alaska Alaska Oil & Gas Cons IComm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay # D L CI CD . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 SCANNED MAY 1 7 2007 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 1- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~\1AY :11, {9 Z007 Received by: Sc~luIII~ergeP ~) , NO. 3880 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Iq~-ID0 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ;V Well Job# Loa DescriDtion Date BL Color CD 15-12A 11211420 R5T GRAVEL PACK 06/25/06 1 11-U1I 11211509 INJE(; nuN pRUFILE 06124106 1 P2-11A 11221564 JEWELRY/STATIC SURVEY 04/27/06 1 13-06A 11217266 INJECTION PROFILE 07/12/06 1 P2-01 11223106 STATIC PRESSURE/JEWELRY 03/25/06 1 L5-08 11217256 PROD PROFILE W/GHOST & DEFT 06/06/06 1 16-04A 11217245 PROD PROFILE W/DEFT 05/08/06 1 05-40 11223123 LDL 07/07/06· 1 17-09 11211412 PROD PROFILE W/DEFT & GHOST 06/26/06 1 MPC-07 N/A SENSA/MEMORY GLS 04122/06 1 04-18 1121584 USIT 06127/06 1 1J·51 11212873 USIT 06/28/06 1 04-31 11217264 USIT 07/07/06 1 D-14A 11217265 USIT 07/09/06 1 PSI-07 10703937 MDT 10/13/03 1 02-16B 11209601 MCNL 04/25/06 1 1 L2....8A 11217234 MCNL 04/06/06 1 1 L5-09 11212847 MCNL 04/25/06 1 1 Z-26A 11216205 MCNL 07/05106 1 1 12-01 11072866 RST 07/06/05 1 1 E-17A 10928602 MCNL (Prints sent 1/24/05) 10/30/04 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 07/19/06 e e Re: L2-18b Subject: Re: L2-18b Date: Wed, 27 Jun 2001 15:45:17 -0800 From: Jane Williamson <Jane_Williamson~admin. state.ak.us> Organization: Alaska Oil & Gas Conservation Commission To: "Stagg, Ted O (ORBIS)" <StaggTO~BP.com> CC: "Gantt, Lamar L" <GanttLL~BP.com>, Julie M Heusser <julie_heusser~admin.state.ak.us>, Thomas E Maunder <tom_rnaunder~admin.state.ak.us> Ted, Thanks so much for the information. This helps alot. Based upon our conversation earlier today, this well is not scheduled for prep work/CT drilling until around Au~Fust, correct? The 403 and 401 application which was recieved on Jun 21 stated start of prep work operation is July 1. If the July 1 date is correct, we need an E-mail to the effect that this is a rush job. 2 weeks minimum (3 preferable) is needed on all applications. Can I also ask that future CT drilling applications.provide a short summary as to the reservoir objective - such as you provided below? Concerning discussion with Julie and me on Friday about the Lisburne CT ST well off K pad, we are available in the morning after 9am. Just give us a shout. I look forward to meeting with you. Please pass this on to John Cubbon as I do not have his E-mail. T~anks again, Jane Williamson AOGCC Petroleum Engineer "Stagg, Ted 0 (ORBIS)" wrote: Jane, I 'ye looked in~o ~his one and. learned several ~hings. L2-18 was a Wahoo producer drilled in 87-88. This well was plugged back to the Ivishak and re-drilled as a lower Zone 1 horizontal producer, L2-lSa, /~z 1998. L2-lSa has been a very low rate oil producer, probably due to most of the well being in the worst lower Zone iA rock. The CTD sidetrack will use a TorqueMaster whipstock to exit the existing L2-18a liner in Zone iA. This whipstock is different from through-tubing whipstocks in that the whipstock consists of a packer and a separate whipstock tray. The packer is set first then the whipstock tray is stung into the packer making the assembly, in effect, a bridge plug in addition to being a whipstock. No further plugging of the existing Zone iA horizontal is needed as everything below the whipstock depth is Zone 1 anyway. L2-78b, the CTD sidetrack, will crosscut Zone iA, exaending up late the lB distributary channels mid-way through the sidetrack. By crosscutting Zone IA we hope to improve productivity over what L2-18a was doing. In summary, there is no reservoir reason for filling the existing L2-18a wellbore in Zone IA with cement. The new sidetrack will be completed with a fully cemented 2 7/8" liner to provide for selective perforating. Please get back to me if there is more we need to provide. 1 of 2 7/24/01 1:54 PM L2-18b Subject: L2-18b Date: Wed, 27 Jun 2001 17:01:00 -0500 From: "Stagg, Ted O (ORBIS)" <StaggTO~BP.com> To: "Jane Williamson (E-mail)" <jane williamson~admin.state.ak.us> CC: "Gantt, Lamar L" <GanttLL~BP.com> Jane, I've looked into this one and learned several things. L2-18 was a Wahoo producer drilled in 87-88. This well was plugged back to the Ivishak and re-drilled as a lower Zone 1 horizontal producer, L2-18a, in 1998. L2-18a has been a very low rate oil producer, probably due to most of the well being in the worst lower Zone IA rock. The CTD sidetrack will use a TorqueMaster whipstock to exit the existing L2-18a liner in Zone iA. This whipstock is different from through-tubing whipstocks in that the whipstock consists of a packer and a separate whipstock tray. The packer is set first then the whipstock tray is stung into the packer making the assembly, in e~ect, a bridge plug in addition to being a whipstock. No further plugging of the existing Zone IA horizontal is needed as everything below the whipstock depth is Zone 1 anyway. L2-18b, the CTD sidetrack, will crosscut Zone IA, extending up into the lB distributary channels mid-way through the sidetrack. By crosscutting Zone iA we hope to improve productivity over what L2-18a was doing. In summary, there is no reservoir reason for filling the existing L2-18a wellbore in Zone lA with cement. The new sidetrack will be completed with a fully cemented 2 7/8" liner to provide for selective perforating. Please get back to me i~ thenze is moze we need to provide. Ted 1 of I 7/24/01 1:52 PM STATE OF ALASKA ALASKA'-~OIL AND GAS CONSERVATION COMN~SION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Pedorate I-I Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack . . Name of Operator BP Exploration (Alaska) Inc. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 1672' NSL, 3694' WEL, SEC. 18, T11 N, R15E, UM At top of productive interval 2716' NSL, 3159' EWL, SEC. 17, T11N, R15E, UM At effective depth 2996' NSL, 84' EWL, SEC. 16, T11N, R15E, UM At total depth 3008' NSL, 173' EWL, SEC. 16, T11N, R15E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service RECEIVED JUN g I 2001 Alaska 0it & Gas Cons. Commission Anchorage 6. Datum Elevation (DF or KB) KBE = 50.83' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number // L2-18A" 9. Permit Number 198-106 '-/"" 10. APl Number 50- 029-21766-01 v/~ 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Casing Present well condition summary v/, Total depth: measured 14070 feet Plugs (measured) true vertical 8659 feet v" Effective depth: measured 13980 feet Junk (measured) true vertical 8661 feet Length Size Cemented MD TVD Structural Conductor 110' 20" 1850# Poleset 110' 110' Surface 4115' 13-3/8" 300 sx AS II I, 600 sx 'G', 175 sx AS I 4115' 3596' Intermediate Production 8298' 9-5/8" 900 sx Class 'G' 8298' 6112' Liner 3012' 7" 501 sx Class'G' 8112'- 11124' 6000'-8218' Liner 3127' 4-1/2" 375 sx Class 'G' 10941' - 14068' 8077' - 8659' Perforation depth: measured 12065'- 12105', 12447'- 13078', 12490'- 13040', 13112'- 13420', 13130'- 13380', 13602'- 13960 true vertical 8702' - 8705', 8699' - 8687', 8697' - 8687', 8686' - 8681', 8685' - 8678', 8675' - 8661' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 10949' Packers and SSSV (type and measured depth) 7" x 4-1/2" Baker 'S-3' packer at 10894'; 4-1/2" Camco 'BaI-O' SSSV Nipple at 2234' 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch 14. Estimated date for commencing operation 15. Status of well classifications as: July 1, 2001 [] Oil [] Gas [] Suspended 16. If proposal was verbally approved Service Name of approver Date Approved Contact Engineer Name~Number: J. ohn Cl,~3~on, ~j~4~4158 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the f/~re~<~/~ is~'¢/~nd correct to the best of mY knowledge ! / Signed / I // I II/I/ Title CT Drilling Engineer Date / /'"' /''' i JohnCubbon[' Conditions of Approval: Notify/~ommission so representative may witness ~$0(~ 9~,. ~,,.'~-,,"~,c.~,4~'~-1~ A .... v ..... -'0./-,~,~ ~/g integrity __ BOP Test ~ Location clearance -I ppru am m'~o. ~[ -- I. Mechanical Integrity Test Subsequent form required 10- t.&(~"~ Approved by order of the Commission .~:~,~._~. ~, .~,fG~ ~1" Commissioner Date $. ~, HTT~[ C ! ''~ ~ ~: ~ Submit In 7riplic'~t-e bp June 12, 2001 To: Attention: Subject: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Tom Maunder Petroleum Engineer Well L2-18B CTD Sidetrack Prep BP Exploration Alaska Inc. Drilling & Wells Coiled Tubing Drilling Team Well L2-18A is scheduled for a through tubing sidetrack to be drilled with coiled tubing. The following summarizes the procedure required to prep L2-18A for drilling and is submitted as an attachment to Form 10-403. A schematic diagram of this proposed completion is attached. t. Tree wing & master valves will be tested. 2. Using slickline, the tubing will be drifted as deep as possible and the gas lift mandrels will be dummied off. 3. The Inner Annulus will be liquid packed and pressure tested. 4. Coil tubing will be used to drift the liner. 5. Using coil tubing, a 4-1/2" through tubing whipstock will be run & set at approximately 12,063'md (8651' TVDss). d. Service coil may then mill a 3.8" window out of the 4-1/2" liner. Slickline and service coil prep work is expected to commence July 1st. Coil tubing drilling operations, as detailed below will commence July 15th, 2001. t. A 3-3A'' sidetrack, -~2000' long will be drilled out of 7" liner into Zone 2. 2. The sidetrack will be completed with a 2-7/8", solid, cemented & perforated liner. John Cubbon CT Drilling Engineer Tel: 564-4158 Fax: 564-551 0 Cell: 240-8040 cubbonjr@bp.com Well File Petrotechnical Data Center Terrie Hubble NOTES: PRE-SDTRK WELLBORE WELLHEAD= FMC L2 18A ACTUATOR= BAKER C KB. ELEV = 50.83' WNDOW). WELL EXCEDS 70 DEG. @ 11841' & GOBS HORIZONTAL @ 12190'. BF. ELEV KOP = 1500' Max Angle = 95 @ 13582' DatumTvDDatumMb= --8800, SS ~ ~ --~ 2:234' H4-1/2"cA BAL-OSSSV NIP, ID=3.813" I : I H 4~' .~ ! GASLFTMAI' DRELS i ST MD TVD DEV TYPE VLV LATCH SIZE DATE : 1 3971 3509 52 IVIVIG DOME RK 1.5" 08108198 Minimum ID = 3.813" @ 2234' 2 8093 5989 53 rVtvIG DOME RK 1.5" 08/08/98 CAMCO BAL-O S$$V NIPPLE '~1-- -- 3 10824 7989 42 KBG-2LS SO INT 1.0" I08/08/98 9_5/8,,X 7- BKR ZXPPKR ~-i 8112' ~ ...... WI6' TIEBACK, ID= 7.50" HANGER, D =6.25" ]- SIDETRACK FROM CMT KO PLUG @ ~ 8300'. SEC. W1SDOW MILLED [ROM ITO~OF 7'~_NR H 8133' ! 8298'to8343'. I 9-5/8" CSG, 47#, L-80, ID = 8.681" H 8298' [~ ~~l 10804' ~7"X4-1/2"BmS-3mR~D=3.875"I 4-1/z'~,12.~#,~80,,ar, ~ 'I0SqS' I~.~X I I-~ ao~2r ~4-112"msxuP,,D=3.8~3"I 17"X4-1/Z'BKRZXPLNRTOPPKR, ID=4.063" H 109§0' ~'--- 17,'c~,2e#,b~0,~r, 0.o383~p~, ~=e.278" I--[ '1~28' ]..al ! !i 11221' H4-1/2"HESX~IRID=3.813'' PERFORATIONSUrv/vIARY I ~1 11570' H4-1/2"HESXNIP, ID=3.813"I / REFLOG: NGT 02/27/88 i ANGLEATTOPPERF: 83 @ 12065' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpWSqz DATETD(CTMD) H 13968' I 2-7/8" 4 12065-12105 O 04/18/00 2- 3/4" 4 12447-13078 O 07/2 8/98 2-7~8" 4 12490-13040 O 11/27/99 2-3~4" 4 13112-13420 O 07/2 8/98 2-7/8" 4 13130-13380 O 11/27/99 2-3~4" 4 13602-13960 O 07/28/98 DATE RL:A/ BY COk~IENTS DATE REV BY COMIVENTS LISBURNE t.~llT 04/01/88 ORJGINAL COMPLETION WELL: L2-18a 01/18/01 SIS-rVH CONVERTEDTOCANVAS PERMITNo: 98-106 03/05/01 SIS-LG FINAL APINo: 50-029-21766-01 07/30/98 RIG SIDETRACK Sec. 18, TllN, R15E, 1672' NSL & 3694' VVEL 08/08/01 CH/KAK CORRECTIONS BP Exploration (Alaska) SIZE SPF INTERVAL OpWSqz DATE 2- 7/8" 4 12065-12105 O 04/1 8/00 2-3~4" 4 12447-13078 O 07/2 8/98 2-7/8" 4 12490-13040 O 11/27/99 2-3~4" 4 13112-13420 O 07/28/98 2- 7/8" 4 13130-13380 0 11/27/99 2-3/4" 4 13602-13960 0 07/28/98 W,EL! J-lEA D= __.? ~TOR~ .......... .? KB. ELEV = 50.83 BF. FIEV = 50.83 ..........................................KOP = '-'~'. ~x'~ngie = ..... 95"@"i358'2 Datum MD = ? ...........................................................................Datum TV D= IMinimum ID = 3,813" @ 2234' CAMCO BAL-O SSSV NIPPLE L2-18B L~ ~rPROPOSED CTD SIDETRAC~-~ 2234' H4-1/2"CA BAL-O SSSV NIP, ID=3.813 I 4115' GAS LIFT MANDRELS 13971I 3509I I MMG I ~°a~l ~S~l I M~ 1108241 7989I I KBG2LS I INT 8126' I 10894' ]q 7" X 4-1/2" BAKERS-3PAKER ] 4-1/2" TBG, 12.6#, L80, 0.0152 bpf, ID=-3.958 Id 10949' J__ ITOPOF 4-1/2" LNR Id 10949' : ;7 TTC. -- ---- / ~ LOG: .N~ I ~te: Refer to ~oduction DB for historical pe~ data ~ S~I~ S~ Ih~{VAL I 4 12(165.12105 4 12,~47.13078 !~~7~~~ ' H ~20s3 SIZE SPF INTERVAL Opn/Sqz DATE 4 12065-12105 O 4/17/00 4 12447-13078 O 7/28/98 4 12490-13040 O 11/27/99 4 13112-13420 O 7/28/98 4 13130-13380 O 11/27/99 4 13602-13960 O 7/28/98 I4-1/2" LNR, 12.6#, L-80, 0.0152 bpf, ID=3.953 --I 10929' H4-1/2" HES X NIP, ,D=3.813 I I 10950' lO95~' 11570' 11800' I 10949' I-t ~-~ I ]--] 5-3/4" X 8 BAKER TIE BACK SLV J--~ 7" X 4-1/2" ZXP LINER TOP PACKER H4-1/2- HES x N,~E, ,~=3.813 I H4-1/2-HES X NIPPLE, ID=3.813 H~o~ o, ~-~-,m~ I 2-7/8" 4.6# L-80 LINER, Cemented & Perforated I-! 14ooo, H 14°68' I ' i~ DATE REV BY COMMENTS 07/30/98 ORIGINAL COMPLETION LAST WORKOV ER 1/18/2001 SIS-MH CONVERTED TO CANVAS 03/15/01 PCP, Proposed CTD Sidetrack PRUDHOE BAY UNIT WELL: L2-18B (Proposed) PERMIT No: 198-106 APl No: 50-029-21766-01 Sec. 16, T11N, R15E, 5105.49 FEL 2271.32 FNL BP Exploration (Alas ka) Well Compliance Report File on Left side of folder 198-106-0 MD 14070 TVD 08659 Microfilm Roll / - PRUDHOE BAY UN PBU L2-18A 50- 029-21766-01 BP EXPLORATION (ALASK A \ ~T~ Completion Date:/.~0/98 Completed Status: 1-OIL Current: Roll 2 / Name D 8829 Interval Sent Received T/C/D SCHLUM PDC/JWL CH 12/22/98 - 1/5/99 D 8868 L DGR/EWR4-MD L DGR/EWR4-TVD L PEX-CNL L PEX-HAL PEX-POROS1TY L PEX-SSTVD L USIT R SRVY RPT ~ SPERRY MPT/GR/EWR4 OH /_~q~L 8300-14069 7~;l/~'7/~ OH /_..,.13}~A~L 6123-8658 ~1 OH ~'~L 11060-14040 ~ [~ ~/q ~ OH ~ 11060-14040~ OH ~ BL(C)50-9830 ~13/~ CH ~~Y ,~o~.,~-~o~o. OH T 9003 ~ SCHLUM PEX-~S OH Was the well cored? yeses. 2/10/99 2/10/99 2/17/99 2/17/99 2/17/99 2/17/99 2/19/99 2/24/99 2/19/99 2/24/99 2/19/99 2/24/99 2/19/99 2/24/99 12/22/98 1/5/99 8/19/98 8/26/98 2/19/99 2/24/99 Are Dry Ditch Samples Required? yes _~ And Receiv~ Analysis Description Receive~Sample SeY~ Comments: Tuesday, August 01, 2000 Page 1 of l ·---' STATE OF ALASKA "~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X 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 51 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 3605' FNL, 3693' FEL, Sec. 18, T11 N, R1 SE, UM (asp's 692940, 5963571) L2-18A At top of productive interval 9. Permit number / approval number 2719' FSL, 3156' FWL, Sec. 17, T11 N, R15E, UM (asp's 699756, 5964796) 198-106 At effective depth 10. APl number 50-029-21766-01 At total depth 11. Field / Pool 2271' FNL, 5105' FEL, Sec. 16, T11 N, R15E, UM (asp's 702045, 5965147) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 14070 feet Plugs (measured) - Tagged PBTD @ 13968' MD (11/26/99) true vertical 8659 feet Effective depth: measured 13968 feet Junk (measured) true vertical 8661 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 1850 Sx Poleset 110' 110' Surface 4064' 13-3/8" 175 sx AS ~, 300 Sx AS "k & 5OO 4115' 3596' Sx Class G Production 8247' 9-5/8" 900 sx C~ass G 8298' 6112' Liner 3012' 7" 5Ol sx C~ass G 11124' 821 8' Liner 3127' 4-1/2" 375 Sx C~ass G 14068' 8608' RECEIVED Perforation depth: measured 12065'- 12105'; 12447'- 15078'; 13112'- 15420'; 13602'- 13960'. true vertical 8702' - 8706'; 8699' - 8687': 8686'- 8681'; 8675'-8662'. ";-' ;~ 2 5 2000 Tubing (size, grade, and measured depth)4-1/2"12.6#, TbgORIGINAL Alaska 0~i & Gas C~.s. Oomrnis~ion L-80 @ 10949' MD. ~AJ!_c'hor-~e Packers & SSSV (type & measured depth) 4-1/2"X7" ZXP LINER TOP PACKER @ 10951'MD; 7" X4-1/2" BAKERS-3PAKER @ 10894'MD. 4-1/2" CA BAL-O SSSV NIP @ 2234' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-8bl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 90 365 0 546 Subsequent to operation 162 1942 9 471 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 .~¢,~/~ ~ ~ Title ARCO Engineering Supervisor Date /TL ~ 2 Z/- ~OfJ Erin Oba ' Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE .... L2-18A DESCRIPTION OF WORK COMPLETED FB FORMIC ACID STIMULATION & PERFORATING OPERATIONS Date Event Summary 1/21/2000: 2/10/2000: 2/13/2000: 4/15/2000: 4/16/2000: TIFL passed. MITOA to 2000 psi - passed. RIH & drifted to 11890' SLM (HAW). Performed a FB Formic Acid Stimulation as follows: MIRU. PT'd equip to 3500 psi. Pumped stimulation sequence fullbore to treat the open perforation intervals located @: 12447'- 13078' MD (Zone 1) Reference Log: SWS Laterolog 7/23/1998. 13112' - 13420' MD (Zone 1 ) 13602'- 13960' MD (Zone 1) Pumped: (a) 2 bbls of 60/40 Methanol Water @ 2 bpm, followed by (b) 146 bbls of 100° F 2% NH4CL Water @ 6.0 - 2.4 bpm, followed by (c) 127 bbls of 9% Formic Acid @ 2.0 - 1.15 bpm, followed by (d) 300 bbls of 2% NH4CL Water @ 2.0 - 0.97 bpm, followed by (e) 30 bbls of 60/40 Methanol Water, followed by (e) shutdown. No noticable pressure loss observed. RD. MIRU CTU. PT'd equip to 3500 psi. Hot oiled tubing w/Crude f/1700' to 2227' to remove parafins. RIH w/TCP perf guns & tagged up on X nipple @ 11558'. Shot 40' of Add Perforations @: 12065'- 12105' MD (Zone 1) Used 2-7/8" carriers in two runs and all shots @ 4 SPF & random orientation. POOH w/tcp guns. ASF. RD. Returned well to production & obtained valid welltest data. ' '-'-' 25 2000 Oil & Gas Cons. ~,omm~ss~on STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations 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 51 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 3605' FNL, 3693' FEL, Sec. 18, T11 N, R15E, UM (asp's 692940, 5963571) L2-18A At top of productive interval 9. Permit number / approval number 2719' FSL, 3156' FWL, Sec. 17, T11N, R15E, UM (asp's699756, 5964796) 198-106 At effective depth 10. APl number 50-029-21766-01 At total depth 11. Field / Pool 2271' FNL, 5105' FEL, Sec. 16, T11 N, R15E, UM (asp's 702045, 5965147) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 14070 feet Plugs (measured) Tagged PBTD @ 13968' MD (11/26/99) true vertical 8659 feet Effective depth: measured 13968 feet Junk (measured) true vertical 8661 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 185o Sx Poleset 110' 110' Surface 4064' 13-3/8" 175 Sx AS ~, 300 Sx AS "k & 500 41 15' 3596' Sx Class G Production 8247' 9-5/8" 900 Sx Class G 8298' 6112' Liner 3012' 7" 5Ol Sx C~ass G 1 1124' 8218' Liner 3127' 4-1/2" 375 Sx C~ass G 14068' 8608' Perforation depth: measured 12447'- 13078'; 13112'- 13420'; 13602'- 13960'. true vertical 8699' - 8687'; 8686' - 8681'; 8675' - 8662'. ! ¢al AL Tubing (size, grade, and measured depth) 4-1/2"12.6#, L-80 Tbg @ 10949' MD. Packers & SSSV (type & measured depth) 4-1/2"x7" ZXP LINER TOP PACKER @ 10951'MD; 7"X4-1/2" BAKERS-3PAKER @ 10894'M~..'-~,~, ~.. 4-1/2" CA BAL-O SSSV NIP @ 2234' MD. 13. Stimulation or cement squeeze summary :.,',-i~;. i~i -'--~ 'i ©~,5;:~ Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure~-u~,,,,~rl 1,,~tr.,~ 0JJ & P-'~'~'~c~ uu,,~,'¢'*.~' OomBi.~8i~ 14. Representative Daily Average Production or Iniection Data ~lt~;~tui~jd OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 150 485 5 - 554 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 '~~'~1,4 ~,~/',.~ Title ARCO EngineeringS upervisor Date / ~ / "~ ~ ~/'~ Erin Oba . . ~ . Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLIOATE L2-18A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 11/26/1999 - 11/27/1999: 12/08/1999: 12/11/1999: 12/14/1999: MIRU CTU & work platform. PT'd equip. RIH & jetted hot oil to PBTD @ 13968' MD. Layed in FIo Pro mudto 11500'. Displaced well to brine. POOH. RIH w/TCP perf guns &shot 800' of Reper[orations @: 12490' - 13040' MD (Zone 1) Reference Log: GR/CCL 8/12/1998. 13130' - 13380' MD (Zone 1) Used 2-7/8" carriers and all shots @ 4 SPF, random orientation, 60° phasing, & overbalanced pressure. POOH w/guns. ASF. Pumped 125 bbls of hot Crude down tubing for rate. Pumped 125 bbls of hot Crude down tubing for rate. Pumped 120 bbls of hot Crude down tubing for rate. Also hot oiled flow lines w/20 bbls of Crude. Put on production. Returned well to production & obtained valid welltest data. RECEIVED JAN 2 1 2000 Oll & 13a rm. Commission Anchorage 2/19/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12356 Companl Alaska Oil & Gas Cons Camm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole] LIS Well Job # Log Description Date BL Sepia Tape L2-18A 98638 PEX & HALS ~ ~ I~i~)~ 980723 1 L2-18A 98638 PEX-AZIMUTHAL LATEROLOG 980723 1 1 ., L2-18A 98638 PEX-CNL 980723 I I ,,, L2-18A 98638 PEX-POROSlTY LOG 980723 1 1 L2-18A 98638 PEX-SSTVD 980723 1 1 ., ....... .... ,,, ,, .,, ,. SIGNED: DATE: 011 & Gao Con:~. Colt~i l .sion Alaska" "' '~ ' "~'i'~'''' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ~Pu]l{~l'ag~ C) I::! I I_L_ I IM CS c~ I~ !::! L~ I C I:: S WELL LOG TRANSMITTAL To.' State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 February 17, 1999 RE: MWD Formation Evaluation Logs · L2-18A, AK-MM-80261 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 D.S. L2-18A: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-21766-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-21766-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Comnanv WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 February10,1999 MWD Formation Evaluation Logs - D.S. L2-18A, AK-MM-80261 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention or2 Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21766-01. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 12/22/98 GeoQuest 3940 Arctic Bird Anchorage, AK 99503 ATTN: Sherrie NO. 12187 Compan~ Alaska Oil & Gas Cons Comm Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape ~2-~8A 98~45 U~Z? 980703 p.S. ~-2A 98629 ~S~-SZO~ -,~_ ~?'~'2--- 9808~6 1 1 1 D.S. 6-~0& 98590 RS' ~ ~'~:~"~:~ 981~13 1 1 1 _ D.~. ~-~o~ ees~o ~ ~e~z~ 1 1 ,,, D.~. ~5-47 98507 R~-BO~ 97~ 1 1 . , , ,,, , ,, ,,, ,, ,,, , ........... , .,, ,, ,, .,. , ~ ,, , ........ SIGNE DATE: dA~'l 0 .r,,; 1~i)!;!) Naska 0il & 6as C;0m;, (;0mmissJ0n Pl~o** ~i~n ond r~tum on, copy oI lhi~ lrommi.ol 1o Shorflo ol th~ obov~ oddr~ or ~ox ~o (907) 56~~;~onk ~ 1. Status of Well classification of Service~lT/'~ [~ Oil I~ Gas r~ Suspended E~ Abandoned [] Service 2. Name of Operator . '"' 7. Permit Number ARCO Alaska Inc. '....- 98-106 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612~ ............ 50-029-21766-01 4. Location of well at surface i ' ~ ~~~'~ 9. Unit or Lease Name At top of productive interval ~~.,:~i_ '! 10. Well Number 2719' NSL, 3156' EWL, SEC. 17, T11N, R15E, UM;i ,.~;;;I~-;..;~ L2-18A At total depth .......... . ............... .~;~ '~:'i 11. Field and Pool 3013' NSL, 169' EWL, SEC. 16, T11N, R15E, UM~ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 50.83'I ADL 028321 12. Date Spudded 113. Date T.D. Reached I 14. Date Cornp., Susp., orAband.llE. Water depth, if offshore 116. No. of Completions 7/10/98I 7/22/9.8 . . I 7/30/98 I .. N/A USUI .... O..ne 17. Total ~)epth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSS,V, set 121. Thickness of Permafrost 14070 8659 FTI 13980 8661 FTI I~Yes ~Nol (Nipple) 2234 MDt 1900'(Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, MIR, MD, RES/AlT, DT/BHC, CNL, LDL, GR, Caliper, SP, MRES 23. CASING~ LINER AND CEMENTING RECORD CASING SEI-I'ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP Bo~roM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5 H-40 Surface 110' 30" 1850# Poleset 13-3/8" 68#/72# K-55/L-80 Surface 4115' 17-1/2" 300 sx AS III, 500sx'G',TopJobw/175sxASl 9-5/8" 47# L-80 Surface 8298' 12-1/4" 900 sx Class 'G' 7" 26# L-80 8112' 11124'. 8-1/2" 501 sx Class 'G' 4-1/2" 12.6# L-80 10941' 14068' 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#, 1-80 10949' 10894' MD TVD MD TVD ' 12447' - 13078' 8699' - 8687 ......... 13112' - 13420' 8686' - 8681' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13602' - 13960' 8675' - 8661' DEPTH INTERVAL (MD) AMOUNT & KiND OF MATERIAL USED Freeze Protect with 160 Bbls of Diesel Oki L .... 27. PRODUCTION TEST ......... Date First Production I Method of Operation (Flowing, gas lift, etc.) October 4,1998I Gas Lift Date of Test Hours Tested PRODUCTION FOR ~rOIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL O~L GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA ,,, ,, Brief description of lithology, po'rosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. .......... Shublik 11102' 8201' Sadlerochit / Zone 4 11152' 8240' Zone 3 11290' 8345' Zone 2 11408' 8428' Zone 1 B 11737' 8613' Base of Sadlerochit 12126' 8707' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my k"no~le~ge Signed ~--~--------~ ~--~r~ ~ ~/,&/c,~ Dan Stone ' Title Engineering Supervisor Date l L2-18A 98-106 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 2?: 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 Facility Date/Time 28 Jun 98 29 Jun 98 30 Jun 98 01 Jul 98 02 Jul 98 03 Jul 98 Lis DS 02 Progress Report Well L2-18A Page 1 Rig ~ ~a~O~ ~ Date 27 August 98 19:00-02:00 02:00-04:00 04:00-05:00 05:00-05:30 05:30-06:00 06:00-09:00 09:00-12:00 12:00-12:30 12:30-13:30 13:30-18:00 18:00-23:00 23:00-04:00 04:00-04:30 04:30-06:00 06:00-10:00 10:00-12:00 12:00-12:30 12:30-15:30 15:30-21:30 21:30-01:00 01:00-02:00 02:00-04:00 04:00-06:00 06:00-09:00 09:00-10:00 10:00-12:00 12:00-13:30 13:30-15:00 15:00-16:00 16:00-17:30 17:30-20:00 20:00-00:00 00:00-00:30 00:30-06:00 06:00-07:30 07:30-10:30 10:30-12:00 12:00-12:30 12:30-20:30 20:30-21:00 21:00-00:00 00:00-00:30 00:30-02:30 02:30-05:00 05:00-05:30 05:30-06:00 06:00-09:00 09:00-12:00 12:00-12:30 12:30-13:30 13:30-15:00 15:00-16:00 16:00-18:30 18:30-01:00 Duration 7hr 2hr lhr 1/2 hr 1/2hr 3hr 3 hr 1/2 hr lhr 4-1/2 hr 5hr 5hr 1/2 hr 1-1/2 hr 4hr 2hr 1/2 hr 3hr 6hr 3-1/2 hr lhr 2hr 2hr 3hr lhr 2hr 1-1/2 hr 1-1/2 hr lhr 1-1/2 hr 2-1/2 hr 4hr 1/2 hr 5-1/2 hr 1-1/2 hr 3hr 1-1/2 hr 1/2 hr 8hr 1/2 hr 3hr 1/2 hr 2hr 2-1/2 hr 1/2 hr 1/2 hr 3hr 3hr 1/2 hr lhr 1-1/2 hr lhr 2-1/2 hr 6-1/2 hr Activity Rig moved 100.00 % Fill pits with Seawater Retrieved Hanger plug Held safety meeting Circulated at 10400.0 ft Circulated at 10400.0 ft Installed Hanger plug Held safety meeting Rigged down Xmas tree Rigged up BOP stack Tested BOP stack Retrieved Hanger plug Rigged up Tubing handling equipment Laid down 0.0 ft of Tubing Circulated at 10358.0 ft Rigged up Logging/braided cable equipment Held safety meeting Prepared & fired cutting charge at 10338.0 ft Worked stuck pipe at 10338.0 ft Conduct braided cable operations - 5/16 size cable Pulled out of hole to 1005.0 ft Prepared & fa-ed cutting charge at 9838.0 ft Conduct braided cable operations - 5/16 size cable Conduct braided cable operations - 5/16 size cable Functioned Control lines Retrieved Cable Held safety meeting Conduct braided cable operations - 5/16 size cable Reverse circulated at 9838.0 ft Pulled out of hole to 9718.0 ft Installed Tubing handling equipment Pulled out Of hole to 7545.0 ft Held safety meeting Pulled out of hole to 90.0 ft Pulled out of hole to 0.0 ft Tested All rams Rigged up Drillstring handling equipment Held safety meeting Ran Drillpipe to 4571.0 ft (4in OD) Installed Drillstring handling equipment Ran Drillpipe to 7523.0 ft (5in OD) Held safety meeting Ran Drillpipe to 9768.0 ft (5in OD) Tested Casing Pulled out of hole to 8708.0 ft Tested Casing Tested Casing Pulled out of hole to 4571.0 ft Held safety meeting Pulled out of hole to 55.0 ft Pulled out of hole to 0.0 ft Serviced Block line Rigged up Lubricator Conducted electric cable operations Facility Date/Time 04 Jul 98 05 Jul 98 06 Jul 98 Lis DS 02 Progress Report Well L2-18A Rig (null) Page Date Duration Activity 01:00-02:00 02:00-02:30 02:30-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-09:00 09:00-09:30 09:30-10:30 10:30-11:30 11:30-12:00 12:00-12:30 12:30-13:30 13:30-15:00 15:00-18:30 18:30-19:00 19:00-20:30 20:30-21:00 21:00-22:00 22:00-01:00 01:00-01:30 01:30-03:00 03:00-04:30 04:30-05:00 05:00-06:00 06:00-07:00 07:00-07:30 07:30-08:00 08:00-10:00 10:00-10:30 10:30-12:00 12:00-12:30 12:30-13:30 13:30-14:30 14:30-15:30 15:30-17:00 17:00-18:00 18:00-20:00 20:00-22:00 22:00-22:30 22:30-00:00 00:00-00:30 00:30-01:00 01:00-03:30 03:30-04:00 04:00-06:00 06:00-06:30 06:30-08:30 08:30-09:00 09:00-10:30 10:30-13:00 13:00-15:00 15:00-15:30 lhr 1/2 hr 2hr 1/2 hr lhr 1/2 hr 1/2 hr 2hr 1/2 hr lhr lhr 1/2 hr 1/2 hr lhr 1-1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr lhr 3hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr lhr lhr 1/2hr 1/2 hr 2hr 1/2 hr 1-1/2 hr 1/2 hr lhr 1 hr lhr 1-1/2 hr 1 hr 2 hr 2hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 2hr 1/2 hr 2hr 1/2 hr 1-1/2 hr 2-1/2 hr 2hr 1/2 hr Rigged down Lubricator Rigged up Tubing handling equipment Ran Tubing to 600.0 ft (2-7/8in OD) Rigged up Drillstring handling equipment Ran Drillpipe in stands to 4000.0 ft Ran Drillpipe in stands to 5101.0 ft Installed Drillstring handling equipment Ran Drillpipe in stands to 9852.0 ft Rigged up Cement unit Batch mixed slurry - 37.000 bbl Displaced slurry - 37.000 bbl Rigged down Circulating head Circulated at 9344.0 ft Mixed and pumped slurry - 37.000 bbl Circulated at 8593.0 ft Pulled Drillpipe in stands to 5100.0 ft Rigged up Drillstring handling equipment Pulled Drillpipe in stands to 600.0 ft Rigged up Tubing handling equipment Laid down 600.0 ft of Tubing R.I.H. to 4506.0 ft Rigged up Drillstring handling equipment R.I.H. to 8530.0 ft Pulled out of hole to 4506.0 ft Rigged up Drillstring handling equipment Pulled out of hole to 1425.0 ft Pulled out of hole to 20.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 4506.0 ft Rigged up Drillstring handling equipment R.I.H. to 5934.0 ft Held safety meeting R.I.H. to 8460.0 ft Tested Cement retainer - Via annulus Batch mixed slurry - 30.000 bbl Displaced slurry - 30.000 bbl Reverse circulated at 8455.0 ft Circulated at 8455.0 ft Pulled Drillpipe in stands to 4506.0 ft Installed Drillstring handling equipment Pulled Drillpipe in stands to 0.0 ft Held safety meeting Retrieved Wear bushing Tested BOP stack Installed Wear bushing Made up BHA no. 3 Made up BHA no. 3 R.I.H. to 5048.0 ft Installed Drillstring handling equipment R.I.H. to 8298.0 ft Milled Casing at 8298.0 ft Pulled out of hole to 5048.0 ft Installed Drillstring handling equipment 2 27 August 98 Facility Date/Time 07 Jul 98 08 Jul 98 09 Jul 98 10 Jul 98 Lis DS 02 Progress Report Well L2-18A Rig (null) 15:30-16:30 16:30-18:00 18:00-18:30 18:30-20:00 20:00-20:30 20:30-23:30 23:30-06:00 06:00-09:30 09:30-10:00 10:00-13:00 13:00-14:30 14:30-17:30 17:30-18:00 18:00-20:00 20:00-22:00 22:00-23:00 23:00-00:00 00:00-00:30 00:30-01:30 01:30-02:00 02:00-02:30 02:30-04:30 04:30-06:00 06:00-06:30 06:30-08:30 08:30-09:00 09:00-09:30 09:30-09:45 09:45-10:00 10:00-10:30 10:30-12:00 12:00-12:30 12:30-16:30 16:30-17:30 17:30-21:30 21:30-23:30 23:30-00:00 00:00-00:30 00:30-02:30 02:30-04:30 04:30-06:00 06:00-11:00 11:00-12:00 12:00-12:30 12:30-13:00 13:00-14:00 14:00-17:30 17:30-20:00 20:00-20:30 20:30-21:30 21:30-22:00 22:00-00:00 00:00-00:30 00:30-02:30 Duration lhr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 3hr 6-1/2 hr 3-1/2 hr 1/2 hr 3 hr 1-1/2 hr 3hr 1/2 hr 2hr 2hr lhr lhr 1/2 hr lhr 1/2 hr 1/2 hr 2hr 1-1/2 hr 1/2 hr 2 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 1-1/2 hr 1/2 hr 4hr lhr 4 hr 2hr 1/2hr 1/2hr 2hr 2hr 1-1/2 hr 5hr lhr 1/2 hr 1/2hr 1 hr 3-1/2 hr 2-1/2 hr 1/2hr lhr 1/2 hr 2hr 1/2 hr 2hr Activity Pulled out of hole to 547.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 5048.0 ft Rigged up Drillstring handling equipment R.I.H. to 8298.0 ft Milled Casing at 8325.0 ft Milled Casing at 8332.0 ft Circulated at 8332.0 ft Milled Casing at 8343.0 ft Circulated at 8343.0 ft Pulled out of hole to 5048.0 ft Rigged up Drillstring handling equipment Pulled out of hole to 549.0 ft Pulled BHA Conmaissioned All functions Ran Drillpipe to 1630.0 ft (4in OD) Held safety meeting Ran Drillpipe to 4504.0 ft (4in OD) Rigged up Drillstring handling equipment Circulated at 4504.0 ft Ran Drillpipe to 8294.0 ft (5in OD) Circulated at 8325.0 ft Ran Drillpipe to 8450.0 ft (5in OD) Circulated at 8450.0 ft Held safety meeting Batch mixed slurry - 35.000 bbl Mixed and pumped slurry - 35.000 bbl Displaced slurry - 103.000 bbl Pulled Drillpipe in stands to 7806.0 ft Circulated at 7806.0 ft Held safety meeting Pulled Drillpipe in stands to 0.0 ft Installed Wear bushing Made up BHA no. 3 R.I.H. to 5332.0 ft Serviced Block line Held safety meeting R.I.H. to 7777.0 ft Washed to 8075.0 ft Functioned downhole tools at 7777.0 ft Pulled out of hole to 187.0 ft Pulled BHA Held safety meeting Pulled BHA Downloaded MWD tool Made up BHA no. 4 R.I.H. to 5329.0 ft Circulated at 5329.0 ft R.I.H. to 8028.0 ft Washed to 8075.0 ft Drilled cement to 8136.0 ft Held safety meeting Drilled cement to 8300.0 ft Page Date 3 27 August 98 Facility Date/Time 11 Jul 98 12 Jul 98 13 Jul 98 14 Jul 98 15 Jul 98 Lis DS 02 Progress Report Well L2-18A Rig (null) Page Date Duration Activity 02:30-06:00 06:00-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-17:30 17:30-19:30 19:30-20:30 20:30-21:30 21:30-00:00 00:00-00:30 00:30-04:00 04:00-05:00 05:00-06:00 06:00-09:30 09:30-10:30 10:30-12:00 12:00-12:30 12:30-13:00 13:00-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-00:00 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-06:00 06:00-11:30 11:30-12:00 12:00-12:30 12:30-18:00 18:00-19:30 19:30-22:00 22:00-23:30 23:30-00:00 00:00-00:30 00:30-02:00 02:00-06:00 06:00-07:30 07:30-08:30 08:30-09:00 09:00-10:00 10:00-11:00 11:00-11:30 11:30-12:00 12:00-12:30 12:30-16:00 3-1/2 hr 6hr 1/2 hr 11-1/2 hr 1/2 hr 5-1/2 hr 6hr 1/2 hr 5hr 2hr lhr 1 hr 2-1/2 hr 1/2hr 3-1/2 hr lhr lhr 3-1/2 hr lhr 1-1/2 hr 1/2 hr 1/2 hr 5hr 1/2 hr lhr 1/2 hr 4hr 1/2 hr 5-1/2 hr 6hr 1/2 hr 11-1/2 hr 1/2 hr 5-1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 5-1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 4 hr 1-1/2 hr lhr 1/2 hr lhr lhr 1/2 hr 1/2 hr 1/2 hr 3-1/2 hr Drilled to 8311.0 ft Drilled to 8452.0 ft (cont...) Held safety meeting Drilled to 8706.0 ft Held safety meeting Drilled to 8865.0 ft Drilled to 9055.0 ft (cont...) Held safety meeting Drilled to 9163.0 ft Repaired Fluid system Drilled to 9182.0 ft Circulated at 9182.0 ft Pulled out of hole to 6280.0 ft Held safety meeting Pulled out of hole to 187.0 ft Pulled BHA Tested BOP stack Tested BOP stack (cont...) Serviced M.W.D. tool Made up BHA no. 5 Held safety meeting Made up BHA no. 5 R.I.H. to 8194.0 ft Tested Kelly R.I.H. to 9145.0 ft Washed to 9182.0 ft Drilled to 9379.0 ft Held safety meeting Drilled to 9665.0 ft Drilled to 9983.0 ft (cont...) Held safety meeting Drilled to 10394.0 ft Held safety meeting Drilled to 10587.0 ft Drilled to 10807.0 ft (cont...) Repaired Mud pumps Held safety meeting Drilled to 11125.0 ft Circulated at 11125.0 ft Pulled out of hole to 8298.0 ft R.I.H. to 11125.0 ft Circulated at 11125.0 ft Held safety meeting Circulated at 11125.0 ft Pulled out of hole to 4327.0 ft Pulled out of hole to 187.0 ft (cont...) Pulled BHA Downloaded MWD tool Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Liner to 120.0 ft (7in OD) Held safety meeting Ran Liner to 2992.0 ft (7in OD) 4 27 August 98 Facility Date/Time 16 Jul 98 17 Jul 98 18 Jul 98 19 Jul 98 20 Jul 98 Lis DS 02 Progress Report Well L2-18A Page 5 Rig (null) Date 27 August 98 16:00-16:30 16:30-17:00 17:00-21:30 21:30-22:30 22:30-00:00 00:00-00:30 00:30-01:00 01:00-02:30 02:30-02:45 02:45-03:10 03:10-03:30 03:30-04:00 04:00-05:30 05:30-06:00 06:00-11:30 11:30-12:00 12:00-12:30 12:30-13:00 13:00-14:30 14:30-15:30 15:30-21:30 21:30-22:30 22:30-23:00 23:00-00:00 00:00-00:30 00:30-04:00 04:00-06:00 06:00-07:30 07:30-08:00 08:00-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-06:00 06:00-11:00 11:00-12:00 12:00-12:30 12:30-13:00 13:00-20:00 20:00-22:00 22:00-00:00 00:00-00:30 00:30-02:30 02:30-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-10:00 10:00-11:30 Duration 1/2 hr 1/2 hr 4-1/2 hr lhr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/4 hr 1/4 hr 1/4 hr 1/2 hr 1-1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr lhr 6hr lhr 1/2 hr lhr 1/2 hr 3-1/2 hr 2hr 1-1/2 hr 1/2hr 4hr 1/2 hr 11-1/2 hr 1/2 hr 5-1/2 hr 6hr 1/2 hr 11-1/2 hr 1/2 hr 5-1/2 hr 5 hr 1 hr 1/2 hr 1/2 hr 7hr 2hr 2hr 1/2 hr 2hr 1/2 hr lhr lhr lhr 4hr 1-1/2 hr Activity Rigged up Drillstring handling equipment Installed Liner hanger Ran Liner on landing string to 8281.0 ft Circulated at 8281.0 fi Ran Liner on landing string to 11109.0 fi Held safety meeting Washed to 11125.0 ft Circulated at 11125.0 ft Held safety meeting Pumped Fresh water spacers - volume 70.000 bbl Mixed and pumped slurry - 102.000 bbl Displaced slurry - 218.000 bbl Circulated at 8113.0 ft Pulled Drillpipe in stands to 7800.0 fi Pulled Drillpipe in stands to 0.0 ft (cont...) Tested Liner Held safety meeting Serviced M.W.D. tool Made up BHA no. 204 Functioned downhole tools at 300.0 ft R.I.H. to 10960.0 fi Serviced Block line Held drill (Kick (well kill)) Drilled cement to 10960.0 ft Held safety meeting Drilled cement to 11037.0 ft Drilled installed equipment - Landing collar Drilled installed equipment - Float shoe (cont...) Drilled to 11135.0 ft Circulated at 11135.0 ft Held safety meeting Drilled to 11417.0 ft Held safety meeting Drilled to 11576.0 ft Drilled to 11766.0 fi (cont...) Held safety meeting Drilled to 12179.0 fi Held safety meeting Drilled to 12297.0 fi Drilled to 12440.0 ft (cont...) Circulated at 12440.0 ft Held safety meeting Circulated at 12440.0 ft Pulled out of hole to 200.0 ft Pulled BHA Tested BOP stack Held safety meeting Tested BOP stack Made up BHA no. 7 Serviced M.W.D. tool Made up BHA no. 7 R.I.H. to 1251.0 ft R.I.H. to 12354.0 ft (cont...) Washed to 12440.0 fi Facility Date/Time 21 Jul 98 22 Jul 98 23 Jul 98 24 Jul 98 25 Jul 98 Progress Report Lis DS 02 Well L2-18A Page 6 Rig (null) Date 27 August 98 11:30-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-00:00 00:00-05:30 05:30-06:00 06:00-08:00 08:00-12:00 12:00-12:30 12:30-13:30 13:30-14:00 14:00-16:00 16:00-20:30 20:30-00:00 00:00-00:30 00:30-05:00 05:00-06:00 06:00-07:30 07:30-08:00 08:00-09:00 09:00-10:00 10:00-12:00 12:00-12:30 12:30-19:30 19:30-20:00 20:00-22:30 22:30-00:00 00:00-00:30 00:30-05:00 05:00-06:00 06:00-07:00 07:00-10:00 10:00-10:30 10:30-12:00 12:00-12:30 12:30-13:00 13:00-14:00 14:00-15:00 15:00-18:30 18:30-19:00 19:00-22:30 22:30-23:30 23:30-00:00 00:00-00:30 00:30-03:00 03:00-03:30 03:30-05:00 05:00-06:00 06:00-07:30 07:30-09:00 Duration 1/2 hr 1/2hr 11-1/2 hr 1/2 hr 5-1/2 hr 6hr 1/2 hr 11-1/2 hr 5-1/2 hr 1/2 hr 2hr 4hr 1/2 hr lhr 1/2hr 2hr 4-1/2 hr 3-1/2 hr 1/2 hr 4-1/2 hr lhr 1-1/2 hr 1/2 hr lhr 1 hr 2hr 1/2 hr 7hr 1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr lhr lhr 3hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1 hr 1 hr 3-1/2 hr 1/2 hr 3-1/2 hr lhr 1/2 hr 1/2 hr 2-1/2 hr 1/2hr 1-1/2 hr lhr 1-1/2 hr 1-1/2 hr Activity Drilled to 12455.0 ft Held safety meeting Drilled to 13032.0 ft Held safety meeting Drilled to 13285.0 ft Drilled to 13507.0 ft (cont...) Held safety meeting Drilled to 13856.0 ft Drilled to 14069.0 ft Circulated at 14069.0 ft Circulated at 14069.0 ft Logged hole with LWD: DIRIDD from 14070.0 ft to 12607.0 ft Held safety meeting Logged hole with LWD: DIR/DD from 12607.0 ft to 11750.0 ft Pulled out of hole to 11124.0 ft R.I.H. to 14070.0 ft Circulated at 14070.0 ft Pulled out of hole to 10640.0 ft Held safety meeting Pulled out of hole to 195.0 ft Pulled BHA Pulled BHA Held safety meeting Ran logs on tubulars Tested Production logging tools - Via string Ran logs on tubulars Held safety meeting Ran logs on tubulars Circulated at 11059.0 ft Rigged up Logging/braided cable equipment Ran logs on tubulars Held safety meeting Ran logs on tubulars Retrieved Slickline / braided cable Serviced Block line Pulled out of hole to 5473.0 ft Rigged up Drillstring handling equipment Pulled out of hole to 800.0 ft Held safety meeting Pulled out of hole to 110.0 ft Pulled out of hole to 0.0 ft Rigged up Casing handling equipment Ran Liner to 3106.0 ft (4-1/2in OD) Rigged up Tubing handling equipment Ran Tubing to 3005.0 ft (2-7/8in OD) Rigged up Drillstring handling equipment Circulated at 3106.0 ft Held safety meeting Ran Drillpipe to 8496.0 ft (4in OD) Rigged up Drillstring handling equipment Ran Drillpipe to 11124.0 ft (5in OD) Circulated at 11124.0 ft Circulated at 11124.0 ft Ran Drillpipe in stands to 14068.0 ft Facility Date/Time 26 Jul 98 27 Jul 98 28 Jul 98 Lis DS 02 Progress Report Well L2-18A Rig (null) Page Date Duration Activity 09:00-13:00 13:00-14:30 14:30-20:00 20:00-21:30 21:30-23:00 23:00-00:00 00:00-00:30 00:30-01:00 01:00-01:30 01:30-02:00 02:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-09:30 09:30-11:30 11:30-13:30 13:30-14:00 14:00-16:00 16:00-16:30 16:30-18:00 18:00-19:00 19:00-20:00 20:00-00:00 00:00-00:30 00:30-04:00 04:00-04:30 04:30-05:00 05:00-05:30 05:30-06:00 06:00-11:30 11:30-12:00 12:00-12:30 12:30-14:00 14:00-14:30 14:30-18:00 18:00-19:00 19:00-22:00 22:00-22:30 22:30-00:00 00:00-00:30 00:30-01:30 01:30-03:00 03:00-03:30 03:30-06:00 06:00-07:30 07:30-08:00 08:00-12:00 12:00-12:30 12:30-13:30 13:30-15:00 15:00-15:30 15:30-18:00 18:00-20:00 4hr 1-1/2 hr 5-1/2 hr 1-1/2 hr 1-1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 2 hr 1 hr 1 hr 1/2 hr 3hr 2hr 2hr 1/2 hr 2hr 1/2 hr 1-1/2 hr lhr lhr 4hr 1/2 hr 3-1/2 hr 1/2hr 1/2 hr 1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr lhr 3hr 1/2 hr 1-1/2 hr 1/2hr 1 hr 1-1/2 hr 1/2hr 2-1/2 hr 1-1/2 hr 1/2 hr 4hr 1/2 hr lhr 1-1/2 hr 1/2 hr 2-1/2 hr 2hr Circulated at 14068.0 ft Mixed and pumped slurry - 77.000 bbl Circulated at 13965.0 ft Pulled Drillpipe in stands to 11552.0 ft Worked stuck pipe at 11552.0 ft Circulated at 11583.0 ft Held safety meeting Pulled Drillpipe in stands to 10941.0 ft Reverse circulated at 10941.0 fl Ran Drillpipe to 11562.0 fl (5in OD) Reverse circulated at 11562.0 ft Ran Drillpipe in stands to 12549.0 fl Reverse circulated at 12549.0 ft Ran Drillpipe in stands to 13960.0 ft Reverse circulated at 13960.0 fl Laid down 2268.0 ft of Drillpipe Pulled Drillpipe in stands to 8380.0 fl Rigged up Drillstring handling equipment Pulled Drillpipe in stands to 3022.0 ft Rigged up Tubing handling equipment Pulled Tubing in stands to 0.0 ft Tested Liner Retrieved Wear bushing Tested BOP stack Held safety meeting Installed Kill manifold Tested Kill line Installed Wear bushing Held safety meeting Rigged up Drillstring handling equipment Ran Tubing to 3133.0 ft (2-7/8in OD) Rigged up Drillstring handling equipment Held safety meeting Ran Drillpipe in stands to 8490.0 fl Rigged up Drillstring handling equipment Ran Drillpipe in stands to 13960.0 fl Serviced Block line Rigged up High pressure lines Rigged up High pressure lines Circulated at 13960.0 ft Held safety meeting Functioned Gun assembly Reverse circulated at 10836.0 ft Flow check Laid down 2700.0 ft of Drillpipe Laid down 2770.0 ft of 5in OD drill pipe Rigged up Drillstring handling equipment Laid down 5355.0 ft of 4in OD drill pipe Held safety meeting Rigged up Tubing handling equipment Laid down 1583.0 ft of Tubing Held safety meeting Laid down 1513.0 ft of Tubing Commissioned Kelly 7 27 August 98 Facility Date/Time 29 Jul 98 30 Jul 98 Lis DS 02 Progress Report Well L2-18A Page 8 Rig (null) Date 27 August 98 20:00-21:30 21:30-22:30 22:30-23:00 23:00-00:00 00:00-00:30 00:30-05:30 05:30-06:00 06:00-06:30 06:30-09:00 09:00-10:30 10:30-12:00 12:00-12:30 12:30-13:30 13:30-14:45 14:45-16:00 16:00-18:00 18:00-20:30 20:30-21:00 21:00-23:30 23:30-00:00 00:00-00:30 00:30-01:30 Duration 1-1/2 hr lhr 1/2 hr lhr 1/2 hr 5hr 1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1 hr 1-1/4 hr 1-1/4 hr 2 hr 2-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2hr lhr Activity Rigged up Top ram Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 535.0 ft (4-1/2in OD) Held safety meeting Ran Tubing to 8715.0 ft (4-1/2in OD) Ran Tubing to 8715.0 ft (4-1/2in OD) Rigged up sub-surface equipment - SCSSSV control line Ran Tubing to 10949.0 ft (4-1/2in OD) Space out tubulars Reverse circulated at 10949.0 ft Held safety meeting Reverse circulated at 10949.0 ft Set packer at 10894.0 ft with 4000.0 psi Tested Casing Removed BOP stack Installed Xmas tree Retrieved Hanger plug Freeze protect well - 160.000 bbl of Diesel Installed Hanger plug Held safety meeting Rigged down Instrument lines Prudhoe Bay Unit Alaska State Plane Zone 4 Lisburne DS 02 L2-18A SURVEY REPORT '18 August, '1998 Your Ref: API-500292176601 Last Survey Date 22-July.98 Job# AKMMS0261 KBE- 50.83' 13. ,RI.L~L. IN,G . =;ER,VI.CE Survey Ref: svy3666 Prudhoe Bay Unit Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth (ft) (fi) 8205.83 53.040 70.600 6006.24 6057.07 8298.00 53.400 70.581 6061.43 6112.26 8303.00 53.420 70.580 6064.41 6115.24 8341.53 50.520 74.270 6088.15 6138.98 8372.82 50.220 74.270 6108.10 6158.93 8404.24 48.200 76.170 6128.63 6179.46 8437.14 45.720 77.220 6151.08 6201.91 8468.75 43.290 78.280 6173.63 6224.46 8500.41 42.020 79.390 6196.91 6247.74 8532.53 40.720 82.890 6221.02 6271.85 8564.25 39.980 86.080 6245.19 6296.02 8595.82 40.000 90.050 6269.39 6320.22 8627.51 40.010 93.800 6293.66 6344.49 8659.13 39.640 98.350 6317.95 6368.78 8691.25 39.650 102.270 6342.69 6393.52 8723.02 40.100 103.410 6367.07 6417.90 8754.62 40.300 103.280 6391.21 6442.04 8785.96 41.100 104.820 6414.97 6465.80 8817.62 41.070 109.120 6438.84 6489.67 8849.34 41.020 108.290 6462.76 6513.59 8945.02 40,710 109.290 6535.12 6585.95 9040.27 42.000 106.88~-'- 6606.62 6657.45 9132.14 43.180 107.950 6674.25 6725.08 9157.22 43.250 107.780 6692.53 6743.36 9265.91 43.430 107.810 6771.58 6822.41 9312.47 43.100 108,400 6805.49 6856.32 9455.70 42.650 107.160 6910.45 6961.28 9550.83 42.120 107.070 6980.72 7031.55 9646.24 42.210 105.880 7051.44 7102.27 9742.15 41.910 103.530 7122.65 7173.48 Sperry. Sun Drilling Services Survey Report for L2-18A Your Ref: A PI-500292176601 Local Coordinates Nothings (fi) 1447.93 N 1472.46 N 1473.80 N 1482.98 N 1489.51N 1495.58 N 1501.12 N 1505.83 N 1509,98 N t513.26 N 1515.24 N 1515.92 N 1515.24 N 1513.10 N 1509.43 N 1504.90 N 1500.20 N 1495.23 N 1489.16 N 1482.48 N 1462.32 N 1442.81N 1424.19 N 1418.92 N 1396,13 N 1386.21N 1356.45 N 1337.58 N 1319.41N 1303.10 N Global Coordinates Dogleg Ve~ical Eastings Nothings Eastings Rate Section (fi) (fi) (fi) (°/100fi) 4501.83E 5965135.53N 697403.35E 4664.92 4571.46E 5965161.84N 697472.32E 0.391 4737.38 4575.24 E 5965163.27 N 697476.07 E 0.391 4741.32 4604.16 E 5965173.19 N 697504.74 E 10.654 4771.27 4627.36 E 5965180.32 N 697527.76 E 0.959 4795.17 4650.35 E 5965186.98 N 697550.60 E 7.892 4818.80 4673.75 E 5965193.11N 697573.84 E 7.890 4842.76 4695.40 E 5965198.37 N 697595.36 E 8.039 4864.86 4716.44 E 5965203.07 N 697616.30 E 4.662 4886.29 4737.41E 5965206.88 N 697637.17 E 8.260 4907.51 4757.85 E 5965209,38 N 697657.55 E 6.916 4928.02 4778.11E 5965210.59 N 697677.79 E 8.081 4948.17 4798,47 E 5965210.43 N 697698,16 E 7.606 4968.20 4818.59 E 5965208.81N 697718.33 E 9.288 4987.80 4838.75 E 5965205.66 N 697738.57 E 7.786 5007.20 4858.60 E 5965201.64 N 697758.54 E 2.702 5026.19 4878.45 E 5965197,45 N 697778.50 E 0.686 5045.13 4898.27 E 5965193.00 N 697798.45 E 4.097 5064.02 4918.16 E 5965187.44 N 697818.48 E 8.925 5082.81 4937.89 E 5965181.27 N 697838.38 E 1.725 5101.36 4997.16 E 5965162.63 N 697898.14 E 0.757 5157.04 5056.98 E 5965144.66 N 697958.44 E 2.151 5213.38 5116.29 E 5965127.58 N 698018~22 E 1.507 5269.34 5132.64E 5965122.73 N 698034.69 E 0.542 5284.74 5203.67 E 5965101.76 N 698106.28 E 0.167 5351,69 5234.00 E 5965092.63 N 698136.86 E 1.121 5380.25 5326.79 E 5965065.26 N 698230.39 E 0.668 5467.70 5388.08 E 5965047.97 N 698292.14 E 0.561 5525.58 5449.49 E 5965031.39 N 698354.00 E 0.843 5583.69 5511.63 E 5965016.68 N 698416.53 E 1.671 5642.78 Comment Tie-on Survey Window Point Alaska State Plane Zone 4 Lisburne DS 02 Continued... 18 August, 1998. f6:23 - 2 - DdllQuest Prudhoe Bay Unit Sperry. Sun Drilling Services Survey Report for L2-18A Your Ref: API.500292176601 Alaska State Plane Zone 4 Lisburne DS 02 Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 9837.61 41.470 104.090 7193.94 7244.77 9932.86 41.270 103.430 7265.42 7316.25 10027.76 40.840 103.910 7336.98 7387.81 10122.56 40.680 104.030 7408.79 7459.62 10217.94 40.880 104.580 7481.01 7531.84 10312.80 40.860 103.470 7552.74 7603.57 10408.62 39.620 102.660 7625.89 7676.72 10503.92 40.380 102.910 7698.89 7749.72 10599.40 42.570 103.440 7770.42 7821.25 10694.58 41.050 102.010 7841.37 7892.20 10789.65 41.890 102.050 7912.60 7963.43 10884.51 41.490 100.700 7983.44 8034.27 10979.74 40.140 100.580 8055.51 8106.34 11072.94 38.690 100.620 8127.51 8178.34 11143.35 38.970 98.480 8182.37 8233.20 11175.11 39.580 97.540 8206.95 8257.78 11206.80 40.350 96.630 8231.24 8282.07 11238.65 40.020 95.930 8255.57 8306.40 11270.35 41.080 97.080 8279.66 8330.49 11302.13 42.320 99.010 8303.39 8354.22 11333.89 44.140 100.12J3_ 8326.53 8377.36 11365.61 46.400 102.660 8348.85 8399,68 11397.42 47.930 103.360 8370.48 8421.31 11429,18 48,790 103.380 8391.58 8442.41 11461,02 50.210 102,920 8412.26 8463.09 11492.79 51.700 101.180 8432.27 8483.10 11524.39 53.740 98.880 8451.41 8502.24 11556.02 55.790 95.700 8469.66 8520.49 11587.36 57.330 94.030 8486.94 8537.77 11619.07 57.550 93.230 8504.00 8554.83 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) fit) (ft) (ft) (°/t00ft) (ft) 1287.95 N 5573.28 E 5965003.12 N 698478,56 E 0.604 5701.56 1272.98 N 5634.43 E 5964989,72 N 698540.07 E 0.504 5759.87 1258.25 N 5694,99 E 5964976.55 N 698600.99 E 0.562 5817,63 1243,30 N 5755.06 E 5964963.15 N 698661.41 E 0.188 5874.88 1227.91 N 5815.42 E 5964949.32 N 698722,t6 E 0.431 5932.35 1212.87 N 5875,64 E 5964935.83 N 698782.74 E 0,766 5989.73 1198.87 N 5935.93 E 5964923.38 N 698843.37 E 1.405 6047.33 1185.31 N 5995,67 E 5964911,36 N 698903,44 E 0,815 6104.45 1170.90 N 6057.24 E 5964898.53 N 698965.36 E 2.323 6163.26 1156,91 N 6119,12 E 5964886,14 N 699027.58 E 1.885 6222.44 1143,79 N 6180.70 E 5964874,60 N 699089,47 E 0.884 6281.44 1131.34 N 6242.55 E 5964863.75 N 699151.62 E 1.036 6340.81 1119,85 N 6303.72 E 5964853.83 N 699213.07 E 1.420 6399.65 1108.96 N 6361.88 E 5964844.44 N 699271.49 E 1.556 6455.61 1101.64 N 6405,42 E 5964838.24 N 699315,20 E 1.946 6497.61 1098.84 N 6425.32 E 5964835.95 N 699335,17 E 2,684 6516.89 1096.33 N 6445,52 E 5964833,96 N 699355.43 E 3.051 6536.51 1094.08 N 6465.95 E 5964832,24 N 699375.91 E 1,756 6556.39 1091.75 N 6486.42 E 5964830.43 N 699396.44 E 4.092 6576.30 1088.78 N 6507.35 E 5964828.01 N 699417.43 E 5.616 6596.58 1085.17 N 6528.80 E 5964824.94 N 699438.97 E 6.210 6617.27 1080.71 N 6550.89 E 5964821.05 N 699461.16 E 9.116 6638.47 1075.46 N 6573.61 E 5964816.38 N 699484.01 E 5.073 6660.18 1069.97 N ' 6596.71 E 5964811.49 N. 699507.24 E 2.708 6682.23 1064.46 N 6620.28 E 5964806.59 N 699530.95 E 4.593 6704.75 1059.31 N 6644.41 E 5964802.07 N 699555.20 E 6.331 6727.87 1054.94 N 6669.17 E 5964798.33 N 699580.06 E 8.672 6751.72 1051.67 N 6694.79 E 5964795.72 N 699605.76 E 10.460 6776.59 1049.46 N 6720.84 E 5964794.18 N 699631.86 E 6.627 6802.04 1047.77 N 6747.52 E 5964793.17 N 699658.57 E 2.237 6828.18 Comment Continued... 18 August, 1998 - 16:23 - 3 - DrfllQuest Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl, Azim, Depth Depth (ft) (ft) (ft) 11650,64 58,900 91,960 8520,73 8571,56 11682,54 60,750 89.860 8536,67 8587,50 11714.01 62.490 88.710 8551.62 8602.45 11745,81 63,510 89,210 8566,06 8616,89 11777,67 64.440 91,360 8580,04 8630,87 11809,29 68,450 93,310 8592.67 8643,50 11841,49 71,490 93.980 8603,70 8654,53 11873.37 75.260 92,980 8612,82 8663,65 11905,10 76,650 91,570 8620,52 8671,35 11936,60 76,940 91,110 8627,72 8678,55 11968.35 77.190 91.720 8634.83 8685.66 12000.22 78.640 91.070 8641.50 8692.33 12031.94 82.670 88.360 8646.65 8697.48 12063.83 83.190 86.500 8650.57 8701.40 12095.46 85.230 82.470 8653.77 8704.60 12126.78 86.460 80.440 8656.04 8706.87 12158.55 88.770 79.640 8657,36 8708.19 12190.42 89.970 79.280 8657.71 8708,64 12222,21 88.590 79.270 8658.11 8708.94 12253.91 88.770 79.050 8658,64 8709.67 12285.70 92.310 79.140 8658,64 8709.37 12316.81 93.480 79.390 8656.97 8707.80 12348.64 93.510 79.160 8655.03 8705.86 12380.28 93.870 79.410 8652.99 8703.82 12408.35 94,100 79.310 8651.04 8701.87 12439.91 94.260 79.360 8648.74 8699.57 12471.54 93.050 78.620 8646.72 8697.55 12504,04 89.290 79.390 8646.06 8696,89 12535.43 89,020 79.740 8646.52 8697.35 12567.05 90.180 79,090 8646,74 8697.57 Sperry-Sun Drilling Services Survey Report for L2-18A Your Ref: API-500292176601 Local Coordinates Northings (ft) 1046,55 N 1046,12 N 1046,46 N 1046,98 N 1046,83 N , 1045,64 N 1043,72 N 1041,87 N 1040,65 N 1039,93 N 1039,17 N 1038,41 N 1038,57 N 1039,g9 N 1043,01 N 1047,65 N 1053,14 N 1058,97 N . 1064,89 N 1070.85 N 1076,86 N 1082,65 N 1088,56 N 1094,43 N 1099,60 N 1105,43 N 1111.46 N 1117,65 N 1123,34 N 1129,14 N Global Coordinates Dogleg Vertical Easflngs Northings Eastings Rate Section (ft) (ft) (ft) (°/100ft) (ft) 6774,50 E 5964792,64 N 699685,57 E 5,441 6864,70 6801,89 E 5964792,92 N 699712,97 E 8,176 6881,74 6829,58 E 5964793,98 N 699740,64 E 6,396 6909,18 6857,91 E 5964795,22 N 699768,94 E 3,500 6937,28 6886,53 E 5964795,81 N 699797,56 E 6,730 6965,57 6915,49 E 5964795,36 N 699826,64 E 13.884 6994,04 6945,67 E 5964794,21 N 699856,76 E 9,641 7023,63 6976,16 E 5964793,15 N 699887,29 E 12,201 7053,52 7006,91 E 5964792,72 N 699918,06 E 6.146 7083,77 7037,57 E 5964792,79 N 699948,73 E 1,694 7113,99 7068,51 E 5964792,82 N 699979,68 E 2,031 7144,48 7099,66 E 5964792,86 N 700010,84 E 4,968 7175,19 7130,95 E 5964793.82 N 700042,11 E 15,246 7206,17 7162.56 E 5964796,05 N 700073,68 E 6,013 7237,65 7193,88 E 5964799.88 N 700104,91 E 14,222 7269,07 7224,77 E 5964805,32 N 700135,67 E 7.564 7300,31 7256.03 E 5964811.61 N 700166.78 E 7.694 7332.04 7287.36 E 5964818.24 N 700197.95 E 3.931 7363.88 7318.59 E 5904824.96 N 700229.01 E 4,341 7395.64 7349.72 E 5964831.71 N 700259,98 E 0.897 7427.31 7380,92 E 5964838.53 N 700291.02 E 11.139 7459,06 7411.45 E 5964845.09 N 700321.39 E 3.846 7490.10 7442,67 E 5964851.81 N 700352.44 E 0.727 7521.85 7473,69 E 5964858.47 N 700383.31 E 1.384 7553.39 7501.21 E 5964864.35 N 700410,68 E 0.893 7581.38 7532.14 E 5964870.97 N 700441.46 E 0.531 7612.83 7563.13 E 5964877.79 N 700472.28 E 4.482 7644.36 7595.02 E 5964864.80 N 700504.00 E 11,809 7676,81 7625.89 E 5964891,28 N 700534.71 E 1.408 7708.18 7656.97 E 5964897.88 N 700565.63 E 4.205 7739.77 Comment Alaska State Plane Zone 4 Lisburne DS 02 Continued,,, 18 August, 1998 - 16:23 - 4 - DrfllQuest Prudhoe Bay Unit Sperry. Sun Drilling Services Survey Report for L2-18A Your Ref: API-500292176601 Alaska State Plane Zone 4 Lisburne DS 02 Measured Sub-Sea Veffical Depth Incl. Azim. Depth Depth (ft) (fi) (fi) 12598.86 91.320 79.460 8846.33 8697.16 12630.60 91.380 79.220 8845.58 8696.41 12661.96 92.160 79.960 8844.61 8695.44 12693.72 92.400 79.720 8643.35 8694.18 12725.22 92.740 80.450 8841.93 8692.76 12756.86 92.780 80.500 8640.41 8691.24 12788.64 93.110 80.510 8638.78 8689.61 12820.41 93.820 80.500 8636.86 8687.69 12852.86 92.370 78.900 8635.11 8685.94 12884.72 88.580 78.000 8634.84 8685.67 12916.10 88.650 78.220 8635.60 8686.43 12947.82 89.230 77.490 8636.19 8687.02 12979.17 89.420 78.040 8636.56 8687.39 13010.82 90.120 79.840 8636.68 8687.51 13042.25 90.550 81.810 8636.50 8687.33 13073.97 89.970 82.520 8636.36 8687.19 13105.68 92.650 83.520 8635.63 8686.46 13137.36 93.470 82.830 8633.94 8684.77 13169.87 93.790 83.010 8631.88 8682.71 13200.74 92.800 83.090 8630.11 8680.94 13232.00 91.480 83.160_ 8628.94 8679.77 13263.45 91.790 83.140 8628.04 8678.87 13294.91 91.050 81.840 8627.26 8678.09 13327.59 90.490 82.620 8626.82 8677.65 13359.37 89.110 82.430 8626.93 8677.76 13391.28 87.040 82.360 8628.01 8678.84 13422.68 85.350 82.290 8630.09 8680.92 13454.25 86.820 82.640 8632.25 8683.08 13486.02 91.080 82.310 8632.83 8683.66 13517.56 94.160 82.340 8631.39 8682.22 Local Coordinates Global Coordinates Dogleg Ve~ical Nothings Easflngs Nothings Eastings Rate Section (fi) (fi) (fi) (fi) , (°/100fi) (fi) 1135.06N 7688.22 E 5984904.60N 700596.72E 3.768 7771.55 1140.93N 7719.40E 5984911.27N 700627.74E 0.779 7803.26 1146.60N 7750.23E 5984917.72N 700658.41E 3.428 7834.59 1152.20 N 7781.47 E 5984924.12 N 700689.50 E 1.068 7866.31 1157.61N 7812.46 E 5964930.33 N 700720.35 E 2.584 7897.76 1162.84N 7843.63 E 5984936.36 N 700751.37 E 0.202 7929.36 1168.08 N 7874.94E 5964942.40 N 700782.53 E 1.039 7961.09 1173.31N 7906.21E 5964948.43 N 700813.66 E 2.235 7992.80 1179.10 N 7938.09 E 5964955.04N 700845.38 E 6.849 8025.18 1185.48 N 7969.30 E 5964962.22 N 700876.41E 12.226 8056.98 1191.94N 8000.00 E 5984969.47 N 700906.93 E 0.736 8088.30 1198.62 N 8031.00 E 5984976.94N 700937.76 E 2.939 8119.94 1205.26 N 8061.64E 5964984.36 N 700968.21E 1.856 8151.22 1211.39 N 8092.69 E 5984991.29 N 700999.09 E 5.518 8182.83 1216.45 N 8123.70 E 5964997.15 N 701029.97 E 7.038 82t4.25 1220.78 N 8155.13 E 5965002.28 N 701061.27 E 2.890 8245.97 1224.63 N 8186.59 E 5965006.93 N 701092.63 E 9.020 8277.66 1228.39 N 8218.00 E 5965011.50 N 701123.93 E 3.381 8309.28 1232.39 N 8250.20 E 5965016.32 N 701156.01E 1.129 8341.72 1236.11N 8280.79 E 5965020.84N 701186.50 E 3.217 8372.53 1239.85 N 8311.80 E 5965025.37 N 701217.41E 4.229 8403.76 1243.60 N 8343.02 E 5965029.92 N 701248.51E 0.988 8435.18 1247.80 N 8374.18 E 5965034.91N 701279.56 E 5.602 8466.63 1252.30 N 8406.55 E 5965040.25 N 701311.80 E 3.722 8499.30 1256.43 N 8438.06E 5965045.19 N 701343.19 E 4.383 8531.08 1260.65 N 8469.67 E 5965050.22 N 701374.69 E 6.491 8562.97 12844.84N 8500.72 E 5965055.20 N 701405.62 E 5.387 8594.29 1268.97 N 8531.94E 5965060.13 N 701436.72 E 4.786 8625.78 1273.13 N 8563.42 E 5965065.10 N 701468.09 E 13.449 8657.54 1277.33 N 8594.84E 5965070.10 N 701499.19 E 9.766 8689.04 Comment Continued... 18 August, 1998 - 16:23 - 5 - DrillQuest Sperry. Sun Drilling Services Survey Report for L2-'i8A Your Ref: API-500292176601 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) fit) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 13549.17 94.990 82.490 8628.86 8679.69 1281.49 N 8625.88 E 5965075.06N 701530.31E 13581.91 95.180 82.630 8625.96 8676.79 1285.72N 8658.21E 5965080.11N 701562.53 E 13642.42 93.700 83.320 8621.28 8672.11 1293.09 N 8718.09 E 5965089.03 N 701622.19 E 13677.21 92,000 84.050 8619.55 8670.38 1296.91N 8752.62 E 5965093.74 N 701656.62 E 13708.71 91,660 84.350 8618.54 8669.37 1300.10 N 8783.95 E 5965097.72 N 701687.85 E 13740.61 91.790 84.190 8617.58 8668.41 1303.28 N 8815.67 E 5965101.72 N 701719.48 E 13772.37 92.340 84.070 8616.44 8667.27 1306.53 N 8847.24 E 5965105.77 N 701750.96 E 13804.11 92.710 85,000 8615.04 8665.87 1309.55 N 8878.81E 5965109.60 N 701782.44 E 13835.83 92,190 84,130 8613.68 8664.51 1312.55 N 8910.36 E 5965113.41N 701813.90 E 13867.57 90,860 84.790 8612.84 8663.67 1315.61N 8941.94E 5965117.29 N 701845.39 E 13899.37 91.290 83,610 8612.24 8663.07 1318.82 N 8973.57 E 5965121.31N 701876.93 E 13931.10 91.690 82,400 8611.42 8662,25 1322.69 N 9005.05 E 5965125.98 N 701908.30 E 13962.73 91.360 82.540 8610.58 8661.41 1326.83 N 9036.40 E 5965130.93 N 701939.53 E 13994.47 91,230 82.270 8609.86 8660,69 1331.02 N 9067.85 E 5965135.93 N 701970.86 E 14014.42 91.510 82.100 8609.38 8660.21 1333.74N 9087.61E 5965139.15 N 701990.55 E 14070.00 91.510 82.100 8607.92 8658.75 1341.37 N 9142.64E 5965148.19 N 702045.37 E 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 Degree__s per 100ft. ?iVertical Section is from Well and calculated along an Azimuth of 81.610° (True). .. Based upon Minimum Curvature type calculations, at a Measured Depth of 14070.00ff., The Bottom Hole Displacement is 9240.52ft., in the Direction of 81.653° (True). Dogleg Rate ("/'lOOft) 2.668 0.720 2.697 5.317 1.439 0,646 1.772 3,151 3.193 4.678 3.949 4,015 1.133 0,944 1,642 0,000 Vertical Section (fi) 8720.55 8753.15 8813.46 8848.18 8879.64 8911.49 8943.20 8974.86 9006.51 9038.20 9069.96 9101.67 9133.29 9165.01 9164.96 9240.52 Comment Projected Survey Alaska State Plane Zone 4 Lisburne DS 02 Continued... 18 August, 1998 - 16:23 - 6 - DrillQuest Prudhoe Bay Unit Sperry. Sun Drilling Services Survey Report for L2-18A Your Ref: A PI.50029217660 Alaska State Plane Zone 4 Lisburne DS 02 Comments Measured 8205.83 8298.00 1407o.00 Station Coordinates TVD Northings Eastings (rt) (ft) (ft) 6057.07 1447.93 N 4501.83 E 6112,26 1472.46 N 4571.46 E 8658.75 1341.37 N 9142.64 E Comment Tie-on Survey Window Point Projected Survey 18 August, 1998 - 16:23 - 7. DrillQuest 0 Ft I I--I-- I I~1G S ~: !:! ~./I I~ E S 19-Aug-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well L2-18A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,205.83' MD 8,298.OO' MD 14,070.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEtVED AUG 2 6 1998 Alaska Oil & Gas Cons, Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (90.7) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. MEMORANDUM State of Alaska TO' f~Alaska Oil and Gas Conservation Commission David Jo/hr~×, DATE: July 19, 1998 Chairman THRU' Blair Wondzell, .~.~~,, FILE NO: P. I. Supervisor FROM' John Spaulding, ~ SUBJECT: Petroleum Insp.?~/d~'~'' adflgsfe.doc Confidential: Yes BOPE Test Doyon 9 ARCO / PBU / L2-18 PTD 98-106 No X July 19, 1998: I traveled to ARCO's Lisburne Field to witness the BOPE Test on Doyon rig 9. The AOGCC BOPE Test report is attached for reference. As noted on the test report no failures were observed. The test went very well, the location and the rig were clean and good access was available. Summary: I witnessed the successful BOPE test on; Doyon Rig 9, 7/19/98, Test time 3 hrs. 0 failures Attachments' adflgsfe.xis STATE OF ALASKA ...... OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initia X Workover: Doyon Rig No. 9 PTD # ARCO/SSD Rep.: L2-18A Rig Rep.: Set @ Location: Sec. Weekly Other TEST DATA: 98-106 DATE: 7/19/98 Rig Ph.# 559-4831 Richard Bordes Tim Krupa 18 T. 11N R. 15E Meridian Umiat MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok PTD On Location ok Standing Order Posted (Gen) ok FLOOR SAFETY VALVES: Well Sign ok Upper Kelly/IBOP Drl. Rig ok Lower Kelly / IBOP Hazard Sec. ok. Ball Type -~ Inside BOP Test Quan. Pressure P/F I 25O/5,000 P 250/5, O0O P 250/5, OOO P 250/5,000 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. P/F P P P f P P 2 P 1 P NA f 250/2500 I 250/5, 000 I 250/5,000 250/5,000 1 250/5,000 250/5,000 250/5,000 250/5,000 MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok - H2S Gas Detector ok ok ' CHOKE MANIFOLD: No. Valves f4 No. Flanges Manual Chokes 1 Hydraulic Chokes I Test Pressure P/F 25O/5, OOO P 36 250/5,000 P P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 5@2050 AVG. 3,050 P 1,700 P minutes 30 sec. minutes 22 sec. X Remote: X Psig. TEST RESULTS : ::: : Number of Failures: 0 ,Test Time:( 3.0 Hours. Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within 0 ~lays. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector F1-021L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: gsfe.xls John H. Spaulding EXPLORATION -+ AOGCC ~001 BP EXPLORATION To: Blair Wondzell Bate: July 6, 1998 From: Allen Sherritt. ODE, SSD MB 8-1 Subject: _Change in P&A_end Kick off depth for L2-18A Permit #: 98-106 Casing depths: 9 5/8"at 12,434' MD, 7" at 12,278' MD to I3,160'M. L2-18A is planned as a Zone lB producer, extended horizontal side-track targeting a DS 18 BHL. The original 8 W' sidetrack was planned @-10,000'MD/7159'TVD in the 9 5/8' casing above the existing production packer. The 6" horizontal section will be drilled along the base of Zone 1 to 14,053' MD and completed with a 4 ~' L-80 solid cemented liner and 4 ~' L-80 tubing. The proposed side-track will improve the drainage pattern and maximise standoff from the GOC. During the de-completion of L2-18, the 9 $/8" casing was found to be damaged from 8484'MD to 9830'MD. The decision was made to bring the KOP point back up the hole to 8300'MD. A section will be milled from -8300'MD to ~8345'MD. The well will be drilled as per the original plan. The 7" liner point will be -11,109'MD and TD of the 6" hole will be -13,681'MD. The targets and purpose of the well have not changed. The well has been P&A'd from below the 9 5/8' production packer to 10,400'MD inside the 2 7/8" tubing stump. The 9 $/8~ casing has been P&A'd from ~9,830'MD to 8,830'MD with two 500' balanced cement plugs. An EZSV was set @ 8,460'MD and cement was squeezed below the retainer to fill the remaining 9 5/8" casing. See the attached P&A drawing. Mr. Blair Wondzell verbally apse adjustm~,,to L2-18A on W4/98. Approved by: ~ B~dllin/ /'"] ' ; S~u~e~~intendent D~~~'/~~ 0 6 1998 07/06/'98 09~$2 FAX 907 564 5193 BP EXPLORATION ~ AOGCC ~002 P&A Condition EZSV @ Tubing Cut -9838'MD TOC @ ~ t 0400'M D FMC Hanger Original RKBE; 45' Hanger: 29.¢ Ms Hole An#e: 56~ [ Jewel~ (J) C-1 1 11474 9 5/8" x 2 7/8 Brown H-B Retrievable Packer 2 12152' 9 5/8" x 7" CPH Liner Packer Cemented in piece 3 12496' 3-1/2" Camco D-Nipple Min iD: 3-1/1~" Camco D-Nipee Casing and Tubing (C) Size Wt, Grade Top I 13-3/8" 72# b80 2 9-5/8" 47# L-80 3 7" 29# b80 2-7/8" 65# b80 Btm. Description 0' 4i15' Casing 0' 12434' Casing 12278' 13160' Liner 9838' 12508' Tubing J-I J-2 J-3 P-I Perforation Data (P) ~ntervai Zone FT 1 12585-12629 Wahoo 64 2 12633-12812 Wahoo 179 3 12817-12944 Wahoo 127 4 1298t-13058 Wahoo 114 PBTD = 13086' MD TD = 13160'MD Annulus fluids: Gas Lift, Ma× H2S Measured = 90 PPM SPF Gun 4 TT 4 TT 4 ~ 4 TT P-3 P~4 C~3 Existing Wellhead:FMC GenlV (2") 2 7~8" ¢om¢~tiorl: 2" Tubing Head Adapter 2" Corn#etlon 2" FMC Gert ~V Tree Will not be able to reuse Date 7~6~98 RevisedjAs bYI Comments PRUDHOE BAY UNIT WELL: L2-18 APl #: 50~029-21766-00 X Shared Services Well: L2-18A ] DrillQuest' PROPOSAL. TARGET SUMMARY 6~[~ ~.'1131~ lt'~UgH,'l~7,c6 E ~41Ka'oe]l,~'T. afl 1E.,D3'E SURFACE LOCATZON J PLOT DATE: 03-J UL-98 ImtB Elgv~t~,~: ~lnale .'~y~tem: ~,calg~ linch; 600It Eastlngs 4500 ~'109 Sc. hie: linch --fi)Oft - 1800 - 120D~ t' 600 I L J I t t KtWerence Is Tm North X I Shared Services Drilling Well: L2.18A Wp4 I DrillQuest- 6300 ,C6900 LO ~1100 ~ -- 4500 8cmla; t inch = 60Blt ~l,,.l~r · 10,~'rlCee:,~eex)Cil MD. lilt3,1~lt*TVD I (] ,OKrYt ~::lt = l~l~ao, ix~, MD, GI~Z.~h:'TiJD PROPOSAL TARGET SUMMARY ,1~ ~ ~l.TO 1~ H,B~I E SURFACE LOCA~ PLOT DA~: 03-~UL-98 EI~: C~Xdlnnle~'~an~; Checked ~: /-'/" I I Sperry-Sun Drilling. Services Proposal Report for L2-18A WP4 Prudhoe Bay Unit Measured Depth incl. Sub.b'~ea DepIh Vertical Legal CoQ rdin stes D eplh Nort~ngs Ea sttngs 8300.00 53.422 70,581 6082:.10 G113.80 8360.00 4,7.422 70.581 6100.31 0152.0 84~0,00 45,556 7,5.45'~ 6127.85 6179.155 85{30,C,0 41,915 88.959 6200.26 8251 i~90.00 40,053 103.968 RP75.93 6327.~ 8606.66, 40.000 105,000 6281.03 6a:]2.73 66:~..02 42.024 103.727 !~00.00 42.024 103.727 6~350.59 64~32,39 BBDD.DD 42,024 i03.727 842.4.917 6476.0"7 B900.00 42,024 103.727 6499.26 6550.96 9000,00 42,024 1Oa~72'/ 657S.55 BF:~.5.25 9100.00 42,024 10~727 6547..~ 5899.53 9200,00 42,024 1 tta.727 8722.12 6773.82 9300,00 42,024 103.727 6796,41 9400,00 42,024 ~ 03,727 6870,69 6922,39 9500.00 42..024 103,'TZ7 6944.1~ 6996.68, 9600.00 42.024 103,.727 7019,,.27 7070.97 6700.00 47_.~24 103.72'/ 7093.55 7145.25 97{38,68 42.Jt24 103.727 7100.00 7151.70 9800,00 4Z.Q2.4 103,727 71 b'7.84- 7219.54 9l~,0.00 42.024 '[03.727 7242. f3 7293.83 le000,00 42.024 103.727 7316,41 7366.11 le100.00 42.024 le3.727 73.~0,70 744?..48 lO2OQ.OO 42.024 103,727 74~4.98, 7516.6B 10:3110,.00 42.024- 103,727 7539;27 7.590.97 10314-_44 42,024- 103~727 7550.00 7601.70 10400.OO 42.,024 103.727 7513.55 7665.25 1 BSO0.~0 42,024 103.727 75R7.Bq 7739.54 10600.00 42.024 t 6;TL727 7752.13 7613.83 10700,D0 42.024 103.727 7836.42 7888.12 1472.76 N 4572.32 E 1455,13 N 4615.91 E 1496,61 Iq 4643.64 E 1506.20 N 4711.76 E 1499.03 N 4776.54 E 1497,95 N 47S0.69 E 1493.50 N 4798.08 E 1483.02 N 484~.99 E 1467,14 N 49~5.02 E 1451.25 N 4971.05 E 14535.87 N 5036.0g E t4[8A8 N 5~01.12 E 141]~,59 N 5166.15 E '[357.21 N 6231.18 E 1371Jt2 N 6296.21 E 1355.95~ N 5361,24 E 1340.05 N .5426,27 E 1324.10 N 5491.31 E 1322.78 N 54!}6.95 E 1308.28 N 5556,34 E 1292.39 N 5621.37 E l'276,50 N .555~L40 E 1260,§2 N 5751A3 E 1244.73 N 51116.4,7 E 1225.85 N 5881.50 E 1221}.55 N 5890,89 E 1212.96 N 5946.53 E 1197.07 N 6011.55 E 11B'L19 bJ 6076.59 E 1165.30 N 6141.62 E (;lloba] Coordinates Dogleg Vertical North~n.qs ;:askings Rele Section (ft) Ct) ('n0Oa) 5955162.16 N 697473.17 E 4738.30 5965178,64 N 697516.36 E 10_~00 4783.67 5~!65187,63 N 697543.86 E 10,000 4812.34 5965199,17 ht 697611.71 E 1O,O00 4851.~3 5965193,6{; I~! 597676.66 F_. JO. ODD 4944.t7 ,Sg6,.,,~OBS.63 N 898264.64'E 0,000 5501.7a 5E6.5051,.4~- N 698330.26 E 0.008 55E3.75 5~65037.21 N 6983~5,68 E O. O00 565~.76 511651)35.98 N ~1.~ E O-OOO 5~1.15 5~23,00 N ~1.~ E 0.000 5657,~ 5964949 -q0 N b-'99797.S3 F__. 0.000 5964937.74- N 698053.B[I E 0.000 6059.88 5964923,53 N 698919.02E 0,0'0,0 6121 59B4909.32 l'q 69898~44 E ~D.O00 61 ~.92 5964695,11 N 699049,86 E O.OOO 6245.93 Alaska State Plane Zone 4 Lisburne DS 02 Comment Tie-on, Slart DIr ~ le,6~o~/1oolt - s3oo.ooft MD, 611S,81~t TVD Conllnue DIr @ 10,006°/~10Dft · 83B0.00f( MD, 6"t5';.01fl. TVO Co]~fil'a~ Dir @ 8.00D=/i0~lt: 8606.6{~11 k$D, 6332,73ETVD F_~ nil-. ar[ ~ 42.024°: 8634.02~t MD. 6353.375rt TVD K"lO C~n~lnupd... 6 July, 159~- 9:44 Sperry-Sun Drilling Services Proposal Report for 1_2-18A WP4 Prudhoe Bay Unit M~sured Sub-Sea VerticaL Lecal Coordinates Global Coordinates Dogleg Vertical Depth - .[acl, AzUre. Depth Depth Nnrlhings Eastlngs Northlngs Eastings Rate Section Comment 10800.00 42.024 103.727 7~10.70 7962,40 1149.42 N 6205.6s E 596481~0.69 N 699115,26 E 0.000 6307.95 10~6,00 42.024 q 03.727 79t~t,99 8036,69 1133.53 N 6271.6q E 54J64 8~6.58 N 699180,70 E 0.000 6369.97 110~,00 42.l)24 103,7Z7 8059.28 8! 10.98 1t17.64 N 6336.72 E 5~54 852.47 N 699248.1 l F_ O,0{~ 643~.98 111~13 42,0~ 1~.7~7 11500.00 45.7~ 100.876 Alaska S~ P~e ,~,4 6 July, -2- DrttlQuest Sperry-Sun Drilling Services Proposal Report for 1_2-18A WP4 z Prudhoe Bay Unit Measured Sub-Sea Vertical Local Coonflnates Depth Incl. Azim. Depth Oaplit Northlngs Eastings {~t) ~) ~) (fl) lP_EQt~.OD 90.727 80.91~. 5541.15 BSB2.1i8 1154,7B N 7693.81 E [2~.00 90.727 80,~ B839.~1 86~.~ ] ~70,47 N 7992,56 E ~3~.0~ 90.727 80,9~ 8638.~ 8~0.34 116~.14 N 509~.32 E 131~,~0 90.~7 80,982 B637.37 B~.O7 1201.81 N 8~90.~8 E 1~,~ 90.~7 ~.982 8636,10 8~ 1217.49 N 8288.83 E 13300,Q0 :90,727 0G.982 8G34.83 BBBF:~3 1233.46 N ~7,59 E 1~,~ 90.7~ 60.082 ~3.~ 8665~ 1248.94 N ~6,~ E t~,Oe 9D.727 ~.a~ ~632.~0 a604.~ ~264,51 N ~.10 E 1~.00 90.727 ~,9~ 8631.~3 8682.~ 1280,18 N 8~3.85 E 13~i.06 90.727 ~ 8630.~0 8681,7~ 1~.89 N ~.g~ E Global Coordinates Dogleg Vertical Northings Eastl rigs R;d~ Sect[on (,~) Cfr) t=~O~) 5964929,60 N 700801.73 E O_0(]0 7:~77.82 59(;4947.81 N 700900.06 E 59~9~.22 ~ 701096.70 E 5955002.42 N 701195.02 E O.e~ ~.~ 5965020.63 N 701,29:3.34 E O, Oi)O 8477.75 5965038.83 N 701391.6~ E O.00~ 4~-77.74 5965(]57.04 N 7[)1489,96 E 0.~1~0 6b'77.72 5965075,24 N 7015~,30 E O.a~O ~.7~ 59E5~ D,OO N 701~6B,OO. E 0.~00 ~76 All dale is in fee~ u~less otherwise stated, Directions am:l coord'mates sm relalive !o True No~th. Vertical depths ar~ relal[ve to Well No[things and Ea~ngs are re~a~t[ve to Wall. The Dogleg Severity is In Degrees par 100ft Vertical Seclion islmm Well and calmJ~led along an Azimuth of 61.608° (True}. 8seed upon Minimum Curvature type calculations, at a Measured Depth of 13661.06ft., The Bottom Ho~e Displacement Ts 8858.761~, in the Direction of 81.608~ (True}. Alaska State Plane Zone 4 Lisburne DS 02 Comment ar§el: t.2-18A T2, Gsological TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 9, 1998 Dan Stone Engineering Supervisor ARCO Alaska, Inc. POBox 196612 Anchorage, AK 99519-6612 Re~ Prudhoe Bay Unit L2-18A ARCO Alaska, Inc. Permit No. 98-106 Sur. Loc. 1672'NSL, 3694'WEL, Sec. 18, T11N, RI5E, UM Btmnholc Loc. 2318'SNL, 5074'EWL, Sec. 17. R15E, UM Dear Mr. Stone: Encloscd is the approved application for permit to rcdrill the above referenced well. The permit to redrill does not exempt you from obtaining additional pcnnits required by law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations arc 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 ission petroleum ficld inspcctor on the North Chairma/~ ) '"-,,~ ~ dlf/Enclosures cc: Dcpartmcnt of Fish & Game. Habitat Section w/o cncl. Departmcnt of Environmcntal Conservation w/o cncl. STATE OF ALASKA ALASKA O~_ AND GAS CONSERVATION COM.~. ,SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI I-IService [] 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 = 51.7' Prudhoe Bay Field/~i~,bur~,e Oil 3. Address 6. Property Designation 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) 1672' NSL, 3694' WEL, SEC. 18, T11N, R15E, UM Prudhoe Bay Unit / At top of productive interval 8. Well Number Number U-630610 2564' SNL, 3516' EWL, SEC. 17, T11N, R15E, UM L2-18A At total depth 9. Approximate spud date Amount $200,000.00 2318' SNL, 5074' EWL, SEC. 17, T11N, R15E, UM 06/11/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 026322, 206'I L2-18 is 23' at 10196' MD 2560 14053' MD / 8630' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10000' Maximum Hole Angle 90.8 ° Maximum surface 2595 psig, At total depth (TVD) 8800' / 3475 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 IBT-Mod 1572' 9850' 7014' 11422' 8140' 294 sx Class 'G' 6" 4-1/2" 12.6# L-80 IBT-Mod 2781' 11272' 7922' 14053' 8630' 337 sx Class 'G' '19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Tot,., ,,,,th= r,',,,,,.sureo, ,3193 fee, true vertical 9221 feet Effective depth: measured 13086 feet Junk (measured) true vertical 9156 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 1850# Poleset 110' 110' Surface 4115' 13-3/8" 3000 sx AS III, 600 sx 'G', 175 sx AS I 4115' 3593' Intermediate Production 12434' 9-5/8" 900 sx Class 'G' 12434' 8730' Liner 913' 7" 375 sx Class 'G' 12276' - 13189' 8633' - 9218' Perforation depth: measured 12565' - 12629', 12633' - 12812', 12817' - 12944', 12981' - 13058' true vertical 8820' - 8863', 8866' - 8984', 8987' - 9068', 9091' - 9138' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis []Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: J. Allen Sherritt, 564-5204 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~--:~-,- ~-o ~ Title Engineering Supervisor Date ¢/'ti Dan Stone · Commission Use Only Permit Number I APl Number I Approyal Date I See cover letter ¢~- /)¢"~ ~,~ 50-029-21766-01 ~.~¢ ~7,,~ for other requirements Conditions of Approval: Samples Required []Yes ,J~No Mud Log Required []Yes ,~No Hydrogen Sulfide Measures [~es []No Directional Survey Required J~Yes I--INo Required Working Pressure for DOPE []2M; []3M; []5M; [] 10M; [] 15M Other.Original Signed By' by order of i Approved By David W. Johnston Commissioner the commission Date~- Form 10-401 Rev. 12-01-85 Submit In Triplicate Iwell Name: r L2-18A I Sidetrack Plan Summary Type of Redrill (producer or injector): I Producer Surface Location: X=692,940.19 Y=5,963,572.45 Target I Location: Bottom Hole Location: I FSL: 1,673', FWL: 1,248', Sec. 18, T11N, R15E, UM X=700118 Y=5964803 FNL: 2564', FWL: 3516', Section 17, T11N, R15E X=701668 Y=5965090 FNL: 2318', FWL: 5074', Section 17, T11 N, R15E I AFE Number: 14JO355 I I Rig: J Doyon9 I I Estimated Start Date: 16-11-98 I I Operating days to complete: 121.2 I MD: 114,053' I ITVDss I8630, I ~KB ~51.7' I I Well Design (conventional, slimhole, etc.): I Ultra-slimhole Extended Horizontal Side-track Objective: I Access Zone lB reserves of 1.14 MMSTBO and maximize GOC standoff. Mud Program Intermediate (8-1/2" hole) Section: 6 % KCL-Baranex/Barotrol [ Density, ppg Funnel Vis, sec LSR YP Gels pH HPHT FL, cc 10.4 - 10.5 45 - 60 25 - 35 4 - 10/15 - 25 8.5 - 9.5 <12cc 10.4 - 10.5 45 - 60 7 - 13 4 - 10/15 - 25 8.5 - 9.0 <12cc Hazards/Concerns I Potential high torque could require lubricant use. I Be alert for lost circulation, differential sticking due to higher MW. Production Hole (6" hole) Section: 4 % QUICKDRILn 8.6 - 8.8 45 -65 12 - 25 35000-55000 8.5 - 9.0 NC Keep Sand content at less than 0.25% in the production interval Directional KOP: Maximum Hole Angle: Close Approach Wells: 10,000' MD 90.8° L2-18 (P&A Shut-in) 23' @ 10196' MD T-03C/(A/ETR3C) (P&A'd) 289' @ 12,306' MD Formation Markers Formation Tops MD TVD (SS) K10 9,983' 7100' KOP will be at 10,000'MD; 7107'TVDSS K5 10,614' 7550 Put River 11,401' 8125 BLC U/TSAG 11,415' 8135' TSHUB 11,436' 8150' TSAD 11,504' 8200' Zone 3 11,655' 8310' Zone 2 11,740' 8370' Zone 1/Romeo 12,000' 8530' CGOC 12,095' 8575' Target Polygon Start 12,477' 8650' TD 14,053' 8630' BSAD 8655' Casin[ q'ubing Program Hole Size Csg Wt/Ft Grade Conn Length Top Btm MD/'TVDss MDrrVDss Existing 13-3/8" 72# L-80 BTC 4,115' Surface 4,115'/3,548' Existing 9-5/8" 47# L-80 BTC 12,434' Surface 12,434'/8,685' 8 Y2" 7" 26# L-80 IBT-MOD 1,572' 9,850'/7,014' 11,422'/8,140' 6" 4.5" 12.6# L-80 IBT-MO D 2,781' 11,272'/7,922' 14,053'/8,630' Tubing 4.5" 9.2# L-80 IBT-MOD 11,272' Surface 11,272'/7,922' Cement Lead Cement Tail Cement Casing/Liner Sx / Wt / Yield Sx / Wt / Yield Comments P&A 142/15.8/1.15 Pre-Rig will P&A and displace cement to place TOC -12,465' MD. 7" 294/15.8/1.15 Drilling Liner Cemented, Class "G", TOC to 200' above liner top @ -9,850'MD. Volumes calculated w/30% excess OH. 4-1/2" 337/15.8/1.15 Solid Cemented Liner, Class "G", TOC to 200' above liner top @ -11,272'MD Volume assumptions: Gauge hole + 50% excess(Production Hole); 80' shoe joihts; TOC as listed. Logging Program ILogs: 6" Hole DPC Logs: MWD/GR/RES from Horizontal to TD. DPC logs will be run after TD of horizontal section. 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 @ 8800' tvdss. Maximum expected surface pressure at 8800' tvdss is 2595 psi (assuming gas column of 0.1 psi/E) Diverter, BOPE and mud fluid system schematics on file with AOGCC. Hazards L2 is classified as a H2S drillsite. Stuck pipe/lost circulation has been reported. Shallow gas (Ugnu, W. Sak) will not be penetrated. Put River (gas) EMW is 10.1 ppg over pressured. Kingak will be penetrated. Approximately 15' MD will be drilled @ 43° hole inclination. 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. L2-18A Summary of Operations 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; Pump cement to P&A the existing completion and perforations; Chemical cut existing tubing in the first full joint above production packer; 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. Perform CMIT on 9 5/8" casing and 2 7/8" tbg to 3000 psi. IA/OA. 4. Bullhead Seawater down tubing to kill well and establish injectivity. Note: if the tubing fails pressure test or there is Iow injectivity, the well ¢ill have to be P&A'd with . . Coiled Tubing. May need to pump LCM prior to cementing perforations to keep from losing the cement to the formation. (See Well L2-03 P&A.) 5. Pump 142sks. (24 bbls. Plus 5 bbls for down squeeze into perf's) of class G, 15.8 ppg cement to place TOC @ 12,465' MD. (100' MD above top perforation.) 6. RIH with chemical cutter and chemically cut tubing @ -11,427'MD (First full joint above 9 5/8" . Packer.) Notify Ops. Drilling Eng. If unable to cut tubing @ desired depth. 7. Freeze protect tubing. 8. Test packoffs on tubing and 9 5/8" annulus, and carefully cycle Iockdown screws. Set BPV. 9. Clear location, dig out cellar, remove electrical lines, flow lines, and remove well house. 10. RDMO Rig Operations 1. The rig will MIRU. 2. Confirm 9 5/8" packoffs tested to 3000 psi during pre-rig. 3. Pull BPV. 4. Circulate out freeze protection and circulate well with seawater. 5. Set TWC and test to 5000psi. 6. ND tree. NU BOP, and test BOP to 250/5000 psi. 7. Pull the tubing to the chemical cut above the production packer @ -11,427'MD. 8. Change packoff (if failed in Pre-Rig) after pulling two jts. of tubing, set on storm packer and test packoff. 9. RIH and set 9 5/8" EZSV - 10,020'MD on wireline as per CCL. 10. Pressure test casing to 3000 psi for 30 mins. 11. RIH and set 9 5/8" whipstock/milling assembly and set 25° right of highside. 12. Displace to 4% KCI Quikdriln mud. 13. Mill window to place KOP @ 10,000' MD. 14. POOH and PU 8 ~" kick off assembly with w/MWD/GR drill drop & turn to 7" casing point @ ~11,422. 15. Run 7" L-80 liner and set 9 5/8" x 7" hanger/packer TOL @ 9,850'MD. 16. Cement in place and pressure test to 3000 psi for 30 mins. 17. PU BHA w/MWD/GR for 6" hole and build to horizontal @ -12,477' MD. 18. PU BHA for horizontal section w/MWD/GR/RES and drill to TD -14,053'MD. 19. Run DPC logs over entire horizontal section. 20. Run 4 Y2" L-80 liner and set 7" x 4 ½" hanger/packer TOL @ -11,272' MD with 2 X nipples. 21. Cement via inner string. Pressure test liner to 3000 psi for 30 mins. 22. Perf as per asset direction. 23. Complete with 3 GLMs, an X nipple and a SSSV on 4-~" tubing and set w/7" x 4 ~" packer @ -11,172' MD. 24. Freeze protect well. 25. RDMO L2-18 FMC Hanger Original RKBE' 45' Existing Completion Hanger' 29.6' Max Hole Angle: 56 --~-~---r-' All Depths are RKB Drilling MD to top of equipment, ' _ ~ except where noted. -- J-1 ~ ~.C-1 Jewelry (J) Depth Description I J-2 1 2204' Camco TRDP-1A SSSV Nipple ID=2.312" ' 2 2288' Chem. Inj. Mandrel Camco I"KBMG-LTS Dummy BK2 3 11474' 9 5/8" x 2 7/8" Brown H-B Retrievable Packer 4 12152' 9 5/8" x 7" CPH Liner Packer Cemented in place 5 12496' 3-1/2" Camco D-Nipple ID=2.25". O-1 Min ID: 3-112" Camco D-Nipple ID=2,25". ~ G-2 ~ G-3 Casing and Tubing (C) Size Wt. Grade Top Btm. Description 1 13-3/8" 72# L-80 0' 4115' Casing 2 9-5/8" 47# L-80 0' 12434' Casing 3 7" 29# L-80 12278' 13160' Liner 2-7/8" 6.5# L-80 0' 12508' Tubing Gas Lift Information (G) MD TVDss Mandrel Valve Type Latch --i , J-3 1 6547' 4990' McMurray Dummy 1" BK ~ ~ J-4 2 9811' 6989' McMurray Dummy 1" BK ~1 ~k 3 11372' 7986' McMurray EODummy 1-1/2" TGE ~ C-2 Perforation Data (P) J-- Interval Zone FT SPF Gun ' ~ J-5 1 12565-12629 Wahoo 64 4 TT 2 12633-12812 Wahoo 179 4 TT P-1 3 12817-12944 Wahoo 127 4 .TT I P-2 4 12981-13058 Wahoo 114 4 TT PBTD = 13086' MD I TD = 13160'MD P-3 Existing Wellhead:FMC GenlV (2") P-4 Annulus fluids: Gas 2 7/8" completion: Lift. Max H2S Measured = 90 PPM 2" Tubing Head Adapter 2" Completion ~ k 2" FMC Gert IV Tree 0-3 Will not be able to reuse _Date Revised by Comments 5/27/98 JAS PRUDHOE BAY UNIT WELL: L2-18 APl #: 50-029-21766-00 FMC Hanger L2-18 Original RKBE' 45' P&A Condition Hanger' 29.6' Max Hole Angle: 56 All Depths are RKB Drilling MD to top of equipment, except where noted. Jewelry (J) ~ ~,C-1 1 11474' 9 5/8" x 2 7/8" Brown H-B Retrievable Packer ' 2 12152' 9 5/8" x 7" CPH Liner Packer Cemented in place 3 12496' 3-1/2" Camco D-Nipple ID=2.25". Min ID: 3-1/2" Camco D-Nipple ID=2.25". ~ Casing and Tubing (C) Size Wt. Grade Top Btm. Description 1 13-3/8" 72# L-80 0' 4115' Casing 2 9-5/8" 47# L-80 0' 12434' Casing ' 3 7" 29# L-80 12278' 13160' Liner 2-7/8" 6.5# L-80 11427' 12508' Tubing Tubing Cut -11427'MD Perforation Data (P) Interval Zone FT SPF Gun 1 12565-12629 Wahoo 64 4 TT ' 2 12633-12812 Wahoo 179 4 TT 3 12817-12944 Wahoo 127 4 TT ;~ J-1 4 12981-13058 Wahoo 114 4 TT ~ ~ J-2 TOC @ .,.,12465,MDj ~ ¢...~, PBTD = 13086' MD ~ C-2 TD = 13160'MD ;:~;~:~:;~' J-3 Annulus fluids: Gas Lift. ~ ,i Max H2S Measured = 90 PPM ;~~ii P-4 2Existing Wellhead:FMC GenlV (2")7,8. completion: ;:~ii~;,'?;¢i,~ 2" Tubing Head Adapter .. 2" Completion ~~~, 6-3 2" FMC Gen IV Tree !Will not be able to reuse Date Revised by Comments 5/27/98 JAS PRUDHOE BAY UNIT WELL: L2-18 AP! #: 50-029-21766-00 .._ L2-18A Sidetrack PROPOSED COMPLETION DESIGN SIDETRACK OUT OF 9 5~8" Casing 13-3/8" 72# L-80 BTC 4,115' MD 4-1/2" L-80, 12.6#, IBT-MOD Tubing + 2200' SSSV Landing Nipple Gas Lift Mandrels - Depth Below KOP - 10,000' MD EZSV @ + 10,020' MD 7" TOL, 29# L-80 Liner 12,278' MD Existing 7", 29# L-80 Liner 13,160' MD 9 5/8"x 7" HangedPacker @ + 9850' MD 7" x 4 1/2" Production Packer @ ,--11326' MD 4-1/2" TOL L-80, 12.6¢, IBT-MOD Liner @ + 11,272' MD 2 X nipples; one across a Tango Shale and one 50 below TSAD 4-1/2" Solid cmt. liner to TD 14,053' MD ~ 7" Drilling liner set @ -11,422' MD. "X" only completion (future CT sidetrack) TOC - 12,465' MD 9-5/8" 47# 12,434' MD Gas Lift Mandrels set @; 3500', 6100', 7045' TVD 3962', 8282', 9827' MD Wellhead: FMC Gen IV (4") Needed for 4 1/2" completion: 4 "Tubing Head Adapter 4" Completion Assembly 4" FMC Gen IV Tree 4 1/2" Liner centralization: Run Turbolators in the fol- lowing configuration: 2 - Righthanded per joint. If Iow dogleg and good hole conditions. Run Straight Blades: 1 per joint if hole conditions warrant. Date Revised by _ Comments 6/1/98 JAS PRUDHOE BAY UNIT WELL: L2-18A AP! #: 50-029-21766-01 . Shared Services Drilling Well: L2-1 8A Wp2 I DrilIQuest7 I Proposal D~tta lor L2-18A Wp2 lical Od~lln: Well Lz. on'.xl Odgln: Weft ~mment Un;Is: 1~ R¢orsn::e: True North ;~ ~verity: Degrees per ti:al Secdon Azimtzt~: 102.5GG' ti:al Sectbn D~'.fil~cn:Wefl ' al:al S~:~ion O~igln: 0.00 N,O.O0 E aasur~:l Incl. Azim. Ve~ca[ Nor'~lngt . Earrings Vertical Doftl~g Dalat h D~p~ Section 10020.L'q 49.4&1 67.6~$ ?L59.10 1949.52 ~ $8~.62 E ~59.46 l~.~ 5~955 90.1~ ~1~.16 ] ~0.~0 N 5~12 E 52~.42 10.~ 1~11.~ ~.107 1493~3 9~.~ 1 ~t.55 N 619639 E ~1.86 10.D~ 11~.91 43.107 149.313 8~t.S~ 1~6.~ ~ 6555.13 E 61~3 0.~ l t742~ ~.~ 14 I.~ ~23A7 l tg?.~ N 6596.~ E 6176.~ 6.~ 1~92.53 g.l~2 g~ 8697.11 1 ~5.05 N 91~.~ E ~26~9 10.~3 124~6.~ ~1~2 ~.~ ~lOIJO l~SJ9 N ~7,g E 6SOS.~ O.Offi 1~3.16 ~.~9 80.92~ 86ll30 1~92.~ H ~63.g1 E ~Tt.~ 0.~ PROPOSAL TARGET SUMMARY Target Narr~: TVDSS TVDRKB: Welthead Offsels: OTobal Coordl~tes: [.2.-18A T1 8650.00 8?0%70 1045.79 N, 7207.05 E 5964303J:X) N. 700~18.00 E L2-18A't'2 8630.00 8681.70 123~Z.89 N. 8763.91 E 5965090.CO N. 70lC-r-~3.~ E SURFACE LOCATION PLOT DATE · 30-APR-98 RKB E~,nb'~: ~.~ ~ Rtg(~ I 13.70, WeN(CBE) , '~ ~lnate System Z~a 4, US F~t I PRELIMINARY 1800 ;~ooo o I 5600 Scale-- linch = 40Oft eOpO 1142t,~MD ,Bd:no, c~ ~Y393.E I 64110 l 6BO0 I 72013 Enstings l 7600 I BOO0 I 8400 4 172' Unet /{4053.1~j IMD / 8800 Reference is True N:orth - 1 BO0 - 4.400 -- 1000 Shared Services Drilling Well: L2-18A Wp2 DrillQttest" Proposal Data for 1.2-18A Wp2 Va rt",:-aJ nO,in: Well Hortzcotal Odgln: t.lozsu~)rnent Ur;is: North Redorenc:~: Trna Norlh PROPOSAL TARGET SUMMARY Target Nam.,: L;7..-1 SA, 'TVDSS "TVD'~KB: We,"i-}ead Offsets: §C:k~.O0 87'01.70 [045.79 N,7207,C,'3 E 8630.00 86Bt.70 '[:;792.8g N, B7EG.91 E 5964803.00 N. 700118.O:) E 5985,0cJ0.00 N. 701688.03 E SURFACE LOCATION i Hodzcmtal Coordin~l~$: 1 RKB EI-3vat~-t: 59C:~572A5 N, 892940,19 E 13.70 ~ Well tCB~ s~.7o~ RKe- NAD27 Alask~ SJsls Ptan,~. Zone 4. US Fo~t PLOT DATE - 30-APR-98 Cre~.'ted By: Chc-,ckL,,d By: 200 600 ,KIO: 7151.7~ TVD PRELIMINARY 766'1.70' nOD :800 - 7' Liner 114¢.1.9t MD .... B~91.70'rvo I t I 5200 51g00 61300 Scale: linch = 400ft ~o sand 7200 Vertical Section TS'A. Dr ,~72:1.2.9 7~"D rzJ: IJSl.?O 7Z2.. ~471.7~ I I 7600 8000 E,E4J~' a'TO6J"P T~'D 4 1,'"2" t_o.~' 14(B~.115 t/D 8C--~I .?o 'I'VD ~' ' D40D Section Azimuth: 102.593' (True North) dhoe Bay Unit 4easured Sub-Sea Vertical Deplh IncL Azlm. Depth Depth (fi) (tt) (fi) 10000.00 49.463 67.~93 7107.40 7159.10 10040.00 52.955 70.197 7132.46 7184,16 10100.00 49.509 76.501 7170.05 7221.75 10200.00 44.648 88.458 7238.26 7289.96 10300.00 41.241 102.285 7311.61 7363.31 10400.00 39.683 1t7.535 7387,8.?, 7439.56 10500.00 40.195 133.120 7464.75 7516.45 10600.00 42-700 147.774 7539.88 '/591.58 10511.62 43.107 149.373 7548.38 7600.O9 10613.82 43.107 ~49.373 7550,0,3 7601.70 10700,00 43.107 ~49.:~r/3 7612_q2 7664.62 10800.00 43.107 ~49.873 7685.92 7737.62 10900.00 43.107 I49.3'73 7758.93 7010.63 11000,00 43.107 149.873 7831.94 7883.64 11100.00 43.107 149.673 7904.95 7956.65 11200,00 43.107 149.373 7977.96 8029.66 11300.00 43.107 149,373 8050.97 8102.67 11400,00 43,107 149.373 8123.97 8175.67 11401.41 43.107 149,373 8525.00 8178.70 11415,10 43.107 149.373 8135.00 8168.70 11421.95 43,107 149.373 8140.00 8191.70 11435.65 43,107 149.373 8150.00 8201.70 11500.00 43.107 149.373 8196.98 8248.68 11504,14 43, 107 149.373 6200.00 8251.70 11600.00 4.3.107 149.373 8269.99 8321.69 11640.91 43.107 149.373 82.99.86 8351.56 I ! 654.48 44.000 147.892 8309.69 8361.39 11654.91 44.009 147.856 8310.00 8361.70 11700.00 44.988 144.2,.56 8342.17 8393.87 I 1739.68 45.936 141.194 1~370.00 8421.70 Sperry-Sun Drilling Services Proposal Report for L2-18A Wp2 Local Coordinates Narthlngs Eastin§;; Cf't) (fi) 1949.52 N 5824.62 E f 960.70 N 5853,72 E 1974.15 N 5898.47 E 1984.00 N 5970.76 E 1977.91 N 6038.26 E 1956.08 N 6098.93 E 1919.17 N 6150.93 E 1868.30 N 6192,67 E 1661.55 N 6196.79 E 1860.26 N 6197.56 E 1809.58 N 6227.56 E 1750.78 N 6282.98 E 1691.98 N 6297,19 E 1663.17 N 6332,00 E 1574.37 N 6366.82 E 1515.57 N 6401,63 E 1456,76 N 6436.45 E 1397,96 N 6471.26 E 1397.13 N 6471.75 E 1389.08 N 6476.52 E 1385.05 N 6478.90 E 1377.00 N 6483.67 E 1339.16 N 6508.07 E 1338.73 N 65137.51 E 1260,35 N 6540.89 E 1256.30 N 6555.13 E 1248.32 N 6560.00 E 1248.06 N 6560.15 E 1221.86 N 6577.80 E 1199.38 N 6594.93 E Global Coordinates Dogleg Northlngs Easfings Rate (fi) (ri) ('/'~ OOft) 5965670.92 N 698712.82 E 5965682.85 N 698741.62 E 10.DDO 5965697.44 N 698785.01 E 10.000 5965709.14 N 698858.02 E 10.DOD 5965704.79 N 698925.66 E 10.D00 5965684.53 N 698986.67 E 10.000 5965648.97 N 699039.80 E 10.000 5965599.19 N 699062.63 E 10.000 5965692.54 N 699087.13 E 10.000 5965591-27 N 699087.93 E 0.ODD 5965541,38 N 699119.22 E 0.000 5965483.49 N 699155.53 E 0.000 5965425.60 N 699191.85 E 0.000 5065367.71 N 699228.16 E 0.000 5965309.62 N 6992B4.47 E 0.000 5965251.93 N 699300.78 E 5965194.04 N 699337.10 E 0.000 5965136.15 N 699373.41 E 0.000 5965135.34 N 699373.92 E 0.000 5965127.41 N 699378,89 E 0.0O0 5965123.45 N 699381.38 E 0.O00 5965115.52 N 699386,35 E 0,003 5965078.26 N 699409.72 E 0,O0O 5965075,87 N 699411.22 E 0,OOD 5965020.37 N 699448,03 E O.00D 5964996,69 N 699460.89 E 0.000 5964988,84 N 699465.96 E 10,003 5964986,59 N 699466.13 E 6.003 59B4962,85 N 699484.44 E 6.000 5964940.80 N 699502.14 E 6.003 VeMIcal Section 6046.78 5077.19 6123.43 6198.38 5262.27 6319.11 6365.16 6399.03 6402.13 6402,70 6424.98 6450,84 6476,70 6502,56 6528,42 6554.28 6580,14 6605,99 6606.36 6609.90 6611.67 6615.21 6831.85 6632.92 6657.71 6668.29 6671.94 6672.06 6685.70 6699.36 Comment PUT RIVER B LCU / TSAG 7' Urmr TSHUB TSAD TZ3 TZ2 Alaska State Plane Zone 4 Llsburne DS 02 PRELIMINARY Congnue~., .-z-] x 1998- 1~04 .1- DrtltOuest Idhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. AzJm. Depth Depth (rt) (fl) 1174223 4 6.00D 141.000 6371.77 8423.47 11800.00 ,~ 8.346 133.798 8411.07 8462.77 11900.00 53-352 122.617 ~474.31 8526.01 12000.00 89.267 112.913 8529.85 8581.65 12000.30 59288 112.885 8530.00 asa 1.70 12100.00 65.817 104.387 8576.00 8627,70 12200.00 72.794 96.725 8611.36 8663.C~ 12300.00 80.038 89.624 6634.86 8686,56 12392.53 86.872 83.340 8645.4i 8697,11 12400.00 86.872 83.340 8645.82 8697,5C 12476.63 86.872 83.340 8650.00 6701.70 12500.00 88.46'7 82.364 8650.95 8702,65 12534.16 90.799 80.638 8651.17 870?-87 12600.00 90.799 80.938 8650.25 8701,95 12700,00 90.799 80.938 8648.88 8700,56 12800.00 90.799 80.938 8647.46 8699/[6 12900.00 90,799 80.938 8646.07 8697.77 13000.00 90.799 80.938 8644.68 8896.38 13100.00 90.799 80.938 8643.28 8694.98 13200.00 90.799 80.938 8641.89 8693.59 13300.00 90.799 80.938 8640.50 8692.20 13400.00 90.799 80.938 8639.10 8690.80 13500.00 90.799 80.938 8637.71 8689.4I 13600.00 90.799 80.938 8636.32 8688.02 ! 3700.00 90,799 80.938 8634.92 8686.62 13800.00 90.799 80.938 8633.53 8685.23 13900.00 90.799 80.938 8632.13 8683.83 14000.00 90,799 80,938 8630,74 8682.44 14053.18 90.799 80,938 8630.00 8661.70 Sperry-Sun Drilling Services Proposal Report for L2-184 Wp2 ._ Local Coordlnates Northings Eastings Global Coordinates Nodhlngs Easlin9$ (ft) (ft) 1197.94 N 6596.08 E 6964939.40 N 699503.33 E 1166.62 N 6824.76 E 5964909.~4 N 699532.80 E 1119.22 N 6685.67 E 596-4863.02 N 699564.91 E 1080.77 N 6759.23 E 5964826.47 N 699669,44 E 1080.67 N 6759.47 E 5964826.37 N 699869,68 E 1052.83 N 68zl3.22 E 5964800.49 N 699754,11 E 1035.67 N 6935.06 E 5964785.89 N 699~46,37 E 1030.39 N 7031.99 E 5964783.10 N 699943.40 E 1036.05 N 7123.64 E 5964791.12 N 700034.87 E 1036.92 N 7131.05 E 5964792.18 N 700042.25 E 1045.79 N 7207.05 E 59§4803.00 N 700118.00 E 1048.70 N 7230.22 E 5964806.50 bl 700141.09 E 1053.66 N 7264,01 E 5964812,33 N 700t74.75 E 1064.03 N 7329.02 E 5964824.36 N 700239.47 E 1079.78 N 7427.76 E 5964842.64 N 700337.77 E 1095.53 N 7526.51 E 5964800,92 N 700436.08 E 1111.27 N 7625.25 E 5964879,20 N 700534.38 E 1127.02 N 7723,~9 E 5964897.48 N 700632.69 E 1142.77 N 7822,73 E 5964915,76 N 700730.99 E $158.52 N 7921.48 E 5964934,04 N 700829,30 E 1174.27 N 8020,~.2 E 5964852.32 N 700927.60 E 1190.02 N 8118.96 E 5964970,60 N 701025.91 E 1205.77 N 8217.70 E 5964988.88 N 701124.21 E 1221.52 N 8316.44 E 5965007.16 N 701222,52 E 1237.27 N 8415.19 E 5965025.44 N 701320.82 E 1253.02 N 8513.93 E 5965043.72 N 701419.13 ~= 1268.77 N 6612.67 E 5965062.00 N 701517.43 E 1284.52 N 8711.41 E 5985080.28 N 701615.74 E 1292,89 N 8763.91 E 5965090.00 N 701668.00 E Dogleg Vertical Rate Section (WOOft) (~) 6.000 6700,29 10.000 6724,12 10.000 6777.43 t 0.000 $~44.59 10.000 6844.81 10.000 6923.57 10.000 7011.96 fO.OOO 7107.08 10.000 7t 98.57 0.000 7208.03 0.0O0 7282.51 8.000 7305.85 8,000 7340.01 0,000 7405,8~ 0,000 7505.82 0.000 7605.80 0,000 7705.79 O.OOO 7805,77 O. 000 7905.75 0,000 8005.74 0.000 8105.72 0.0o0 8205.70 O.O00 8305.69 0.000 8405.67 0.000 8505.66 0.000 8605.64 0.000 8705.62 0.000 8805.61 0.000 8858.76 Comment TZ1 Targel: L2-184 T1, Geological 81/2' Liner rget: L2-184 T2, Geological Alaska State Plane Zone 4 Lisburne DS 02 PRELIMINARY . I '-t-, .. CO fl, 1998- f$:04 .2- Sperry-Sun Drilling Services ; Proposal Report for L2-18A Wp2 'udhoe Bay Unit data is in tee~ unless otherwise stated. Directions and coordinates are re]alive to True North. rtical depths are relative 1o Well. Northings and Eastings are relative to Well. Dogleg Severity is in Degrees per 100fl, rtical Section is from Well and calculated along an Azimuth o! 81.608" (True). sed upon Minimum Curvature type calculations, at a Measured Depth o! 14053.16ft., .- Bottom Hole Displacement is 8858.7b"ff., In Ihe Direction of 81.608' (True). p.p. ELIMINAEY Alaska State Plane Zone 4 L[sburne DS 92 x -3. DritlQuest ,pdf, f$~8 - 15:04 ~PR-30-g8 THU 03:50.--' SPERRY-SUN ~L~$~ F~× ~0. lgO?~ '~-154 P. 08 Sperry-Sun Drilling Services Proposal Report for £2-18A Wp2 Prudhoe Bay Unit Alaska State Plane Zone 4 Lisburne DS 02 Measured Vertical Depth Incl, Azim, Depth Nm'things EasUngs (ft) (ft) (ft) (ft) Vertical Dogleg Section Rate (fi) (°/100ft) 10000.00 49.463 67.693 7159.1o 1949.52 N 5824.62 E 5259.46 10040.00 52,955 70,197 7184,16 1960.70 N 5853.72 E 5285.42 10.000 10611.62 43.107 149.373 7600,09 1861.55 N 6196.7,9 ~ 5641,86 I0,000 11640.91 43.107 149,373 8351.58 1256.30 N 6555.13 E 6123.53 0.000 11654.4,8 44.000 147.8~,?. 8361.3~ 1248.32 N 6560.00 E 6130.02 10.000 11742.23 46.000 141.000 8423.47 1197,94 N 6596.08 E 6176.23 6.000 12392.53 86.872 83.340 8697,11 10,38.05 N 7123.64 E 6726.39 10.000 12476.63 88.872 83.340 8701.70 1045.79 N 7207.05 E 6805.66 0.000 12534.16 90.799 80.938 8702.87 1053.66 N 7264.01 E 6859.54 8,000 14053.18 90.7D9 80.938 8681,70 1292.89 N 8763.91 E 8271.20 0.000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North, Vertical depths are relative to Well. Northlngs and EastJngs are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 102,593° (True). Ba~ed upon Minimum Curvature type calculations, at a Measured Depth of 14053.16ft.. The Bottom Hole Displacement is 8858.76ft., in the Direction of 81,608° (True). Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northlngs EaaUngs Formation Name (ft) (ft) (ft) (fi) (ft) 10813.82 7601.70 7550.00 1860,26 N 6197.56 E 11401.41 8176.70 8125.00 1397.13 N 64.71.75 E PUT RIVER 11415.10 8186.70 8135.00 1389.08 N 6476.52 E BLCU / TSAG 11435.65 8201.70 8150.00 1377,00 N 6483.67 E TSHUB 11504.14 8251.70 8200.00 1336.73 N 6507.51 E TSAD 11654.91 836t.70 8310.00 1248.06 N 6560.15 E TZ3 11739.68 8421,70 8370.00 1199,36 N 6594.93 E TZ2 12000.30 8581.70' 8530,00 1080.67 N 6759.47 E TZ1 ., Casing details From Measured Vertical Depth Depth (ft) (lq 10000.00 7159.10 <Surface> <Surface> To Measured Vertical Depth Depth Casing Detail (fi) (fi) 11421.05 8191.70 7' Liter 14053,16 ~681.70 4 1/2' Targets associated with Lhis wellpath Ta~et Name 1.2-1SA Pomy L2-18^ T1 t_2-18A T2 Ta¢gel Entry Coordinates TVD Northings Eastings Target (ft) (fi) (ft) Shape 8711.70 1148,79 N 7091.65 E Polygon 8701.70 1045.79 N 7207.05 E Po~nl 8681.70 1292.89 N 8763.91 E Po[al Target Type Geological Geological Geological ~PR-30-~ THU 03'48 PM - ~RRY-$UN ~L~$K~ FA× NO. 190756Z -~, P. 04 5631 SIIverado Way #G Anchorage, Alaska 99518 (907) 563-3256 /=ax (907) 563-7252 Shared Services Drilling Tim Bums Approved Well Close Approach Review PBU 1 L2-18A Wp2 Tt'm, The above mentioned well has been scannM using standard anti-collision mcthods vi~ I)IL4P. TIM Icon w,te pet£omted with th~ following p~[cm: $tm~ ~cm. insp~fion ~nc 9,~,70 ' Sla~n~ ~n Radlu~ I~.~ ' Ra~ o(~dlu~ lu~ ~ t~ l~.~ ' Scan Paramctcrs Comments: At LI~ c~largcd r~dius utc following wclls wcrc dc[~cl~l during th~ r~Ln Nnm: ~il li~ m3 y ~o~ tnclu~ all ~ wcl~ ~, ~ly ~ o~wh~ ~om~rban Suble~ Well Plaon~ Well Eltllv~ ~C 1~11.4] 'MD 36436 ' 45.10 · 137.68 ~3C 12~51 ~ 28854 ' ?.g0 ' ~.29 ~E~C _ 123~.2.0~ 33~ ' 32~.10 ' 10ILS ~-18 1019&13 ~D 23~3 ' 3~1.~ ' -26~69 ~-18 105~3.41 ~ 361.70 ' ~2.~ ' la0~7 .. Tolerance Plot required: Yex Close Approach Comment~: In~otma~n concerning status of well NETR3C Is pending. It appears to be an old exploral~o weft end cca~ be shut in. For planr~ng purposas, It will b~ t/oat, ed as a flowing well un~l new Information b ob~ned. Clo~e Approach Scan Performed by: .~..~.~/~,~.~,,.~/ Date: Chcckcd b~ ,. ~ Date: Shared S~rvices Approval: Date: hared WELL NAME L2-18A · ervlces ri I ling DRILLING PERMIT~SUNDRY~PRE-RIG [ Alaska cov]m SHEET I The attached work cannot commence without obtaining the required signatures in the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) DRILLING PERMIT ODE:/l~~'/~/'~ ' Date: Pern~Ap-plication Revi,~wed: SDE~S: ~--~. ~_nate: Pe~t~pplicati~n Sub~tted: . T~k~ ~ rote:G//~[ PRE-RIG WORK Pre-Rig Memo Reviewed: SDE/ES: Date: Pre-Rig Memo Sent to Slope: ODE: Date: Pre-Rig Sundry Documentation Prepared: ODE: Date:~ Pre-Rig Sundry Application Reviewed: SDE/ES: Date: Pre-Rig Sundry Application Submitted: TA: Date:~ ~1 SUNDRY NOTICE D Sundry Documentation Prepared: ODE: Date: '--]Sundry Application Reviewed: SDE/ES: Date: Z] Sundry Application Submitted: TA: Date: NOTE: /F SUNDRY IS FOR PRE-RIG WORK, USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW Reason for Sundry (Check all that apply) Abandon Alter Casing Suspend Repair Well Plugging Pull Tubing Variance Other(Explain): Change Approved Program Operation Shutdown Re-enter Suspended Well Time Extension Perforate Stimulate APPROVAL TO PROCEED Approved AOGCC Permit/Sundry Received TA: Date: Approval to Commence Operations SDE/ES: Date: STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [~Abandon E]Suspend [] Plugging E~Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1672' NSL, 3694' WEL, SEC. 18, T11N, R15E, UM At top of productive interval 4166' NSL, 3982' EWL, SEC. 17, T11N, R15E, UM At effective depth 4262' NSL, 5168' EWL, SEC. 17, T11N, R15E, UM At total depth 4281' NSL, 4477' EWL, SEC. 17, T11N, R15E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KB) RKB = 45' 7. Unit or Property Name Prudhoe Bay Unit / Lisburne 8. Well Number L2-18 9. Permit Number 87-118 10. APl Number 50-029-21766 11. Field and Pool Prudhoe Bay Field / Lisburne Oil Pool 12. Present well condition summary Total depth: measured 13193 feet true vertical 9221 feet Effective depth: measured 13086 feet true vertical 9156 feet Casing Plugs (measured) Junk (measured) Length Size Cemented TVD Structural Conductor 110' 20" 1850# Poleset 110' 110' Surface 4115' 13-3/8" 3000 sx AS III, 600 sx 'G', 175 sx AS I 4115' 3593' Intermediate Production 12434' 9-5/8" 900 sx Class 'G' 12434' 8730' Liner 913' 7" 375 sx Class 'G' 12276' - 13189' 8633' - 9218' Perforation depth: measured 12565' - 12629', 12633' - 12812', 12817' - 12944', 12981' - 13058' true vertical 8820'-8863', 8866'-8984', 8987'-9068', 9091'-9138' DUPlICaTE Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 12508' Packers and SSSV (type and measured depth) Brown H-B packer at 11474'; CPH Liner packer'at 12152'; TRDP-1A SSSV nipple at 2204' 13. Attachments [] Description summary of proposal 14. Estimated date for commencing operation June 4, 1998 If proposal was verbally approved Name of approver contact Engineer Name/Number: J. Allen Sherritt, 564-5204 Date approved [] Detailed operations program [] BOP sketch 15. Status of well classifications as: [] Oil [~ Gas [] Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~-%-.-~'---~-- -~. ~ Dan Stone Title Engineering Supervisor Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- order of the Commission Commissioner Date j Form 10-403 Rev. 06/15/88 Submit In Triplicate DATE [ CHECK NO. I VENDOR ~))~- .ASKAST 14- O0 DATE INVOICE~ / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 032498 CIX, 032498~2 :IL00. O0 !00_ O0 HANDLINQ INST- S/H TERRI HUBBLE X THE ATTACHED CHECK IS IN PAYMENT FOR rrEMS DESCRIBED AEInVF · WELL PERMIT CHECKLIST FIELD & POOL CGP~//~ ADMINISTRATION COMPANY .,,~/~"C.?(:~ WELL NAME ,/~'_/~r,~/ ~- ~ -/~',,~. INIT CLASS /~_~..,,,,' ,/"' ~'/7 GEOL AREA 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. , 8. 9. 10. 11. ,_R D,~TE ¢ 12. ENGINEERING APPR DATE l f.or'a Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 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 ;~x:~c3 psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. GEOLOGY APPR DATE. 30. 31. 32. 33. 34. PROGRAM: ~. I~ wellbore seg I ann. exp [] dev redrll serv [] I disposal para req il UNIT# ,,~///C,_$"~O ON/OFF SHORE ~- ~ ANNULAR DISPOSAL 35. APPR DATE N 'Y N Y N Y N Y N Y N Y N N y~~Y iNN Y N N N N N Is presence of H2S gas probable ................. N Permit can be issued w/o hydrogen sulfide measures ..... y Data presented on potential overpressure zones ....... ,,,Y/'N / ,/,,? Seismic analysis of shallow gas zones ............. /Y Seabed condition survey (if off-shore) ............. / Y N Contact name/phon,e.for weekly progress reports .... .,,,~.. Y N [exploratory onlyj With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or ca~. Y N to surface; ~ (C) will no~ of the well used for disposal; Y N (D) ~mpair recovery from a Y N ;and -'-""~(E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annul§r COMMISSION: ~ RNC - co C¢ ~- Comments/Instructions: 0 M:cheklist rev 05/29/98 dlf: C:\msoffice\wordian\diana\checklist 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. * ALASKA COMPUTING CENTER * ....... SCHLUFiBERGER ....... COMPANY NAFIE : ARCO ALASKA, INC. WELL NAMiE : L2-18A FIELD NAF1E : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292176601 REFERENCE NO : 98645 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21 -DEC-1998 PAGE: **** REEL HEADER **** SERVICE NAFiE : EDIT DATE : 98/12/21 ORIGIN : FLIC REEL NAME : 98645 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, L2-18A, API# 50-029-21766-01 **** TAPE HEADER **** SERVICE NAFiE : EDIT DATE : 98/12/21 ORIGIN : FLIC TAPE NA~E : 98645 CONTINUATION # : 1 PREVIOUS TAPE : CO~4~ENT : ARCO ALASKA INC., PRUDHOE BAY, L2-18A, API# 50-029-21766-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: L2 - 18A API NUMBER: 500292176601 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 21-DEC-98 JOB NUMBER: 98645 LOGGING ENGINEER: B BOEH~E OPERATOR WITNESS: J DETHLEFS SURFACE LOCATION SECTION: 18 TOWNSHIP: 1 iN RANGE: 15E FNL : FSL: 1673 FEL: FWL: 1248 ELEVATION (FT FROM MSL O) KELLY BUSHING: 45. O0 DERRICK FLOOR: 44. O0 GROUND LEVEL: 13. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 12. 500 2. 875 12508.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (FiEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 21 -DEC- 1998 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH $ CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CCL LOG DATA AQUIRED OM ARCO ALASKA'S L2-18A WELL. THIS LOG IS THE PRIMARY DEPTH CONTROL. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION ' O01CO1 DATE : 98/12/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AFOMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS ArUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CCL 11906.0 4765.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUM~ER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH CCL REMARKS: THIS FILE CONTAINS THE EDITED CASED HOLE DATA. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 21 -DEC- 1998'~ 52 PAGE: LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DEPT FT 1217513 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CCL GAPI 1217513 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CCL V 1217513 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CCL LB 1217513 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11906. 000 GRCH. CCL 42. 332 CCL. CCL O. 071 TENS. CCL 1101.000 DEPT. 4765.500 GRCH. CCL 31.244 CCL.CCL -999.250 TENS. CCL 595.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-DEC-1998~.'52 PA GE: **** FILE TRAILER **** FILE NAFIE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUPi~ER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE S~4MARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11946.0 4765.5 CCL $ LOG HEADER DATA DATE LOGGED: 02 -DEC-98 SOFTWARE VERSION: 8Cl-205 TIME LOGGER ON BOTTOM: 1054 02-DEC-98 TD DRILLER (FT) : 11897.0 TD LOGGER (FT) : 1191 O. 0 TOP LOG INTERVAL (FT) .' 4770.0 BOTTOM LOG INTERVAL (FT) : 11906.0 LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR G~ RAY CCL COLLAR LOCATOR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUFiBER PSPT-A PSPT-A 12.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21 -DEC-1998 '~52 PAGE: DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 12508.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 180.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COU~f RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: PRIMARY DEPTH LOG TOOL ZEROED AT GROUND LEVEL DEPTH REFE~CED BACK TO KB KB ELEVATION = 45 F. GL ELEVATION = 13 F. DEPTH SET TO 32 F AT GL. LINE MAGNETICALLY MARKED EVERY 100 F. THIS FILE CONTAINS THE RAW DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape ~rification Listing Schlumberger Alaska Computing Center 21 -DEC-1998 ~_~¥52 PAGE: 6 TYPE REPR CODE VALUE 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CrJ~SSMOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1217513 O0 000 O0 0 2 1 1 4 68 0000000000 GR PS1 GAPI 1217513 O0 000 O0 0 2 1 1 4 68 0000000000 CCL PS1 V 1217513 O0 000 O0 0 2 1 1 4 68 0000000000 TENS PS1 LB 1217513 O0 000 O0 0 2 1 1 4 68 0000000000 WPRE PS1 PSI 1217513 O0 000 O0 0 2 1 1 4 68 0000000000 WTEP PSI DEGC 1217513 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11946.000 GR.PS1 WPRE. PS1 3399.242 WTEP.PS1 26.003 CCL.PS1 79.978 -0.038 TENS. PSi 692.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/12/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-DEC-1998~52 PAGE: **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/12/21 ORIGIN : FLIC TAPE NAME : 98645 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, L2-18A, API# 50-029-21766-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/12/21 ORIGIN : FLIC REEL NAME : 98645 CONTINUATION # : PREVIOUS REEL .. COMFIEAFf : ARCO ALASKA INC., PRUDHOE BAY, L2-18A, API# 50-029-21766-01 Sperry-Sun Drilling Services LIS Scan Utility Tue Feb 09 10:58:40 1999 Reel Header Service name ............. LISTPE Date ..................... 99/02/09 Origin .... ~ .............. STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 99/02/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Services 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 NI/MBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM- 80261 R. MCNEILL R. BORDES L2-18A 500292176601 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 09-FEB-99 MWD RUN 3 MWD RUN 4 AK-MM-80261 AK-MM- 80261 R. MCNEILL R. MCNEILL R. BORDES R. BORDES JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MWD RUN 5 AK-MM-80261 R. MCNEILL R. BORDES MWD RUN 5 AK-MM-80261 R. MCNEILL R. BORDES 18 lin 15E 1672 FEL: 3694 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 50.80 DERRICK FLOOR: 34.40 GROUND LEVEL: 13.70 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 8.500 7.000 11125.0 PRODUCTION STRING 6.000 14070.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 DRILLED NO FOOTAGE A/qD IS NOT PRESENTED. 3. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) . 4. MWD RUN 4 IS DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP) . 5. MWD RUN 5 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAV RESISTIVITY PHASE-4 (EWR-4) . 6. A MEASUREMENT AFTER DRILLING (MAD) PASS WAS PERFORMED AFTER MWD RUN 5 AND IS PRESENTED AS A TAIL TO THIS LOG. 7. A CHANGE FROM DUAL GAMMA RAY (DGR) TO SCINTILLATION TYPE GAMMA RAY (NGP) OCCURRED AT l1089'MD, 8191'TVD. 8. A CHANGE FROM SCINTILLATION TYPE GAMMA RAY (NGP) TO DUAL GAMMA RAY (DGR) OCCURRED AT 12382 'MD, 8704'TVD. 9. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14069'MD, 8659'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED GAMMA RAY. 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 ....... 99/02/09 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 8262 5 14036.0 ROP 8291 5 14074.0 RPD 12415 0 14043.0 RPM 12415 0 14043.0 RPS 12415 0 14043.0 RPX 12415 0 14043.0 FET 12415 5 14042.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASEL 8262 8273 8275 8276 8286 8288 8298 8303 8309 8325 8329 8334 8346 8355 8363 8386 8390 8395 8400 8437 8440 8443 8446 8551 8554 8579 8587 8598 8729 8739 INE DEPTH .5 .5 .0 .5 .5 .5 .0 .5 5 5 5 5 0 0 0 5 0 0 0 0 0 5 5 5 5 0 0 5 0 0 GR 8266.0 8277.0 8278.5 8280.5 8293.5 8295.5 8308.5 8313.5 8318.5 8331.0 8333.5 8340.5 8352.5 8360 0 8366 0 8391 5 8394 5 8401 0 8404 5 8443 0 8447 0 8450 5 8452 0 8557 0 8559 0 8581 0 8593 0 8604.0 8734.5 8743.5 EQUIVALENT UNSHIFTED DEPTH 8760.5 8765.0 8767.0 8874.5 8881.5 8885.0 8912.0 8915.0 8918 5 8928 0 8938 0 8945 5 8969 0 8975 0 9020 5 9033 5 904'1 5 9063 0 9068 5 9177 5 9180 0 9527 0 9532 5 9568 5 9580.5 9586.5 9593.5 9633.5 9638.0 9640.5 9724.5 9729.0 9732.0 9774.5 9981.5 9996.0 10001 0 10045 0 10059 5 10062 5 10074 0 10081 5 10142 5 10159 5 10170 0 10186 5 10214 5 10218 0 10235 0 10289 0 10303 5 10312 0 10330 0 10335 5 10370 0 10388 0 10394 5 8765 0 8770 0 8772 0 8879 0 8884 5 8889 0 8916 5 8918 0 8920 5 8930 5 8940 0 8949 0 8973 5 8978 0 9023 5 9038 5 9047.0 9071.0 9074 0 9184 5 9186 5 9532 0 9539 0 9577 5 9588 0 9595 5 9602 0 9640 0 9645 5 9648 5 9731 5 9736 5 9739 5 9780 5 9988 0 10001 5 10005 5 10052.5 10065 5 10069 0 10080 5 10085 5 10149 5 10164 5 10176 5 10191 5 10220 5 10222 5 10242 5 10296 0 10309 5 10317 0 10335 5 10340 0 10372 0 10392 0 10397 5 10409 0 10441 0 10448 0 10480 5 10486 5 10493 0 10506 5 10526 5 10614 0 10627 5 10631 0 10700 0 10710 0 10712 5 10716 5 10732 5 10736.5 10742 5 10757 5 10761 5 10763 5 10766 0 10772 0 10776.0 10781 5 10784 0 10787 0 10790 0 10793 5 10801 0 10806 0 10818 5 10830 5 10835 0 10851 5 10860 5 10863.0 10875.5 10883 5 10892 5 10902 0 10905 5 10913 5 10918 5 10927 5 10934 0 10943 0 10954 0 10957 5 10968 0 10971 5 10974 0 10977 0 10985 0 10988 0 10993 0 11005.5 10413.5 10447.5 10452.5 10485.0 10490.0 10495.5 10511.5 10534.0 10623.0 10631.0 10638.5 10704.0 10714.5 10718.0 10721.5 10737.5 10741.5 10747.0 10762.5 10767.0 10769.0 10770 5 10776 5 10780 0 10784 5 10786 5 10789 5 10793 5 10799 0 10803 5 10807 5 10821.5 10831.5 10835.5 10854.5 10863.5 10867.5 10878.5 10888 5 10895 0 10906 5 10908 5 10915 0 10921 5 10932 5 10943 0 10950 5 10958 5 10961 5 10971 5 10974 5 10976 5 10981 0 10988 5 10992 0 10998 5 11007 5 11018.0 11023.5 11027.5 11032.0 11034.5 11042.5 11054.0 11058.0 11067.5 11068.5 11071.0 11074.5 11076 5 11079 5 11083 5 11085 5 11092 5 11099 0 11105 5 11107 0 11110 5 11113 0 11119 0 11124 0 11127 5 11132 0 11143 0 11145 5 11156 5 11158 5 11162 0 11165 5 11172 0 11174 5 11177 5 11197.5 11199.0 11200.0 11205.5 11208.0 11221 5 11225 5 11228 0 11237 0 11240 0 11264 5 11267 5 11272 0 11294 0 11296 0 11298 5 11301 5 11305 0 11308 0 11310 5 11316 0 11319 0 11020.5 11026.0 11030.5 11034.5 11037.5 11044.5 11057 5 11060 5 11070 5 11071 5 11073 5 11077 0 11081 0 11083.0 11088.5 11092.5 11099.0 11106.5 11109.0 11111 0 11114 0 11116 5 11121 0 11123 5 11128 5 11131 5 11148 5 11152 0 11156 0 11158 0 11162 0 11164 5 11172 0 11174 0 11176 5 11196 5 11199 0 11200.5 11204.5 11208.5 11220 0 11223 5 11226 0 11239 0 11241 5 11266 0 11269 5 11273 5 11296 5 11298 5 11300 0 11302 0 11306 5 11311 0 11313 5 11317 5 11320 0 11330.5 11334.5 11339.0 11397 0 11401 0 11404 5 11445 5 11448 5 11450 5 11521 5 11524 0 11524 5 11527 5 11536 0 11543 0 11547 0 11553 0 11554 5 11559 5 11563 0 11566 0 11569 0 11574 5 11578 0 11600 5 11605 0 11609 0 11613 5 11617 0 11692 5 11702 0 11710.0 11712.0 11716.5 11724.0 11726.5 11740.0 11748 5 11752 5 11756 5 11764 0 11773 0 11776 0 11782 5 11792 5 11796 5 11802 0 11805 5 11809 5 11812 5 11817 0 11833.5 11839.0 11840.5 11844.0 11847.0 11858.0 11333.0 11335.5 11342.0 11401.0 11403.5 11406.0 11447 0 11449 0 11451 5 11522 5 11527 0 11529 5 11531 5 11541 5 11545 0 11546 5 11551.5 11554.0 11558.5 11560.0 11564 0 11567 5 11572 5 11575 0 11598 5 11603 0 11606 5 11611 0 11616 0 11688 5 11700 0 11708 0 11709 0 11715 5 11724 0 11727.0 11738.0 11750.0 11754.0 11759.5 11762.0 11769.5 11774.0 11785.0 11792.5 11794.5 11799 5 11802 0 11807 5 11811 5 11816 0 11829 0 11833 0 11837 5 11841 0 11844 5 11851 5 11860.5 11855.0 14074 · 0 14068 · 5 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 4 MWD 5 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP 8300.0 9184.0 11125.0 12441.0 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 BASE 9184.0 11125.0 12441.0 14069.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOLrR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 8262.5 14074 11168.2 11624 ROP 0.095 2102.34 96.6273 11566 GR 27.06 640.22 103.506 11548 RPX 5.2 2000 66.7132 3257 RPS 5.2 2000 66.7132 3257 RPM 2.34 2000 156.549 3257 RPD 4.42 2000 173.767 3257 FET 0.25 25.54 1.27535 3255 First Reading 8262.5 8291.5 8262.5 12415 12415 12415 12415 12415.5 Last Reading 14074 14074 14036 14043 14043 14043 14043 14042.5 First Reading For Entire File .......... 8262.5 Last Reading For Entire File ........... 14074 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/09 Maximum Physical Record..65535 File Type ........ . ........ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/09 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 FET RPD RPM RPS RPX GR RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: START DEPTH STOP DEPTH 11712.5 14045.5 11712.5 14045.5 11712.5 14045.5 11712.5 14045.5 11712.5 14045.5 11712.5 14038.5 11712.5 14078.5 MAD RUN NO. MAD PASS NO. 5 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 12441.0 MERGE BASE 14069.0 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 Name Min Max Mean Nsam DEPT 11712.5 14078.5 12895.5 4733 RAT 90.1711 5772.66 559.809 4733 GR 23.71 192.82 74.566 4653 RPX 1.38 2000 39.7213 4667 RPS 3.16 2000 62.1262 4667 RPM 3.4 2000 108.861 4667 RPD 4.81 2000 136.083 4667 FET 4.43 100.1 47.3981 4667 First Reading 11712.5 11712.5 11712.5 11712.5 11712.5 11712.5 11712.5 11712.5 Last Reading 14078.5 14078.5 14038.5 14045.5 14045.5 14045 o 5 14045.5 14045.5 First Reading For Entire File .......... 11712.5 Last Reading For Entire File ........... 14078.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8266.0 ROP 8300.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ STOP DEPTH 9149.5 9183.0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING 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 il-JUL-98 INSITE 3.2 B12 UP3 / ISC 5.08 CIM 5.46 MEMORY 9184.0 8300.0 9184.0 39.6 53.4 TOOL NUMBER P1039CG6 8.500 8.5 6%KCL/BNEX/BTR 10.40 57.0 11.0 27000 3,5 .000 .000 .000 .000 52.2 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8266 9183 8724.5 1835 8266 GR 27.06 131.38 76.1563 1768 8266 ROP 0.22 287.87 51.7839 1767 8300 Last Reading 9183 9149.5 9183 First Reading For Entire File .......... 8266 Last Reading For Entire File ........... 9183 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HE~kDER FILE NUMBER: 4 R3%W MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE S UMMAi~Y VENDOR TOOL CODE START DEPTH GR 9148.0 ROP 9184.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMI/M ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ STOP DEPTH 11088.5 11125.0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING 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 14 -JUL- 98 INSITE 3.2 B12 UP3 / ISC 5.08 CIM 5.46 MEMORY 11125.0 9184.0 11125.0 38.7 43.4 TOOL NUMBER P1039CG6 8.500 8.5 6%KCL/BNEX/BTR 10.40 58.0 9.2 28500 3.4 .000 .000 .000 .000 57.8 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9148 11125 10136.5 3955 9148 GR 34.79 444.48 150.217 3882 9148 ROP 0.34 529.83 103.748 3882 9184.5 Last Reading 11125 11088.5 11125 First Reading For Entire File .......... 9148 Last Reading For Entire File ........... 11125 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/09 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 ....... 99/02/09 Maximum Physical Recordo.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 11089.0 ROP 11125.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12382.0 12440.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Lo99in9 Direction ................. Down 19-JUL-98 INSITE 3.2 B12 UP3 / ISC 5.08 CIM 5.46 MEMORY 12441.0 11125.0 12441.0 39.0 93.9 TOOL NUMBER PCG 11 6.000 6.0 QUIC~RILn 8.70 48.0 8.9 26000 8.2 .000 .000 .000 .000 49.5- .6 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11089 12440 11764.5 2703 11089 GR 28.7 640.22 90.88 2587 11089 ROP 0.06 1615.66 93.9242 2630 11125.5 Last Reading 12440 12382 12440 First Reading For Entire File .......... 11089 Last Reading For Entire File ........... 12440 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/09 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 ....... 99/02/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 R_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTI{ GR 12381 . 5 14030 . 5 RPD 12409 . 5 14037 . 5 RPM 12409 . 5 14037 . 5 RPS 12409 . 5 14037 . 5 RPX 12409 . 5 14037 . 5 FET 12410 . 0 14037 . 0 ROP 12441 . 5 14068 . 5 $ LOG HEADER DATA DATE LOGGED: SOFTW/kRE 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 AlkrD 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: 22 - JTJL- 98 INSITE 3.2 B12 UP3 / ISC 5.08 CIM 5.46 MEMORY 14069.0 12441.0 14069.0 87.0 95.2 TOOL NTJMBER P0997GR4 P0997GR4 6.000 6.0 QUICKDRILn 8.80 51.0 8.8 20000 4.8 .280 .000 .195 .220 56.1 .0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 5 API 4 1 68 RPX MWD 5 OHMM 4 1 68 RPS MWD 5 OHMM 4 1 68 RPM MWD 5 OHMM 4 1 68 RPD MWD 5 OHMM 4 1 68 ROP MWD 5 FT/H 4 1 68 FET MWD 5 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 12381.5 14068.5 13225 3375 GR 40.13 192.82 72.9847 3299 RPX 5.2 2000 66.7132 3257 RPS 5.2 2000 66.7132 3257 RPM 2.34 2000 156.549 3257 RPD 4.42 2000 173.767 3257 ROP 0.61 2102.34 114.625 3255 FET 0.25 25.54 1.27535 3255 First Reading 12381.5 12381.5 12409.5 12409.5 12409.5 12409.5 12441.5 12410 Last Reading 14068.5 14030.5 14037.5 14037.5 14037.5 14037.5 14068.5 14037 First Reading For Entire File .......... 12381.5 Last Reading For Entire File ........... 14068.5 File Trailer Service name ............. STSLIBo006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/09 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 ....... 99/02/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NTJMBER: 7 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 5 VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR RAT $ LOG HEADER DATA DATE LOGGED: SOFTWARE 11710.0 11710 0 11710 0 11710 0 11710 0 11710 0 11710 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 14040.0 14040.0 14040.0 14040.0 14040.0 14033.0 14073.5 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) : 22 -JUL- 98 INSITE 3.2 B12 UP3 / ISC 5.08 CIM 5.46 MEMORY 14069.0 12441.0 14069.0 87.0 95.2 TOOL NUMBER P0997GR4 P0997GR4 6.000 6.0 QUICKDRILn 8.80 51.0 8.8 20000 4.8 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 .280 .000 · 195 .220 .0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MAD 5 API 4 1 68 RPD MAD 5 OHMM 4 1 68 RPM MAD 5 OHMM 4 1 68 RPS MAD 5 OHMM 4 1 68 RPX MAD 5 OHMM 4 1 68 FET MAD 5 HOUR 4 1 68 RAT MAD 5 FT/H 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 56.1 Name Min Max Mean Nsam DEPT 11710 14073.5 12891.8 4728 GR 23.71 192.82 74.6185 4647 RPD 4.81 2000 136.273 4661 RPM 3.4 2000 107.868 4661 RPS 3.16 2000 61.9019 4661 RPX 1.38 2000 39.692 4661 FET 4.43 100.1 47.3384 4661 RAT 90.1711 5772.66 564.798 4728 First Reading 11710 11710 11710 11710 11710 11710 11710 11710 Last Reading 14073.5 14033 14040 14040 14040 14040 14040 14073.5 First Reading For Entire File .......... 11710 Last Reading For Entire File ........... 14073.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/02/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/02/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File
