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Home My WebLink About204-028MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, August 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC C-42 MILNE PT UNIT C-42 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/16/2024 C-42 50-029-23196-00-00 204-028-0 W SPT 6598 2040280 1650 3197 3197 3197 3197 385 427 426 428 4YRTST P Bob Noble 7/5/2024 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT C-42 Inspection Date: Tubing OA Packer Depth 1070 1870 1843 1842IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240706091237 BBL Pumped:0.8 BBL Returned:0.8 Friday, August 16, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.16 15:47:32 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/14/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230418 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KU 12-17 50133205770000 208089 4/19/2023 YELLOW JACKET PERF MPU C-42 50029231960000 204028 3/22/2023 YELLOW JACKET PERF MPU E-19 50029227460000 197037 4/11/2023 YELLOW JACKET SCBL-CALIPER MPU H-15 50029232840000 205159 3/8/2023 YELLOW JACKET PERF MPU L-12 50029223340000 193011 4/2/2023 YELLOW JACKET CUT PBU 01-31 50029216260000 186132 5/1/2023 YELLOW JACKET SCBL PBU L-117 50029230390000 201167 3/5/2023 YELLOW JACKET SCBL PBU V-02 50029232090000 204077 3/27/2023 YELLOW JACKET SCBL SRU 231-33 50133101630100 223008 3/31/2023 YELLOW JACKET GPT-PERF SRU 231-33 50133101630100 223008 4/14/2023 YELLOW JACKET GPT-PLUG-PERF Please include current contact information if different from above. T37746 T37747 T37748 T37749 T37750 T37751 T37752 T37753 T37754 T37754 MPU C-42 50029231960000 204028 3/22/2023 YELLOW JACKET PERF Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.14 14:53:01 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: WAG MPU C-42 (PTD# 204-028) Cellar Bubbling Date:Tuesday, March 28, 2023 1:50:50 PM Attachments:image001.png image002.png From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Tuesday, March 28, 2023 1:26 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: OPERABLE: WAG MPU C-42 (PTD# 204-028) Cellar Bubbling Mr. Wallace, WAG injector MPU C-42 (PTD# 204-028) was identified as having a surface casing leak in October 2022. The repairs were made per Sundry #322-725. A witnessed MIT-IA passed to 1500 psi on 3/25/2023. The well is now classified as OPERABLE. Please respond if there are any questions or comments. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Thursday, March 9, 2023 9:17 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: WAG MPU C-42 (PTD# 204-028) Cellar Bubbling Mr. Wallace, WAG injector MPU C-42 (PTD# 204-028) was identified as having a surface casing leak in October 2022. The repairs were made per Sundry #322-725. The well is now ready to be returned to injection. The well is now classified as UNDER EVALUATION and placed on a 28 day clock for evaluation. Once the well, has achieved stable injection an AOGCC witnessed MIT-IA will be scheduled. Plan Forward: 1. Place well on injection 2. AOGCC witnessed MIT-IA 3. Engineer to evaluate repair Please respond if there are any questions or comments. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Monday, October 24, 2022 8:01 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: WAG MPU C-42 (PTD# 204-028) Cellar Bubbling Mr. Wallace, WAG Injector MPU C-42 (PTD# 204-028) was pressure tested after identifying bubbling in the cellar. This MIT-OA failed. The well is now classified as NOT OPERABLE and is shut in. Plan Forward: 1. Engineer to evaluate repair Please respond with any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Tuesday, October 18, 2022 11:09 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: WAG MPU C-42 (PTD# 204-028) Cellar Bubbling Mr. Wallace, WAG Injector MPU C-42 (PTD# 204-028) was identified as having bubbling in the cellar. The well is now classified as UNDER EVALUATION for diagnostics and review. The well will remain online in steady state while initial diagnostics are conducted. It is now on a 28 day clock for diagnostics and resolution. Plan Forward: 1. PPPOT-T/IC 2. MIT-OA 3. Engineer to evaluate additional diagnostics as required. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you havereceived this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, April 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC C-42 MILNE PT UNIT C-42 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/26/2023 C-42 50-029-23196-00-00 204-028-0 W SPT 6598 2040280 1650 1580 1585 1576 1539 586 742 738 728 OTHER P Austin McLeod 3/25/2023 Surface casing repaired. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT C-42 Inspection Date: Tubing OA Packer Depth 871 2205 2153 2129IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230325155742 BBL Pumped:1.5 BBL Returned:1.4 Wednesday, April 26, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 6XQGU\6XQGU\ James B. Regg Digitally signed by James B. Regg Date: 2023.04.26 13:17:10 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Surface Casing Repair Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,985 feet N/A feet true vertical 7,496 feet N/A feet Effective Depth measured 8,918 feet feet true vertical 7,424 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 / IBT-M 8,104' 6,635' Baker 7-5/8" x 4-1/2" Premier Hyd Baker LTP Packers and SSSV (type, measured and true vertical depth)Baker ZXP N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Operations Manager Contact Phone: 6,598, 6,633 & 6,662 8,065, 8,102 & 8,133 N/A 322-725 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Scott Pessetto scott.pessetto@hilcorp.com 907-564-4373 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 112' 200 Size 112' 4,980' 855 8400 0 4,5800 1,721 measured TVD 5-1/2" 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-028 50-029-23196-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0047434 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT C-42 Plugs Junk measured Length Liner 458' 891' Casing Conductor 7,100' 7,496' 8,584' 8,985' 8,220' 5,808'Surface Production Liner 20" 10-3/4" 7-5/8" 78' 5,773' 6,390psi 10,540psi 5,210psi 6,890psi 7,740psi 10,160psi 8,252' 6,776' Burst N/A Collapse N/A 2,470psi 4,790psi PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 4:11 pm, Apr 17, 2023 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.04.17 13:19:40 -08'00' David Haakinson (3533) Surface Casing Repair RBDMS JSB 042023 Service MILNE PT UNIT C-42 DSR-4/17/23 MILNE POINT / KUPARUK RIVER OIL 322-725 204-028 Perforate WCB 12-28-2023 Tree : CIW 4 1/16" 5M Wellhead: 11" x 11" 5M FMC Gen 5 11" 5M x 4 1/16" 5M adapter 4.5" TCll threads top & Btm 4" CIW-H BPV profile. DATE REV. BY COMMENTS Orig. DF Elev. = 50.40’ (Doyon 141) Orig.GL Elev. = 16.60' (Doyon 141) MILNE POINT UNIT WELL C-42i API NO: 50-029-23196-00 10.75", 45.5 ppf, L-80 Btrc. Perforation Summary Ref log: SLB SCMT Dated: 05-01-04 Size SPF Interval (TVD) Hilcorp Alaska LLC 3.5“ TIW Type-L Latch collar KOP @ 450’ Max. hole angle = 49 deg. Hole angle thru' perfs = 10 deg. 3.5“ TIW float shoe w/ Aluminum nose 20" 91.1# ppf, H-40 BTC MPU C-42i 7.625" 29.7 #/ft , L-80, Btc-mod casing ( drift id = 6.875", cap. = 0.0459 bpf ) 3.5” 9.2 #/ft , L-80 , ST-L ( drift id = 2.992” , cap. = 0.0087 bpf ) 4.5” 12.6 #/ft , L-80 , IBT-mod. ( drift id = 3.958” , cap = 0.0125 bpf ) 5.5“ 17. #/ft , L-80 , ST-L ( drift id = 5.190” , cap = 0.0262 bpf ) 10.75“ 45.5 #/ft , L-80 , Btc ( drift id = 9.950” , cap. = 0.0962 bpf ) Baker Liner tie-back slv. Baker ZXP pkr. w/ HMC hanger 8,125‘ 8,133‘ WLEG 8,104’ 4.5” XN-Nipple ( 3.725” no-go ) 7-5/8“ Baker Premier packer 8,091‘ 8,065‘ 4.5“ HES X-Nipple 8,054‘ 4.5” HES X-Nipple ( 3.813’) 5,807’ 2,023’ 7-5/8”, 29.7# L-80 btc shoe 4.5” Baker CMD Sliding sleeve ( 3.813” bore ) 03/25/04 MDO Drilled and completed Doyon 14 10.75“ ES Cementer @ 1,902‘ 8,030‘ 8,252‘ Hes super seal Float shoe 8,584‘ 3.5“ Baker STL landing collar 8,985‘ 8,950‘ 8,918‘ 3.5” 9.2 #/ft , L-80 , ST-L 5.5“ 17. #/ft , L-80 , ST-L Baker Liner tie-back 7-5/8“x 3.5” Baker ZXP liner pkr. w/ C-2 8,094‘ 8,101‘ 7-5/8“x 5.5” flex lock hanger 8,108‘ 120‘ 2.5“ 2 8,736‘ - 8,746’ 7,249‘ - 7,259’ 09-30-09 JRP Add Perforations, Add ELMD to XN 2.5“ 2 8,590‘ - 8,600’ 7,106 - 7,116' - 2.5“ 6 8,768‘ - 8,784’ 7,281‘ - 7,297’ 8,097‘elmd 2.5“ 2 8,646‘ - 8,705’ 7,159‘ - 7,219’ Well Name Rig API Number Well Permit Number Start Date End Date MP C-42 Slickline 50-029-23196-00-00 204-028 1/30/2023 3/25/2023 T/I/O = 2275/262/0 MIT-IA 2000 psi **Passed** First 15 min IA lost 43 psi, Second 15 min IA lost 10 psi, 3.7 bbls diesel to pressure up, OA leaking at surface during test, stopped leaking after pressure fell off, FWP = 2268/ 260/ vac. T/I/O=3000/200/0 Support techs bled TBG from 3000 psi to 50 psi in 9 hrs all gas, (bleed trailer). Pressurd up OA with nitrogen to depress the OA FL. Support Techs started to jack hammer cement from cellar to expose depth of conductor. Final WHP's=50/0/0. No operations to report. 1/28/2022 - Saturday WELL S/I ON ARRIVAL. BEGIN R/U .125 CARBON, 1-7/8'' RS, QC, 10' X 1-7/8'' RS (2.60'' wheels), QC, OJ, QC, KJ, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 4500H. RAN 20' X 2.70'' DUMMY WHIPSTOCK, 1-7/8'' SAMPLE BAILER TAG @ 8783' SLM, (recover schmoo). RAN 2.73'' CENT., BHP's. RAN 4-1/2 XXN-PLUG (8 ea. 1/8" ports), SET IN XN- NIPPLE @ 8100' SLM / 8091' MD. WELL S/I ON DEPARTURE. T/I/O=3500/200/0 Support techs bled TBG from 3500 to 3000 psi in 60 mins (all gas) post plug set. Monitored WHP's for 45 mins no increase in pressure on the TBG. Final WHP's =3000/200/0. 1/31/2023 - Tuesday 1/29/2023 - Sunday No operations to report. 1/30/2023 - Monday 1/27/2022 - Friday No operations to report. 1/25/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/26/2022 - Thursday No operations to report. 0 MIT-IA 2000 psi **Passed** First 15 min IA lost 43 psi, Second 15 min IA lost 10 psi, 3.7 bbls diesel to pressure up, OA leaking at surface during test, stopped leaking after pressure fell off, RAN 4-1/2 XXN-PLUG (8 ea. 1/8" ports), SET IN XN- NIPPLE @ 8100' SLM / 8091' MD. 0 Support techs bled TBG from 3000 psi to 50 psi in 9 hrs all gas, (bleed trailer). Pressurd up OA with nitrogen to depress the OA FL. Support Techs started to jack hammer cement from cellar to expose depth of conductor. Well Name Rig API Number Well Permit Number Start Date End Date MP C-42 Slickline 50-029-23196-00-00 204-028 1/30/2023 3/25/2023 2/3/2022 - Friday DIG DIRT OUT OF CONDUCTOR. ABLE TO REMOVE APPROXIMATELY 1' OF DIRT FROM BETWEEN CONDUCTOR AND 10-3/4' CASING. PUMP N2 DOWN OA AND SEE LEAK (5' 4" BELOW OA VALVE / APPROXIMATELY 1' BELOW THE CURRENT TOP OF CONDUCTOR). SDFN. 2/1/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Well Support Techs prep cellar for upcoming surface casing repair. Support techs uncoverd conductor 5' from top of conductor. T/I/O = 0/0/0 Load Tubing, Pumped 42 bbls Produced Water, Pumped 45 bbls Criesel, T/I/O = 0/100/0 2/2/2022 - Thursday CUT 6' OFF OF CONDUCTOR USING CUT OFF DISC. REMOVED PACKED DIRT FROM 10-3/4" CASING. SEE NO VISUAL HOLE. PUMP N2 DOWN OA AND SEE LEAK BELOW THE CUT OFF POINT OF CONDUCTOR. CONDUCTOR IS PACKED WITH DIRT AND LEAK POINT IS NOT VISIBLE. SDFN. No operations to report. UT INSPECT 10-3/4" CASING IN 1 FOOT INTERVALS. TOP INTERVAL (0-1') HAD A LOW READING OF 0.355". THE NEXT INTERVAL (1'-2') HAD A LOW READING OF 0.335". THE CASING COLLAR HAD A LOW READING OF 0.404". THE FINAL INTERVAL (3'-4') HAD A LOW READING OF 0.336". 2/4/2022 - Saturday No operations to report. 2/7/2023 - Tuesday 2/5/2023 - Sunday No operations to report. 2/6/2023 - Monday CUT 6' OFF OF CONDUCTOR USING CUT OFF DISC. REMOVED PACKED DIRT FROM 10-3/4" CASING. SEE NO VISUAL HOLE. PUMP N2 DOWN OA AND SEE LEAK BELOW THE CUT OFF POINT OF CONDUCTOR. CONDUCTOR IS PACKED WITH DIRT AND LEAK POINT IS NOT VISIBLE. Support techs uncoverd conductor 5' from top of conductor. T DIG DIRT OUT OF CONDUCTOR. ABLE TO REMOVE APPROXIMATELY 1' OF DIRT FROM BETWEEN CONDUCTOR AND 10-3/4' CASING. PUMP N2 DOWN OA AND SEE LEAK (5' 4" BELOW OA VALVE / APPROXIMATELY 1' BELOW THE CURRENT TOP OF CONDUCTOR). S Well Name Rig API Number Well Permit Number Start Date End Date MP C-42 Surf. Crews 50-029-23196-00-00 204-028 1/30/2023 3/25/2023 WELD UPPER PORTION OF CONDUCTOR BACK. BEGIN FILLING CONDUCTOR WITH CEMENT. SDFN. MISTRAS INSPECT BOTH WELDS ON UPPER AND LOWER BANDS. INSPECTION SHOWS GOOD WELD. WELD SLEEVE AND CLAMSHELL ONTO SURFACE CASING. SDFN. 2/25/2022 - Saturday WELD LOWER PORTION OF CONDUCTOR BACK IN PLACE. PLACE UPPER SECTION OF CONDUCTOR IN PLACE AND SECURE. 2/28/2023 - Tuesday 2/26/2023 - Sunday Pressure Test OA, Pumped 1.31 bbls Diesel down OA to pressure up to 500 psi, Hold Pressure, No Leaks, Good Test, Bleed back to 0 psi 2/27/2023 - Monday 2/24/2022 - Friday UT INSPECT BOTTOM 3 FEET OF EXPOSED SURFACE CASING. MINIMUM WALL THICKNESS SEEN WAS 0.22" NEAR EXISTING HOLE. WELD TOP BAND ONTO SURFACE CASING. ATTEMPT TO WELD BOTTOM BAND. DIESEL BEGAN DRIPPING FROM EXISTING HOLE MAKING IT UNSAFE TO WELD. STOP THE JOB. WIDEN EXISTING HOLE TO 3/8". INSERT HOSE DOWN INTO SURFACE CASING AND SIPHON APPROXIMATELY 10 GALLONS TO REDUCE THE FLUID LEVEL. WELD BOTTOM BAND ONTO SURFACE CASING. SDFN. 2/22/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/23/2022 - Thursday CUT AND REMOVE OUTSIDE INSULATION AROUND CONDUCTOR. CUT AND REMOVE AN ADDITIONAL 2' FROM CONDUCTOR TO EXPOSE HOLE. GUY COOK WITH AOGCC ONSITE FOR INSPECTION OF CASING AND HOLE. SDFN. WELD UPPER PORTION OF CONDUCTOR BACK. BEGIN FILLING CONDUCTOR WITH CEMENT. WELD LOWER PORTION OF CONDUCTOR BACK IN PLACE. PLACE UPPER SECTION OF CONDUCTOR IN PLACE AND SECURE. MISTRAS INSPECT BOTH WELDS ON UPPER AND LOWER BANDS. INSPECTION SHOWS GOOD WELD. WELD SLEEVE AND CLAMSHELL ONTO SURFACE CASING. CUT AND REMOVE AN ADDITIONAL 2' FROM CONDUCTOR TO EXPOSE HOLE. GUY COOK WITH AOGCC ONSITE FOR INSPECTION OF CASING AND HOLE. WELD TOP BAND ONTO SURFACE CASING. ATTEMPT TO WELD BOTTOM BAND. DIESEL BEGAN DRIPPING FROM EXISTING HOLE MAKING IT UNSAFE TO WELD. STOP THE JOB. WIDEN EXISTING HOLE TO 3/8". INSERT HOSE DOWN INTO SURFACE CASING AND SIPHON APPROXIMATELY 10 GALLONS TO REDUCE THE FLUID LEVEL. WELD BOTTOM BAND ONTO SURFACE CASING. Well Name Rig API Number Well Permit Number Start Date End Date MP C-42 Surf. Crews 50-029-23196-00-00 204-028 1/30/2023 3/25/2023 No operations to report. No operations to report. 3/4/2022 - Saturday FILL CONDUCTOR WITH CEMENT TO WITHIN 1' OF THE TOP OF CONDUCTOR. SDFN TO MONITOR FOR FALL BACK. 3/7/2023 - Tuesday 3/5/2023 - Sunday No operations to report. 3/6/2023 - Monday 3/3/2022 - Friday No operations to report. 3/1/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 3/2/2022 - Thursday No operations to report. FILL CONDUCTOR WITH CEMENT TO WITHIN 1' OF THE TOP OF CONDUCTOR. Well Name Rig API Number Well Permit Number Start Date End Date MP C-42 Slickline 50-029-23196-00-00 204-028 1/30/2023 3/25/2023 WELL SHUT-IN ON ARRIVAL. EQUALIZE AND PULL 4-1/2" XXN PLUG FROM XN-NIPPLE AT 8,091' MD. WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED. No operations to report. 3/11/2022 - Saturday No operations to report. 3/14/2023 - Tuesday 3/12/2023 - Sunday No operations to report. 3/13/2023 - Monday 3/10/2022 - Friday No operations to report. 3/8/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 3/9/2022 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP C-42 Slickline 50-029-23196-00-00 204-028 1/30/2023 3/25/2023 No operations to report. No operations to report. 3/18/2022 - Saturday No operations to report. 3/21/2023 - Tuesday 3/19/2023 - Sunday No operations to report. 3/20/2023 - Monday 3/17/2022 - Friday No operations to report. 3/15/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 3/16/2022 - Thursday T/I/O = 2800/0/0. Pumped 5 bbls 60/40 down Tubing, Pumped 50 bbls Produced Water down Tubing, Pumped 3 bbls 60/40, FWP = 2400/850/300. Well Name Rig API Number Well Permit Number Start Date End Date MP C-42 Slickline 50-029-23196-00-00 204-028 1/30/2023 3/25/2023 No operations to report. T/I/O= 1580/870/586 AOGCC MIT-IA to 2129 psi PASSED (Witnessed by Austin McLeod) Pressured up IA to 2205 psi with 1.5 bbls diesel. 1st 15 min IA lost 52 psi. 2nd 15 min IA lost 24 psi for a total loss of 76 psi in 30 min. Bled back 1.5 bbls. Fin al Whp's= 1535/870/585 3/25/2022 - Saturday No operations to report. 3/28/2023 - Tuesday 3/26/2023 - Sunday No operations to report. 3/27/2023 - Monday 3/24/2022 - Friday No operations to report. 3/22/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary SI WELL, T/I/O = 1000/200/100. TAGGED TD AT 8780 FT. RAN GUN 1, INTERVAL 8675-8705 FT, ALL SHOTS FIRED. RAN GUN 2, INTERVAL 8645-8675 FT. ALL SHOTS FIRED. 6 SPF, 60 DEG PHASE. ENTRANCE HOLE = 0.32" PENETRATION = 31.10". FINAL T/I/O = 1000/200/100, WELL INJECTING ON DEPARTURE. 3/23/2022 - Thursday No operations to report. 6 AOGCC MIT-IA to 2129 psi PASSED (Witnessed by Austin McLeod) Pressured up IA to 2205 psi with 1.5 bbls diesel. 1st 15 min IA lost 52 psi. 2nd 15 min IA lost 24 psi for a total loss of 76 psi in 30 min. RAN GUN 1, INTERVAL 8675-8705 FT, ALL SHOTS FIRED. RAN GUN 2, INTERVAL 8645-8675 FT. ALL SHOTS FIRED. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: WAG MPU C-42 (PTD# 204-028) Cellar Bubbling Date:Thursday, March 9, 2023 9:29:49 AM Attachments:image001.png image002.png From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Thursday, March 9, 2023 9:17 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: WAG MPU C-42 (PTD# 204-028) Cellar Bubbling Mr. Wallace, WAG injector MPU C-42 (PTD# 204-028) was identified as having a surface casing leak in October 2022. The repairs were made per Sundry #322-725. The well is now ready to be returned to injection. The well is now classified as UNDER EVALUATION and placed on a 28 day clock for evaluation. Once the well, has achieved stable injection an AOGCC witnessed MIT-IA will be scheduled. Plan Forward: 1. Place well on injection 2. AOGCC witnessed MIT-IA 3. Engineer to evaluate repair Please respond if there are any questions or comments. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Monday, October 24, 2022 8:01 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: WAG MPU C-42 (PTD# 204-028) Cellar Bubbling Mr. Wallace, WAG Injector MPU C-42 (PTD# 204-028) was pressure tested after identifying bubbling in the cellar. This MIT-OA failed. The well is now classified as NOT OPERABLE and is shut in. Plan Forward: 1. Engineer to evaluate repair Please respond with any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Tuesday, October 18, 2022 11:09 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: WAG MPU C-42 (PTD# 204-028) Cellar Bubbling Mr. Wallace, WAG Injector MPU C-42 (PTD# 204-028) was identified as having bubbling in the cellar. The well is now classified as UNDER EVALUATION for diagnostics and review. The well will remain online in steady state while initial diagnostics are conducted. It is now on a 28 day clock for diagnostics and resolution. Plan Forward: 1. PPPOT-T/IC 2. MIT-OA 3. Engineer to evaluate additional diagnostics as required. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you havereceived this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or 2023-0226_Surface_Casing_Repair_MPU_C-42_gc Page 1 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 2/26/2023 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Casing Repair Petroleum Inspector MPU C-42 Hilcorp Alaska LLC PTD 2040280; Sundry 322-725 2/26/2023: I traveled location with AOGCC Petroleum Inspector Sean Sullivan to inspect the surface casing repair of the 10 ¾ inch surface casing on MPU C-42. We met with Nick Frazier (Hilcorp) when we arrived. We took pictures of the repair and spoke about getting the dirt and gravel tested by environmental since the wellhouse smelled strongly of diesel from the gravel in the cellar and the gravel was obviously wet. Next, we spoke about a pressure test of the 10 ¾ inch casing repair. We were informed that since this well has an open casing shoe, they would be performing a rolling pressure test and would pump up to 10 barrels of diesel to hold the pressure on the OA to 500 psi. We spoke about the pressure test some more and I informed Nick we will call Mel Rixse, the AOGCC Engineer overseeing the job, about potentially pumping 10 bbls of diesel into the ground if the open shoe would not hold pressure. We spoke to Mr. Rixse and he agreed the repair was to be pressure tested, checked for leaks, and then bled off. Hilcorp was not allowed to pump 10 bbls of diesel. The amount of diesel that would be allowed to be pumped to achieve 500 psi would be two bbls only. The pressure test was completed, and the repair held good with only 1.3 bbls pumped. With no signs of leaking from the repair and test pressure holding well at 500 psi, I gave Nick the okay to bleed off and continue forward with testing the gravel in the cellar for hydrocarbons and cleaning it up if there is any present. I also asked for information like pad thickness, and tundra level to be sent to me so I can document the information. AOGCC Petroleum Inspector Sean Sullivan and I left location. Attachments: Photos (6) 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.09 13:56:20 -08'00' 2023-0226_Surface_Casing_Repair_MPU_C-42_gc Page 2 of 4 Surface Casing Repair – MPU C-42 (PTD 204028) Photos by AOGCC Inspector G. Cook 2/26/2023 2023-0226_Surface_Casing_Repair_MPU_C-42_gc Page 3 of 4 2023-0226_Surface_Casing_Repair_MPU_C-42_gc Page 4 of 4 2023-0223_Surface_Csg_Repair_MPU_C-42_gc Page 1 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 2/23/2023 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Casing Repair Petroleum Inspector MPU C-42 Hilcorp Alaska LLC PTD 2040280; Sundry 322-725 2/23/2023: I traveled to Milne Point Unit C-42 to document the damage on the 10 ¾- inch surface casing. I met with Nick Frazier (Hilcorp) and took some photographs of the casing before they started the repair. The leak is on the back of the well and approximately 7 feet down from the lower lock-down screws on the wellhead. I told them to go ahead with the repair and to notify us for inspection when the repair was complete before they buried the casing so we could document the repair. Attachments: Photos (6) 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.08 15:07:06 -08'00' 2023-0223_Surface_Csg_Repair_MPU_C-42_gc Page 2 of 4 Surface Casing Repair – MPU C-42 (PTD 2040280) Photos by AOGCC Inspector G. Cook 2/23/2023 2023-0223_Surface_Csg_Repair_MPU_C-42_gc Page 3 of 4 2023-0223_Surface_Csg_Repair_MPU_C-42_gc Page 4 of 4 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Surface Casing Repair 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,985'N/A Casing Collapse Conductor N/A Surface 2,470psi Production 4,790psi Liner 6,390psi Liner 10,540psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY scott.pessetto@hilcorp.com 907-564-4373 Scott Pessetto Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 12.6# / L-80 / IBT-M 8,104' 1/8/2023 Baker 7-5/8" x 4-1/2" Premier Hyd, Baker LTP & Baker ZXP and N/A 8,065 MD/ 6,598 TVD, 8,102 MD/ 6,633 TVD & 8,133 MD/ 6,662 TVD and N/A See Schematic See Schematic 4-1/2" Perforation Depth MD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047434 204-028 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23196-00-00 Hilcorp Alaska LLC KUPARUK RIVER OIL N/A C.O. 432E MILNE PT UNIT C-42 Length Size Proposed Pools: 112' 112' TVD Burst PRESENT WELL CONDITION SUMMARY 7,496' 8,918' 7,424' 4,075 N/A 78' 20" MILNE POINT 10,160psi MD N/A 7,740psi 5,210psi 6,890psi 4,980' 6,776' 7,100' 5,808' 8,252' 7,496'8,985' 8,584'5-1/2"458' 891' 3-1/2" 10-3/4" 7-5/8" 5,773' 8,220' Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Taylor Wellman for David Haakinson By Anne Prysunka at 9:19 am, Dec 30, 2022 322-725 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2022.12.30 09:00:16 -09'00' Taylor Wellman (2143) MGR03JAN23 * Photo document surface casing holes and welded plates. Include in 10-404. * 24 hour notice to AOGCC for opportunity to inspect and view welding of 12.25" ID clamshell patch. * 24 hour notice to AOGCC for opportunity to inspect well support structure if required for SC support. 10-404 DSR-1/3/23SFD 12/30/2022GCW 01/04/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.01.05 12:13:12 -09'00' RBDMS JSB 011023 Surface Casing Repair and Add Perf Well: MPC-42 PTD: 204-028 API: 50-029-23196-00 Well Name:MPU C-42 API Number:50-029-23196-00 Current Status:SI WAG Injector Rig:SL, EL, Welders Estimated Start Date:1/8/2023 Estimated Duration:14 Reg.Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:204-028 First Call Engineer:Scott Pessetto (907) 564-4373 (O) (801) 822-2203 (M) Second Call Engineer:Jerimiah Galloway (907) 564-5005 (O) (828) 553-2537 (M) AFE Number:222-01362 Job Type SC Repair / Perforate Current Bottom Hole Pressure: 4,789 psi @ 7141’ TVD SBHP on 08/13/19 |12.9 PPGE MPSP:4,075 psi (0.1psi/ft gas gradient) Max Deviation:49 deg @ 6,220’ MD Min ID: 2.992 3-1/2” 9.2# liner @ 8,094’ MD Brief Well Summary Well C-42 is a Kuparuk A and C-sand injector. Well C-42 is currently shut-in due to a surface casing leak. The tubing and inner annulus are competent. Leak detection on the surface casing indicates the leak is very shallow. An immediate stream of fluid started from the conductor after nitrogen was pumped down the OA. Notes Regarding Wellbore Condition •• MIT-IA passed to 1880 psi on 7/22/2020. •• No IA anomalies during injection. •• Last tag 8,783’ MD, noted heavy pickups for 500’ pulling out of hole after tag. •• Schmoo/solids likely to be encountered •• Conductor is not supporting load Objective: Return well to WAG injection •• Repair surface casing leak •• Perforate B-silt sand (8,645’ – 8,705’ MD, 60’) Procedure Pre-Sundry Work: Slickline 1. MIRU Slickline Unit. PT PCE to 250 psi Low / 4,000 psi High. 2. MU 20’ of 2-1/2” Dummy Drift Gun and attempt to drift to at least perf depth of 8,705’ MD. i. Last tag 8/12/2019 - 8,783’ MD. 1’ of fill over perfs. 3. Run SBHP survey using dual spartek gauges at requested stops: i. 8,590’ MD / 7,106’ TVD – 30 minutes ii. 8,073’ MD / 6,606’ TVD – 15 minutes 4. Perform MIT-IA to 2000 psi. 5. Load tubing to surface with diesel. 6. Set XX plug in 3.813” X nipple at 2,023’ MD. 7. Perform negative test on plug. N Set plug in XN nipple at 8,097' MD mgr Passing MIT-IA required to proceed. mgr Surface Casing Repair and Add Perf Well: MPC-42 PTD: 204-028 API: 50-029-23196-00 NOTE: AOGCC requires daily activity log with high level steps and 1-2 photos of significant steps during excavation, repair and backfill for submission with 10-404. See W-40 example in job folder. Surface Casing Repair 1. Begin to document daily work with a high level activity log. Include 1-2 photos and a one sentence summary of each day’s activities. The log will be submitted to the AOGCC with the 10- 404 at job completion. 2. Bleed tubing, IA, and OA to 0 psi. 3. Sniff cellar and adjacent area with multi-gas meter for LEL, CO, H2S, and O2. Ensure confined space, egress, and ventilation is adequate for operations. 4. Due to expected shallow surface casing leak, plan to leave wellhouse on for initial conductor cut. a. Disconnect and blind flow lines prior to commencing work. b. Shoring box required for any excavation deeper than 2ft below existing cellar. i. No excavation should commence until discussion with WIE/OE. ii.Well support structure analysis will need to conducted prior to starting excavation beyond 2’ below grade. iii. Well house to be removed as needed to facilitate casing repair. iv. If excavating, a qualified person must be on-site for daily sign off of excavation per OSHA requirements, every 24 hours. v. Complete an ACWR (Area Civil Work Request) which includes a location for all utilities, thermosyphons, and any underground infrastructure. 5. Install fire blankets around conductor landing ring to protect surface casing from any machining debris. Operations (SUNDRY REQUIRED) 1. Cut and remove the conductor from cellar floor to the landing ring. a. Drill hole in conductor near grade level with cold cutting drill bit. Flush conductor with water through drilled hole until clean returns are observed. b. Install N2 purge equipment for the OA at WSL’s discretion. i. Use of an N2 cap/purge will be determined on site, prior to proceeding. c. Primary cutting option is to use an air arc torch but the Hot Work Permit for this portion of the job will dictate if an alternative cutting method will be required. d. Two horizontal cuts (below the landing ring and one at the bottom of the conductor section) and two vertical cuts will be required to remove the conductor. e. Prior to cutting conductor, install continuous gas monitoring for LEL’s from conductor. f. Landing ring is currently sitting above the conductor indicating conductor is not currently supporting downward load. 2. Chip away excess cement from the surface casing. Buff and prepare the surface casing for inspection and welding. 3. Perform UT inspection of the exposed surface casing. a. Inspect for any additional holes below the landing ring. b. If holes are not identified at surface, contact OE/WIE. i. WIE – Jerimiah Galloway - 907.564.5005 ii. OE – Scott Pessetto - 907.564.4373 c. Sleeve banding locations to be identified, marked and UT’d on a grid for nominal wall thickness verification. d. Stop further work and contact OE/WIE if UT results show internal wear >50% nominal casing thickness or external corrosion >50% nominal wall. i. Calculated Nominal Compressive Strength 10.75”, L-80, 45.5# at 50% wall loss: 394 kips ii. Calculated Nominal Tensile Capacity 10.75”, L-80, 45.5# at 50% wall loss: 390 kips Surface Casing Repair and Add Perf Well: MPC-42 PTD: 204-028 API: 50-029-23196-00 iii. Worst case vertical load on 10.75” casing: 253 kips e. If UT results show wall loss greater than 50%, the well support structure may be required. All work to stop until engineering analysis is complete. i. Notify AOGCC if proceeding with use of the well support structure. f. Notify AOGCC inspector for opportunity to inspect and continue to document with photos as part of the10-404. 4.Contingency: If the Well Support Structure is required: a. Confirm no pressure build in tubing since the previous negative test. b. Set BPV in tubing hanger. c. Remove wellhouse. d. Nipple down production tree. e. Move in well support structure. 5. Weld 12.25” ID clamshell patch casing sleeve. Notify AOGCC inspector for opportunity to inspect and document all steps of the below welding operation. a. Clean area to receive casing patch weld to surface casing. b. Contingency: If UT reveals thin casing with a probability of weld burning through. Use a cold cutting drill bit to drill a small hole to drain diesel below planned weld. c. Dry fit casing sleeve and banding to ensure compatibility and positioning. The sleeve will be welded to a band at the bottom and landing ring on top. d. Band material: A572-50 or A516-70N, ID=10.75” thickness=.75”. e. Confirm OA pressure bled to 0 psi. f. Verify air movers/ventilation and establish a fire watch. Monitor LEL’s, O2 and CO. g. Install sleeve in accordance with sleeve design and weld package, continuously monitoring weld temperatures. i. Melting sticks are not permitted. h. NDE weld. i. Photograph weld as part of 10-404 requirements. 6. Leak test OA to 500 psi to confirm no conductor leak path remains. a.Note: the OA has an open shoe. 7. Re-install conductor onto the top of the existing conductor in the ground. a. Weld cut conductor halves back onto conductor b. Cement surface casing by conductor annulus to within 1’ of conductor top. c. Install corrosion inhibitor in SC x Conductor annulus to conductor top. Slickline 1. MIRU Slickline Unit. PT PCE to 250 psi Low / 4,000 psi High. 2. Pull XX plug in 3.813” XX nipple at 2,023’ MD. END OF SURFACE CASING REPAIR E-line Perforating Procedure (SUNDRY REQUIRED) 1. MIRU EL unit and PT PCE to 250psi Low / 4,000 psi High. 2. PU Perf Gun BHA and perforate the interval listed below. a. Document changes in wellhead pressure and condition of guns as they return. 3. Perform log correlation pass Surface Casing Repair and Add Perf Well: MPC-42 PTD: 204-028 API: 50-029-23196-00 4. Contact Geologist and/or Ops Engineer to review depth and planned perforation depths prior to firing guns. b. Ops Engineer: Scott Pessetto scott.pessetto@hilcorp.com; (801) 822-2203 c. Geologist: Graham Emerson graham.emerson@hilcorp.com; (907) 793-0315 d. Perforating Guns: 2 - 2-1/2” HMX, 6 SPF, 60 degree phase guns. Formation Length (ft) Top (MD) Bottom (MD) Top (TVD) Bottom (TVD) Kuparuk B-silt ±60’ ±8,645’ ±8,705’ ±7,159’ ±7,219’ 5. RDMO EL unit. 6. Bring well on injection. Attachments: 1. As-built Schematic 2. Proposed Schematic Tree : CIW 4 1/16" 5M Wellhead: 11" x 11" 5M FMC Gen 5 11" 5M x 4 1/16" 5M adapter 4.5" TCll threads top & Btm 4" CIW-H BPV profile. DATE REV. BY COMMENTS Orig. DF Elev. = 50.40’ (Doyon 141) Orig.GL Elev. = 16.60' (Doyon 141) MILNE POINT UNIT WELL C-42i API NO: 50-029-23196-00 10.75", 45.5 ppf, L-80 Btrc. Perforation Summary Ref log: SLB SCMT Dated: 05-01-04 Size SPF Interval (TVD) Hilcorp Alaska LLC 3.5“ TIW Type-L Latch collar KOP @ 450’ Max. hole angle = 49 deg. Hole angle thru' perfs = 10 deg. 3.5“ TIW float shoe w/ Aluminum nose 20" 91.1# ppf, H-40 BTC MPU C-42i 7.625" 29.7 #/ft , L-80, Btc-mod casing ( drift id = 6.875", cap. = 0.0459 bpf ) 3.5” 9.2 #/ft , L-80 , ST-L ( drift id = 2.992” , cap. = 0.0087 bpf ) 4.5” 12.6 #/ft , L-80 , IBT-mod. ( drift id = 3.958” , cap = 0.0125 bpf ) 5.5“ 17. #/ft , L-80 , ST-L ( drift id = 5.190” , cap = 0.0262 bpf ) 10.75“ 45.5 #/ft , L-80 , Btc ( drift id = 9.950” , cap. = 0.0962 bpf ) Baker Liner tie-back slv. Baker ZXP pkr. w/ HMC hanger 8,125‘ 8,133‘ WLEG 8,104’ 4.5” XN-Nipple ( 3.725” no-go ) 7-5/8“ Baker Premier packer 8,091‘ 8,065‘ 4.5“ HES X-Nipple 8,054‘ 4.5” HES X-Nipple ( 3.813’) 5,807’ 2,023’ 7-5/8”, 29.7# L-80 btc shoe 4.5” Baker CMD Sliding sleeve ( 3.813” bore ) 03/25/04 MDO Drilled and completed Doyon 14 10.75“ ES Cementer @ 1,902‘ 8,030‘ 8,252‘ Hes super seal Float shoe 8,584‘ 3.5“ Baker STL landing collar 8,985‘ 8,950‘ 8,918‘ 3.5” 9.2 #/ft , L-80 , ST-L 5.5“ 17. #/ft , L-80 , ST-L Baker Liner tie-back 7-5/8“x 3.5” Baker ZXP liner pkr. w/ C-2 8,094‘ 8,101‘ 7-5/8“x 5.5” flex lock hanger 8,108‘ 120‘ 2.5“ 2 8,736‘ - 8,746’ 7,249‘ - 7,259’ 8,590‘ - 8,600’ 7,106‘ - 7,116’22.5“ 2.5“ 6 8,768‘ - 8,784’ 7,281‘ - 7,297’ 09-30-09 JRP Add Perforations, Add ELMD to XN 8,097‘elmd Tree : CIW 4 1/16" 5M Wellhead: 11" x 11" 5M FMC Gen 5 11" 5M x 4 1/16" 5M adapter 4.5" TCll threads top & Btm 4" CIW-H BPV profile. DATE REV. BY COMMENTS Orig. DF Elev. = 50.40’ (Doyon 141) Orig.GL Elev. = 16.60' (Doyon 141) MILNE POINT UNIT WELL C-42i API NO: 50-029-23196-00 10.75", 45.5 ppf, L-80 Btrc. Perforation Summary Ref log: SLB SCMT Dated: 05-01-04 Size SPF Interval (TVD) Hilcorp Alaska LLC 3.5“ TIW Type-L Latch collar KOP @ 450’ Max. hole angle = 49 deg. Hole angle thru' perfs = 10 deg. 3.5“ TIW float shoe w/ Aluminum nose 20" 91.1# ppf, H-40 BTC MPU C-42i 7.625" 29.7 #/ft , L-80, Btc-mod casing ( drift id = 6.875", cap. = 0.0459 bpf ) 3.5” 9.2 #/ft , L-80 , ST-L ( drift id = 2.992” , cap. = 0.0087 bpf ) 4.5” 12.6 #/ft , L-80 , IBT-mod. ( drift id = 3.958” , cap = 0.0125 bpf ) 5.5“ 17. #/ft , L-80 , ST-L ( drift id = 5.190” , cap = 0.0262 bpf ) 10.75“ 45.5 #/ft , L-80 , Btc ( drift id = 9.950” , cap. = 0.0962 bpf ) Baker Liner tie-back slv. Baker ZXP pkr. w/ HMC hanger 8,125‘ 8,133‘ WLEG 8,104’ 4.5” XN-Nipple ( 3.725” no-go ) 7-5/8“ Baker Premier packer 8,091‘ 8,065‘ 4.5“ HES X-Nipple 8,054‘ 4.5” HES X-Nipple ( 3.813’) 5,807’ 2,023’ 7-5/8”, 29.7# L-80 btc shoe 4.5” Baker CMD Sliding sleeve ( 3.813” bore ) 03/25/04 MDO Drilled and completed Doyon 14 10.75“ ES Cementer @ 1,902‘ 8,030‘ 8,252‘ Hes super seal Float shoe 8,584‘ 3.5“ Baker STL landing collar 8,985‘ 8,950‘ 8,918‘ 3.5” 9.2 #/ft , L-80 , ST-L 5.5“ 17. #/ft , L-80 , ST-L Baker Liner tie-back 7-5/8“x 3.5” Baker ZXP liner pkr. w/ C-2 8,094‘ 8,101‘ 7-5/8“x 5.5” flex lock hanger 8,108‘ 120‘ 2.5“ 2 8,736‘ - 8,746’ 7,249‘ - 7,259’ 8,590‘ - 8,600’ 7,106‘ - 7,116’22.5“ 2.5“ 6 8,768‘ - 8,784’ 7,281‘ - 7,297’ 09-30-09 JRP Add Perforations, Add ELMD to XN 8,097‘elmd CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: WAG MPU C-42 (PTD# 204-028) Cellar Bubbling Date:Tuesday, October 25, 2022 1:17:47 PM Attachments:image003.png image004.png From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Monday, October 24, 2022 8:01 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: WAG MPU C-42 (PTD# 204-028) Cellar Bubbling Mr. Wallace, WAG Injector MPU C-42 (PTD# 204-028) was pressure tested after identifying bubbling in the cellar. This MIT-OA failed. The well is now classified as NOT OPERABLE and is shut in. Plan Forward: 1. Engineer to evaluate repair Please respond with any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Tuesday, October 18, 2022 11:09 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: WAG MPU C-42 (PTD# 204-028) Cellar Bubbling Mr. Wallace, WAG Injector MPU C-42 (PTD# 204-028) was identified as having bubbling in the cellar. The well is now classified as UNDER EVALUATION for diagnostics and review. The well will remain online in steady state while initial diagnostics are conducted. It is now on a 28 day clock for diagnostics and resolution. Plan Forward: 1. PPPOT-T/IC 2. MIT-OA 3. Engineer to evaluate additional diagnostics as required. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you havereceived this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: WAG MPU C-42 (PTD# 204-028) Cellar Bubbling Date:Wednesday, October 19, 2022 8:40:37 AM Attachments:image003.png image004.png From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Tuesday, October 18, 2022 11:09 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: UNDER EVALUATION: WAG MPU C-42 (PTD# 204-028) Cellar Bubbling Mr. Wallace, WAG Injector MPU C-42 (PTD# 204-028) was identified as having bubbling in the cellar. The well is now classified as UNDER EVALUATION for diagnostics and review. The well will remain online in steady state while initial diagnostics are conducted. It is now on a 28 day clock for diagnostics and resolution. Plan Forward: 1. PPPOT-T/IC 2. MIT-OA 3. Engineer to evaluate additional diagnostics as required. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you havereceived this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will notadversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Inspector Name: Adam Earl Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 29, 2020 TO: Jim Regg r P.I. Supervisor 1 �� /�(�� , SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC Rel Insp Num: C-42 FROM: Adam Earl MILNE PT UNIT C-42 Petroleum Inspector Packer Depth Pretest Initial Src: Inspector Well C-42 Reviewed By: G TVD 6598 Tubing r P.I. Supry JI NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT C-42 API Well Number 50-029-23196-00-00 Inspector Name: Adam Earl Permit Number: 204-028-0 Inspection Date: 7/22/2020 Insp Num: mitAGE200726112536 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C-42 "Type Inj G TVD 6598 Tubing 3462 3465 3464 3464 PTD 2040280 Type Test SPT Test psi 1650 IA 501 1934 1890 1884 - BBL Pumped: � — 3 QA 1 — Returned: ed: 1.. BBL _ 144 254 254 - Interval 4YRTST P/F P Notes: MITIA Wednesday, July 29, 2020 Page I of I • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,August 29,2016 TO: Jim Reg P.I.Supervisor I tie"� CI ( I SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC C-42 FROM: Johnnie Hill MILNE PT UNIT KR C-42 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supra: NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR C-42 API Well Number 50-029-23196-00-00 Inspector Name: Johnnie Hill Permit Number: 204-028-0 Inspection Date: 7/6/2016 Insp Num: mitJWH160826174506 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min C 42 W 6598 2363 2365 - 2363 . 2363 Well Type Inj , ITVD Tubing 2040280SPT 1650 242 1807 1771 1770 PTD - Type Test; ,Test psi IA Interval 4YRTST 'P/F P ✓ OA 179 292 I 294 295 - Notes: 1.7bbls of diesel used - SCANNED JUN 2 3 2.01?. Monday,August 29,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, December 01, 2015 5:04 PM To: Wallace, Chris D (DOA) Cc: Regg, James B (DOA) Subject: RE:Injector MPC-42 (PTD#2040280) Remain on Injection Attachments: MPC-42 TIO.xlsx Chris, Injector MPC-42 (PTD#2040280) returned to injection on 11/5/15 following diagnostics for diesel freeze protect found bubbling in the surface casing by conductor annulus. Bubbling ceased within a few days of return to stabilized injection and appears to have resulted from thermal expansion alone. Hilcorp believes there are no further integrity concerns with this well and plans to keep the well on injection. A TIO plot is attached for reference. Please call with any questions. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNED AUG 1 0 2016 ,.,I, 1I.i.1 ., I1 From: Wyatt Rivard Sent: Monday, November 02, 2015 2:52 PM To: 'Wallace, Chris D (DOA)' Cc: 'Regg, James B (DOA)'; 'Brooks, Phoebe L (DOA)' Subject: RE: Injector MPC-42 (PTD # 2040280) Return to Injection Chris, Hilcorp plans to return injector MPC-42 () 040280)to injection for a 28 day monitoring period following recent diagnostics. MPC-42 was shut-in on 10/28/15 for bubbling freeze protect in the surface casing by conductor annulus while injecting water.The well had a passing MIT-OA to 1005 psi on 10-31-15 demonstrating surface casing integrity. Additionally, IA and OA fluid levels were found at surface. Hilcorp believes the bubbling in the conductor was the result of thermal expansion following the recent swap from gas to produced water i.n4ction and that there are no integrity concerns on this well. A TIO plot and copy of MIT-OA are attached for reference› - Diagnostics 10/28/15: Well SI for bubbling in the conductor. Bubbling ceased soon after SI/cooldown of the we , 9 ' pressure decreased from "'400 to —80 psi. IA went on a vac. 10/31/15: IA and OA fluid levels at surface. No gas in IA or OA. 10/31/15: MIT-OA with diesel passed to 1005 psi. • • I i i i i vSTOZ/TO/ZT - SZOZ/6Z/TT - STOZ/LZ/TT -- STOZ/SZ/TT - STOZ/£Z/TT - STOZ/TZ/TT f _ STOZ/6T/TT w _ STOZ/LT/TT _ STOZ/ST/TT I - STOZ/£T/TT - STOZ/TT/TT J : STOZ/60/TT : STOZ/LO/TT - STOZ/SO/TT _ STOZ/£0/TT •E : STOZ/TO/TT Tycl STOZ/0£/OT C9 - STOZ/8Z/OT : STOZ/9Z/OT +, a : _ STOZ/bZ/0T aSTOZ/ZZ/OT 0 = STOZ/OZ/OT i= : STOZ/8T/OT __ - STOZ/9T/OT 71-0 _ STOZ/tiT/OT I a - STOZ/ZT/OT - STOZ/OT/OT : STOZ/80/0T : STOZ/90/OT : STOZ/b0/OT : STOZ/ZO/OT < STOZ/0£/60 I - STOZ/8Z/60 STOZ/9Z/60 STOZ/tiZ/60 - STOZ/ZZ/60 - STOZ/OZ/60 STOZ/81/60 g STOZ/9T/60 3 STOZ/bT/60 I• - STOZ/ZT/60 I STOZ/OT/60 - STOZ/80/60 - STOZ/90/60 - STOZ/b0/60 STOZ/Z0/60 0 0 0 0 0 0 0 0 0 0 0 0 Ln o Lr, o Ln o Ln o Ln L ,Y V c (-,i N N .--I c-1 a.1nssaad e e Image Project Well History File Cover Page XHVlE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J. Q If-- 0 ~ <ß Well History File Identifier Page Count from Scanned File: 1<) (P (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES ~ Date7!17/ob If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) D Two-sided ""1111111111 II III R~CAN ...ø Color Items: D Greyscale Items: DIGITAL DATA ~kettes, No.3 D Other, Norrype: D Poor Quality Originals: D Other: NOTES: BY: ~ Date 7/17/OÞ Date 7/'7/{)~ ~ x 30 = 10 0 Date? /'7/06 Project Proofing BY: ~ Scanning Preparation BY: ~ Production Scanning Stage 1 BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: D Rescan Needed 1111111111111111111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: V\1f 151 III 111111111111111I W\~ 151 + as = TOTAL PAGES 8' S (Count does not include cover sheet) IAAJn 151 r r V r 111/11111111111111I NO 151 vvvf NO 151 11I11111111I111111I 111111111111111111I 151 Quality Checked 11I1111111111111111 10/6/2005 Well History File Cover Page.doc .. :, ... ..: r_ .w rR .u<.:✓ A ..a .^i, ;ln.S`.C.^"f Zei' ».,. '+ 16 ?aPSna": M'a.; =trc w: t ems ^. .. v"tWW TM.. _ as ..S.+r F' • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 m a-- Mr. Tom Maunder, F rye'= Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPC -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPC -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, t yetis) FEB 2, 2 ZO Mehreen Vazir BPXA, Well Integrity Coordinator M ` .. • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPC -Pad 10/9/2011 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 MPC-01 1811430 50029206630000 Sealed conductor NA NA NA NA NA MPC-02 1821940 50029208660000 Sealed conductor NA NA NA NA NA MPC-03 1820500 50029207860000 Sealed conductor NA NA NA NA NA MPC-04 1821260 50029208010000 Sealed conductor NA NA NA NA NA MPC -05A 1842430 50029212440100 Tanko conductor NA NA NA NA NA MPC-06 1842410 50029212570000 Tanko conductor NA NA NA NA NA MPC-07 1850020 50029212660000 Tanko conductor NA NA NA NA NA MPC -08 1850140 50029212770000 Tanko w/o top NA NA NA 3.4 10/9/2011 MPC -09 1850360 50029212990000 Tanko conductor NA NA NA NA NA MPC -10 1850150 50029212780000 Tanko conductor NA NA NA NA NA MPC -11 1850590 50029213210000 Tanko conductor NA NA NA NA NA MPC -12A 1990910 50029213730100 Tanko conductor NA NA NA NA NA MPC-13 1850670 50029213280000 Tanko conductor NA NA NA NA NA MPC -14 1850880 50029213440000 1.8 NA 1.8 NA 5.1 8/31/2011 MPC-15 1851030 50029213580000 Sealed conductor - NA NA NA NA NA MPC-16 1851100 50029213640000 Sealed conductor NA NA NA NA NA MPC-17 1852630 50029214730000 Tanko conductor NA NA NA NA NA MPC-18 1852690 50029214790000 Abandoned NA NA NA NA NA MPC-19 1852960 50029215040000 Tanko conductor NA NA NA NA NA MPC-20 1890150 50029219140000 Tanko conductor NA NA NA NA NA MPC-21 1940800 50029224860000 4.6 NA 4.6 NA 8.5 8/29/2011 MPC -22A 1951980 50029224890100 38 NA Need top job MPC -23 1960160 50029226430000 1.9 NA 1.9 NA 17.0 8/28/2011 MPC -24 2010940 50029230200000 1.6 NA 1.6 NA 20.4 8/28/2011 MPC -25A 1960210 50029226380100 1.7 NA 1.7 NA 17.0 8/28/2011 MPC-26 1952060 50029226340000 1.8 NA 1.8 NA 17.0 8/28/2011 MPC -28A 2051630 50029226480100 1.6 NA 1.6 NA 10.2 8/29/2011 MPC-36 1980010 50029228530000 4.5 NA 4.5 NA 45.9 8/29/2011 MPC-39 1972480 50029228490000 5.5 NA 5.5 NA 49.3 8/29/2011 MPC-40 2002130 50029228710000 0.75 NA 0.75 NA 5.1 8/29/2011 MPC-41 2010780 50029230140000 0.5 NA 0.5 NA 8.5 8/31/2011 -IIP MPC-42 2040280 50029231960000 1.5 NA 1.5 NA 13.6 8/30/2011 MPC-43 2040390 50029232000000 3.3 NA 3.3 NA 30.6 8/30/2011 WELL LOG � is TRANSMITTAL PROACTIVE DIAgNOSTic SERViCES, Wc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE: Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / M The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2 -1 900 Benson Blvd. U -10 aOC4- Go �a' C9 03G 9 Anchorage, Alaska 99508 and n ProActive Diagnostic Services, Inc. (� T Attn: Robert A. Richey 130 West International Airport Road Suite C NTT 5 MU, Anchorage, AK 99518 Fax: (907) 245-8952 1) Injection Profile 1 O-Sep -10 MPU E -03 BL / EDE 50-029 - 21916 -00 2) Inject Profile 1 2 - A ug - 1 0 MPU C - 42 BL/ EDE 'q Signed: Date Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD Su 1TE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -88952 E- NIAIL : pdsanchoraae(&_memorvlog.com WEBSITE : www.memoryl®g.com C:\Documents and SettingsTme Williams \Desktop \TrwmTdt_HP.docx STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ Other ~ Pertormed: Alter Casing ~ Pull Tubing ~ Pertorate New Pool ~ Waiver~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Suspended Well ~ 2. Operator BP Exploration (Aiaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory ~ ~. 204-0280 3. Address: P.O. Box 196612 Stratigraphic^ Service Q 6. API Number: Anchorage,AK 99519-6612 \ 50-029-23196-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ~ ADLO-047434 ~~""~ MPC-42 10. Field/Pool(s): ~ MILNE POINT UNIT FIELD / KUPARUK RIVER OIL POOL 11. Present Well Condition Summary: Total Depth measured ~' 8985 feet Plugs (measured) None feet true vertical `~ 7496.01 feet Junk (measured) None feet Effective Depth measured 8918 feet Packer (measured) 8065 8101 8133 true vertical 7429.5 feet (true vertical) 6598 6631 6669 Casing Length Size MD TVD Burst Collapse Structural Conductor 112 20" 91.5# H-40 34 - 112 34 - 112 14920 470 Surface 5806 10-3/4" 45.5# L-80 35 - 5808 35 - 4980 5210 2480 Intermediate Production 8252 7-5/8" 29.7# L-80 32 - 8252 32 - 6776 6890 4760 Liner 891 3-1/2" 9.2# L-80 8094 - 8985 6625 - 7496 10160 10530 Liner 458 5-1/2" 17# L-80 8126 - 8584 6655 - 7100 7740 6280 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 . ..-....M .~.... 30 - 8104 30 - 6631 Packers and SSSV (type, measured and true vertical depth) . 4-1/2" Baker S-3 Hvdro Set Packer 8065 .e-- TPK~ 7'"~ 6598 5-1/2" Baker ZXP Hvdro Set Packer 8101 6631 5-1/2" Baker ZXP Hvdro Set Packer 8133 6661 ~~~f.., ~~~R,./ 12. Stimulation or cement squeeze summary: ~~ ~ ,,; ~ t~ ~ r ~ $ z~~4 Intervals treated (measured): ~i~sk~ ~it ~ Gas ~Q~~ ~~mmis i Treatment descriptions including volumes used and final pressure: a s an AfIChOf~~@ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1282 2293 Subsequent to operation: 1966 5161 14. Attachments: 5'C,~. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development [] Service Q Daily Report of Well Operations X 16. Well Status after work: Oil Gas WDSPL GSTOR ^ ~WAG Q GINJ ^ WINJ ^ 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: 309-323 Contact Gary Preble Printed Name Gary Pre e Title Data Management Engineer Signature Phone 564-4944 Date 10/8/2009 Form 10-40~Revised 7/2009 ~~~~s ~ ~ l~fi ~~ ~ Submit Original Only ~o'~ . O`'j M PC-42 204-028 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPC-42 6/16/04 PER 8,736. 8,746. 7,249.35 7,259.21 MPC-42 9/30/09 APF 8,590. 8,600. 7,105.79 7,115.6 MPC-42 9/30/09 APF 8,768. 8,784. 7,280.93 7,296.73 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED 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 n -..J ~ ~ MPC-42 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 5 METH 40 60/40 METH 1 DIESEL 46 TOTAL • • t -~~ ~ , ~ az ~ ,~ _- c ~ Y ~ ~ ~ `~` f ~ ~ ~ ~ ~` ~"' 9' , E x ~ ~ . ~~ . ,,p ~ ~ a 9 ~ ~' ~~ f C ~ ~~ ~ ~~ ,~~~ ~~~ ~.~ ~., g f G ~ ~,- t ~,_ P ~ ~ n ~ ~ ~ ~ ~ ~ ~, ~ , ~°~ ~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~" ~~ ~ ~. ~ ~~ ~ ~`~~ ~ ~ ~ ~ ~ ~ SEAN PARNELL, GOVERNOR ~ ~ ~ ~ ~~~ ~~~ ~~ , ~ ~~i ~ ~..s ~~ ~.TN ~!~ .~ ~ ~: a.~"~.~ ~~ ~~'~ , :~~-~ ~ ~ ~*~~~~+ ~ ~L[~S~ ~IL ~ 1T1~-7 f~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOrIT CODiDIIS5I0I~i ~` ANCHORAGE,ALASKA 99501-3539 ~S' PHONE (907) 279-1433 ~ FAX (907) 276-7542 Ms. Katie Nitzberg Staff Geologist BP Exploration (Alaska), Inc. P.O. Box 196612 r. ~ ~,~ Anchorage, AK 99519-6612 ~. ~ ~'~` Re: Milne Point Unit Field, Kuparuk River Oil Pool, MPC-42 Sundry Number: 309-323 Dear Ms. Nitzberg: a`' - ~ ~ ~ ~ ~ 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair S~ DATED r.~iis Z~day of September 2009 Encl. STATE OF ALASKA ~ ALA~IL AND GAS CONSERVATION COMMIS~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~ ~p, a.. ¢ ^~ , ;r,~;; ,_ ._ ~ ~ ~ ~.'.~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^~ ' Re-enter Suspended Weli [~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Other ^ Specify: Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Time Extension ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ~ Exploratory ~ 204-0280 • 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~~ 6. API Number: Anchorage, AK 99519-6612 50-029-23196-00-00 . 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: /~ ~ G ,n"-~ %~' S i E ti R i ^ ~ % MPC-42 ~ pac ng xcep on equ red? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): ~~ ~ ~h ~~~, ~q ADLO-047434 - Milne Point Unit Field / Kuparuk River~ Pool ~ ~ ~• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8985 ~ 7496.01 ~ 8918 7429.5 NONE NONE Casing Length Size MD ND Burst Collapse Structural Conductor 112 20" 91.5 # H-40 34 112 34 112 1490 470 Surface 5808 10-3/4" 45.5# L-80 35 5808 35 4980 5210 2480 Intermediate Production 8252 7-5/8" 29.7# L-80 32 8252 32 6776 6890 4790 Liner 891 3-1/2" 9.2# L-80 8094 8985 6625 7496 10160 10530 Liner 458 5-1/2" 17# L-80 8126 8584 6655 7100 7740 6280 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8736 - 8746 7249.35 - 7259.21 4-1/2" 12.6# L-80 30 - 8104 Packers and SSSV Tvne: 4-1/2" Baker S-3 Hvdro Set Packer Packers and SSSV MD and ND (ft): 8065 6598 5-1/2" Baker ZXP Hvdro Set Packer 8101 6631 5-1/2" Baker ZXP Hvdro Set Packer 8133 6661 12. Attachments: Description Summary of Proposal Q 13. Weii Class after proposed work: Detailed Operations Program ^ BOP Sketch ~ Exploratory ^ Development ^ Service ^~ - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/19/2009 Oil ^ Gas ^ WDSPL ^ Plugged ^ 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 C. Ryan Rupert Printed Name Katie Nitrberg Title Staff Geologist Signature Phone Date ~ ~ -~~ --~" 564-4531 9/10/2009 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Conditions of a roval: Notif Commission so that a t ti it S d N b /~' ~~ ~v ~ pp y represen ve may w a ness un ry um er: ., Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: /o - Y APPROVED BY Approved by: COMMISSIONER THE COMMISSION / ~ Date: ~ ~ Form 10-403 Revised 07/2009 . .~~~~~ ~// ~'~ j:.~~~ ~=~~ < ~" ~ crt_t i~ >; ~QO~ ~'_/S •~g ~! G~,y,,,~ ,~f ~~iGENAL - , ro Subr~itah Dup1i~ate ~ LJ To: Rob Handy/Lee Hulme MPU Wells Ops Coordinator From: C. Ryan Rupert / Katie Nitzberg MPC Pad engineer / MPU LOT Geologist Subject: MPC-42 ADD PERF AFE: MKCPDWL42 Date: September 8t", 2009 Cost: $60,000 IOR: 100 1 S D&T with 2-1/2" dumm un 2 E Perforate 8768' - 8784' and 8590' - 8600' MD Well Detail Current Status: Operable Online WAG Injector Max Inclination: 50° at 6794' MD, ~12-7° through perfing interval Max Dog Leg: 5.8 at 5168'MD Minimum ID: 2.992" from 8094-8985" MD (3-i/2" liner) Last TD tag: 8844' MD on 8/18/08 Latest H2S value: None taken. Highest in block = 3.9 ppm in Feb 2001 BHP: 4885 psi on o3/03/0~ (22 days SI) converted to ~ooo' SS Obiective The objective of this job is to add perfs to the MPC-42. The well is currently only perf d, in the A3 sands. The A2 and C sands are unperf d, and likely still have formation damage from drilling Well Historv This well was originally drilled as an A2 + A3 sand injector. The cement job on the 3- i/2" liner was bad and showed NO cement below 84i5' MD on the CBL ran 5/1/04. Due to the poor cement job, the decision was made to perf ONLY the A3 on 6/i6/2oo4. The A3 was perfd from 8736'-8746' MD. The log was tied into the 5/1/04 Schlumberger SCMT bond log (primary depth control log). Although there is no cement isolation behind pipe, and injection water seems to be , exposed to the A2 sand, due to formation damage from drilling, the A2 and C are / thought to be taking little to no injection water. The ~/26/04 water flow log confirmed most of the flow was going into the A3 sand. Although some flow might be going into the A2 sands, after analogue analysis, the volume of water into the A2 sand seems ' -a • ~ atypically low. The well is one of the most valuable MPC pad injectors, and supports a 40o BOPD offset GL well. Significant reserves are present in the A2 and C sands in this block. Critical Issues The TD tag on 8/18/09 noted 98' of rathole, but found a`sticky bottom', please be advised. If part of the perf interval is inaccessible, please perf as much as possible. If unable to perf deeper than 8~~8' MD, please abort perfing operations. Tie in all perforating to the Schlumberger SCMT bond log (Primary Depth Control) run on 5/~/2004. The well injected gas from 1/2/09 to 8/20/09 and has been on water injection since. The well is not scheduled to go on gas injection ti112o10. Slickline 1. SI Well. MIRU SL. 2. RIH with gauge ring and tag XN-profile at 8091'MD (3.725 no-go ID). Use this depth to make subsequent depth correction. POOH. 3. Drift and Tag TD w/ 2-1/2" dummy perf gun. Bottom proposed ADPERF is 8784' MD. Obtain sample if obstruction/fill encountered. 4. RDMO SL. E-Line ADPERF ( 16' and 10') 1. MIRU EL. 2. Add 16' of perfs per the attached perforating procedure with 2-1/2" HSD Power Jet 2506 HMX (6 SPF, 60 deg phasing). ~ c~ a~ ,, v,~,.~.:;~,a Proposed Add Perfs ~ .~ 2--~ °~ • 8768' - 8784' M D ~''~ 9' .~"~`~/ Reference Loq: Schlumberger SCMT bond log (Primary Depth Control) run on 5/~/2004 3. Add 10' of perfs per the attached perforating procedure with 2-1/2"" HSD Power Jet 2506 HMX (2 spf, 60 deg phasing). Pro osed Add Perfs 2of5 ~ ~ , :~ ~ ' ~ ~ ~-`~ =5 ~ • 8590' - 8600' MD . ~~ ~ ,,~~~`~ Reference Loq: Schlumberger SCMT bond log (Primary Depth Control) run on 5/~/2004 4. RDMO E-Line and return to injection service at 1500 BWPD Please contact Ryan Rupert 564-5557 (w); 301-1736 (c) with any questions, comments, or concerns. 3of5 5'Iz µ ~ 58,~, t a° ~ 4ors ! , ~ z . ~ ~ Tree= CIW 4 1118" 5M Wellhead 11• z 11• 5M FMC Gen 5 11' ~M x 4 1l18' 5M adap~Eer 4.5" TC~ threads ~op 8 Blm 4" CMIf-H 8PV profile. 20' 9t.tif ppf.l+4o B7C '124' ~a~s es ctine~tao i,~oz~ 7u.75'. A5.5 ppf. ~~D BYe. 5.R07' Kt~ ~ a5o' M~x. hoie ang~e = 49 deg. H~ ~gie Hwu' perfs = 10 deg. M P U C-42 i ~~- DF Elev. = 50.4D' (Doya- 141 } Orig_GL Elev. =18.90' {Doyon 941 } 3.5' 92 #!R , L-SO . 5T-L ~ drift id = 2.992' , cap. = 0.0~87 bpf ) 4.5' 126 #lft . L-SD , IBT-mod. ~ driftid=3.958".cap=0.D125bpf} 5.5' 17. #fft . L-8D , ST-L { drift id = 5.19D" , cep = 0.0282 6pF ) 7.$25" 29.7 #1ft . L-80. 6to-ma~d cas~g ( driR id = 8.875', c:~p. = 0.045~ bpf ) 10.75' 45_5 #/R . L-8D , Btc I ( driR id = 8.950' . cap. = 0.0982 6pF 1 Baker l..~er tie-back siv. 8,125' Baker ZXP plv. w! H1NC hanger 8,133" 7-518', 29_7# L-80 b6c shce 8,Z57 5.5' 17_ #tR . L~0 , ST-l He5 super seal FfoeR stwe Perfaration Summary R~F Iog: StiE SAF IRkrvil (7VD) 25' 2 8.736' - 8.749" 7.248" - 7~58' 4_5' HES X-Nipple ( 3.813') 2.p23- 4.5' Baker CMD Sliding sleev+e (3.813"bore) 4.5" HES X~pple 8,054' 7-5J8' Baker Premier packer 8.D85' 4.5" XN-I~ipple [ 3.813' 6are ) $.091 ` € 3.7~i' rto-ga ) wt.EG 8.1 @4' 7-6/8"x ~.5' Baker Liner tie-beck 8.DB4' Baker ZXP finer pfv_ rr/ G2 6.101' 7-5l8"z 5.5 flex Ixk han8er 8,1 DB' 3.5' 9.2 #~ft , l-B~ . 5T-L 3.5 Baloer STL Fanding cdlar ~•I u~ ~~ I 3.5' TiW Typ~L Lai~h collx g.ggp• 3.5' TIW 11oat shoe w! Al~minum noF~e 8,805' [u-~€ ev. sr ~~B+T~ MILNE PUIHT UNIT ~~ MQO Drilled end cart~slebed Dayan 14 yyELL G~21 API MO: 50-029-23196-00 BP EXPLORATION 5 of 5 ' ~ ~ ~ • ~ PERFORATING PROCEDURE Var4006,~~~, ~ .....~...~ Well: MPC-42i API #: 50-029-23196-00 ............................................................... g ............y..............P................. Date: 09/03/2009 Prod En r C. R an Ru.ert Office Ph: 564.5557 H2S Level: ........................... ......................... . ........................................................ ................................................................ Home Ph: 3.9 ppm ........................................................ Cell: 301.1736 ........................................................ CC or AFC: MKCPDWL42 Detail Code: ............................................................... ......................................................................................................................... Description: Drift to TD with Dummy.Gun:,Add.Perfs ............................... . . . ..................................................................................................... WBL Entries 1 S D&T with 2-1/2" Dummy Gun ~2~ E Pertorate 8768' - 8784' and 8590' - 8600' MD Well Obiectives and Loaqinq Notes: For the a detailed NS well history, please see MPC-42i ADPERF program currently on the WBL. The objective of the slickline portion of this procedure is to evaluate the extent of any restriction that might exist and ensure the guns can make it to target depths. Reference Log Tie in Log ##### ................... feet Log: .SCMT .SCMT #REF! tie-in log to be on Date: 5/1/2004 ............................. 5/1/2004 .............................. depth with the reference log. Company: .Schlumber. Schlumber. .............................. Depths (from-to) Depths (from-to) Feet SPF Orient. Phasing Zone Ad/Re/Iperf 8,784' 8,768' ' 8,768' 8,784' 16' 6 6~~ Random 0 -cuP A2 Add .................................................................... ...... ....... ...... ....... .......8,590' 8,600' ..... ....... ....... ...... ..... .... ......... ........ . .....8,590' ....... .......8,600'...... .....1.0'.... ........2........ . ..... ..... . .Random. .....60°..... ................... KUP C Add Gas Jetting Expected? .No At what Depth? .N/A ............. ...... Requested Gun Size: 2.5" HSD Charge: Power Jet 2506, HMX ......................... Desired Penetration: Entry Hole Diam: ,0.32" Is Drawdown Necessary/Desired/Unnecessary During Perforating Unnecessar~r.:,Do, not flow well durin~ perforatin~ . .......................... ..... ... . .... Describe below how to achieve drawdown (check w/ Pad Operator to see if necessary piping is installed) (e.g. N2 Lift, Hardline Lift Gas, Gas Litt, Flow Well, Backflow Through Drain or Hardline) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . Tie in to Jewelry @ n/a MD Tie in using: Schlumber~er.SCMT Lo~,run.on,5/1/04 ............................................................................ Minimum ID: . in Min ID Type: 2:992 . . ................3:1/2...Liner................ C~ 8094-TD'MD ..................... Taii Depth: ........ ........ 8,104 ft MD Casing Size: 3.5 in 9.2# L-80 . Est Res. Pres. @ , MD 7000' SS 4,585 psi .......................... ................... ............................... Last Tag: .8:844 ft ELMD on 8/18/2008 ............................... Well: MPC-42i --------------- Perforation Summary Date: ............................. API #: 50-02~23196-00 . ........................................................... On-Site Prod Engr: ............................................................. PBTD General Comments: O/B/U - O .............................. ............................... ............................... .................. ..................... .......................... ~ ~ Ramirez, Darlene V (DOA) From: Foerster, Catherine P (DOA) Sent: Sunday, September 20, 2009 1:40 PM To: Ramirez, Darlene V (DOA) Subject: Re: 309-323 Approve Sent from my iPhone On Sep 18, 2009, at 10:31 AM, "Ramirez, Darlene V(DOA)" <darlene.ramirezC~alaska.gov > wrote: > «S45C-209Q91809Q21.pdf» > The message is ready to be sent with the following file or link > attachments: > > S45C-209091$09021.pdf > > > Note: To protect against computer viruses, e-mail programs may > prevent sending or receiving certain types of file attachments. > Check your e-mail security settings to determine how attachments are > handled. > <S45C-209091809021.pdf> 1VIEld~®iZAl®1DL71VI To: Jim Regg ~ '~ , ~~ i ~ C~`o P.I. Supervisor '~ ~ ~ t FROM: Chuck Scheve Petroleum Inspector State ®f Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 23, 2008 SUBJECT: Mechanical Inteb ity Tests BP EXPLORATION (ALASKA) INC C-42 MILNE PT UNIT KR C-42 Src: Inspector NON-CONFIDENTIAL Reviewed By: --~ , P.I. Suprv Comm Well Name' MILNE PT UNIT KR C-42 Insp Num: mitCS080721063002 Rel Insp Num: API Well Number 50-02 9-2 3 1 96-00-00 Permit Number: 204-028-0 Inspector Name• Chuck Scheve Inspection Date: x/18/loos Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well C-42 Type Inj. ~' TVD 6s9a IA Isoo zsoo za7o 247o i P.T. 2oao2so TypeTest SPT Test psi I6a9.s pA ~~s sso ' sso sso Interval 4YRTST p~ P '~ Tubing 1950 I9so I9so 1950 Notes: ~~a.~N1~E6~ AU G ~ ~ 2008 Wednesday, July 23, 2008 Page I of 1 Recent MITIAs for MPC-42 (PTD #2040280) Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIllntegrityEngineer@BP.com) Sent: Thursday, July 10, 2008 2:53 PM ~~~' ~l ~`~' ~ ~' To: Regg, James B (DOA); Maunder, Thomas E (DOA}; Fleckenstein, Robert J (DOA) Cc: NSU, ADW Well Integrity Engineer; MPU, Wells Ops Coord; MPU, Wells Ops Coord2; MPU, IM Field Coordinator; MPU, IM Facility Coordinator Subject: Recent MITIAs for MPC-42 (PTD #2040280) Attachments: MIT MPU C-42 07-05-08.x1s Hi Jim, Tom, and Bob, Please find the attached MIT forms for MPC-42 (PTD #2040280). Well MPC-42 was shut-in for the Milne Point plant shut down in late June. Therefore the plant was not able to place the well on injection for UIC testing. This test was completed and passed. The plan is to return the well to injection, notify the AOGCC inspector, and repeat the MITIA. MPC-42: 4-yr UIC Compliance MIT-IA «MIT MPU C-42 07-05-08.x1s» Please let us know if you have any questions. Thank you, Anna ~u6e, ~? E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~NN~D JUL 2 ~ 2008 7/10/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc Milne Point /MPU / C-Pad 07/05/08 Mel Iveson ~~~~ 7/,~~~~ Packer Dep Pretest Initial 15 Min. 30 Min. Well MPC-42 Type Inj. N TVD 6,598' Tubing 1,000 1,000 1,000 1,000 Interval 4 P.T.D. 2040280 Type test P Test psi 1650 Casing ''2,000 1,960 1,950 P/F P -~ Notes: 4-Year UIC MITIA due but well is shut-in. This MITIA OA 150 300 300 300 was conducted for UIC compliance. Plan to return well to injection and conduct AOGCC witnessed test. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential. Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 2008-0705 MIT MPU C-42.x1s • • -~~ .~ - MICROFILMED 03/0112008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE o- `.. ~. F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc ~ /~ J~~ DATA SUBMITTAL COMPLIANCE REPORT 7/3/2006 J~.L ~~~'1 Permit to Drill 2040280 Well Name/No. MILNE PT UNIT KR C-42 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23196-00-00 MD 8985 ./ TVD 7496 ,- Completion Date 6/16/2004 r Completion Status 1WINJ Current Status 1WINJ êUlc~ REQUIRED INFORMATION Directional surve& ~ Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, IFR\CASANDRA, PWD, GYRO, DIR (data taken from Logs Portion of Master Well Data Maint Well Log Information: . Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~D 0 Asc Directional Survey 0 727 Open 4/23/2004 GYRO "'Rpt Directional Survey 0 727 Open 4/23/2004 GYRO ~D 0 Asc Directional Survey 727 89850 Open 4/23/2004 IIFR ~Pt Directional Survey 727 8985 Open 4/23/2004 IIFR &to 0 Asc Directional Survey 727 8985 Open 4/23/2004 MWD ~Pt Directional Survey 737 8985 4/23/2004 MWD ,.....-ED C Lis 12724 Cement Evaluation 0 8864 Case 9/22/2004 SLIM CEMENT MAPPING TOOL BOND LOG/PRIMARY DEPTH CONTROL LOG 01 May, 2004 Plus Graphics rED 0 Lis 12767 Induction/Resistivity 170 8991 Open 9/14/2004 GRlEWR4 ROP PWD Y 12767 LIS Verification 170 8991 Open 9/14/2004 GRlEWR4 ROP PWD . )2Ð C Lis 12973 Reservoir Saturation 8200 8865 Case 3/16/2005 RST SIGMA-BORAX LOG WITEMP & PRES RST-C, PBMS-A 7 Aug, 2004 "E15 C Lis 12974 Reservoir Saturation 8000 8862 Case 3/16/2005 RST SIGMA-BORAX LOG RST-C, PBMS-A PBMS-A 26 July, 2004 J.og Cement Evaluation 5 Col 0 8864 2/28/2005 slim mapping tool bond log/primary depth control log ,.&j C Lis 13533 Induction/Resistivity 112 8985 Open 2/22/2006 ROP DGR EWR plus Graphics Permit to Drill 2040280 MD 8985 TVD ßog-- I I '"' . _ ... 1297' Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? ~ Chips Received? ~ Analysis ~ Received? DATA SUBMITTAL COMPLIANCE REPORT 7/3/2006 Well Name/No. MILNE PT UNIT KR C-42 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23196-00-00 UIC Y ~---~I RST Sigma-Borax Log \ RST-C, PBMS-A 07 Aug, 2004 I RST SIGMA-BORAX LOG . RST-C, PBMS-A PBMS-A I 26 July, 2004 . Comments: --~-- 7496 Completion Date 6/16/2004 Current Status 1WINJ 8865 Case Completion Status 5 Blu 8200 1WINJ Reservoir Saturation Reservoir Saturation 5 Col 8000 8862 Case 3/16/2005 Interval Start Stop Sample Set Number Comments Sent Received Daily History Received? ~ Formation Tops Compliance Reviewed By: - . / f. · --~) Date: 3J\J ~ )~~ \0 . (Y .; . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 f 36:J3 RE: MWD FOl111ation Evaluation Logs MPC-42, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPC-42: LAS Data & Digital Log Images: 50-029-23196-00 D\ c, dc4··D~~ 1 CD Rom Mêtn ~\90 \Dlo Schlumberger Schlumberger-DCS 2525 Gambell S~ Suite 400 Anchorage, AK 99503·2838 ATTN: Beth . 202-009 /) M'> /1'_ "7 -....... MPS-21 ø<-Vl/ - ~T-MPE-25L1 -? 6'-/ -/1:;2.. - MPG-19 """'- U. ~PB-27 ~ I. - 2-:2L MPE-25A n. /14_ rì'i~'/ MPC-42 .,4(;/ V E.102 Ao1-o2 (/ ;20(- I 'F0 Well 10670013 10687675 10900120 10964102 10703992 10830797 10672379 Job# Log Description MEM CBL CBL SCMT SCMT SCMT SCMT RST 05/03/04 03/30/04 11/25/04 11/30/04 04/18/04 05/01/04 05/01/04 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2·1 900 E Banson Blvd. Anchorage AK 99508-4254 Date Delívered: . ?}f~) 02/22105 NO. 3346 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Milne Point Midnight Sun Date Color BL CD Schlumberger OCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 rL ::~ê4J: IlL t~ - ~ - ó(j; cf- oz. ~ . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn,: Robin Deason 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 13, 2004 RE: MWD FOffilation Evaluation Logs MPC-42, AK-MW-2951136 1 LIS fOffilatted Disc with verification listing. API#: 50-029-23196-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date:r L- /r-()f RFrr:IVED "';1'::[:) I " 0£\0" U L.. LV £1 /~as!{a OllS, Gas Cons. Carom_ Anchorage Rb: MPC-42 . . Subject: RE: MPC-42 From: "Green, Matt D" <GreenMD@BP.com> Date: Man, 26 Jul 2004 10:51 :50 -0800 To: "Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> Tom, d-Ö'-\ - 0 .~\{ Attached is the bond log - as you can see, zero cement. As discussed in previous correspondence, we have had the well on injection for several weeks now and will now shut it in for PNL/Borax and WFL to determine conformance. I will call to discuss. Cheers, Matt. -----Original Message----- From: Thomas Maunder [nailto:tom maunder@admin.state.ak.uil Sent: Friday, July 23, 2004 9:35 AM To: Archey, Pat; Stewman, Sondra D Subject: MPC-42 Pat and Sandra, I have just looked at the 407 for MPC-42. Looks like the operations went well and the precautions of top-set with drilling liner allowed the well to be successfully drilled. Since this is an injection well, I need to conduct a review/verification of the construction. The last piece I need to complete that review is the bond log run on May 1. A hard copy of the bond log may have been submitted, however due to an unfilled position our filing is lagging a bit. Is it possible to forward me an electronic copy of the SCMT log dated May I?? Your assistance will be appreciated. I would also like to have an opportunity to discuss how we might employ a process I use with Alpine to expedite this review process. Thanks. Tom Maunder, PE AOGCC Content-Description: MPC-42i_ SCMT _I-MAY -2004_ PRINT. zip Content-Type: application/x-zip-compressed Content-Encoding: base64 1 of 1 7/26/2004 1 :50 PM .. STATE OF ALASKA _ ALASKA ~ AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil o Gas o Plugged o Abandoned o Suspended }i\ ~~}, 1b. Well Class: 20MC25.105 20MC 25.110 o Development o Exploratory OGINJ .. WINJ o WDSPL No. of Completions One Other .jfi/ /'7 o Stratigraphic 1m Service 2. Operator Name: 5. Date Comp., Su~p., or'Aoand. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6/16/2004 ./ 204-028 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 3/2/2004 '" 50- 029-23196-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: , Surface: 3/15/2004 MPC-42 1231' NSL, 2255' WEL, SEC. 10, T13N, R10E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 5218' NSL, 2741' WEL, SEC. 10, T13N, R10E, UM 50.90' Milne Point Unit / Kuparuk River Sands Total Depth: 9. Plug Back Depth (MD+ TVD) 5247' NSL, 2760' WEL, SEC. 10, T13N, R10E, UM 8918' + 7427' Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 558204 ¡ y- 6029513 ¡ Zone- ASP4 ./ 8985' + 7496' ,¡ Ft ADL 047434 TPI: x- 557680 y- 6033496 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 557661 j y- 6033525 . Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 1m Yes ONo N/A MSL 1800' (Approx.) 21. Logs Run: MWD , GR , RES, IFR\CASANDRA , PWD , GYRO, DIR 2. CASING, LINER AND CEMENTING RECORD CASING ~E'!'tI\$P~PTH Mt)( ;:)E'!'tINGU¡:PTHTV[) ~~~...·...i Ii i ·ii... ................... ........... AMOUNT SIZE WT. PER FT. GRADE TOP. BOTTOM TOp BOTtOM . PULLED 20" 92# H-40 34' 112' 34' 112' 42" 260 sx Arctic Set (Aoorox.) 10-3/4" 45.5# L-80 35' 5808' 35' 4980' 13-1/2" 582 sx Arcticset III, 260 sx Class 'G' 7-5/8" 29.7# L-80 32' 8252' 32' 6776' 9-7/8" 148 sx Class 'G' 5-1/2" 17# L-80 8126' 8584' 6655' 7100' 6-3/4" 101 sx Class 'G' 3-1/2" 9.2# L-80 8094' 8985' 6625' 7496' 4-3/4" 89 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TJBING ....: i Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 2 SPF 5" x 4-1/2" x 12.6#, L-80 8104' 8065' MD TVD MD TVD ./ 125. ,A,ÇID,¡;CAi"T"c"!.'J:;I1(IJ:;" I ETC. ,i ii. 8736' - 8746' 7249' - 7259' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 92 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): June 26, 2004 Water Injection Date of Test Hours Tested PRODUCTION FOR Oll-BSl GAs-McF W A TER-BSl CHOKE SIZE GAS-Oil RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... Oll-Bsl GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". r···~6c·'~,;:-¡::'¡~.·E:·r:'6rT'~~' ORIGINAL I . . ,.,.i None I(J¿~~ 1"- .i2 .. ··.....E··~IED .', .~~9Fl l ~~¡" Re.. _J? c,r Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 2&. GEOLOGIC MARKERS. NAME MD TVD SBF2-NA SBF21 SBF24-MF SBF1-NB SBF12 SBE4-NC SBE41 TSBD-OA TSBB-OB SBA5 TKLB TKUP TKC1 TKUB TKUA TKA3 TKA4 TKA2 TKA1 TMLV 4901' 4912' 4920' 4926' 4946' 4962' 4977' 5100' 5213' 5247' 8190' 8436' 8580' 8595' 8725' 8736' 8736' 8755' 8802' 8835' 4313' 4321' 4328' 4332' 4348' 4361' 4373' 4466' 4555' 4581' 6716' 6955' 7096' 7111' 7239' 7249' 7249' 7268' 7315' 7347' 29. .RMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Post Rig Work Summary and a Leak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Technical Assistant 204-028 Permit No. I 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. ~ MPC-42 Well Number Date Dl-l0 -() ~ Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Walter Quay, 564-4178 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. 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: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Tree: CIW 41/16" 5M . Wellhead: 11" x 11" 5M Gen 5 11" 5M x 4 1/16" 5M adap r 4.5" TCII threads top & Stm 4" CIW-H SPV profile. 20" 91.1# ppf, H-40 BTC ~ 10.75" ES Cementer @ 1,902' _ 10.75",45.5 ppf, L-80 Btre. 5,807' I ~ KOP @ 450' Max. hole angle = 49 deg. Hole angle thru' perfs = 10 deg. 3.5" 9.2 #/ft , L-80 , ST-L ( drift id = 2.992" , cap. = 0.0087 bpf ) 4.5" 12.6 #/ft , L-80 , IBT-mod. ( drift id = 3.958" , cap = 0.0125 bpf) 5.5" 17. #/ft , L-80 , ST-L ( drift id = 5.190" , cap = 0.0262 bpf) 7.625" 29.7 #/ft , L-80, Btc-mod casing ( drift id = 6.875", cap. = 0.0459 bpf ) 10.75" 45.5 #/ft , L-80 , Btc ( drift id = 9.950" , cap. = 0.0962 bpf ) Baker Liner tie-back slv. I 8,125' I Baker ZXP pkr. wI HMC hanger I 8,133' I 7-5/8",29.7# L-80 btc shoe I 8,252' ,r Hes super seal Float shoe I 8,584' I~ Perforation Summary Ref log: Size SPF Interval (TVD) 2.5" 2 8,736' - 8,746' 7,249' - 7,259' MPU C-42i ... Orig. OF .= 50.40' (Doyon 141) Orig.GL = 16.60' (Doyon 141) 4.5" HES X-Nipple (3.813') I 2,023' I 4.5" Baker CMD Sliding sleeve I 8,030' ( 3.813" bore) 4.5" HES X-Nipple 8,054' 7-5/8" Baker Premier packer 8,065' 4.5" XN-Nipple (3.813" bore) 18,091' ( 3.725" no-go) WLEG 8,104' 7 -5/8"x 3.5" Saker Liner tie-back Baker ZXP liner pkr. w/ C-2 .... 7-5/8"x 5.5" flex lock hanger 8,094' 8,101' 8,108' 5.5" 17. #/ft, L-80 , ST-L .. i 3.5" 9.2 #/ft , L-80 , ST-L 3.5" Saker STL landing collar I 8,918' I 3.5" TIW Type-L Latch collar I 8,950' I - 3.5" TIW float shoe w/ Aluminum nose I 8,985' I -# ~ L DATE REV. BY COMMENTS 03/25/04 MOO Drilled and completed Doyon 14 MILNE POINT UNIT WELL C-42i API NO: 50-029-23196-00 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-42 MPC-42 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/1/2004 Rig Release: 3/18/2004 Rig Number: Spud Date: 3/2/2004 End: 3/18/2004 3/1/2004 08:00 - 09:00 1.00 MOB P PRE Skid Rig floor from drlg position to move position 09:00 - 10:00 1.00 MOB P PRE Move rig off well MPG-18 10:00 - 15:00 5.00 MOB P PRE Move rig from MP-G pad to MP-C pad 15:00 - 17:00 2.00 MOB P PRE Move rig over well MPC-42 - Shim rig 17:00 - 18:00 1.00 MOB P PRE Skid rig floor from move position to drlg position 18:00 - 19:30 1.50 RIGU P PRE Rig up floor - Spot rockwasher and berm (Accept rig @ 19:30 hrs 3/1/2004) 19:30 - 22:00 2.50 RIGU P PRE Nipple up Divertor - (RF to LR 34.90' - RF to GL 33.80') - Take on water into pits - Start mixing mud - Spot tiger tank - Set Sperry Sun MWD lab - Set Mud Lab 22:00 - 23:00 1.00 RIGU P PRE Start loading pipe shed with 4" drill pipe 23:00 - 00:00 1.00 RIGU P PRE Nipple up Divertor line 3/2/2004 00:00 - 01 :00 1.00 RIGU P PRE Con't Nipple up Divertor Line 01 :00 - 03:00 2.00 RIGU P PRE PJSM - Change out saver sub on Top drive - Change out grabber dies - Con't loading 4" drill pipe in pipe shed 03:00 - 14:00 11.00 DRILL P SURF Pick up 4" drill pipe from pipe shed - Total 264 jts 88 stds 14:00 - 15:30 1.50 DRILL P SURF Picking up Flex DC and HWDP and stand in derrick 15:30 - 16:00 0.50 DRILL P SURF Making up Bit 13.5 MX-C1 3x15 1 x1 0 16:00 - 16:30 0.50 DRILL P SURF Pre-Spud meeting with crew 16:30 - 17:00 0.50 BOPSUP P SURF Diverter test, the right to witness test was wavier by John Spaulding AOOGC, fill stack and check for leaks 17:00 - 18:00 1.00 DRILL P SURF Di rectional Drill from 112 to 224 18:00 - 20:30 2.50 DRILL P SURF Picking up rest of BHA, Rig up for Gyro 20:30 - 00:00 3.50 DRILL P SURF Directional Drill from 224 to 459 with 400 gals min, 1100 psi, 80 rpms, running Gyro every 100 ft starting @ 200 ft AST 1.08 ART 1.80 3/3/2004 00:00 - 21 :00 21.00 DRILL P SURF Directional Drill from 459 to 2,934 with 80 RPMS, 500 GPM 1900 psi AST 5.38 ART 7.64 ( Run Gyros to 834' ) 21 :00 - 23:30 2.50 DRILL P SURF Circ, three bottoms up with full drill rate 500 gals min. 2040 psi, 80 rpms 23:30 - 00:00 0.50 DRILL P SURF Pumping out with full drilling rate 3/4/2004 00:00 - 01 :30 1.50 DRILL P SURF Pumping out to HWP with full drilling rate, clay balls started coming back about the time we got to HWDP 01 :30 - 03:00 1.50 DRILL P SURF Tripping out with BHA, break off bit 03:00 - 03:30 0.50 DRILL P SURF Pickup new bit, Drop off UBHO sub 03:30 - 04:00 0.50 DRILL P SURF Service Top drive 04:00 - 04:30 0.50 DRILL P SURF RIH Flex Dc's - 1 Stand HWT - Surface test MWD - Test Good 04:30 - 06:00 1.50 DRILL P SURF Change out 5" to 4" Handling Tools - RIH from 728' to 2839' 06:00 - 06:30 0.50 DRILL P SURF Wash from 2839' to 2934' - Slowly stage up pumps to drilling rate to circulate out clay balls to surface - Rotate 80 RPM - TQ 3 K - GPM 450 - PP 1200 psi 06:30 - 00:00 17.50 DRILL P SURF Directional Drill from 2934' to 4831' with 80 RPMS, 500 GPM, 2,720 psi, AST 4.34 ART 7.26 3/5/2004 00:00 - 19:00 19.00 DRILL P SURF Directional Drill from 4,831' to 5816' with 80 RPMS, 500 GPM, 3400 psi AST 7.76 ART 6.89 19:00 - 22:00 3.00 CASE P SURF Circ, Three bottoms up with 500 gals min 2900 psi, 80 rpms 22:00 - 00:00 2.00 CASE P SURF Pumping out, with full drilling rate From 5816 to 3500 3/6/2004 00:00 - 02:30 2.50 CASE P SURF Pumping out, with full drilling rate From 3500 to 721, getting clay balls started @ 1300 ft. 02:30 - 04:30 2.00 CASE P SURF RIH to bottom, Fill pipe ever 20 stands, wash 90 ft. 04:30 - 08:30 4.00 CASE P SURF Circ, Three bottoms up with 80 rpms, 500 gpm, 2950 psi 08:30 - 12:00 3.50 CASE P SURF Pumping out with full drilling rate to HWDP Printed: 3/22/2004 8:46:18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-42 MPC-42 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/1/2004 Rig Release: 3/18/2004 Rig Number: Spud Date: 3/2/2004 End: 3/18/2004 3/6/2004 12:00 - 14:00 2.00 CASE P SURF Stand back HWT - Lay down BHA 14:00 - 14:30 0.50 CASE P SURF Clear rig floor from all vendors tools - 14:30 - 16:00 1.50 CASE P SURF Rig up casing equipment - Load remaining casing in pipe shed 16:00 - 17:00 1.00 CASE P SURF PJSM - Pick up float equipment - make up same - Circulate thru float equipment - Pick up and run 103/4" L-80 45.5# BTC-M casing 17:00 - 23:00 6.00 CASE P SURF Run 103/4" L-80 45.5# BTC-M casing to 5772' - Make up landing joint / Hanger and land casing @ 5808' 23:00 - 23:30 0.50 CASE P SURF Rig down Franks fill up tool - Blow down Top drive - Rig up Schlumberger cementing head and lines 23:30 - 00:00 0.50 CASE P SURF Break circulation - Stage up pump from 4 bpm to 8.5 bpm with no losses - Circulate two casing volumes - condition mud for cement job 3/7/2004 00:00 - 01 :30 1.50 CASE P SURF Circulate 2 Casing volumes - staging pump up from 6 bpm to 8.5 bpm - Circulation pressure 150 psi 01 :30 - 04:00 2.50 CEMT P SURF Switch to Schlumberger - Pump 1 st stage - Pump 20 bbls CW100 @ 5 bpm @ 275 psi - Test lines to 4000 psi - Mix and pump 40 bbls Mud Push spacer mixed at 10 ppg - Drop by pass wiper dart last 5 bbls of spacer @ 8 bpm @ 225 psi - Reload top dart before mixing I pumping cement - Mix and V pump 280 sxs "Artic set lite' - Yield 4.45 cf/sx - 220 bbls mixe~ at 10.7 ppg @ 88.4 bpm @ 650 psi - Mix and pump 260 sxs Class "G" Tail - Yield 1.16 cf/sx 54 bbls of slurry - mixed at 15.8 ppg @ 4 bpm @ 425 psi - Kick out top plug with 30 bbls water with Dowell - Switch to Rig - Displace with 327.5 bbls mud - 75 bbls water - 118 bbls mud - Displacement rate 8 bpm - Slow to 4 bpm last 10 bbls pumped - Bump plug with 1500 psi - Hold for 2 mins - Bleed off pressure - Floats holding - Load Howco Closing plug in cement head - Pressure up on casing open Howco ES Cementer - pressure to open 2400 psi - Cementer opened - Circulate hole clean 04:00 - 06:30 2.50 CEMT P SURF Circ out Thick mud and cement - (20 bbls cement back to surface on 1st Stage cement job) - Suck out rockwasher- Move trucks around for 2nd stage - PJSM 06:30 - 08:30 2.00 CEMT P SURF Switch to Schlumberger - Pump 20 bbls CW100 @ 5 bpm @ 200 psi - Test lines to 4000 psi - Mix and pump 40 bbls Mud Push mixed at 10 ppg - @ 5 bpm @ 200 psi (one gallon dye in first 5 bbls pumped) - Mix and pump 302 sxs "Artie Set Lite" ./ 240 bbls - Yield 4.45 cflsx - mixed at 10.7 ppg @ 8.3 bpm @ 600 psi - Dye to surface - Shut down mixing cement - Drop Top Plug - Schlumberger kick out plug with 30 bbls water - Switch to rig displace with mud - Pump 140 bbls @ 5 bpm @ 290 psi- Last 10 bbls slowed rate down to 3 bpm @ 250 psi - Bump plug - increase psi to 1180 - ES Cementer closed - increased pressure to 1400 psi - Held for 2 mins - Release pressure - No Flow back - ES Cementer closed and holding - CI P 08: 1 0 hrs. ( 48 bbls contaminated cement and 50 bbls good cement back to surface) 08:30 - 10:30 2.00 CASE P SURF Flush Diverter - Back out - Lay down landing joint - Flush flowline 10:30 - 11 :00 0.50 CASE P SURF Lay down casing tools - 11 :00 - 12:00 1.00 CASE P SURF Nipple down riser - diverter system Printed: 3/22/2004 8:46: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-42 MPC-42 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/1/2004 Rig Release: 3/18/2004 Rig Number: Spud Date: 3/2/2004 End: 3/18/2004 3/7/2004 12:00 - 13:00 1.00 CASE P SURF MU Speed head test seal to 1000 psi for 10 min. 13:00 - 15:00 2.00 CASE P SURF Nipple up BOPS 15:00 - 16:00 1.00 CASE P SURF Change out Bails and clear rig floor 16:00 - 20:00 4.00 BOPSUP P SURF Install test plug, test BOPS and Manifold 250-4,000 psi 5 min. per test, test hydril 250-2500 psi 5 min. per test, the right to witness bop test was waiver by Chuck Scheve AOOGC, install wear ring 20:00 - 22:00 2.00 CASE P SURF Pick up BHA#3 MXCX! with 3-16 1-12 jets, 7" Sperry drill with 1.22 bend, stab, float sub,Gamma/Res/PWD/HCIM,Dir Hoc,TM Hoc,stab,3 flex dC,stab,12 HWDP,Jars,5 HWDP 22:00 - 22:30 0.50 CASE P SURF Tripping in to 1,901 22:30 - 23:00 0.50 CASE P SURF Drill out ES-Cementer with 400 gals min. 1120 psi,40 rpms, 5K bit wt. 23:00 - 00:00 1.00 CASE P SURF Tripping in , pushing part of cement plug in front of bit to 2,836' 3/8/2004 00:00 - 01 :00 1.00 CASE P SURF Tripping in from 2,835', to 5,620' pushing parts of rubber plug in front of bit 01 :00 - 01 :30 0.50 CASE P SURF Circ. and wash to 5,680' acts like may have some rubber beside bit 01 :30 - 03:00 1.50 CASE P SURF Slip and cut Drilling line 03:00 - 04:00 1.00 CASE P SURF Testing csg to 2500 psi for 30 min., good test 04:00 - 05:00 1.00 DRILL P SURF Drill landing collar @ 5,720' 50 RPM @ 9K torque - 424 GPM @ 2250 05:00 - 06:30 1.50 DRILL P SURF Circ. out containamented mud - @ reduced rate - slowly stage pumps up to 424 gpm 06:30 - 07:30 1.00 DRILL P SURF Drill shoe track with 50 rpm @ 8K torque 424 gpm @ 1950 psi Drill 20' new hole to 5836' 07:30 - 09:00 1.50 DRILL P INT1 Displace hole with 9 ppg LSND - Rotate and reciprocate - @ 50 RPM @ 8K torque 09:00 - 10:00 1.00 DRILL P INT1 Perform FIT - MD 5808' TVD 4985' - Mud weight 9 ppg - Surface pressure 520 psi = 11.01 EMW ~ 10:00 - 10:30 0.50 DRILL P INT1 Calibrate Epoch Depth Tracking Sensors 10:30 - 00:00 13.50 DRILL P INT1 Drill from 5836' to 7,151' with 100 rpms, 600 gpms, 3600 psi, (started raising mud wt slow @ 7,000') ECD 10.0, AST 1.36 ART 7.77 3/9/2004 00:00 - 08:00 8.00 DRILL P INT1 Drill from 7,151' to 7660' with 100 rpms, 600 gpms, 3950 psi, @ 7350' cut flow rate back to 550 gals per min due to pump pressure ECD 10.3, AST 5.74, ART 5.95 08:00 - 08:30 0.50 DRILL P INT1 Clean pump suction screens, increase pulsation damper pressure to 1200 psi for MWD detection 08:30 - 16:00 7.50 DRILL P INT1 Drill 7,660' to 8,015' with 100 rpms, 520 gpms, 3970 psi 16:00 - 19:00 3.00 DRILL P INT1 Circ., Three bottoms up with 110 rpms 550 gpms 3900 psi 19:00 - 21 :00 2.00 DRILL P INT1 Pumping out to csg. shoe @ 5,800' with full drilling rate, 25,000 # drag when bit come in to CSG 21 :00 - 21 :30 0.50 DRILL P JNT1 Flow check,slug pipe, check trip tank, Blow down top drive 21 :30 - 23:00 1.50 DRILL P INT1 Tripping out to HWDP 23:00 - 00:00 1.00 DRILL P INT1 Stand back BHA, Break off bit 3/10/2004 00:00 - 00:30 0.50 DRILL P INT1 Down load MWD tool 00:30 - 02:00 1.50 DRILL P INT1 C/O MWD Pulsor,Mud Motor, M/U mud motor, XR-VC bit WI 3-181/12 jets, Set angle on motor, Orient motor and MWD 02:00 - 02:30 0.50 DRILL P INT1 Up load MWD tool 02:30 - 03:30 1.00 DRILL P INT1 Trip in with Bha #4 Bit, 7" sperrydrill motor w/ 1.22 bend,stab,float sub,Gramma/res/PWD/HCIM, Dir HOC, TM hoc, stab,3 flex dc, 12 HWDP, jars, 5 HWDP, Test MWD Printed: 3/22/2004 8:46: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-42 MPC-42 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/1/2004 Rig Release: 3/18/2004 Rig Number: Spud Date: 3/2/2004 End: 3/18/2004 3/10/2004 03:30 - 04:00 0.50 DRILL P INT1 Service rig and topdrive 04:00 - 07:00 3.00 DRILL P INT1 Tripping in, filling pipe every 20 stands, wash 90 ft to bottom 07:00 - 12:30 5.50 DRILL P INT1 Drill 8015' to 8,232' with 550 gals min. 3600 psi 100 rpms 12:30 - 15:30 3.00 DRILL P INT1 Mad pass 8210 to 8060' @ 1 00 ft per hr. 15:30 - 16:00 0.50 DRILL P INT1 Drill 8232' to 8258' with 100 rpms 550 Gpms 3600 psi AST 3.07 ART 1.46 16:00 - 19:00 3.00 DRILL P INTi Circ three bottoms up with 560 gpm 3480 psi 110 rpms 19:00 - 21 :00 2.00 DRILL P INT1 Pumping out to shoe 5800' with full drilling rate from 6650' to 5800 15 to 20 k over pulls 21 :00 - 21 :30 0.50 DRILL P INT1 Service rig and flow check 21 :30 - 22:30 1.00 DRILL P INT1 RIH to bottom with reduced running speed, beclause of high mud wt. washed 70 ft to bottom 22:30 - 00:00 1.50 DRILL P INTi Circ three bottoms up with 560 gpms,3480 psi, 11 0 rpms, max trip gas 184 units, no mud cut, ECD started 10.47 final 1 0.3 3/11/2004 00:00 - 01 :00 1.00 DRILL P INT1 Finish, Circ three bottoms up with 560 gpms,3480 psi, 11 0 rpms, max trip gas 184 units, no mud cut, ECD started 10.47 final 10.3 01 :00 - 03:30 2.50 CASE P INT1 Pumping out with full drilling rate to 5,800 03:30 - 04:00 0.50 CASE P INTi Flow check well,slug pipe, blow down top drive 04:00 - 06:00 2.00 CASE P INT1 Tripping out to HWP 06:00 - 08:30 2.50 CASE P INT1 Laying down BHA, clear floor 08:30 - 09:30 1.00 CASE P INT1 Change out top rams to 7 5/8, body test1500 psi 09:30 - 11 :00 1.50 CASE P INT1 Rig up to run 7 5/8 Csg, PJSM on running Csg 11 :00 - 16:30 5.50 CASE P INT1 Picking up 7 5/8 L-80 29.7 # Csg to 5800' 16:30 - 17:30 1.00 CASE P INT1 Circ @ csg shoe 6 bbls min. 550 psi 17:30 - 19:30 2.00 CASE P INTi Picking up 7 5/8 L-80 29.7# Csg to 8,252' , Total Jts run 199 jts two pup jts, shoe @ 8252, float 8,167' 19:30 - 20:00 0.50 CASE P INT1 Lay down Franks tool and rig up cement head, blow down top drive 20:00 - 22:30 2.50 CASE P INTi Circ and reciprocating csg with stage up to 6 bbls min. 550 psi, pick up wt 300K slack off 175K worked pipe 20 ft , 22:30 - 00:00 1.50 CEMT P INTi PJSM, Swap over to Schlumberger, pump as follows, 5 bbls H20, test lines to 3500 psi, 10 bbls CW100, 20 bbls MUdPUS~ mixed @ 10.5,drop bottom plug last 5 bbls spacer, 148 sxs Class G yield 1.16 mixed 15.8, 4 bbls min, 30.6 bbls of slurry, washout cement line, drop top plug, kicked out wI 20 bbls water, Swap to rig displace 6 bbls min. 300 psi, slow pump to 3 bbls min. final pressure 500 psi, bump plug with 1500 psi, full returns thru out job, Reciprocating tru out job, landed on hanger with 175K, floats held 3/12/2004 00:00 - 00:30 0.50 CEMT P INT1 Finish displacement 6 bbls min. 300 psi, slow pump to 3 bbls min. final pressure 500 psi, bump plug with 1500 psi, full returns tru out job, Reciprocating thru out job, landed on hanger with 175K, floats held, cement in place @ 00:153/12/2004 00:30 - 01 :30 1.00 CEMT P INTi Rig down cement head, flush packoff seal area, lay down landing jt. 01 :30 - 02:30 1.00 CEMT P INT1 Clear floor of Csg tools and change out bales on top drive 02:30 - 03:00 0.50 BOPSUP P INT1 Install 9 7/8 x 7 5/8 packoff as per FMC, test to 5,000 psi for 10 min. 03:00 - 04:00 1.00 BOPSUP P INT1 Change out top rams to 2 7/8" X 5" variable, test same to 250--4,000 psi for 5 min. per test 04:00 - 04:30 0.50 BOPSUF P INT1 Install wear ring 04:30 - 06:30 2.00 CASE P INTi Picking up BHA # 5, surface test MWD Printed; 3/22/2004 8;46: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-42 MPC-42 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/1/2004 Rig Release: 3/18/2004 Rig Number: Spud Date: 3/2/2004 End: 3/18/2004 3/12/2004 06:30 - 09:30 3.00 CASE P INT1 Trip in to 8165, fill pie every 25 stands 09:30 - 10:30 1.00 CASE P INT1 slip and cut drilling line 10:30 - 12:00 1.50 CASE P INT1 Rig up and Test csg to 3500 psi for 30 min. good test 12:00 - 13:00 1.00 DRILL P INT1 Drill cement and float collar to 8248' 13:00 - 15:00 2.00 CASE P INT1 Circ and displace well with 12.9 # LSD mud, circ clean ECD 13.9 ~- 15:00 - 15:30 0.50 DRILL P INT1 Drill cement and shoe and 20 ft of new hole to 8,278' 15:30 - 16:30 1.00 CASE P INT1 Circ bottoms up with 275 gpm 2770 100 rpms 16:30 - 17:00 0.50 DRILL P INT2 FIT test 8278' TVD 6801 MW 12.9,565 psi= 14.5 EMW 17:00 - 00:00 7.00 DRILL P INT2 Drilling 8,278' to 8549' TVD 7066' , control drilling, 50 ft per hr. 150 rpms 250 gpm 2400 psi, Ecd 14.1 back ground gas running 50 units, @ 8,388 gas got to 500 units for app. 10 min. mud cut to 12.6 from 12.9, then drop back to 50 units, conn. gas 30 units over back ground, hole taking 8-10 bbls hr. total mud loss to well 30 bbls 3/13/2004 00:00 - 00:30 0.50 DRILL P INT2 Drill 8549' to 8,558 with 150 rpms, 7k bit wt., 250 gpm, 2400 psi 00:30 - 01 :30 1.00 DRILL P INT2 Circ up, drilling Break, ECD 14.0 back ground gas 30 units, max gas 30 units 01 :30 - 02:00 0.50 DRILL P INT2 Drill 8558' to 8,576' with 150 rpms, 7k bit wt., 250 gpm, 2400 psi 02:00 - 03:00 1.00 DRILL P INT2 Circ up, drilling Break, ECD 14.0 back ground gas 20 units, max 38 units 03:00 - 03:30 0.50 DRILL P INT2 Drill 8576' to 8,585' with 150 rpms, 7k bit wt., 250 gpm, 2400 psi 03:30 - 04:30 1.00 DRILL P INT2 Circ up, bottoms up for samples, ECD 13.8 back ground gas 20 units, max 28 units, Town called 8,585 TO 04:30 - 05:00 0.50 DRILL P INT2 Pumping out to Csg shoe @ 8,252', Flow check well, Trip to bottom, Bridge @ 8410, kelley up washed right thru,worked twice. 05:00 - 07:00 2.00 DRILL P INT2 Circ, Two bottoms up with 250 gpm.,2400 psi, 150 rpms, ECD 13.8 07:00 - 07:30 0.50 CASE P LNR1 Pumping out to csg shoe @ 8252, Flow check 07:30 - 09:30 2.00 CASE P LNR1 Trip out to BHA 09:30 - 10:30 1.00 CASE P LNR1 Lay down BHA 10:30 - 11 :00 0.50 CASE P LNR1 PJSM, rig up to pick up liner 11 :00 - 12:00 1.00 CASE P LNR1 Picking up 5.5, 17#, L-80 STL liner and Baker HMC hanger,ZXP liner top packer total jts 10, total 431 ft., circ liner volume 12:00 - 12:30 0.50 CASE P LNR1 Service rig 12:30 - 16:30 4.00 CASE P LNR1 Tripping in with liner slow, to 8,240' 16:30 - 17:30 1.00 CASE P LNR1 Circ liner @ csg shoe 3 bbls min 730 psi, pickup wt 173k,slack off 129k 17:30 - 18:00 0.50 CASE P LNR1 Tripping in with liner to 8560' 18:00 - 19:30 1.50 CASE P LNR1 Circ wash and work liner 8570 to 8585' last 10 ft was fill and hard to wash out, 4 bbls min. 930 psi 19:30 - 20:30 1.00 CASE P LNR1 Circ and reciprocate pipe @ 8585', pickup wt 185k slackoff 115K, liner tie back top 8125', liner hanger 8138', liner packer 8132', Liner shoe 8584' float collar 8495', landing insert 8452' 20:30 - 21 :30 1.00 CEMT P LNR1 Swap to Schlumberger and pumped 5 bbls water, test lines to 4000 psi, 1 0 bbls CW 1 00,1 0 bbls mud push Mix @ 13.5, 101 sx class G yeild 1.16, 18 bbls slurry, mixed @ 15.8, wash lines with 10 bbls water, drop plug, displace with 92 bbls 12.7 mud, Printed: 3/22/2004 8:46: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-42 MPC-42 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/1/2004 Rig Release: 3/18/2004 Rig Number: Spud Date: 3/2/2004 End: 3/18/2004 3/13/2004 20:30 - 21 :30 1.00 CEMT P LNR1 bump plug with 3500 psi, full returns, displace @ 3 bbls min final pumping psi 800 psi 21 :30 - 22:00 0.50 CASE P LNR1 Release from liner,set packer wt 65k down wt., circ bottoms up 10 bbls min, overboard 8 bbls cement 22:00 - 22:30 0.50 CASE P LNR1 Test liner top packer with 1,000 psi, good test 22:30 - 23:30 1.00 CASE P LNR1 Displace well with 9.1 LSD mud @ 12 bbls min. 23:30 - 00:00 0.50 CASE P LNR1 Monitor well, rigging down cement head 3/14/2004 00:00 - 01 :00 1.00 CASE P LNR1 Service break and lay down cementing head and lines, pump dry job 01 :00 - 03:00 2.00 CASE P LNR1 Tripping out with liner running tools, lay down same 03:00 - 03:30 0.50 CASE P LNR1 PJSM, Pull wear ring, run test plug, rig up to test BOPs 03:30 - 06:30 3.00 CASE P LNR1 Testing Bops and manifold with 250- 4000 psi 5 min. per test, Hydril 250- 2500 psi 5 min. per test. The right to witness test was wavier by John Crisp AOGCC 06:30 - 07:00 0.50 CASE P LNR1 install wear ring 07:00 - 08:00 1.00 DRILL P PROD1 Rig up to pickup 2 7/8 HWP 08:00 - 10:00 2.00 DRILL P PROD1 Picking up 2 7/8 hwp and circ thru to clear out scale, stand back in derrick 10:00 - 16:00 6.00 DRILL P PROD1 Picking up Bha # 5, DS49 bit wI 4x1 Os, 3 5/8 Sperrydrill, float sub, stab,DM collar, OM sleeve,EWD,Hang off sub,Flow tube,X over,3 flex DC,X over,Up jars,X over,Circ sub,12 HWDP, 18 jts 27/8 drill pipe total ft. of BHA 1135 ft. 16:00 - 20:00 4.00 DRILL P PROD1 Tripping in hole to 8,240', test MWD every 20 stds. 20:00 - 21 :00 1.00 CASE P PROD1 RIU and test CSG and liner to 3,500 psi for 30 min. good test 21 :00 - 22:30 1.50 DRILL P PROD1 Wash to landing collar, 8450' Rotate toro, high pump EP mud Lube sweep 22:30 - 00:00 1.50 DRILL P PROD1 Drilling landing collar float collar and shoe 8585' with 30 rpms, 5500 torque, 2-3k bit wt. 175 gpm., 2520 psi 3/15/2004 00:00 - 00:30 0.50 DRILL P PROD1 Drilling 8,585' to 8,605' with 30 rpms, 175 gpm, 2800 psi 00:30 - 01 :00 0.50 DRILL P PROD1 FIT test with 700 psi, 9.1 mud wt, 7100 TVD= 11. 0 EMW 01 :00 - 06:00 5.00 DRILL P PROD1 Drilling 8,605' to 8985' with 30 rpms, 175 gpm, 2950 psi., Back ground gas 60 units 06:00 - 07:30 1.50 DRILL P PROD1 Circ 1 .5 bottoms up with 175 gpm 2800 psi, 30 rpms 07:30 - 08:00 0.50 DRILL P PROD1 Pumping out to shoe @ 8,584' with full drilling rate 08:00 - 08:30 0.50 DRILL P PROD1 Service top drive, monitor well 08:30 - 09:00 0.50 DRILL P PROD1 RIH wash to bottom 09:00 - 10:30 1.50 DRILL P PROD1 Circ 1 .5 bottoms up with 175 gpm 2800 psi, 30 rpms 10:30 - 11 :00 0.50 DRILL P PROD1 Pumping out to shoe @ 8,584' with full drilling rate,flow check, slug pipe 11 :00 - 12:00 1.00 DRILL P PROD1 Trip out to 5132' 12:00 - 13:00 1.00 DRILL P PROD1 Hole not taking proper fill, monitor well. hole flowing ~ 13:00 - 14:30 1.50 DRILL N DPRB PROD1 Trip back to bottom 8985' 14:30 - 16:30 2.00 DRILL N DPRB PROD1 Circ bottoms up with 180 gpm 2600 psi mud cut from 9.1 to 8.6 Gas 600 units 16:30 - 18:00 1.50 DRILL N DPRB PROD1 Circ raised mud wt. 9.1 to 9.7, 20 units BG gas 18:00 - 19:00 1.00 DRILL N DPRB PROD1 Pump out to top of liner @ 8125' with full drilling rate 19:00 - 20:00 1.00 DRILL N DPRB PROD1 Flow check well, hole static 20:00 - 21 :00 1.00 DRILL N DPRB PROD1 Trip back to bottom 8985 21 :00 - 22:30 1.50 DRILL N DPRB PROD1 Circ bottoms up, with 180 gpm 2600 psi, 20 units BG gas, bottoms up 60 units 22:30 - 23:30 1.00 CASE P PROD1 Pump out to top of liner, @ 8125' 23:30 - 00:00 0.50 CASE P PROD1 Flow check, slug pipe 3/16/2004 00:00 - 02:30 I 2.50 CASE P PROD1 Tripping out to BHA I Printed: 3/22/2004 8:46: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-42 MPC-42 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/1/2004 Rig Release: 3/18/2004 Rig Number: Spud Date: 3/2/2004 End: 3/18/2004 3/16/2004 02:30 - 06:00 3.50 CASE P PROD1 PJSM, Lay down 2 7/8 pipe and BHA 06:00 - 07:00 1.00 CASE P PROD1 PJSM, Clear rig floor - Rig up to pick up 3.5 liner 07:00 - 08:30 1.50 CASE P PROD1 Pick up 27 joints 31/2" 9.2# L-SO ST·L liner - Make up Baker 7 5/S" x 5 1/2" Flex Lock Hanger with Baker 75/8" x.5 1/2" ZXP Top Packer - C-2 profile and 7" tie back sleeve 08:30 - 09:00 0.50 CASE P PROD1 Rig down liner running tools - Clear rig floor 09:00 - 14:30 5.50 CASE P PROD1 Con't RIH with 31/2" liner from 900' to 8580' - Fill pipe every 15 stands 14:30 - 15:00 0.50 CASE P PROD1 Break Circulation - Circulate 1 Drill pipe and liner volume @ 38 spm @ 600 psi 15:00 - 15:30 0.50 CASE P PROD1 Con't RIH with 3 1/2" liner from 8580' to 8965' - Make up cement head - Break circulation - Wash to bottom @ 8985' 15:30 - 18:30 3.00 CASE P PROD1 Circulate @ 3 bpm @ ICP 800 - FCP 680 18:30 - 20:00 1.50 CEMT P PROD1 Switch to Schlumberger - Pump 5 bbls water - Test lines to 4000 psi - Pump 5 bbls CW1 00 - 10 bbls Alpha Spacer mixed at 10.5 ppg - 19 bbls Class "G" cement - 89 sxs - Yield 1.20 cf/sx - Mixed at 15.8 ppg - Pump rate 2.8 bpm at 680 psi - Displace with 93.4 bbls 9.2 ppg Brine Bump plug set packer with 3500 psi - Displacement rate 3 bpm at 400 psi 20:00 - 20:30 0.50 CASE P PROD1 Release from hanger - Displace well to 9.2 Brine - @ 10.5 bpm - 2700 psi - 7 bbls cement back to surface 20:30 - 21 :00 0.50 CASE P PROD1 Rig down cement lines - Lay down cement head 21 :00 - 22:00 1.00 CASE P PROD1 Test packer to 1000 psi for 10 mins - good test - Lay down 12 joints 4" drill pipe from 8060' to 7388' 22:00 - 23:00 1.00 CASE P PROD1 Cut drilling line - Rig service - Monitor well 23:00 - 00:00 1.00 CASE P PROD1 POH with Baker running tool from 7388' to 3700' 3/17/2004 00:00 - 01 :00 1.00 CASE P PROD1 POH with Baker running tools 01 :00 - 01 :30 0.50 CASE P PROD1 Break and lay down Liner running tools - Make up 6 3/4" bit - 7 5/8" casing scraper - Float sub with float - XO 01 :30 - 04:00 2.50 CASE P PROD1 RIH with Bit and scraper - Tag top liner @ 8100' 04:00 - 05:00 1.00 CASE P PROD1 Rig up test equipment - Test casing to 3500 psi for 30 mins - Record on chart - Rig down test equipment 05:00 - 07:00 2.00 CASE P PROD1 Displace well to seawater with corrision inhibitor added - @ 10 bpm - ICP 3050 - FCP 2600 - Flow check - Well static 07:00 - 13:00 6.00 CASE P PROD1 Lay down 4" drill pipe 13:00 - 14:00 1.00 CASE P PROD1 Lay down BHA - Clear rig floor - Pull wear ring 14:00 - 14:30 0.50 RUNCOMP COMP Rig up Tubing equipment - Mobilize Tail assembly - Count and flag tubing 14:30 - 15:00 0.50 RUNCOMP COMP PJSM - Make up tail assembly 15:00 - 20:00 5.00 RUNCOMP COMP Pick up and run 193 joints of 4112 L-80 12.6# IBT-M - to 8000' 20:00 - 22:00 2.00 RUNCOMP COMP Sting WLEG into tie back sleeve - Space out - Lay down three joints - Pick up three pup joints - One joint tubing for space out - Pick up Hanger - Landing joint - Land Tubing @ 8103'- RILDS - Back out landing joint - lay down - Test TWC from below to 1000 psi - Test good - (Total joints ran 191 + 3 Pups) 22:00 - 23:00 1.00 RUNCOMP COMP Nipple down BOP's - Set back on stump 23:00 - 00:00 1.00 RUNCOMP COMP Nipple up FMC 11" X 4 1/16" 5K tubing head adapter - FMC Tubing head - Install tree seal - Nipple up CIW 4 1/16" 5K tree 3/18/2004 00:00 - 01 :30 1.50 RUNCOMP COMP Nipple up adapter flange / tree - Test adapter flange to 5K 10 mins - Test good - Shell test tree to 4000 psi - Test good- Check annulus - No pressure - Pull TWC 01 :30 - 03:30 2.00 I RUNCOrvp COMP Rig up to freeze protect - Displace seawater with 92 bbls diesel for freeze protection - Pump down annulus @ 2.5 bpm @ 100 I Printed: 3/22/2004 8:46: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-42 MPC-42 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/1/2004 Rig Release: 3/18/2004 Rig Number: Spud Date: 3/2/2004 End: 3/18/2004 3/18/2004 01 :30 - 03:30 2.00 RUNCOMP COMP psi - Taking returns out tubing - U-Tube annulus and tubing - Suck back lines Drop ball and rod - Pressure up tubing to 3500 psi set Baker Premier packer - Record on chart for 30 mins - Test good - Bleed off pressure to 1000 psi - Pressure up annulus to 3500 psi - Record on chart for 30 mins - Test good - Bleed off pressure on both sides to zero - Suck back circulating lines - Install BPV Secure well - Clean cellar - Release rig from wellwork on MPC-42 at 07:00 hours on 3/18/2004 03:30 - 06:00 2.50 RUNCOMP COMP 06:00 - 07:00 1.00 RUNCOMP COMP Printed: 3/22/2004 8:46:18 AM . . MPC-42i Milner Point Unit I Kuparuk River Sands 50-029-23196-00-00 204-028 Accept: Spud: Release: 03/01/04 03/02/04 03/18/04 14 POST-RIG WORK 03/18/04 XPUMPED 92 BBLS DIESEL TO FREEZE PROTECT WELL. SET PACKER. PT TUBING TO 4000 PSI WITH 2 BBLS DIESEL, RETURNED 1.9 BBLS. PT IA TO 3500 PSI WITH 3.6 BBLS DIESEL, RETURNED 3.6 BBLS. SET BACK PRESSURE VALVE. 04/16/04 XPULLED BPV, BALL AND ROD, AND RHC-M, DRIFTED TO TD WI 10'X 2.5" DUMMY PERF GUN TAGGED SOLID TD AT 8875' CORR. TD, 86' OF RATHOLE BELOW PROPOSED BOTTOM PERF. 05/19/04 PRESSURE TEST FLOWLINES, GAS LEG TO 4600 PSI AND WATER LEG TO 3600 PSI. 06/16/04 PERFORATED FROM 8736'-8746' AS PER PROGRAM. TIED INTO SLB SCMT LOG DATED 1-MAY- 2004 AS PER PROGRAM WITH GR/CCL. SHOT 2.5" HSD 2SPF, POWER JET 60 DEG PHASED 10' LONG GUN WITH SECURE SYSTEM. ALL SHOTS FIRED. TAGGED TD AT 8875'. --- 06/25/04 PERFORMED SBHP SURVEY. TAGGED TD @ 8873' CMD USING CORRECTION OFF OF XN NIPPLE. 07/04/04 WHP=1600/120010, INITIAL MIT-IA PASSD TO 2250 PSI. TEST WITNESSED BY JOHN SPAULDING OF THE AOGCC. PUMPED 1.1 BBLS DOWN IA. BLED IA DOWN TO 450 PSI, FWHP=1600/45010 2,856 (psi 11.03 (ppg) 2,851 (psi 11.01 (ppg) 5,123 (psi 14.50 (ppg) 4,059 (psi) 11.00 (ppg) . . Printed: 3/22/2004 8:45:56 AM 525 (psi 520 (psi 565 (psi 702 (psi) 9.00 (ppg) 9.00 (ppg) 12.90 (ppg) 9.10 (ppg) 4,986.0 (ft) 4,985.0 (ft) 6,801.0 (ft) 7,101.0 1ft (ft) 5,808.0 (ft) 8,278.0 (ft) 8,605.0 (ft) Legal Name: MPC-42 Common Name: MPC-42 3/7/2004 FIT 3/8/2004 FIT 3/12/2004 FIT 3/14/2004 FIT e - 08-Apr-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPC-42 GYRO Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' M D (if applicable) 0.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. :::e;)~ ;~~~ Signed ~ û!i¡ Please call me at 273-3545 if you have any questions or concerns. Regards, À 0 V -- b ..:t P William T. Allen Survey Manager Attachment(s) Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPC, Slot MPC-42 (98-5) MPC-42 GYRO Job No. AKF02951136, Surveyed: 15 March, 2004 Survey Report 7 April, 2004 Your Ref: API 500292319600 Surface Coordinates: 6029513.21 N, 558204.12 E (70029' 28.4875" N, 149031'27.0250" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1029513.21 N, 58204.12 E (Grid) Surface Coordinates relative to Structure Reference: 2164.29 N, 163.03 E (True) Kelly Bushing Elevation: 50.40ft above Mean Sea Level Kelly Bushing Elevation: 50.40ft above Project V Reference Kelly Bushing Elevation: 50.40ft above Structure Reference sper-"r-"Y-su,! DR t L- L-ING ... ... $ S RVfESS A Halliburton Company '* DEFINITIVE . . Survey Ref: svy1370 ,..",... 11 Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-42 GYRO Your Ref: API 500292319600 Job No. AKF02951136, Surveyed: 15 March, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 0.00 0.000 0.000 -50.40 0.00 0.00 N 0.00 E 6029513.21 N 558204.12 E 0.00 Tolerable Gyro 166.00 0.450 79.000 115.60 166.00 0.12 N 0.64 E 6029513.34 N 558204.76 E 0.271 0.04 271.00 0.800 86.000 220.59 270.99 0.25 N 1.78 E 6029513.48 N 558205.89 E 0.341 0.02 359.00 2.100 41.000 308.56 358.96 1.51 N 3.45 E 6029514.75 N 558207.55 E 1.858 1.05 448.00 4.150 37.000 397.43 447.83 5.32 N 6.45E 6029518.58 N 558210.53 E 2.315 4.42 540.00 5.300 38.000 489.11 539.51 11.32 N 11.07 E 6029524.62 N 558215.11 E 1.253 9.77 . 630.00 6.000 35.000 578.68 629.08 18.45 N 16.33 E 6029531.79 N 558220.31 E 0.844 16.14 727.00 7.000 35.000 675.05 725.45 27.45 N 22.63 E 6029540.83 N 558226.53 E 1.031 24.23 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 352.440° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 727.00ft., The Bottom Hole Displacement is 35.57ft., in the Direction of 39.505° (True). Survey tool ørOfram for MPC-42 GYRO From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) . 0.00 0.00 727.00 725.45 Tolerable Gyro 7 April, 2004 - 10:11 Page 2 of2 DrillQuest 3.03.06.002 e e 08-Apr-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPC-42 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 8,985.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ;;¿) f1.-y ;Æ.oo L/. Signed 1t-J 0 ttvI Please call me at 273-3545 if you have any questions or concerns. Regards, ~ 0 c{ - d tÁJ> William T. Allen Survey Manager Attachment(s) Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPC, Slot MPC-42 (98-5) MPC-42 Job No. AKZZ2951136, Surveyed: 15 March, 2004 Survey Report 7 April, 2004 Your Ref: API 500292319600 ~rface Coordinates: 6029513.21 N, 558204.12 E (70· 29' 28.4875" N, 149· 31' 27.0250" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1029513.21 N, 58204.12 E (Grid) Surface Coordinates relative to Structure Reference: 2164.29 N, 163.03 E (True) Kelly Bushing Elevation: 50. 40ft above Mean Sea Level Kelly Bushing Elevation: 50.40ft above Project V Reference Kelly Bushing Elevation: 50. 40ft above Structure Reference SpE!............y-su'l! DFULLfNG ···seRVIê:es A Halliburton Company ,... DEF/NITIV . . Survey Ref: svy1372 ".- Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-42 Your Ref: API 500292319600 Job No. AKZZ2951136, Surveyed: 15 March, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 727.00 7.000 35.000 675.05 725.45 27.45 N 22.63 E 6029540.83 N 558226.53 E 24.23 AK-6 BP IFR-AK 755.93 6.950 32.550 703.77 754.17 30.37 N 24.58 E 6029543.77 N 558228.46 E 1.043 26.87 852.34 8.110 35.730 799.34 849.74 40.80 N 31.69 E 6029554.26 N 558235.49 E 1.278 36.28 947.77 9.750 34.850 893.61 944.01 52.90 N 40.24 E 6029566.42 N 558243.95 E 1.724 47.15 1043.44 11.740 34.610 987.60 1038.00 67.56 N 50.40 E 6029581.16 N 558253.99 E 2.081 60.34 1139.29 13.640 24.830 1081.12 1131.52 85.85 N 60.69 E 6029599.53 N 558264.13 E 2.986 77.12 . 1234.66 17 .280 10.380 1173.05 1223.45 110.00 N 67.97 E 6029623.74 N 558271.22 E 5.530 100.10 1331.08 19.040 13.240 1264.67 1315.07 139.40 N 74.15 E 6029653.19 N 558277.18 E 2.046 128.43 1426.33 20.980 14.050 1354.17 1404.57 171.07 N 81.85 E 6029684.91 N 558284.63 E 2.057 158.81 1523.24 22.930 19.640 1444.05 1494.45 205.69 N 92.41 E 6029719.61 N 558294.91 E 2.948 191.74 1618.05 24.860 21.100 1530.73 1581.13 241.68 N 105.79 E 6029755.71 N 558308.01 E 2.129 225.66 1714.40 24.570 20.790 1618.26 1668.66 279.30 N 120.19 E 6029793.44 N 558322.12 E 0.330 261.06 1810.29 24.960 21.030 1705.33 1755.73 316.82 N 134.53 E 6029831.08 N 558336.16 E 0.420 296.37 1905.84 26.380 21.620 1791.45 1841.85 355.38 N 149.58 E 6029869.75 N 558350.92 E 1.510 332.61 2004.03 28.340 21.380 1878.65 1929.05 397.36 N 166.12 E 6029911.86 N 558367.12 E 1.999 372.05 2100.00 30.980 21.560 1962.04 2012.44 441.55 N 183.50 E 6029956.18 N 558384.16 E 2.752 413.57 2195.69 33.790 21.450 2042.84 2093.24 489.23 N 202.29 E 6030004.01 N 558402.57 E 2.937 458.37 2291.29 35.250 20.320 2121.60 2172.00 539.85 N 221.59 E 6030054.78 N 558421.48 E 1.668 506.00 2387.29 35.590 20.190 2199.84 2250.24 592.05 N 240.85 E 6030107.12 N 558440.33 E 0.363 555.21 2484.08 35.900 19.860 2278.39 2328.79 645.17 N 260.21 E 6030160.40 N 558459.27 E 0.377 605.33 2579.14 35.850 20.180 2355.42 2405.82 697.51 N 279.28 E 6030212.89 N 558477.94 E 0.204 654.70 2674.95 34.610 20.070 2433.68 2484.08 749.40 N 298.30 E 6030264.93 N 558496.55 E 1.296 703.64 . 2771.34 32.610 20.000 2513.95 2564.35 799.53 N 316.58 E 6030315.19 N 558514.43 E 2.075 750.93 2865.77 32.210 20.180 2593.67 2644.07 847.06 N 333.96 E 6030362.86 N 558531 .44 E 0.436 795.76 2958.44 32.150 20.810 2672.11 2722.51 893.29 N 351.24 E 6030409.22 N 558548.36 E 0.368 839.31 3054.51 31.780 21.490 2753.61 2804.01 940.72 N 369.59 E 6030456.80 N 558566.34 E 0.537 883.92 3150.15 32.360 20.610 2834.66 2885.06 988.12 N 387.83 E 6030504.33 N 558584.20 E 0.779 928.50 3245.39 32.720 20.890 2914.94 2965.34 1036.02 N 405.98 E 6030552.38 N 558601.98 E 0.410 973.60 3341.39 33.040 20.860 2995.57 3045.97 1084.72 N 424.55 E 6030601.22 N 558620.17 E 0.334 1019.43 3437.64 33.440 20.880 3076.07 3126.47 1134.01 N 443.35 E 6030650.66 N 558638.58 E 0.416 1065.83 3535.31 33.500 21.450 3157.54 3207.94 1184.24 N 462.79 E 6030701.04 N 558657.63 E 0.328 1113.06 3631.78 33.460 21.850 3238.01 3288.41 1233.71 N 482.43 E 6030750.66 N 558676.88 E 0.232 1159.51 3727.09 33.360 21.950 3317.57 3367.97 1282.40 N 502.00 E 6030799.50 N 558696.07 E 0.120 1205.21 3823.03 33.850 20.130 3397.47 3447.87 1331.96 N 521.06 E 6030849.20 N 558714.74 E 1.168 1251.83 3917.57 34.300 19.770 3475.78 3526.18 1381.75N 539.13 E 6030899.13 N 558732.42 E 0.522 1298.81 7 April, 2004 - 10:12 Page 20f5 Dril/Quest 3.03.06.002 -- Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-42 Your Ref: AP/500292319600 Job No. AKZZ2951136, Surveyed: 15 March, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northin9s Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ¡0/100ft) 4013.73 35.090 16.610 3554.85 3605.25 1433.74 N 556.20 E 6030951.26 N 558749.08 E 2.043 1348.1 0 4109.41 35.190 15.890 3633.09 3683.49 1486.61 N 571.61 E 6031004.24 N 558764.07 E 0.446 1398.48 4206.69 36.000 13.220 3712.20 3762.60 1541.40 N 585.82 E 6031059.15 N 558777.86 E 1.801 1450.93 4302.84 36.690 8.560 3789.66 3840.06 1597.33 N 596.56 E 6031115.16 N 558788.16 E 2.960 1504.96 4397.76 37.330 4.540 3865.47 3915.87 1654.07 N 603.06 E 6031171.95N 558794.21 E 2.637 1560.35 4493.54 37.160 2.890 3941.71 3992.11 1711.91 N 606.82 E 6031229.82 N 558797.52 E 1.058 1617.19 . 4589.55 37.570 0.800 4018.02 4068.42 1770.14 N 608.69 E 6031288.06 N 558798.93 E 1.388 1674.67 4685.80 38.900 0.630 4093.62 4144.02 1829.70 N 609.43 E 6031347.62 N 558799.21 E 1.386 1733.62 4781.97 38.600 356.930 4168.64 4219.04 1889.86 N 608.16 E 6031407.77 N 558797.46 E 2.428 1793.42 4878.81 38.020 355.320 4244.63 4295.03 1949.75 N 604.11 E 6031467.63 N 558792.94 E 1.192 1853.32 4974.92 37.730 350.190 4320.51 4370.91 2008.24 N 596.68 E 6031526.06 N 558785.06 E 3.290 1912.28 5071.31 38.620 346.320 4396.29 4446.69 2066.54 N 584.54 E 6031584.26 N 558772.46 E 2.647 1971.67 5167.50 40.510 338.090 4470.50 4520.90 2124.74 N 565.76 E 6031642.31 N 558753.24 E 5.789 2031.83 5263.77 41.430 331.900 4543.21 4593.61 2181.87 N 539.08 E 6031699.23 N 558726.11 E 4.321 2091.98 5359.93 42.560 329.240 4614.69 4665.09 2237.88 N 507.46 E 6031755.00 N 558694.05 E 2.192 2151.67 5455.14 43.590 327.140 4684.23 4734.63 2293.13 N 473.18 E 6031809.97 N 558659.34 E 1.854 2210.94 5552.53 45.440 326.110 4753.68 4804.08 2350.14 N 435.62 E 6031866.69 N 558621.33 E 2.039 2272.40 5648.62 47.510 326.490 4819.85 4870.25 2408.10 N 396.96 E 6031924.35 N 558582.22 E 2.173 2334.94 5743.93 46.110 326.780 4885.08 4935.48 2466.14 N 358.75 E 6031982.08 N 558543.55 E 1 .486 2397.50 5837.69 45.640 326.450 4950.36 5000.76 2522.33 N 321.71 E 6032037.98 N 558506.08 E 0.561 2458.08 5933.86 46.640 326.360 5016.99 5067.39 2580.09 N 283.34 E 6032095.44 N 558467.26 E 1.042 2520.39 6028.91 48.340 326.580 5081.22 5131.62 2638.50 N 244.64 E 6032153.54 N 558428.10 E 1.797 2583.38 . 6125.51 48.650 328.330 5145.24 5195.64 2699.48 N 205.73 E 6032214.22 N 558388.71 E 1.394 2648.95 6220.20 49.070 328.050 5207.53 5257.93 2760.08 N 168.14 E 6032274.52 N 558350.65 E 0.496 2713.97 6314.84 48.810 327.870 5269.70 5320.10 2820.57 N 130.28 E 6032334.71 N 558312.32 E 0.310 2778.91 6411.05 49.140 330.290 5332.85 5383.25 2882.83 N 93.00 E 6032396.68 N 558274.55 E 1.928 2845.54 6507.52 49.410 330.140 5395.79 5446.19 2946.28 N 56.68 E 6032459.85 N 558237.74 E 0.304 2913.21 6603.50 49.650 329.490 5458.09 5508.49 3009.40 N 19.97 E 6032522.67 N 558200.53 E 0.573 2980.61 6699.56 49.480 329.250 5520.39 5570.79 3072.31 N 17.28 W 6032585.29 N 558162.79 E 0.260 3047.88 6794.13 49.750 329.390 5581.67 5632.07 3134.26 N 54.04 W 6032646.95 N 558125.55 E 0.307 3114.13 6890.69 48.970 333.230 5644.57 5694.97 3198.51 N 89.21 W 6032710.92 N 558089.87 E 3.124 3182.44 6986.77 48.820 333.700 5707.74 5758.14 3263.28 N 121.56 W 6032775.44 N 558057.02 E 0.400 3250.91 7083.16 49.450 334.400 5770.80 5821.20 3328.82 N 153.45 W 6032840.73 N 558024.61 E 0.854 3320.08 7179.22 48.320 333.240 5833.97 5884.37 3393.77 N 185.38 W 6032905.43 N 557992.18 E 1.487 3388.66 7275.22 46.050 331.150 5899.21 5949.61 3456.06 N 218.20 W 6032967.46 N 557958.88 E 2.853 3454.73 7 April, 2004 - 10:12 Page 3 of 5 DrillQuest 3.03.06.002 ,- Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-42 Your Ref: API 500292319600 Job No. AKZZ2951136, Surveyed: 15 March, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northin9s Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7370.15 42.680 330.680 5967.07 6017.47 3514.06 N 250.45 W 6033025.21 N 557926.17 E 3.567 3516.47 7466.36 39.390 333.620 6039.64 6090.04 3569.87 N 280.00 W 6033080.77 N 557896.19 E 3.964 3575.67 7562.38 36.800 332.580 6115.20 6165.60 3622.70 N 306.78 W 6033133.40 N 557868.99 E 2.779 3631.57 7658.16 34.890 330.470 6192.84 6243.24 3672.00 N 333.50 W 6033182.49 N 557841.89 E 2.375 3683.96 7754.82 32.890 331.120 6273.07 6323.47 3719.04 N 359.80 W 6033229.32 N 557815.22 E 2.103 3734.05 7851.40 29.960 332.820 6355.48 6405.88 3763.47 N 383.49 W 6033273.56 N 557791.18 E 3.169 3781.21 . 7947.98 26.330 332.850 6440.63 6491.03 3803.99 N 404.28 W 6033313.92 N 557770.07 E 3.759 3824.12 8037.71 22.890 334.250 6522.19 6572.59 3837.43 N 420.95 W 6033347.23 N 557753.14 E 3.888 3859.45 8133.53 18.780 333.050 6611.73 6662.13 3867.97 N 436.04 W 6033377.65 N 557737.81 E 4.312 3891.72 8190.20 16.690 333.770 6665.70 6716.10 3883.41 N 443.78 W 6033393.02 N 557729.96 E 3.708 3908.04 8295.08 12.860 334.670 6767.10 6817.50 3907.48 N 455.43 W 6033417.00 N 557718.12 E 3.658 3933.43 8391.66 12.350 334.640 6861.35 6911.75 3926.52 N 464.45 W 6033435.98 N 557708.95 E 0.528 3953.50 8483.50 12.140 336.510 6951.10 7001.50 3944.26 N 472.51 W 6033453.65 N 557700.75 E 0.489 3972.14 8579.52 11.310 334.760 7045.11 7095.51 3962.03 N 480.55 W 6033471.36 N 557692.57 E 0.940 3990.82 8674.35 10.480 333.000 7138.23 7188.63 3978.13 N 488.43 W 6033487.39 N 557684.57 E 0.943 4007.81 8769.56 9.030 329.280 7232.07 7282.47 3992.27 N 496.18 W 6033501.47 N 557676.71 E 1.660 4022.84 8865.77 7.370 324.670 7327.29 7377.69 4003.79 N 503.60 W 6033512.94 N 557669.19 E 1.854 4035.25 8944.11 6.960 324.100 7405.02 7455.42 4011.74 N 509.29 W 6033520.84 N 557663.44 E 0.531 4043.87 8985.00 6.960 324.100 7445.61 7496.01 4015.75 N 512.20 W 6033524.83 N 557660.50 E 0.000 4048.23 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. . The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 352.4400 (True). Based upon Minimum Curvature type calculations. at a Measured Depth of 8985.0Oft., The Bottom Hole Displacement is 4048.28ft., in the Direction of 352.731 0 (True). 7 April, 2004 - 10:12 Page 4 of 5 DrillQuest 3.03.06.002 ...... Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-42 Your Ref: API 500292319600 Job No. AKZZ2951136, Surveyed: 15 March, 2004 BPXA Milne Point Unit Comments Measured Depth (ft) Station Coordinates TVD Northin9s Eastings (ft) (ft) (ft) Comment ~8985.00 7496.01 4015.75 N 512.20 W Projected Survey . Survey too/prOgram for MPC-42 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 727.00 0.00 725.45 727.00 8985.00 725.45 Tolerable Gyro (MPC-42 GYRO) 7496.01 AK-6 BP JFR-AK (MPC-42) . 7 April, 2004 - 10:12 Page 50f5 Dri/lQuest 3.03.06.002 e e 08-Apr-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPC-42 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 8,985.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date I-. ) ILp )JLO vi Signed ~rJl/;.J Please call me at 273-3545 if you have any questions or concerns. Regards, ~ 0 v/_ G Â f William T. Allen Survey Manager Attachment(s) Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPC, Slot MPC-42 (98-5) MPC-42 MWD Job No. AKMW2951136, Surveyed: 15 March, 2004 Survey Report 7 April, 2004 Your Ref: API 500292319600 Surface Coordinates: 6029513.21 N, 558204.12 E (70029' 28.4875" N, 149031'27.0250" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1029513.21 N, 58204.12 E (Grid) Surface Coordinates relative to Structure Reference: 2164.29 N, 163.03 E (True) Kelly Bushing Elevation: 50.40ft above Mean Sea Level Kelly Bushing Elevation: 50.40ft above Project V Reference,? Kelly Bushing ElevaUon, 50._ above Súuc'w.. Refe<ence 0 0 c¡ _ (J)- 0 .pEI""'I""'Y-SU" CRU"'LINGSERVIc:eS A Halliburton Company e e Survey Ref: svy1371 Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-42 MWD Your Ref: AP/500292319600 Job No. AKMW2951136, Surveyed: 15 March, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ¡O/100ft) 727.00 7.000 35.000 675.05 725.45 27.45 N 22.63 E 6029540.83 N 558226.53 E 24.23 MWD Magnetic 755.93 6.950 32.670 703.77 754.17 30.36 N 24.59 E 6029543.77 N 558228.4 7 E 0.993 26.87 852.34 8.110 35.850 799.34 849.74 40.79 N 31.72 E 6029554.24 N 558235.52 E 1.278 36.26 947.77 9.750 34.880 893.61 944.01 52.87 N 40.28 E 6029566.40 N 558243.99 E 1.726 47.11 1043.44 11.740 34.570 987.60 1038.00 67.53 N 50.44 E 6029581.14 N 558254.03 E 2.081 60.31 e 1139.29 13.640 25.030 1081.12 1131.52 85.81 N 60.75 E 6029599.49 N 558264.20 E 2.945 77.07 1234.66 17.280 10.890 1173.05 1223.45 109.92 N 68.19 E 6029623.66 N 558271.45 E 5.468 100.00 1331.08 19.040 13.350 1264.67 1315.07 139.29 N 74.53 E 6029653.08 N 558277.56 E 1.991 128.27 1426.33 20.980 14.190 1354.16 1404.56 170.94 N 82.30 E 6029684.79 N 558285.08 E 2.059 158.63 1523.24 22.930 19.830 1444.05 1494.45 205.53 N 92.96 E 6029719.46 N 558295.47 E 2.962 191.51 1618.05 24.860 21.240 1530.73 1581.13 241.48 N 106.44 E 6029755.52 N 558308.67 E 2.123 225.38 1714.40 24.570 20.990 1618.26 1668.66 279.06 N 120.96 E 6029793.21 N 558322.89 E 0.320 260.72 1810.29 24.960 21.260 1705.33 1755.73 316.53 N 135.43 E 6029830.79 N 558337.07 E 0.423 295.96 1905.84 26.380 21.840 1791.44 1841.84 355.02 N 150.64 E 6029869.40 N 558351.98 E 1.509 332.12 2004.03 28.340 21.520 1878.65 1929.05 396.96 N 167.31 E 6029911.46 N 558368.32 E 2.002 371.49 2100.00 30.980 21.750 1962.04 2012.44 441.10 N 184.82 E 6029955.74 N 558385.48 E 2.753 412.95 2195.69 33.790 21.580 2042.83 2093.23 488.72 N 203.74 E 6030003.51 N 558404.02 E 2.938 457.67 2291.29 35.250 20.540 2121.60 2172.00 539.28 N 223.19 E 6030054.22 N 558423.09 E 1.647 505.23 2387.29 35.590 20.300 2199.83 2250.23 591.42 N 242.61 E 6030106.52 N 558442.09 E 0.383 554.36 2484.08 35.900 20.050 2278.39 2328.79 644.50 N 262.11 E 6030159.74 N 558461.17 E 0.354 604.41 2579.14 35.850 20.380 2355.42 2405.82 696.77 N 281.36 E 6030212.16 N 558480.01 E 0.210 653.70 2674.95 34.610 20.230 2433.68 2484.08 748.61 N 300.54 E 6030264.15 N 558498.79 E 1.297 702.56 e 2771.34 32.610 20.180 2513.95 2564.35 798.68 N 318.96 E 6030314.36 N 558516.82 E 2.075 749.77 2865.77 32.210 20.440 2593.67 2644.07 846.14 N 336.53 E 6030361.96 N 558534.02 E 0.449 794.51 2958.44 32.150 20.910 2672.10 2722.50 892.32 N 353.95 E 6030408.27 N 558551.08 E 0.278 837.99 3054.51 31.780 21.670 2753.61 2804.01 939.70 N 372.42 E 6030455.80 N 558569.17 E 0.569 882.54 3150.15 32.360 20.790 2834.65 2885.05 987.04 N 390.80 E 6030503.28 N 558587.19 E 0.779 927.04 3245.39 32.720 21.020 2914.94 2965.34 1034.89 N 409.08 E 6030551.28 N 558605.09 E 0.400 972.08 3341.39 33.040 20.820 2995.56 3045.96 1083.58 N 427.69 E 6030600.10 N 558623.32 E 0.352 1017.89 3437.64 33.440 20.930 3076.06 3126.46 1132.87 N 446.49 E 6030649.54 N 558641.73 E 0.420 1064.28 3535.31 33.500 21 .430 3157.54 3207.94 1183.10 N 465.95 E 6030699.92 N 558660.80 E 0.289 1111.51 3631.78 33.460 21.900 3238.00 3288.40 1232.56 N 485.60 E 6030749.53 N 558680.06 E 0.272 1157.95 3727.09 33.360 22.200 3317.56 3367.96 1281.20 N 505.30 E 6030798.32 N 558699.38 E 0.203 1203.58 3823.03 33.850 20.230 3397.47 3447.87 1330.69 N 524.51 E 6030847.97 N 558718.20 E 1.246 1250.12 3917.57 34.300 19.950 3475.78 3526.18 1380.44 N 542.70 E 6030897.86 N 558736.00 E 0.504 1297.04 7 April, 2004 - 10:12 Page 2 of 5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-42 MWD Your Ref: API 500292319600 Job No. AKMW2951136, Surveyed: 15 March, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (a/100ft) 4013.73 35.090 16.810 3554.85 3605.25 1432.37 N 559.94 E 6030949.92 N 558752.83 E 2.032 1346.25 4109.41 35.190 16.120 3633.09 3683.49 1485.18 N 575.55 E 6031002.85 N 558768.03 E 0.428 1396.55 4206.69 36.000 13.440 3712.20 3762.60 1539.92 N 589.98 E 6031057.70 N 558782.03 E 1.807 1448.92 4302.84 36.690 8.810 3789.66 3840.06 1595.80 N 600.95 E 6031113.67 N 558792.56 E 2.942 1502.87 4397.76 37.330 4.830 3865.46 3915.86 1652.51 N 607.72 E 6031170.43 N 558798.88 E 2.612 1558.19 e 4493.54 37.160 3.200 3941.71 3992.11 1710.33N 611.78 E 6031228.28 N 558802.49 E 1.045 1614.98 4589.55 37.570 1.080 4018.02 4068.42 1768.55 N 613.95 E 6031286.52 N 558804.20 E 1 .406 1672.41 4685.80 38.900 0.960 4093.62 4144.02 1828.11 N 615.01 E 6031346.08 N 558804.80 E 1.384 1731.31 4781.97 38.600 357.260 4168.63 4219.03 1888.28 N 614.08 E 6031406.23 N 558803.40 E 2.428 1791.07 4878.81 38.020 355.810 4244.62 4295.02 1948.19 N 610.45 E 6031466.12 N 558799.31 E 1.105 1850.95 4974.92 37.730 350.380 4320.51 4370.91 2006.72 N 603.38 E 6031524.60 N 558791.77 E 3.481 1909.90 5071.31 38.620 346.520 4396.29 4446.69 2065.06 N 591.43 E 6031582.84 N 558779.37 E 2.641 1969.30 5167.50 40.510 338.110 4470.50 4520.90 2123.29 N 572.77 E 6031640.92 N 558760.25 E 5.901 2029.48 5263.77 41 .430 332.280 4543.21 4593.61 2180.52 N 546.29 E 6031697.94 N 558733.32 E 4.083 2089.70 5359.93 42.560 329.850 4614.68 4665.08 2236.81 N 515.15E 6031753.99 N 558701.75 E 2.059 2149.59 5455.14 43.590 327.650 4684.23 4734.63 2292.39 N 481.42 E 6031809.30 N 558667.58 E 1.913 2209.13 5552.53 45.440 326.950 4753.68 4804.08 2349.84 N 444.52 E 6031866.46 N 558630.24 E 1.965 2270.93 5648.62 47.510 327.230 4819.85 4870.25 2408.33 N 406.68 E 6031924.65 N 558591.93 E 2.165 2333.89 5743.93 46.110 327.080 4885.08 4935.48 2466.71 N 368.99 E 6031982.73 N 558553.79 E 1.473 2396.72 5837.69 45.640 326.750 4950.35 5000.75 2523.10 N 332.25 E 6032038.83 N 558516.61 E 0.561 2457.46 5933.86 46.640 326.740 5016.99 5067.39 2581.09 N 294.22 E 6032096.52 N 558478.13 E 1.040 2519.94 6028.91 48.340 327.000 5081.21 5131.61 2639.76 N 255.93 E 6032154.89 N 558439.38 E 1.800 2583.14 e 6125.51 48.650 328.800 5145.23 5195.63 2701.04 N 217.50 E 6032215.87 N 558400.47 E 1.432 2648.95 6220.20 49.070 328.540 5207.53 5257.93 2761.95 N 180.42 E 6032276.49 N 558362.91 E 0.489 2714.21 6314.84 48.810 328.320 5269.69 5320.09 2822.75 N 143.06 E 6032337.00 N 558325.08 E 0.326 2779.40 6411.05 49.140 330.750 5332.85 5383.25 2885.31 N 1 06.26 E 6032399.26 N 558287.80 E 1.936 2846.25 6507.52 49.410 330.700 5395.79 5446.19 2949.08 N 70.51 E 6032462.75 N 558251.55 E 0.283 2914.17 6603.50 49.650 329.990 5458.09 5508.49 3012.53 N 34.39 E 6032525.92 N 558214.92 E 0.616 2981.82 6699.56 49.480 329.690 5520.39 5570.79 3075.75 N 2.35W 6032588.85 N 558177.70 E 0.296 3049.32 6794.13 49.750 329.770 5581.66 5632.06 3137.96 N 38.66 W 6032650.78 N 558140.90 E 0.293 3115.77 6890.69 48.970 333.750 5644.57 5694.97 3202.48 N 73.33 W 6032715.02 N 558105.73 E 3.230 3184.29 6986.77 48.820 334.320 5707.73 5758.13 3267.57 N 105.03 W 6032779.86 N 558073.52 E 0.473 3252.99 7083.16 49.450 335.030 5770.80 5821.20 3333.46 N 136.20 W 6032845.50 N 558041.83 E 0.859 3322.40 7179.22 48.320 333.660 5833.97 5884.37 3398.70 N 167.53 W 6032910.49 N 558009.99 E 1.593 3391.19 7275.22 46.050 331.120 5899.21 5949.61 3461.10 N 200.13 W 6032972.63 N 557976.90 E 3.059 3457.34 7 April, 2004·10:12 Page 3 of 5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-42 MWD Your Ref: API 500292319600 Job No. AKMW2951136, Surveyed: 15 March, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 7370.15 42.680 329.550 5967.07 6017.47 3518.78 N 232.95 W 6033030.06 N 557943.63 E 3.733 3518.84 7466.36 39.390 331.980 6039.64 6090.04 3573.86 N 263.83 W 6033084.89 N 557912.32 E 3.800 3577.50 7562.38 36.800 331.580 6115.20 6165.60 3626.05 N 291.84 W 6033136.87 N 557883.91 E 2.710 3632.93 7658.16 34.890 329.340 6192.84 6243.24 3674.86 N 319.46 W 6033185.45 N 557855.90 E 2.419 3684.94 7754.82 32.890 330.940 6273.07 6323.47 3721.58 N 346.31 W 6033231.97 N 557828.69 E 2.265 3734.79 e 7851.40 29.960 332.770 6355.48 6405.88 3765.96 N 370.09 W 6033276.15 N 557804.56 E 3.190 3781.91 7947.98 26.330 333.250 6440.63 6491.03 3806.54 N 390.77 W 6033316.58 N 557783.56 E 3.766 3824.86 8037.71 22.890 333.960 6522.19 6572.59 3840.00 N 407.39 W 6033349.90 N 557766.68 E 3.848 3860.22 8133.53 18.780 332.960 6611.73 6662.13 3870.49 N 422.59 W 6033380.28 N 557751.24 E 4.305 3892.45 8190.20 16.690 333.950 6665.70 6716.10 3885.93 N 430.31 W 6033395.65 N 557743.40 E 3.726 3908.77 8295.08 12.860 334.980 6767.10 6817.50 3910.05 N 441.87 W 6033419.68 N 557731.66 E 3.660 3934.19 8391.66 12.350 335.710 6861.35 6911.75 3929.20 N 450.66 W 6033438.76 N 557722.71 E 0.553 3954.34 8483.50 12.140 336.670 6951.10 7001.50 3947.02 N 458.53 W 6033456.52 N 557714.71 E 0.318 3973.04 8579.52 11.310 334.760 7045.12 7095.52 3964.81 N 466.54 W 6033474.25 N 557706.56 E 0.954 3991.73 8674.35 10.480 333.440 7138.24 7188.64 3980.93 N 474.36 W 6033490.31 N 557698.61 E 0.914 4008.74 8769.56 9.030 329.400 7232.07 7282.47 3995.11 N 482.04 W 6033504.43 N 557690.82 E 1.683 4023.80 8865.77 7.370 324.770 7327.29 7377.69 4006.65 N 489.44 W 6033515.91 N 557683.33 E 1.856 4036.22 8944.11 6.960 323.850 7405.02 7455.42 4014.59 N 495.14 W 6033523.80 N 557677.57 E 0.543 4044.84 8985.00 6.960 323.850 7445.61 7496.01 4018.59 N 498.06 W 6033527.78 N 557674.62 E 0.000 4049.19 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. e The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 352.440° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8985.00ft., The Bottom Hole Displacement is 4049.34ft., in the Direction of 352.935° (True). 7 April, 2004· 10:12 Page 4 of 5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-42 MWD Your Ref: API 500292319600 Job No. AKMW2951136, Surveyed: 15 March, 2004 BPXA Milne Point Unit Comments Measured Depth (ft) Station Coordinates TVD Northin9S Eastin9s (ft) (ft) (ft) Comment 8985.00 7496.01 4018.59 N 498.06 W Projected Survey e Survey tool program for MPC-42 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 727.00 0.00 725.45 727.00 8985.00 725.45 Tolerable Gyro (MPC-42 GYRO) 7496.01 MWD Magnetic (MPC-42 MWD) e 7 April, 2004 - 10:12 Page 5 of 5 DrillQuest 3.03.06.002 MEMORANDUM . State of Alaska -- Alaska Oil and Gas Conservation Commission TO: Jim Regg 0 i.l P.I. Supervisor !)en Ilb¡M DATE: Tuesday, July 13,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC C-42 MILNE PT UNIT KR C-42 '~h.~~· ~~Tn"~"~:;'¿"~'-' FROM: John Spaulding Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :J8'f.2- Comm NON-CONFIDENTIAL Well Name: MILNE PT UNIT KR C-42 Insp Num: mitJS040704152828 ReI Insp Num: API Well Number: 50-029-23196-00-00 Permit Number: 204-028-0 Inspector Name: John Spaulding Inspection Date: 7/512004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well C-42 Type Inj, S TVD IA II75 2250 2210 2210 P.T. 2040280 TypeTest SPT Test psi 1649.5 OA 125 125 125 125 Interval INITAL P/F P Tubing 1600 1600 1600 1600 Notes: Test psi increased upon my request, in order to get a 500+ psi differential. V Tuesday, July 13, 2004 Page 1 of I Re: MPC-42 Injector Reservoir Isolation. . . Subject: Re: MPC-42 Injector Reservoir Isolation. From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 07 May 2004 19:53:21 -0800 ~O ~·-O ~ To: "Green, Matt D" <GreenMD@BP.com> CC: "Townsend, Monte A" <TownseMA@BP.com>, "Frazier, Nicholas B" <fraznb@BP.com> Matt, Monte or Nick, I apologize for not getting this back to you earlier. What is proposed is as we discussed yesterday. The 5-1/2" liner cement job and the shale below the Kuparuk should be sufficient to provide isolation to the Kuparuk intervals. Your diagnostic plan should help you identify the split between the sands and determine if remedial action is needed. This plan is acceptable. There is only one item that is not clear and that is how soon you would plan to run the WFL, etc. Mention is made of the "first 9 months". Does than mean that the diagnostic logs would not be run until 9 months hence? I look forward to your clarification. Good luck with the operations. Tom Maunder, PE AOGCC Green, Matt D wrote: Tom, As discussed during our phone conversation today (6-May-04), an SCMT log was run on 1-May-04 that showed very poor to zero cement in the 4.75-in open hole by 3.5-in liner section. The cement job was most likely overdisplaced as an additional 3-bbl over calculated volume was pumped before the plug was bumped. However, we believe that we have sufficient isolation of the Kuparuk reservoir as defined in the Area Injection Order lOB and would like to perforate the Kuparuk A-sand as planned. Isolation below the Kuparuk reservoir is contained by the Miluveach shale. Isolation above the Kuparuk reservoir is contained by the 6.75-in open hole by 5.5-in liner cement job. The 5.5-in liner shoe was set immediately above the Kuparuk C-sand at 8,584-ft MD and all indications are that the 5.5-in liner cement job went well; full returns, reciprocation throughout job, 2 centralisers/joint, plug bumped as planned. The FIT at the 5.5-in liner shoe was also successful to 11.0-lb/gal. After perforation of the Kuparuk A-sand, we would like to commence injection. After approx. two weeks, we would then plan warm back passes, followed by a water flow log, possibly with Borax, to determine where the injection fluid is going. An injection profile for the first 9-mth of the well life will thus be determined. Please let us know if you have any issues with the above strategy. Field operations are planned in the next few days. Attached are the current wellbore diagram, DIMS cement reports and the SCMT log (to follow). I will be away from 9th to 17th May. In my absence, please contact either Monte Townsend (564-4602) or Nick Frazier (564-4638). Cheers, Matt Matthew D Green Drilling Engineer BP Exploration Alaska, MB 4-1 PO Box 196612 Anchorage AK 99519-6612 (W) +1 (907) 564 5581 (M) +1 (907) 529 8501 (F) +1 (907) 564 4441 lof2 7/26/20041:52 PM an Loc n o Feet 1 :12,,000 ASP 4 NAD lCU Marker Pick Well Status (18 Abandoned Gas Injector Or Gas Pro.ducer Shut-In Miscible Injector Operatirlg Miscible Injector Shut-In ~ Not Yet Completed ITd Not Yet Reached. NullJUnknown · Oil Producer flowing Oil Producer Gas Lift Oil Producer Hydraulic Pump Oil Producer Shut-In Oil Producer Submersible Oil Suspended · Oil Well Plugged Back For Redrili ¢ Suspended Water Injector Water Injector Injecting Water Injector Shut-In · Water Producer flowing . . FRANK H. MURKOWSKI, GOVERNOR -~ AI/ASHA OIL.AlÐ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. Anchorage, Alaska 99519-6612 Re: Milne Point MPC-42 BP Exploration (Alaska) Inc. Permit No: 204-028 Surface Location: 1231' FSL & 2255' FEL, Sec. 10, T13N, RlOE, UM Bottomhole Location: 151' FSL & 2864' FEL, Sec. 03, T13N, RlOE, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you kom obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Since elevated sub-surface pressures were encountered by MPC-12A in the area, a weekly report of the daily well operations is requested kom the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four ours notice for a representative of the Commission to witness any required test. Contact ission's North Slope petroleum field inspector at 659-3607 (pager). U' BY ORDER OF.IHE COMMISSION DATED this.ta..1'1fãy of February, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ALASKA Oil 10 ~::;~g~S~:~~ON cOMMI!o~ECE'VE,D PERMIT TO DRILL FEB 0 5 2004 20 AAC 25.005 11b. Current Well Class 0 Exploratory o Stratigraphic Test II Service 5. Bond: II Blanket 0 Single Well Bond No. 2S100302630-277 ' 6. Proposed Depth: MD 8955' . TVD 7452" 7. Property Designation: ADL 047434 B Drill 0 Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Suñace: ·1231' NSL, 2255' WEL, SEC. 10, T13N, R10E, (As Staked) Top of Productive Horizon: 5247' NSL, 2766' WEL, SEC. 10, T13N, R10E, UM Total Depth: 151' NSL, 2864' WEL, SEC. 03, T13N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-558203.88 ' y-6029513.38· Zone-ASP4 16. Deviated Wells: Kickoff Depth 1trCasing Progl'am Size Casing 20" 10-3/4" 7-518" 5-1/2" 3-1/2" 350' ft Maximum Hole Angle Hole 42" Weiçht 92# 45.5# 29.7# 17# 9.2# Grade H-40 L-80 L-80 L-80 L-80 Coupling Weld BTC-M BTC-M ST-L ST-L 13-1/2" 9-718" 6-3/4" 4-3/4" fr;A , ('\ O. G·.i<:¡ r.ons. Camml<¡S\ofI -Al,.~ÍiA \,;1 ¡:,¡ J.. Jl:Jev~R>pment Pi!.· D.M,I,Iftiple Zone o Development,Whll!!PSlñgle Zone /.31:-. 11. Well Name and Number: MPC-42 12. Field I Pool(s): Milne Point Unit I Kuparuk River Sands 8. Land Use Permit: 13. Approximate Spud Date: 02/16/04 14. Distance to Nearest Property: 8300' 9. Acres in Property: 2560 " 47° 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): ::;~~. feet 1500' away Kuparuk Sand Penetration MPC-03 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4479; psig Surface: 3785' psig Lençth MD TVD MD TVD (includinç staçe data) 112' Suñace Surface 112' 112' 260 sx Arctic Set (Approx.) 5811' Suñace Surface 5811' 4950' 706 sx Arcticset III, 256 sx Class 'G' 8318' Surface Surface 8318' 6830' 147 sx Class 'G' 329' 8218' 6735' 854 7' 7050' 70 sx Class 'G' 837' 8118' 6643' 8955' 7451' 97 sx Class 'G' PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Depth TVD Junk (measured): 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Pat Archey Title Senior Drilling Engineer Phone 564-5803 Date "2..1 5'Þr Permit To Drill...,/,v/ /",'>ó APINu.m~er: ..-, -:::2/(4/ -/'\0" PermitApprova~ / t..I See cover letter for Number: ,£J../7-v~ 50- DZ-q- ~ /10 (.....II Date: d-//:J..ytJ ( other requirements Conditions of Approval: Samples Required 0 Yes ~No Mud Log Required 0 Yes Øo Hydrogen e Measures ~es 0 No Directional Survey Required ~es 0 No .t::;?~~~~, Y\\ \~ ~~~'~,\:\J(.S\.\.-(\0s. C\,\ )'1.)'\ L"'-R\, Q..~\,~~ <td a 0 "'~'- ~s .450<0) Structural Conductor Surface Intermediate Production liner Perforation Depth MD (ft): 20. Attachments 181 Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 181 Drilling Program 0 Time vs Depth Plot o Seabed Report 181 Drilling Fluid Program o Shallow Hazard Analysis 18120 AAC 25.050 Requirements Date: Contact Walter Quay, 564-4178 Prepared By Name/Number: Sondra Stewman, 564-4750 BY ORDER OF THE COMMISSION Date ~~t Oq\G'~lAL . . MPc-42 I Well Name: MPC-42 Drill and Complete Plan Summary I Type of Well (service / producer / injector): 1 Kuparuk Wag Injector Surface Location: (As Staked) Target Location: Top OA Target Location: Lower Colville Target Location: Top Kuparuk D Target Location: BHL Well TD Distance to Property line Distance to nearest pool 1231' FSL, 2255' FEL, SEC. 10, T13N, R10E / E=558203.88 N=6029513.38 ... 3262' FSL, 1707' FEL, SEC. 10, T13N, R10E E=558732 N=6031548 Z=4390' TVD SS 5016' FSL, 2643' FEL, SEC.1 0 , T13N, R10E E=557780 N=6033295 Z=6500' TVD SS 5247' FSL, 2766' FEL, SEC.10 , T13N, R10E E=557655 N=6033525 Z= 7148' TVD SS 151' FSL, 2864' FEL, SEC. 03 , T13N, R10E ... E=557555 N=6033708 Z=7402' TVD SS 8300' 1550' from MPC-03 I AFE Number: 1 I 1 Rig: 1 Doyon 14 Estimated Start Date: 116 Feb 2004 1 I Operating days to complete: 118 MD: 18955' 'I I TVD: 17452' '"" 1 Max Inc: 147 1 I KOP: 1350' I I KBE:50' Well Design (conventional, slimhole, etc.): 1 Slimhole Objective: 1 Kuparuk "A" , Mud Program: 13-1/2 Suñace hole (0-5811'): Fresh Water Surface hole mud Densitv Viscosity Yield Point API FL (ppg) (sec/qt.) (Lb/100ft) cc/30min Initial 8.6-9.5 250-300 45-70 NC m:! 9.0-9.5 9-7/8" First Intermediate Hole (5811- 8318'): Density (ppg PV YP HTHP 9.0 - 9.5 10 - 20 25 - 30 10- 11 LSND pH API Filtrate LG Solids 9.0 - 9.5 < 6 < 15 6-3/4" Second Intermediate Hole (8318' - 8547'): ¡/ LSND Density (ppg PV YP HTHP I pH API Filtrate LG Solids I ~ - 13.0 10 - 20 25 - 30 10 - 11 9.0 - 9.5 < 6 < 15 4-3/4" Production Hole (8547- 8955'): Density (ppg PV YP 9.1-9.3 10-20 25-30 LSND HTHP pH API Filtrate LG Solids 10- 11 9.0 - 9.5 < 6 < 15 LCM Restrictions: No Restrictions. Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 05-4 disposal site" Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. 7 Cement Program: . . MPc-42 Casin~ Size 110-3/4" 45.5-lb/ft L-80 BTC-M Surface Casing First Stage B . 40% Excess for Tail Slurry, aSls Gauge hole below To ES Cementer (-1900') for Lead Slurry Total Cement Volume: 275-bbl Wash 20-bbl water Spacer 40-bbl 1 0.2-lb/gal Alpha Spacer Lead 221-bbl, 279-sx 10.7 Ib/gal ArcticSetLight 3 - 4.45 fe/sx T "I 54-bbl, 256-sx 15.8 Ib/gal Prem G - 1.17 felsx al (top of tail at -5,311-ft MD) Casin~ Size 110-3/4" 45.5-lb/ft L-80 BTC-M Surface Casing - Second Stage Basis 1175% excess over gauge hole in permafrost interval Total Cement Volume: 339-bbl Wash 20-bbl water Spacer Lead 40-bbl 1 0.2-lb/gal Alpha Spacer 339-bbl, 427-sx 10.7 Ib/gal ArcticSetLight 3 - 4.45 ft::S/sx (cement to surface) CaSin¡ Size 17-5/8" 29.7-lbltt L-80 BTC-M Intermediate Casing B . Top of tail cement 500-ft above Shoe. 40% excess over gauge. aSls Total Cement Volume: 31-bbl Wash 10-bbl water Spacer Tail 20-bbl 10.2-lb/gal MudPush II Spacer 31-bbl, 147-sx 15.8lb/gal Prem G -1.17felsx (top of tail at 7818-ft MD) Casing Size 15-1/2" 17-lb/ft L-80 ST-L Drilling Liner Basis 140% Excess in Open Hole, Liner Lap + 200' above Liner Top in Annulus Total Cement Volume: 15-bbl Wash 10-bbl water Spacer 1 0-bbI13.5-lb/gal MudPush II Spacer Tail 15-bbl, 70-sx 15.8 Ib/gal Prem G - 1.16 felsx Casin~ Size 13-1/2" 9.2 Ibltt L-80 BTC Production Liner Basis 140% Excess in Open Hole, Liner Lap + 200' above Liner Top in Annulus Total Cement Volume: 20 bbl Wash 5-bbl water Spacer Lead Temp 5-bbl 1 0.2-lb/gal Alpha Spacer (Alpha) 20-bbl, 97-sx 15.8 Ib/gal Prem G - 1.16 felsx BHST ::::85°F from SOR 8 . . MPC-42 Evaluation Program: 13-1/2" Section , Open Hole: MWD/GRlRES IFRlCASANDRA Photo Gyro as required. Sperry InSite Cased Hole: N/A 9-7/8" Section , Open Hole: MWD/GRlRES/PWD IFRlCASANDRA Sperry InSite Cased Hole: N/A 6-3/4" Section Open Hole: MWD/GRlRES/PWD IFRlCASANDRA Sperry InSite Cased Hole: N/A 4-3/4" Section Open Hole: MWD/GRlRES/PWD IFRlCASANDRA Sperry InSite Cased Hole: Cement Evaluation Log 9 . . MPC-42 Formation Markers: v""¥ Formation Tops MDrkb TVDrkb (ft) Pore Pr~ssure Estimated EMW (ft) (pSI) (Ib/gal)* BPRF 1816 1750 -738 8.35 TUZC 4280 3820 -1637 8.35 SSF2-NA 4860 4290 -1841 8.35 SBA5 5239 4560 -1958 8.35 THRZ 8181 6702 8.35 BHRZ 8272 6786 8.35- KLGM 8313 6825 -4404 12.50 ~.' TKUD 8433 6940 -4479 12.50 ' TKUC 8568 7070 -2409 to -3176 6.6-8.7 ,,' TKUB 8578 7080 -2413to-3180 6.6-8.7 TKUA 8700 7200 -2342 to -2863 6.3-7.7 TKA3 8707 7207 -2345 to -2866 6.3-7.7 TKA2 8724 7224 -2350 to -2872 6.3-7.7 TKA1 8770 7269 -2365 to -2890 6.3-7.7 TMLV 8806 7305 -2377 to -2905 6.3-7.7 TD CasingITubing Program: Hole Csg WtJ Grade Conn Burst Collapse Length Top Bottom Size Diam Ft MDITVDrkb MDITVDrkb 20-in 92 H-40 Weld 1,530 520 112-ft 0 112'/112' 13.5-in 10.75 45.5 L-80 BTC-M 2,480 5,210 5,811' 0 5,811 '/4,950' 9.875-in 7.625-in 29.7 L-80 BTC-M 6,890 4,790 8,318' 0 8,318'/6,830' 6.75 5.5-in 17 L-80 ST-L 7,740 6,280 329' 8,218'/6735 8,547'/7,050' 4.75 3.5-in 9.2 L-80 ST-L 10,160 10,530 837' 8,118'/6643 8,955'/7,451 ' Tubing 4.5-in 12.6 L-80 1ST 8,430 7,500 8,100 0 8,100'/6627' Recommended Bit Program: BHA 1 2 3 4 Hole Size 13-1/2" 9-78" 6-3/4" 4-3/4" Depth (MD) o - 5811 ' 5811' - 8318' 8318' - 8547' 8547' - 8955' Bit Type Mill Tooth Mill Tooth Mill Tooth TCI Nozzle/Flow rate 10 . . MPC-42 Well Control: Surface Interval Surface hole will be drilled with a diverter. Intermediate hole: · Maximum anticipated BHP: 4,479-psi @ 6,940-ft TVDrkb - Base of Kalubik · Maximum surface pressure: f 3,785-psi @ surface (Based on BlIP and a full column of gas from TD @ O.l-psi/ft) · Planned BOP test pressure: 4,000-psi. · Integrity test: An FIT to l1.0-lb/gal at the 10-314" casing shoe. Kick tolerance: 74-bbl with 9.5-lb/gal mud. · Integrity test: An FIT to 14.0-lb/gal at the 7-5/8" casing shoe. Kick tolerance: Infinite bbl with 13.0-lb/gal mud. · Integrity test: An FIT to l1.0-lb/gal at the 5-112" casing shoe. Kick tolerance: Infinite bbl with 9.5-lb/gal mud. · Planned completion fluid: Seawater 1 7.0-lb/gal Diesel (1 ,800-ft tvd). Drilling Hazards & Contingencies: · No drilling problems related to the hydrates were reported. /' · Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation · We do not expect losses while drilling this well. · Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures · It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. pressure is expected to be (8.3§ Ib/gal EMW). In this well, the Schrader Bluff formation will be drilled with 9.3-lb/gal mud. · Overpressure is not expected to the first intermediate casing point (7-5/8") above the Kalubik silts. Estimated pore pressures are 8.35 ppg EMW."" The casing point for this interval is critical; not go too deep and encounter the overpressure, yet get deep enough to obtain sufficient FIT and cover the breathing prone Colville to allow control of the pressure in the next interval. /. Overpressure is expected in the second intermediate interval. This interval will be drilled with ........ 13.0 ppg mud. This casing point is also critical in that it must cover the over-pressured interval to aIJow reducing the MW in the next interval. · Sub-normal pressure (6.3-7.7 ppg EMW) is expected in the production interval. It '" Pad Data Sheet 11 . . MPC-42 · Please Read the C-Pad Data Sheet thoroughly. Breathing · Low probability if ECD < 11.5 ppg EMW in the Colville section. Hydrocarbons · Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Faults · Two faults are expected in the Colville interval, one in the upper (-5723' MD) and one in the lower (-7826'). Neither are expected to be problematic. Hydrogen Sulfide · MPC Pad is not designated as an H2S Pad. C-Pad wells <1 O-ppm H2S on the 2004 report.- Anti-collision Issues · MPC-42 passes the Major Risk Criteria. Distance to Nearest Property · MPC-42 is 8,300 -ft from the nearest Milne Point property line. Distance to Nearest Well Within Pool · MPC-42 is 1 ,500-ft from the Kuparuk sand penetration in MPC-03. 12 . . MPC-42 DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1. Install starting head on 20-in conductor. DrillinQ 1. MIRU Doyon 14, NU diverter. 2. Drill 13.5-in hole to surface casing point as per directional plan. 3. Rig up and run 10-3/4 in casing and cement in place. 4. NO diverter. NU BOPE. 5. Drill 9.875-in hole to Interval TO as per directional plan. 6. Rig up and run 7.625 in casing and cement in place. 7. Drill to 6.75" Interval TO as per directional plan. 8. Rig up and run 5.5 in Liner and cement in place. 9. Drill to 4.75" Interval TO as per directional plan. 10. Rig up and run 3.5 in Liner and cement in place. 11. RU and Run 4.5" Completion. (Packer Will be Set -600' above injected zone to facilitate the drilling liner for the over-pressured Kalubik)" Commission approval of packer> 200' above top perforations is sought. 12. NO BOP/NU Tree 13. Set packer, Freeze Protect. 14. RDMO Doyon 14. Post RiQ 1. Run cement evaluation log. 2. Perforate. 13 ~ COMPANY DETAILS BP Amoco CakuJation Method; Minimum Curvature Error System: ISCWSA Scan Method: Trav Cylinder North Error Surface: ElJiptical + Casing Wamin.ll; Method: Rules Based cr- Start Dir 1.5/100': 350' MD, 350'TVD Start Dir 2.5/100' : 750' MD, 749.27'TVD EndDir : 1815.53'MD,1750'TVD ~\: Start Dir 3/100': 2206.88' MD, 2086.36'TVD End Dir : 2296.47' MD, 2162.31'TVD " â o o ~ ..c Õ. Ö .. Q i :> Æ REFERENCE INFORMA nON SURVEY PROGRAM Plan: MPC-42 wp06 (plan Lily MPC·42lP1an MPC-42) Co-ordinate (NÆ) Reference: Well Centre; Pian Lily MPC-42, True Nortb Depth Fro Depth To SurveylPlan Tool Created By: Ken Allen Date: 1/23/2004 V~~1:=~=:~ ~?~~(~J1.~t)SO.oo 33.70 1000.00 Plamed: MPC-42 wp06 Vl6 CB-GYRO-SS Checked: Date:_ Meas~a~;~~=~ ~;D'f::~~ 50.00 woo.oo 8955.80 Planned: MPC42 wp06 V16 MWD+IFR+MS Reviewed: Date:_ CASING DETAILS WELL DETAILS N~ +N/·S +EI-W Northing Easting Latitude Longitude Slot No. TVD MD Name Size Plan Lily MPC-42 2158.72 143.67 602950718 558184.84 7()"29'28.43IN 149"31'21.594W N/A 1 4950.00 5811.07 103/4" 10.750 TARGET DETAILS 2 6830.00 8318.27 7 5/8" 7.625 3 7050.00 8547.29 5 1/2" 5.500 N,"'" TVD +"'"" +E!-W Northing Ea!oiing Shape 4 7451.90 8955.79 3 1/2" 3.500 MPC42 A 4440.00 203657 563.17 6031548.00 558732.00 Point MPC-12B F1t#la 5950.00 3526.16 -38230 6033030.00 557775.00 Polygon MPC42B 6450.00 3791.14 -37522 6033295.00 557780.00 Point FORMATION TOP DETAILS MPC·I2B C 7198.00 4022.13 498.43 6033525.00 557655.00 Circle (Radius: 20() MPC-12B F1t#lb 7450.00 3517.86 677.77 6033030.00 558835.00 Polygon No. TVDPath MDPath Formation SECTION DETAILS 1 1750.00 1815.53 BPRF 2 3820.00 4280.48 ruzc Sec MD Inc Azi TVD +N/-S +EI-W DLeg TFace VSec Target 3 4290.00 4860.47 SBF2-NA 4 4560.00 5239.22 SBA5 1 33.70 0.00 0.00 33.70 0.00 0.00 0.00 0.00 0.00 5 6702.00 8181.58 THRZ 2 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 6 6786.00 8271.61 BHRZ 3 750.00 6.00 40.00 749.27 16.03 13.45 1.50 40.00 14.20 7 6825.00 8312.98 KLGM 4 1528.54 25.00 20.00 1496.40 203.60 96.67 2.50 334.29 189.71 8 6940.00 8433.58 TKUD 5 1815.53 30.74 20.00 1750.00 329.61 142.54 2.00 0.00 308.90 9 7070.00 8567.81 TKUC 6 1931.88 30.74 20.00 1850.00 385.50 162.88 0.00 0.00 361.76 10 7080.00 8578.06 TKUB 7 2206.88 30.74 20.00 2086.36 517.58 210.95 0.00 0.00 486.69 . 11 7200.00 8700.33 TKUA 8 2296.47 33.33 21.36 2162.31 562.03 227.75 3.00 16.14 528.65 12 7207.00 8707.43 TKA3 9 4250.99 33.33 21.36 3795.36 1562.18 618.90 0.00 0.00 1471.20 13 7224.00 8724.67 TKA2 10 5064.19 45.00 331.86 4440.00 2036.57 563.17 4.00 ·90.51 1948.83 MPC-42 A 14 7269.00 8770.31 TKAI 11 5114.20 47.00 331.86 4474.74 2068.30 546.20 4.00 0.02 1982.45 15 7305.00 8806.82 TMLV 12 7181.98 47.00 331.86 5884.95 3401.84 -167.02 0.00 0.00 3395.60 13 7902.00 29.00 331.86 6450.00 3791.14 -375.22 2.50 -180.00 3808.13 MPC-42 B 14 8698.30 9.58 332.12 7198.00 4022.13 -498.43 2.44 179.87 4052.87 MPC-12B C 15 8805.80 9.58 332.12 7304.00 4037.94 -506.80 0.00 0.00 4069.61 16 8955.80 9.58 332.12 7451.91 4060.01 -518.47 0.00 0.00 4092.98 End Dir : 5114.2' MD, 4474.74' TVD Start Dir4/100': 4250.99' MD, 3795.36'TVD 600cr- Start Dir 2.5/100': 7181.98' MD, 5884.95'TVD 0 ¡r! I . I ¡ß I I 1fP ,I JfP '/~ 7902' MD, 6450'TVD \6° 51/2" End Dir ; 8698.3' MD, 7198' TVD 8955.8'MD,7451.91'TVD I r I J , I I 4800 I I I I I I I I I I 6000 Vertical Section at 352.72° [1200ftlin] COMPANY DETAILS REFERENCE INFORMATION Co-ordinale (NÆ) Reference: Well Centre: Plan Li]y MPC42, True North Vertiçal (fVD) Reference: SO' KB MPC12 Lily 50.00 Section (VS) Reference: S]ot- (O.OON,O.OOE) Measured Depth Reference: 50' KB MPCI2 Li]y 50.00 Calcu]ation Method: Minimwn Curvature BpIII"'I""V-1ILn ~·~\1J.;.·~·!;~!;_~~!!!y.r~"·M BP Amoco Calculation Method: Minimwn Curvature Enor System: ISCWSA ScanMetbcxJ: Tl1lvCy]inderNorth Error Surface: Elliptical + Cal:iing Waminl[ Method: Rules Based 95% conf. CASING DETAILS No. TVD MD Name 1 4950.00 5811.07 103/4" 2 6830.00 8318.27 7 5/8" 3 7050.00 8547.29 5 1/2" 4 7451.90 8955.79 3 1/2" 10.750 7.625 5.500 3.500 Size c â o o E:. +' ~ ~ £' ~ o C/) End Dir : 8698.3' MD, 7198' TVD FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 1750.00 1815.53 BPRF : 7902' MD, 6450'TVD 2 3820.00 4280.48 TUZC 3 4290.00 4860.47 SBF2-NA 4 4560.00 5239.22 SBA5 5 6702.00 8181.58 THRZ 6 6786.00 8271.61 BHRZ 7 6825.00 8312.98 KLGM 8 6940.00 8433.58 TKUD 9 7070.00 8567.81 TKUC 10 7080.00 8578.06 TKUB 11 7200.00 8700.33 TKUA 12 7207.00 8707.43 TKA3 13 7224.00 8724.67 TKAZ 14 7269.00 8770.31 TKAl 15 7305.00 8806.82 TMLV Dir : 5114.2' MD, 4474.74' TVD Dir 4/1 00' : 4250.99' MD, 3795.36'TVD 1400- I I ¡ I I 700 West(-)Æast(+) [700ft/in] , I ' 1400 I I I I I I I SURVEY PROGRAM Depth Fm Depth To SurveylPlan 33.70 IO()O.()O Planned; MPC42 wp06 V16 1000.00 8955.80 Planned: MPC-42 wp06 Vl6 Plan: MPC-42 wp06 (plan Lily MPC-42/Plan MPC-42) Tool Created By: Ken Allen Checked: Date: 1I23/20()4 CB..CJYRO-SS MWD+IFR+MS Date: Reviewed: Date WELL DETAILS N=, +NI-S +EI-W Northing Easting Latitude Longitude Slot Plan Lily MPC-42 2158.72 143.67 6029507.28 558184.84 7()029'28.431N 149"31'27.594W NlA TARGET DETAILS N"", TVD +NI-S +EI-W Northing Basting Shape MPC-42A 4440.00 2036.57 563.17 6031548.00 558732.()O Point MPC-12BF]t#la 5950.00 3526.16 -382.30 6033030.00 557775.0() Polygon MPC-42B 6450.00 379Ll4 -37522 6033295.00 557780.00 Point MPC-12B C 7198.00 4022.13 498.43 6033525.00 557655.00 Circ1e(Radius:200) MPC-J2B Flt#lb 7450.00 3517.86 677.77 6033030.00 558835.00 Polygon SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFaee VSee Target 1 33.70 0.00 0.00 33.70 0.00 0.00 0.00 0.00 0.00 2 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 3 750.00 6.00 40.00 749.27 16.03 13.45 1.50 40.00 14.20 4 1528.54 25.00 20.00 1496.40 203.60 96.67 2.50 334.29 189.71 5 1815.53 30.74 20.00 1750.00 329.61 142.54 2.00 0.00 308.90 6 1931.88 30.74 20.00 1850.00 385.50 162.88 0.00 0.00 361.76 7 2206.88 30.74 20.00 2086.36 517.58 210.95 0.00 0.00 486.69 . 8 2296.47 33.33 21.36 2162.31 562.03 227.75 3.00 16.14 528.65 9 4250.99 33.33 21.36 3795.36 1562.18 618.90 0.00 0.00 1471.20 10 5064.19 45.00 331.86 4440.00 2036.57 563.17 4.00 -90.51 1948.83 MPC·42 A 11 5114.20 47.00 331.86 4474.74 2068.30 546.20 4.00 0.02 1982.45 12 7181.98 47.00 331.86 5884.95 3401.84 -167.02 0.00 0.00 3395.60 13 7902.00 29.00 331.86 6450.00 3791.14 -375.22 2.50 -180.00 3808.13 MPC-42 B 14 8698.30 9.58 332.12 7198.00 4022.13 -498.43 2.44 179.87 4052.87 MPC-12B C 15 8805.80 9.58 332.12 7304.00 4037.94 -506.80 0.00 0.00 4069.61 16 8955.80 9.58 332.12 7451.91 4060.01 -518.47 0.00 0.00 4092.98 o . l ,I ,I ~ I I ,pP I ¿! 6ò~ ~ j(~ .Y~O '" /~~ ~ '/~ "tLU.lJøt~TON C,I.W>Ø'..\N\' . Sperry-Sun - Draft Copy KW A Planning . spe¡-,¡-,y-sun DRIL.L.ING seRVIc:es Plan: MPC-42 wp06 Date Composed: Version: Tied-to: 1/8/2004 16 From Well Ref. Point Principal: Yes Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: M pt C Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6027347.71 ft 558058.04 ft Latitude: 70 29 Longitude: 149 31 North Reference: Grid Convergence: 7.200 N 31.821 W True 0.45 deg Well: Plan Lily MPC-42 Slot Name: Well Position: +N/-S 2158.72 ft Northing: 6029507.28 ft +E/-W 143.67 ft Easting: 558184.84 ft Position Uncertainty: 0.00 ft Latitude: Longitude: 70 29 28.431 N 149 31 27.594 W Wellpath: Plan MPC-42 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Well Ref. Point 33.70 ft Mean Sea Level 25.33 deg 80.88 deg Direction deg 352.72 Current Datum: Magnetic Data: Field Strength: Vertical Section: 50' KB MPC12 Lily 6/4/2003 57535 nT Depth From (TVD) ft 33.70 Height 50.00 ft Casing Points 5811.07 4950.00 10.750 13.500 10314" 8318.27 6830.00 7.625 9.875 7 5/8" 8547.29 7050.00 5.500 6.750 5 1/2" 8955.79 7451.90 3.500 4.750 31/2" Formations 1815.53 1750.00 BPRF 4280.48 3820.00 TUZC 4860.47 4290.00 SBF2-NA 5239.22 4560.00 SBA5 8181.58 6702.00 THRZ 8271.61 6786.00 BHRZ 8312.98 6825.00 KLGM 8433.58 6940.00 TKUD 8567.81 7070.00 TKUC 8578.06 7080.00 TKUB 8700.33 7200.00 TKUA 8707.43 7207.00 TKA3 8724.67 7224.00 TKA2 8770.31 7269.00 TKA1 8806.82 7305.00 TMLV 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 A H.U.LJIMJIUON CQMP.v<"'i . Sperry-Sun - Draft Copy KW A Planning . spe..........y-sun DRILLING SERVIc:eS Targets MPC-42 A 4440.00 2036.57 563.17 6031548.00 558732.00 70 29 48.460 N 149 31 11.017 W -Plan hit target MPC-12B Flt#1a 5950.00 3526.16 -382.30 6033030.00 557775.00 70 30 3.109 N 149 31 38.849 W -Polygon 1 5950.00 3526.16 -382.30 6033030.00 557775.00 70 30 3.109 N 149 31 38.849 W -Polygon 2 5950.00 2619.79 -859.48 6032120.01 557304.97 70 2954.195 N 149 31 52.895 W -Plan out by 194.94 at 5950.00 3460.90 -198.60 6032966.19 557959.18 70 30 2.468 N 149 31 33.441 W MPC-42 B 6450.00 3791.14 -375.22 6033295.00 557780.00 70 30 5.715 N 149 31 38.641 W -Plan hit target MPC-12B C 7198.00 4022.13 -498.43 6033525.00 557655.00 70 30 7.987 N 149 31 42.269 W -Circle (Radius: 200) -Plan hit target MPC-12B Flt#1b 7450.00 3517.86 677.77 6033030.00 558835.00 70 30 3.028 N 149 31 7.639 W -Polygon 1 7450.00 3517.86 677.77 6033030.00 558835.00 70 30 3.028 N 149 31 7.639 W -Polygon 2 7450.00 2613.42 -44.43 6032120.02 558119.97 70 29 54.133 N 149 31 28.902 W -Plan out by 1313.11 at 7450.00 4059.72 -518.32 6033562.43 557634.82 70 30 8.357 N 149 31 42.855 W Plan Section Information 33.70 0.00 0.00 33.70 0.00 0.00 0.00 0.00 0.00 0.00 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 0.00 750.00 6.00 40.00 749.27 16.03 13.45 1.50 1.50 0.00 40.00 1528.54 25.00 20.00 1496.40 203.60 96.67 2.50 2.44 -2.57 334.29 1815.53 30.74 20.00 1750.00 329.61 142.54 2.00 2.00 0.00 0.00 1931.88 30.74 20.00 1850.00 385.50 162.88 0.00 0.00 0.00 0.00 2206.88 30.74 20.00 2086.36 517.58 210.95 0.00 0.00 0.00 0.00 2296.47 33.33 21.36 2162.31 562.03 227.75 3.00 2.89 1.52 16.14 4250.99 33.33 21.36 3795.36 1562.18 618.90 0.00 0.00 0.00 0.00 5064.19 45.00 331.86 4440.00 2036.57 563.17 4.00 1.44 -6.09 -90.51 MPC-42 A 5114.20 47.00 331.86 4474.74 2068.30 546.20 4.00 4.00 0.00 0.02 7181.98 47.00 331.86 5884.95 3401.84 -167.02 0.00 0.00 0.00 0.00 7902.00 29.00 331.86 6450.00 3791.14 -375.22 2.50 -2.50 0.00 -180.00 MPC-42 B 8698.30 9.58 332.12 7198.00 4022.13 -498.43 2.44 -2.44 0.03 179.87 MPC-12B C 8805.80 9.58 332.12 7304.00 4037.94 -506.80 0.00 0.00 0.00 0.00 8955.80 9.58 332.12 7451.91 4060.01 -518.47 0.00 0.00 0.00 0.00 Survey 33.70 0.00 0.00 33.70 -16.30 6029507.28 558184.84 0.00 0.00 0.00 0.00 CB-GYRO-S~ 100.00 0.00 0.00 100.00 50.00 6029507.28 558184.84 0.00 0.00 0.00 0.00 CB-GYRO-S~ 200.00 0.00 0.00 200.00 150.00 6029507.28 558184.84 0.00 0.00 0.00 0.00 CB-GYRO-S~ 300.00 0.00 0.00 300.00 250.00 6029507.28 558184.84 0.00 0.00 0.00 0.00 CB-GYRO-S~ 350.00 0.00 0.00 350.00 300.00 6029507.28 558184.84 0.00 0.00 0.00 0.00 CB-GYRO-S~ 400.00 0.75 40.00 400.00 350.00 6029507.53 558185.05 0.22 0.33 1.50 0.00 CB-GYRO-S~ 500.00 2.25 40.00 499.96 449.96 6029509.55 558186.72 2.00 2.94 1.50 0.00 CB-GYRO-S~ 600.00 3.75 40.00 599.82 549.82 6029513.59 558190.05 5.55 8.18 1.50 360.00 CB-GYRO-S~ 700.00 5.25 40.00 699.51 649.51 6029519.63 558195.04 10.87 16.02 1.50 0.00 CB-GYRO-S~ 750.00 6.00 40.00 749.27 699.27 6029523.41 558198.16 14.20 20.92 1.50 0.00 CB-GYRO-S~ 800.00 7.15 35.64 798.94 748.94 6029527.97 558201.62 18.25 26.65 2.50 334.29 CB-GYRO-S~ 900.00 9.52 30.12 897.88 847.88 6029540.24 558209.30 29.37 41.14 2.50 338.63 CB-GYRO-S~ 1000.00 11.94 26.81 996.12 946.12 6029556.69 558217.98 44.51 59.76 2.50 344.08 CB-GYRO-S~ 1100.00 14.39 24.60 1093.49 1043.49 6029577.30 558227.66 63.64 82.53 2.50 347.34 MWD+IFR+IIIS 1200.00 16.86 23.03 1189.79 1139.79 6029602.03 558238.32 86.71 1 09.46 2.50 349.49 MWD+IFR+III S 1300.00 19.33 21.85 1284.84 1234.84 6029630.83 558249.92 113.69 140.51 2.50 351.00 MWD+IFR+III S 1400.00 21.81 20.93 1378.45 1328.45 6029663.64 558262.46 144.52 175.64 2.50 352.13 MWD+IFR+III S 1500.00 24.29 20.19 1470.46 1420.46 6029700.40 558275.91 179.14 214.79 2.50 352.99 MWD+IFR+III S 1528.54 25.00 20.00 1496.40 1446.40 6029711.61 558279.91 189.71 226.69 2.50 353.67 MWD+IFR+ III S AJt.U.UM'RTON("QMf'~ . Sperry-Sun - Draft Copy KW A Planning . =at;.n=1 ·...,y-sun DFlILLINIi seFlVlc:es Survey 1600.00 26.43 20.00 1560.79 1510.79 6029740.82 558290.28 217.27 257.70 2.00 0.00 MWD+IFR+1I13 1700.00 28.43 20.00 1649.54 1599.54 6029784.23 558305.70 258.21 303.76 2.00 0.00 MWD+IFR+1I13 1800.00 30.43 20.00 1736.63 1686.63 6029830.52 558322.14 301.88 352.89 2.00 360.00 MWD+IFR+1I13 1815.53 30.74 20.00 1750.00 1700.00 6029837.97 558324.78 308.90 360.80 2.00 0.00 BPRF 1900.00 30.74 20.00 1822.60 1772.60 6029878.65 558339.23 347.28 403.97 0.00 180.00 MWD+IFR+ 1113 1931.88 30.74 20.00 1850.00 1800.00 6029894.00 558344.68 361.76 420.27 0.00 180.00 MWD+IFR+1I13 2000.00 30.74 20.00 1908.55 1858.55 6029926.81 558356.33 392.71 455.09 0.00 180.00 MWD+IFR+ 1113 2100.00 30.74 20.00 1994.50 1944.50 6029974.97 558373.44 438.14 506.20 0.00 180.00 MWD+IFR+ 1113 2206.88 30.74 20.00 2086.36 2036.36 6030026.45 558391.72 486.69 560.83 0.00 180.00 MWD+IFR+1I13 2296.47 33.33 21.36 2162.31 2112.31 6030071.02 558408.17 528.65 608.35 3.00 16.14 MWD+IFR+ 1113 2300.00 33.33 21.36 2165.26 2115.26 6030072.83 558408.86 530.36 610.29 0.00 0.00 MWD+IFR+1I13 2400.00 33.33 21.36 2248.81 2198.81 6030124.15 558428.47 578.58 665.23 0.00 0.00 MWD+IFR+ 1113 2500.00 33.33 21.36 2332.36 2282.36 6030175.48 558448.08 626.80 720.18 0.00 0.00 MWD+IFR+1I13 2600.00 33.33 21.36 2415.91 2365.91 6030226.80 558467.69 675.03 775.12 0.00 0.00 MWD+IFR+ 1113 2700.00 33.33 21.36 2499.47 2449.47 6030278.12 558487.30 723.25 830.07 0.00 0.00 MWD+IFR+ 1113 2800.00 33.33 21.36 2583.02 2533.02 6030329.44 558506.91 771.47 885.01 0.00 0.00 MWD+IFR+1I13 2900.00 33.33 21.36 2666.57 2616.57 6030380.76 558526.52 819.70 939.96 0.00 0.00 MWD+IFR+1I13 3000.00 33.33 21.36 2750.12 2700.12 6030432.08 558546.13 867.92 994.90 0.00 0.00 MWD+IFR+1I13 3100.00 33.33 21.36 2833.68 2783.68 6030483.40 558565.73 916.14 1049.85 0.00 0.00 MWD+IFR+1I13 3200.00 33.33 21.36 2917.23 2867.23 6030534.72 558585.34 964.37 1104.79 0.00 0.00 MWD+IFR+1I13 3300.00 33.33 21.36 3000.78 2950.78 6030586.04 558604.95 1012.59 1159.74 0.00 0.00 MWD+IFR+ 1113 3400.00 33.33 21.36 3084.33 3034.33 6030637.36 558624.56 1060.82 1214.68 0.00 0.00 MWD+IFR+1I13 3500.00 33.33 21.36 3167.89 3117.89 6030688.69 558644.17 1109.04 1269.63 0.00 0.00 MWD+IFR+ 1113 3600.00 33.33 21.36 3251.44 3201.44 6030740.01 558663.78 1157.26 1324.57 0.00 0.00 MWD+IFR+ 1113 3700.00 33.33 21.36 3334.99 3284.99 6030791.33 558683.39 1205.49 1379.52 0.00 0.00 MWD+IFR+1I13 3800.00 33.33 21.36 3418.55 3368.55 6030842.65 558703.00 1253.71 1434.46 0.00 0.00 MWD+IFR+1I13 3900.00 33.33 21.36 3502.10 3452.10 6030893.97 558722.61 1301.93 1489.41 0.00 0.00 MWD+IFR+1I13 4000.00 33.33 21.36 3585.65 3535.65 6030945.29 558742.22 1350.16 1544.35 0.00 0.00 MWD+IFR+ 1113 4100.00 33.33 21.36 3669.20 3619.20 6030996.61 558761.83 1398.38 1599.30 0.00 0.00 MWD+IFR+1I13 4200.00 33.33 21.36 3752.76 3702.76 6031047.93 558781.44 1446.60 1654.24 0.00 0.00 MWD+IFR+1I13 4250.99 33.33 21.36 3795.36 3745.36 6031074.10 558791.44 1471.20 1682.26 0.00 0.00 MWD+IFR+1I13 4280.48 33.34 19.21 3820.00 3770.00 6031089.34 558796.93 1485.56 1698.47 4.00 269.49 TUZC 4300.00 33.36 17.79 3836.30 3786.30 6031099.54 558800.26 1495.22 1709.20 4.00 271.28 MWD+IFR+1I13 4400.00 33.74 10.59 3919.68 3869.68 6031153.15 558813.35 1546.58 1764.47 4.00 272.47 MWD+IFR+ 1113 4500.00 34.53 3.60 4002.47 3952.47 6031208.81 558819.80 1600.88 1820.59 4.00 278.47 MWD+IFR+1I13 4600.00 35.70 356.94 4084.30 4034.30 6031266.25 558819.57 1657.84 1878.12 4.00 284.26 MWD+IFR+1I13 4700.00 37.22 350.71 4164.75 4114.75 6031325.20 558812.67 1717.19 1937.54 4.00 289.71 MWD+IFR+1I13 4800.00 39.04 344.94 4243.44 4193.44 6031385.37 558799.13 1778.64 1999.28 4.00 294.72 MWD+IFR+1I13 4860.47 40.27 341.67 4290.00 4240.00 6031422.23 558787.74 1816.69 2037.87 4.00 299.27 SBF2-NA 4900.00 41.12 339.63 4319.97 4269.97 6031446.47 558779.01 1841.89 2063.64 4.00 301.78 MWD+IFR+1I13 5000.00 43.42 334.76 4393.99 4343.99 6031508.19 558752.42 1906.63 2130.90 4.00 303.33 MWD+IFR+1I13 5064.19 45.00 331.86 4440.00 4390.00 6031548.00 558732.00 1948.83 2175.65 4.00 306.93 MPC-42A 5100.00 46.43 331.86 4465.00 4415.00 6031570.51 558719.73 1972.78 2201.29 4.00 0.02 MWD+IFR+1I13 5114.20 47.00 331.86 4474.74 4424.74 6031579.59 558714.79 1982.45 2211.63 4.00 0.02 MWD+IFR+1I13 5200.00 47.00 331.86 4533.25 4483.25 6031634.68 558684.76 2041.08 2274.38 0.00 0.00 MWD+IFR+1I13 5239.22 47.00 331.86 4560.00 4510.00 6031659.86 558671.04 2067.88 2303.06 0.00 0.00 SBA5 5300.00 47.00 331.86 4601.45 4551.45 6031698.90 558649.77 2109.42 2347.51 0.00 0.00 MWD+IFR+1I13 5400.00 47.00 331.86 4669.65 4619.65 6031763.11 558614.78 2177.76 2420.65 0.00 0.00 MWD+IFR+1I13 5500.00 47.00 331.86 4737.85 4687.85 6031827.32 558579.79 2246.11 2493.79 0.00 0.00 MWD+IFR+1I13 5600.00 47.00 331.86 4806.05 4756.05 6031891.54 558544.80 2314.45 2566.92 0.00 0.00 MWD+IFR+1I13 5700.00 47.00 331.86 4874.25 4824.25 6031955.75 558509.80 2382.79 2640.06 0.00 0.00 MWD+IFR+1I13 5800.00 47.00 331.86 4942.45 4892.45 6032019.96 558474.81 2451.13 2713.19 0.00 0.00 MWD+IFR+1I13 " t!.\UJ81TJilTOl< ("mw~ . Sperry-Sun - Draft Copy KW A Planning . =....=1 '1 ·y-sun DRILLING $ERVIC:E$ Survey 5811.07 47.00 331.86 4950.00 4900.00 6032027.07 558470.94 2458.70 2721.29 0.00 0.00 10 3/4" 5900.00 47.00 331.86 5010.65 4960.65 6032084.18 558439.82 2519.47 2786.33 0.00 0.00 MWD+IFR+1I13 6000.00 47.00 331.86 5078.85 5028.85 6032148.39 558404.83 2587.81 2859.47 0.00 0.00 MWD+IFR+1I13 6100.00 47.00 331.86 5147.05 5097.05 6032212.61 558369.83 2656.15 2932.60 0.00 0.00 MWD+IFR+ 1113 6200.00 47.00 331.86 5215.24 5165.24 6032276.82 558334.84 2724.50 3005.74 0.00 0.00 MWD+IFR+1I13 6300.00 47.00 331.86 5283.44 5233.44 6032341.03 558299.85 2792.84 3078.87 0.00 0.00 MWD+IFR+ 1113 6400.00 47.00 331.86 5351.64 5301.64 6032405.25 558264.86 2861.18 3152.01 0.00 0.00 MWD+IFR+1I13 6500.00 47.00 331.86 5419.84 5369.84 6032469.46 558229.87 2929.52 3225.15 0.00 0.00 MWD+IFR+1I13 6600.00 47.00 331.86 5488.04 5438.04 6032533.67 558194.87 2997.86 3298.28 0.00 0.00 MWD+IFR+1I13 6700.00 47.00 331.86 5556.24 5506.24 6032597.89 558159.88 3066.20 3371.42 0.00 0.00 MWD+IFR+ 1113 6800.00 47.00 331.86 5624.44 5574.44 6032662.10 558124.89 3134.55 3444.55 0.00 0.00 MWD+IFR+1I13 6900.00 47.00 331.86 5692.64 5642.64 6032726.32 558089.90 3202.89 3517.69 0.00 0.00 MWD+IFR+1I13 7000.00 47.00 331.86 5760.84 5710.84 6032790.53 558054.90 3271.23 3590.83 0.00 0.00 MWD+IFR+1I13 7100.00 47.00 331.86 5829.04 5779.04 6032854.74 558019.91 3339.57 3663.96 0.00 0.00 MWD+IFR+1I13 7181.98 47.00 331.86 5884.95 5834.95 6032907.39 557991.23 3395.60 3723.92 0.00 0.00 MWD+IFR+1I13 7200.00 46.55 331.86 5897.29 5847.29 6032918.91 557984.94 3407.87 3737.05 2.50 180.00 MWD+IFR+ 1113 7275.35 44.67 331.86 5950.00 5900.00 6032966.19 557959.18 3458.18 3790.90 2.50 180.00 MPC-12B Fljj1a 7300.00 44.05 331.86 5967.62 5917.62 6032981.32 557950.94 3474.28 3808.13 2.50 180.00 MWD+IFR+ 1113 7400.00 41.55 331.86 6040.99 5990.99 6033040.97 557918.43 3537.77 3876.06 2.50 180.00 MWD+IFR+ 1113 7500.00 39.05 331.86 6117.25 6067.25 6033097.75 557887.49 3598.20 3940.74 2.50 180.00 MWD+IFR+1I13 7600.00 36.55 331.86 6196.26 6146.26 6033151.56 557858.17 3655.47 4002.02 2.50 180.00 MWD+IFR+ 1113 7700.00 34.05 331.86 6277.86 6227.86 6033202.29 557830.52 3709.46 4059.81 2.50 180.00 MWD+IFR+1I13 7800.00 31.55 331.86 6361.91 6311.91 6033249.85 557804.60 3760.08 4113.97 2.50 180.00 MWD+IFR+1I13 7902.00 29.00 331.86 6450.00 6400.00 6033295.00 557780.00 3808.13 4165.39 2.50 180.00 MPC-42 B 8000.00 26.61 331.87 6536.67 6486.67 6033335.13 557758.13 3850.84 4211.10 2.44 179.87 MWD+IFR+1I13 8100.00 24.17 331.89 6627.01 6577.01 6033372.78 557737.63 3890.91 4253.98 2.44 179.86 MWD+IFR+ 1113 8181.58 22.18 331.90 6702.00 6652.00 6033400.98 557722.29 3920.92 4286.08 2.44 179.85 THRZ 8200.00 21.73 331.90 6719.08 6669.08 6033407.03 557719.00 3927.35 4292.97 2.44 179.84 MWD+IFR+ 1113 8271.61 19.99 331.92 6786.00 6736.00 6033429.43 557706.81 3951.19 4318.47 2.44 179.83 BHRZ 8300.00 19.29 331.93 6812.74 6762.74 6033437.81 557702.26 3960.11 4328.01 2.44 179.82 MWD+IFR+ 1113 8312.98 18.98 331.93 6825.00 6775.00 6033441.55 557700.23 3964.09 4332.26 2.44 179.81 KLGM 8318.27 18.85 331.93 6830.00 6780.00 6033443.06 557699.41 3965.69 4333.98 2.44 179.81 75/8" 8400.00 16.85 331.95 6907.80 6857.80 6033465.07 557687.45 3989.11 4359.03 2.44 179.81 MWD+IFR+1I13 8433.58 16.04 331.96 6940.00 6890.00 6033473.42 557682.92 3998.00 4368.54 2.44 179.79 TKUD 8500.00 14.42 331.99 7004.09 6954.09 6033488.76 557674.60 4014.31 4385.98 2.44 179.78 MWD+IFR+1I13 8547.29 13.26 332.01 7050.00 7000.00 6033498.70 557669.22 4024.89 4397.29 2.44 179.75 51/2" 8567.81 12.76 332.02 7070.00 7020.00 6033502.76 557667.02 4029.22 4401.91 2.44 179.73 TKUC 8578.06 12.51 332.03 7080.00 7030.00 6033504.74 557665.95 4031.31 4404.16 2.44 179.72 TKUB 8600.00 11.98 332.04 7101.44 7051.44 6033508.83 557663.73 4035.67 4408.81 2.44 179.71 MWD+IFR+ 1113 8698.30 9.58 332.12 7198.00 7148.00 6033525.00 557655.00 4052.87 4427.19 2.44 179.70 MPC-12B C 8700.00 9.58 332.12 7199.67 7149.67 6033525.25 557654.87 4053.13 4427.47 0.00 0.00 MWD+IFR+1I13 8700.33 9.58 332.12 7200.00 7150.00 6033525.30 557654.84 4053.18 4427.53 0.00 0.00 TKUA 8707.43 9.58 332.12 7207.00 7157.00 6033526.34 557654.28 4054.29 4428.71 0.00 0.00 TKA3 8724.67 9.58 332.12 7224.00 7174.00 6033528.86 557652.92 4056.98 4431.58 0.00 0.00 TKA2 8770.31 9.58 332.12 7269.00 7219.00 6033535.55 557649.31 4064.08 4439.18 0.00 0.00 TKA1 8805.80 9.58 332.12 7304.00 7254.00 6033540.75 557646.51 4069.61 4445.08 0.00 0.00 MWD+IFR+1I13 8806.82 9.58 332.12 7305.00 7255.00 6033540.89 557646.43 4069.77 4445.25 0.00 0.00 TMLV 8900.00 9.58 332.12 7396.89 7346.89 6033554.54 557639.07 4084.29 4460.76 0.00 0.00 MWD+IFR+ 1113 8953.87 9.58 332.12 7450.00 7400.00 6033562.43 557634.82 4092.68 4469.72 0.00 0.00 MPC-12B FIt¡ 1b 8955.79 9.58 332.12 7451.90 7401.90 6033562.71 557634.66 4092.98 4470.04 0.00 0.00 31/2" 8955.80 9.58 332.12 7451.91 7401.91 6033562.72 557634.66 4092.98 4470.05 0.00 0.00 MWD+IFR+ 1113 -128 20 -80 --60 -40 -20 -20 --60 --80 -100 ANTI-COLLISION SETTINGS COMT'ANY DFTi\l! S \\'1'06 (I 00 MD Colour To MD 300 600 10000 13000 o 90 I'bn:v!PC···12 [vn \ iHU.t....'IIIUr>< /'0\1<'\" . Sperry-Sun - Draft Copy Anticollision Report . =:11-'= 'I 'Y-SLn ClRI....LING ~eRVIc:eS ObP Company: BP Amoco Field: Milne Point Reference Site: M Pt C Pad Reference Well: Plan Lily MPC-42 L Reference Wellpath: Plan MPC-42 GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 33.70 to 8955.80 ft Maximum Radius: 1092.21 ft Date: 1/23/2004 Time: 11 :51 :17 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan Lily MPC-42, True North 50' KB MPC12 Lily 50.0 Reference: Error Model: Scan Method: Error Surface: Db~ Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing II Survey Program for Definitive Wellpath Date: 6/4/2003 Validated: No Planned From To Survey I ft ft 33.70 1000.00 Planned: MPC-42 wp06 V16 1000.00 8955.80 Planned: MPC-42 wp06 V16 Version: 3 Toolcode Tool Name CB-GYRO-SS MWD+IFR+MS Camera based gyro single shots MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 5811.07 4950.00 10.750 13.500 103/4" 8318.27 6830.00 7.625 9.875 7 5/8" 8547.29 7050.00 5.500 6.750 5 1/2" 8955.79 7451.90 3.500 4.750 3 1/2" Summary < Offset Wellpath > Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft MPtCPad MPC-01 MPC-01 V1 407.42 375.00 63.94 9.46 54.48 Pass: Major Risk M Pt C Pad MPC-02 MPC-02 V1 1262.07 1300.00 123.55 34.24 89.31 Pass: Major Risk M Pt C Pad MPC-03 MPC-03 V1 1294.77 1275.00 127.34 24.33 103.00 Pass: Major Risk M Pt C Pad MPC-04 MPC-04 V1 1663.10 1650.00 266.77 50.99 215.78 Pass: Major Risk M Pt C Pad MPC-07 MPC-07 V1 395.12 400.00 248.13 11.87 236.27 Pass: Major Risk M Pt C Pad MPC-09 MPC-09 V4 491.09 500.00 192.61 11.86 180.75 Pass: Major Risk MPtCPad MPC-11 MPC-11 V1 592.91 600.00 174.49 17.79 156.70 Pass: Major Risk M Pt C Pad MPC-12 MPC-12 V9 3053.19 3500.00 355.25 100.05 255.20 Pass: Major Risk M pt C Pad MPC-12 MPC-12A V2 8017.60 8450.00 424.53 238.53 186.00 Pass: Major Risk M Pt C Pad MPC-12 MPC-12APB1 V6 8015.86 8450.00 426.67 237.41 189.26 Pass: Major Risk M Pt C Pad MPC-17 MPC-17 V1 618.39 625.00 61.19 16.70 44.49 Pass: Major Risk M Pt C Pad MPC-19 MPC-19 V1 684.47 675.00 241.48 15.30 226.18 Pass: Major Risk M Pt C Pad MPC-21 MPC-21 V1 1230.97 1250.00 68.25 22.80 45.45 Pass: Major Risk M Pt C Pad MPC-23 MPC-23 V1 329.99 325.00 229.31 6.93 222.38 Pass: Major Risk M pt C Pad MPC-24 MPC-24 V13 739.00 750.00 180.62 14.19 166.43 Pass: Major Risk M Pt C Pad MPC-25A MPC-25A V1 500.00 500.00 182.58 9.28 173.30 Pass: Major Risk M Pt C Pad MPC-25 MPC-25 V1 500.00 500.00 182.58 9.28 173.30 Pass: Major Risk M Pt C Pad MPC-25 Plan MPC-25B VO Plan: 493.22 500.00 182.47 9.12 173.34 Pass: Major Risk M Pt C Pad MPC-26 MPC-26 V5 353.49 350.00 203.24 7.36 195.88 Pass: Major Risk M Pt C Pad MPC-26 MPC-26L 1 V4 353.49 350.00 203.24 7.36 195.88 Pass: Major Risk M pt C Pad MPC-26 MPC-26L 1 PB 1 V1 353.49 350.00 203.24 7.41 195.83 Pass: Major Risk M Pt C Pad MPC-26 MPC-26L 1 PB2 V1 353.49 350.00 203.24 7.41 195.83 Pass: Major Risk M Pt C Pad MPC-26 MPC-26L 1 PB3 V1 353.49 350.00 203.24 7.41 195.83 Pass: Major Risk M Pt C Pad Plan MPC-43 RonaldcPlan MPC-43 V3 Plan: M 425.19 425.00 120.33 10.26 110.07 Pass: Major Risk Site: M Pt C Pad Well: MPC-01 Rule Assigned: Major Risk Wellpath: MPC-01 V1 Inter-Site Error: 0.00 ft I Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable I-}K~ TVD MD TVD Ref Offset TFo+AZI TFO-HS CasingIH!Ðistance Area Deviation Warning ft ft ft ft ft deg deg in ft ft ft 33.70 33.70 0.40 0.40 0.00 0.00 162.28 162.28 60.08 1.01 59.07 Pass I 58.00 58.00 25.00 25.00 0.06 0.06 162.30 162.30 60.12 1.59 58.54 Pass I 83.00 83.00 50.00 50.00 0.11 0.11 162.35 162.35 60.25 2.18 58.08 Pass 108.00 108.00 75.00 75.00 0.18 0.18 162.43 162.43 60.47 2.84 57.64 Pass 133.00 133.00 100.00 100.00 0.27 0.29 162.54 162.54 60.74 3.67 57.06 Pass 157.99 157.99 125.00 124.99 0.35 0.40 162.68 162.68 61.03 4.51 56.52 Pass 182.99 182.99 150.00 149.99 0.44 0.51 162.84 162.84 61.36 5.35 56.00 Pass 207.99 207.99 175.00 174.99 0.52 0.60 163.02 163.02 61.71 6.09 55.62 Pass MP~2 Proposed Completion . TREE: WEL LHEA D: Tu bi ng Han ger: Conductor Casing 20" 54.5 ppf, K-55 J -112' I KOP @ -400' MAX HOLE Angle -47 deg Surface Casing 10-3/4" L-80 9.875" Drift 9.950" ID I 5811' I~ WLEG - 5.5" OD ~ I ~ ~ Intermediate 1 7-5/8" L-80 6.75"Drift 6.875" ID I ·8318' ~ 3-1/2" IBT 9.6 ppf, L-80 Drilling Liner 5-1/2" L-80 4.76" Drift 4.892" ID ..4 8547' Prod. Liner 3-1/2" L-80, 9.3 ppf 2.992" ID 2.867" Drift 8955' ~ DATE 2/4/04 REV. BY COMMENTS W.o. Quay Proposed Completion DOYON14 : Orig. KB Elev. = Orig. GL Elev. = 2000'TVD 4.5" HES X-Nipple Below SB. , 4950'TVD 4.5" HES XD sliding sleeve 4.5" HES X-Nipple +/-8100' 7-5/8" x 4.5" Baker Premier Packer 4.5" HES X-Nipple 4.5" HES XN-Nipple Tie-back extension. -6' Long - 5.75" ID 4.892" ID ZXP Liner Top Packer 3-1/2" x 5-1/2" x 7-5/8" Flexlock Liner Hanger ZXP Liner Top Packer 7-5/8" X 5-1/2" HMC Liner Hanger .. 9-7/8" Hole 6830'TVD I Top Set Kalubik .. 6-3/4" Hole 17050'TVD I TopSet Kuparuk C 4-3/4" Hole .. I 7451'TVD MI' NF POINT UNIT WE.. No.: C-42 API: 50-0 ?9-XXXXX BP EXPLORATION (AK) I . 0 0 '<t W 0 + N 2400 MON C-1 _C'J -- - ~ - -- - - -- - ~~ - -~.- " ~ to r' V r-. · 19 -J l- e · z f2 4 . 3 « -! '" + MPC-43 0... 2 · · 17 Ii ~ 24. + MP~-42 25. 9 · . 1 -~- VICINITY MAP 26. · 21 I N.T.S. 23. 7 · · 11 36. 10. · 13 LEGEND 28. .20 + AS-STAKED CONDUCTOR 39. . EXISTING CONDUCTOR 8 · · 14 40. 41. 6 · · 15 5 · · 16 · 22 18. · 12 ~MON C-2 ---- r I \r I I ~~'" 'U]ði SE:c----¡g. ____ ---- ~ 1. ALASKA STATE PLANE COORDINATES ARE ALASKA ZONE 4, NAD 27. 2. GEODETIC COORDINATES ARE NAD 27. 3. PAD SCALE FACTOR IS 0.99990385. 4. HORIZONTAL AND VERTICAL CONTROL IS BASED ON MONUMENTS MPU C-1 AND MPU C-2. 5. ELEVATIONS ARE BASED ON BPX MILNE PT. DATUM (M.S.L.). 6. DATE OF SURVEY: JANUARY 1, 2004. 7. 2. REFERENCE FIELD BOOK: MP04-01 Pgs. 01-04. ---- +N800 o o o ~ ---- ---- ---- ----~ ---- MPU C-PAD ---- ---- LOCATED WITHIN PROTRACTED SEC. 10, T. 13 N., R. 10 E., UMIAT MERIDIAN, WELL A.S.P. PLANT GEODETIC GEODETIC PAD NO. COORDINA TES COORDINATES POSITION(DMS) POSITION(D.DD) ELEV. y= 6,029,513.38" N= 2,018.00 70'29'28.489" 70.4912469' 16.4' MPC-42 X= 558,203.88 'E= 800.00 149'31'27.032" 149.5241756' Y=6,029,626.70 N=2,137.00 70'29'29.607" 70.4915575' 16.1' MPC-43 X= 558,167.56 E= 800.00 149'31'28.075" 149.5244653' AK. SECTION OFFSETS 1,231' FSL 2,255' FEL 1 344' FSL 2:290' FEL bR~' ¡ ffi~~rnœo DRAWN, JACOBS CHECKED: HACKLEMAN DA1£r 1/3/04 DRAWING: FRB04 MPC 01-00 JOB NO: 1"=300' ObP BP EXPLORATION MILNE POINT UNIT C-PAD SHEET, AS-STAKED WELL CONDUCTORS WELLS MPC-42 & MPC-43 1 OF 1 o 1/3/04ISSUEO FOR INFORMATION NO. DATE REVISION JJ <\\1-1 BY CHI( ENGlPlEEfGNfDL.NfOSUR\ÆYC!RS 8OTtfI[ST fRWEEØ LANf ANCIiORAG£. AtASI<A 99503 SCALE: w 1 w o - Re: MPC-42 Packer Setting Distance Ab.perforations . Walter, Thanks for the explanation. I do not see any problem with your proposal. I will place a copy of your email in the file. Tom Maunder, PE AOGCC Quay, Walter (Natchiq) wrote: Tom, Commission approval is sought for this different packer placement depth. To document the proposed completion for Milne Point C-42. The proposed completion would have the packer set +/- 600' measured depth (> 200' as per 20 AAC 25.412 (b) )above the perforated zone. This is the resultant of expected high pressure in the Kalubik, requiring the top setting of this zone with a long string (7-5/8"), along with the addition of a drilling liner (5-1/2") to isolate the expected pressure in the Kalubik from the drilling (4-3/4") of the normal to sub-pressured Kuparuk Reservoir. These extra strings are deemed necessary to successfully complete this well. With the extra strings, the final liner will be 3-1/2", with the intention to run this liner above the drilling liner (removing it from the IA). Formation Tops MD TVD Est. Pore Pressure Est. MW Est. Packer -8100' Kalubik 8313' 6825' 4404 12.5 ppg Kuparuk A 8700' 7200' 2345 -- 2866 psi 6.3 -- 7.7 ppg 10f2 2110120047:36 AM Re: MPC-42 Packer Setting Distance Above Perforations . . Walter Quay Quavwd@bp.com (907)564-4178 (907)440-8632 - Cell 20f2 2/10/2004 7:36 AM P055217 DATE I 1/6/2004 CHECK NO. 055217 . DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 1/6/2004 PRO 1 0504A PERMIT TO DRILL H ~ECEIVE[) FEB 0 5 2004 ~yyrk> Z¡·ë Alaska Oil & Gas Cons. Comrw;5Îon Anchorage THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ . BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE. AKèè5Jf:I-6612 NATIONAL CITY BANK Ashland, Ohio 56-389 412 No. P 0 5 5 217 CONSOLIDATED COMMERCIAL ACCOUNT PAY: ¡llIb) "nli. TO THE ORDER OF: AMOUNT *******$100.00******1 II!! 0 5 5 2 L ? III I: 0 l. L 2 0 ~ 8 ~ 5 I: 0 L 2 ? 8 q bill . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER ø~d ~-C¡2 ZOC¡ r(JZ6 WELL NAME PTD# ~,Development V Service þJ./lt?¡ :LAJ...TC;CWR- CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (1f API Dum ber last two (2) digits are between 60-69) Exploration Stratigraphic ~'CLUEn Tbe permit is for a new weHbore segment of existing well Permit No, API No. Production. sbould continue to be reported as a function· of tbe original API number. stated above. BOLE In accordance witb 20 AAC 25.005(1), aU records, data and logs acquired for tbe pilot bole must be dearly differentiated in botb name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for we)) (name on permit). PILOT (PH) SPACING EXCEPTION ~rm~YM -& {I,b.ZOS DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of ;¡ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacinge:Jception tbat may occur. An dry ditcb sample sets submitted to tbe Commission must be in no greater than 30' sample intervals from beJow tbe permafrost or from where sampJes are first caught and ] 0' sampJe iòte:r:vaJs tbrough target ZODes. Wi .Field & Pool MILNE POINl"~UPARUK RIVER OIL - 525100 PTD#:2040280 Company BP EXPLORATION (ALASKA) INC _~ Initial ClasslType 121 P!'!~mitJe~ attached. Yes Leas!'! .numb~r ap:!rQ:!riate. . . . Yes. 13 .Uni-'lu~ w~".n.ar:ne .aod fJl.!mb~~ . . . .. ................................ Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14 WellJo.cat!'!d in.ad.efil1edpoQI. . . _ . . . . . . Yes. . . . . . . 5 WellJocat!'!d proper distaoceJrom driJliog ul1itb.oul1dary Yes. . . . . . . 6 WeJI Jocat!'!d prop~r distaoceJrom QttJer wells . . . . . . . Yes 7SIJfflciel1t acr!'!age.ayailable indriljifJQ. unit. . . Yes. 18 Jf.deviated, isweJlbore platil1cJuded . . Yes. ~ 0 ~~:~:~:~ ~:;:::r~:~;:.:~Od in J~rc~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . :~:: : . . . . . . . . . . .. ........................................ _ . . . . . . . . . . . . . . . . . . . . 11 P!'!~mitcao be i$su.ed witho.ut co_ns~rva!iOI1 Qrd~r. . Yes. . . Appr Date 12 Pe~mitcao be i$su.ed without admil1ist~atil(eapprovaJ . . Yes _ SFD 2/13/2004 13 Can permit be approved before 15-day wait Yes 14 Well Jocated wi!h.ill area an.d.strç¡ta authorized by.lojection OrdßUI (puUO# in.commeots).(For. Yßs. . _ . _ . Ar!'!a lnjection.Order No.10:B . . _ . . . _ 15 AJ/wells.wit!1in.1¿4.l1Jite.are.a.of~eyiewidefJtlfied(Fo~s.ervice.w.eIJOI1I}')............... Yes...... .MPU!>12,A..(I?&A).................................. _................ _..... 16 Pre-produçed iojector; duration .of pre-production less.t!1an 3 mOllths.(fQr .seryiçe welt Qnly) . . No. . . . . . . . . . . . . 17 AÇMP.Find[ng .of ÇQn$isteocy.has been .is.suedJor.this proiect . . NA . . Well driJled from existioQ. pad. Administration --- Engineering Appr Date TEM 2/9/2004 ~ -?Vv( Geology Appr SFD Date 2/6/2004 Geologic Commissioner: 0T5 -. 118 .Cooductor stdngprQvided . . 19 .SIJr::fac!Lcas.ing.prQtects.all.koownUSDWs... 20 .GMT.voladequate.to circIJlateon CQnduçtor.& suJfC$g . 21 .CMTvoladequ.ateto tieHnlQng string to.surf cs~. . 122CMTWill coyer.alll<no.wnproductiye hQrilQn.s . . 23Casiog de.si90S ad.eQua!~ fo~ Ç,T~ 6&.permafrost 24 Adequate.tan.kageor reserve pit 25 Jf.a.re-ddll~ has.a. 10:4.03 for aba.ndQnrnent beeo apprQved . . . 26 Adequate .w.eLlbore. s.eparation propos.ed. . . . . . . . _ . . . . . . . . . . . . . . . . . . . 27 Jfdivert~r required, does it meet reguJations . 28 DrilJioQ. fluid.pfQgram sc.hematic.& eqIJip Jistadequate. 29 ßOPEs, do they meetreguJa.tion . 30 ßOPEpress ra!ioQ. appropriate; .t~st to (pu.t psig in .comments). . 31C.hoke.maMQld compJies w/,A.PIRp-53 (May 84). . 32 Work will occu~ withoutoperat[on .shutdo.wn. 33 Is. :!resence.oJ H2S gas probable 34 Mechanicalcondjtio[l of wells with)n AOR verified (for. service well only) . 35 Pe~mitcao be issued wlo. hYdrogensulfid~ measIJres . 36 .Datapr~sel'!ted on :!otential over:!ressure ZOnes. 37 Seismicaoalysis.of shaJlow gas.zooe.s 38 .Seabed .col1ditioo survey lif off-shore) . . . 39 . Contact nam.elp!1oneforweekl}' progres.sreRorts[e1<:!loratoryooly] · Yes · NA Yes. No. Yes · Yes . . Yes. NA Well Name: MILNE PT UNIT KR C-42 SER / PEND GeoArea 890 Program SER On/Off Shore On Unit 11328 Well bore seg Annular Disposal - - - - - - - - - - - - - - - - - - · . Conforms wi.th. CO 2Q5~ which allows 4 wells Pß~ goyemmental quarter s.ectJo.n in Sections3a.nd 1 Q . . . · . T1.3N. R10E, UM, This wiJI be the second well io the NW/4 of SecJ 0 &$W/4 of Sec. 3. . SFU - - - - - - - - - - - - - - - - - - - - - - - - . . . . .Yes . . . . . . . Proximi.ty. analysis perfo~med, No clos~ app~oach. iss.ues. identified, .Gyors .ayailable for magnetic iotßr::ference. . . Yes Yes. · Yes Yes. . · Yes · Yes. · No. Yes. No. Yes. NA NA. . NA .. - - - - - Date: Engineering Commissioner: Date Public Commissioner Date Z-{ 13/4- - - - ~ - - · All aquifers. exempted 40 CFR H7, t02(b)(3), . - - - - - - - . - . - - Al1yhydrpcarboo ZOne$ will.be .cO\iere.d .with çem~nt. . - - - - - - - - - - - - · . Rig ieequippedwith $teelpit$.NQ œservepjtplanoe.d, All wa$te to.Glas$ JIw.eU(st . . . . . Expßcted BHF> in KIJparuk.6.3-7.7 EMW-. planned MW 9.1-9.3. Risk pfhjghecpressure in KaJubiksllts ideottfied . F>lanned MW inp-3i4" $ection 13~Q :!pg.. . . . . . . · M,I\SF> calcu[ate.d JQr .Kalubik silts. 37.85 psi. 400.0 p$i.tes.t pœssure reque$ted.. . . - - - - - - - · Mud $hould preclude H2S. on .the rig, .Rjg. is equipped with s.eO$OfS and .alarm~. . MPÇ-12A is.- .450 NE.of 7 -5i8" csg.p.oint. . KaJubtksilts ar.e .0Yerpress.ured.. Cpil hoJe. not cemented.. *** · . 1:12S has been meassured. io C-padKupa.n¡k weJls.. . . . . . . . . . . . . . . · Kalubik/Kup De1<pected to. beoverp~eS$we.d(12.5 pp~.EMW); wiJI be drJlled wtth 13,Q PP9.mud.. . . . . . . · . KUPø~uk reseryoi~ wiIJ b~ underpressured.(6.3: 7.7 ppg; will be .drilled with 9.1 c 9.3 PP9 mud. . . ***Kup C.s.aod oot pen.etrated. .G-42.dualJioer .shQuJd iSQlate Kalubjk and .KIJparuk, - - - - ~ - - - . - - - o o . . e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dri~ng Services LIS Scan Utility e ó(ocf-o;1.. <? /¿7(,. 7 " $Revision: 3 $ LisLib $Revision: 4 $ Thu Sep 09 08:09:58 2004 Reel Header Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/09/09 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number.... ..01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/09/09 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... .UNKNOWN Comments........ ........ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPC-42 500292319600 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 09-SEP-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002951136 C.A. DEMOSKI L. BROWN MWD RUN 2 MW0002951136 J. STRAHAN L. BROWN MWD RUN 3 MW0002951136 C.A. DEMOSKI L. BROWN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0002951136 T. MCGUIRE D. GREENE MWD RUN 5 MW0002951136 T. MCGUIRE D. GREENE MWD RUN 6 MW0002951136 T. MCGUIRE D. GREENE # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 10 13N 10E 1231 2255 MSL 0) 50.40 16.60 REce'VED # WELL CASING RECORD c:r.:-D -1 ?n04 Vi-I . _v¥ OPEN HOLE CASING DRILLERS ~.aO'¡\&GasCoJ1s.CfJmmí_1 Ao~ømge 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT SIt (IN) 13 .500 9.875 6.750 4.750 SIZE (IN) 20.000 10.750 7.625 5.500 DEPTH (FT) 112.0 5805.0 8252.0 8584.0 e # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 - 6 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 3 - 5 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). 4. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN ON 1 MAY 2004. THESE DIGITAL DATA WERE PROVIDED BY K. COONEY (SIS/BP) ON 8/30/2004. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 5. MWD RUNS 1 - 6 REPRESENT WELL MPC-42 WITH API#: 50-029-23196-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8985'MD/7496'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/09 Maximum Physical Record. .65535 File Type.......... ..... .LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPD 1 and clipped curves; all bit runs merged. .5000 START DEPTH 170.5 170.5 STOP DEPTH 8944.5 8944.5 f RPM RPS RPX GR ROP $ 170.5- 170.5 170.5 177.5 223.5 8944.5 8944.5 8944.5 8930.5 8991.5 _ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------ BASELINE DEPTH 177.5 189.0 190.0 196.5 220.0 249.5 252.0 266.0 270.5 275.5 280.5 285.5 292.5 295.0 298.5 325.0 327.5 329.5 336.0 340.5 346.5 361. 0 371.0 381.5 389.5 393.5 410.5 414.5 419.5 427.0 448.0 452.5 459.5 474.5 481. 5 484.0 492.0 506.5 515.5 519.5 527.5 533.5 537.0 545.5 555.5 566.0 572.0 600.5 610.0 628.5 644.0 650.5 665.0 667.0 674.5 677.0 682.5 GR 178.5 190.0 192.0 200.0 220.0 249.5 252.0 266.5 271. 0 275.5 280.5 284.0 291. 5 294.5 296.0 325.0 328.0 329.5 337.0 341.5 346.0 363.0 372.0 383.0 388.5 395.0 413.0 416.5 422.5 428.0 447.0 453.0 459.0 471.5 480.0 483.5 491. 5 506.0 518.0 521.0 527.5 535.5 539.0 546.0 555.5 565.5 572 .5 603.0 610.5 626.0 643.0 649.0 665.5 667.0 672.5 674.0 678.0 686.5 693.0 710.0 722.5 726.5 737.5 747.5 760.5 767.5 775.0 781. 5 794.5 803.0 822.5 824.0 831.5 838.5 856.5 864.5 879.0 882.0 888.0 919.5 923.5 932.5 938.5 945.0 949.5 955.0 966.0 993.5 1008.0 1021. 5 1051.5 1060.0 1069.0 1088.5 1102.5 1109.5 1115.5 1145.5 1158.0 1171.0 1186.5 1206.5 1219.0 1236.5 1248.5 1277.5 1285.5 1291.5 1298.5 1306.5 1316.0 1332.5 1338.0 1341. 5 13 54.5 1400.5 1413 . 0 1426.0 1437.0 1441. 5 1446.5 1483.5 1515.5 1520.0 1526.0 684.5- 692 .5 708.0 721.0 724.0 737.5 746.5 759.0 766.5 772.5 780.0 793.0 801.0 821.0 823.5 831. 5 839.5 856.0 864.0 875.5 878.5 885.0 913.5 917.0 927.5 936.5 943.0 948.0 955.5 967.5 993.0 1008.5 1019.0 1049.5 1059.0 1068.0 1085.5 1099.0 1106.5 1114.5 1146.0 1160.0 1170.0 1185.5 1205.5 1217.5 1233.5 1246.0 1275.5 1285.5 1292.5 1299.0 1305.5 1315.5 1331.0 1336.0 1340.5 1351.0 1396.0 1411.5 1424.5 1437.0 1442.5 1447.0 1482.0 1514.0 1519.5 1524.5 _ 1535.5 1648.0 1667.5 1670.5 1697.0 1750.5 1785.0 1800.0 1802.5 1811.5 1820.5 1841.0 1845.0 1869.0 1938.0 1985.5 1995.5 2030.5 2038.5 2068.0 2081.5 2100.5 2112.5 2126.0 2171.5 2181.5 2204.5 2211.5 2223.5 2237.0 2316.5 2375.5 2392.5 2405.5 2428.5 2445.0 2464.0 2472.0 2520.5 2540.5 2580.5 2589.0 2628.0 2656.5 2677.5 2693.5 2701.5 2730.5 2743.5 2758.0 2780.5 2803.0 2871.5 2888.5 2899.0 2908.5 2932.0 2942.5 2949.0 2962.5 2985.5 2993.0 3000.5 3015.0 3020.5 3026.5 3039.0 3046.5 e 1535.5 1647.0 1666.0 1669.0 1694.5 1747.5 1784 . 0 1801.0 1802.5 1811.0 1820.0 1839.5 1844.5 1868.0 1938.5 1983.0 1993.0 2029.5 2036.5 2065.0 2080.5 2098.5 2111.0 2123.5 2168.5 2179.5 2203.0 2211.0 2223.0 2236.0 2315.0 2373.5 2390.5 2403.0 2427.0 2442.5 2462.0 2471.0 2519.5 2539.0 2577.5 2587.0 2626.0 2655.0 2675.5 2691. 5 2698.5 2725.5 2739.0 2754.5 2779.0 2802.0 2870.0 2884.5 2895.5 2906.0 2930.0 2941.0 2948.5 2962.5 2983.0 2991. 5 2999.5 3013.5 3018.0 3024.5 3038.0 3044.5 e 3054.5 3060.5 3065.5 3079.0 3099.0 3105.0 3116.0 3141. 5 3151. 5 3156.0 3167.5 3200.0 3218.5 3237.0 3246.0 3268.5 3280.0 3285.5 3290.0 3312.5 3336.5 3353.0 3369.0 3385.5 3391. 5 3404.0 3411.0 3426.5 3436.0 3440.5 3456.0 3459.5 3471. 5 3475.5 3481.0 3491. 0 3525.0 3532.0 3548.5 3559.5 3596.5 3608.0 3627.0 3635.0 3640.0 3668.5 3673.0 3683.0 3703.0 3710.5 3723.0 3741.5 3764.0 3769.5 3814.0 3833.5 3869.0 3881.0 3897.0 3905.5 3942.0 3955.0 3963.5 4060.0 4071.5 4076.5 4084.5 4096.5 3053. !fÞ 3058.5 3063.5 3078.0 3096.0 3102.5 3112.5 3142.0 3149.5 3152.5 3164.0 3197.0 3214.5 3234.0 3246.0 3268.0 3277.5 3283.0 3289.0 3313.0 3335.0 3349.0 3365.5 3384.0 3390.5 3402.5 3410.5 3425.5 3435.5 3442.0 3454.5 3457.5 3469.5 3472.5 3481.0 3491.0 3526.0 3532.0 3547.0 3559.5 3597.0 3607.5 3627.5 3633.0 3638.5 3672.5 3675.0 3685.0 3704.0 3710.5 3723.0 3740.5 3763.5 3769.0 3814.0 3833.5 3867.5 3878.5 3896.0 3904.0 3942.0 3954.0 3963.5 4058.5 4071. 0 4078.0 4086.0 4096.0 e 4114.0 4120.5 4146.5 4155.5 4209.5 4238.0 4247.0 4276.0 4320.0 4331.0 4370.5 4389.0 4435.0 4454.5 4485.0 4518.0 4534.5 4552.5 4567.0 4570.5 4578.5 4607.0 4631.5 4644.0 4676.5 4689.5 4735.0 4756.5 4773.0 4783.0 4804.0 4832.0 4861.0 4902.5 4917.5 4925.5 4938.5 4955.0 4966.0 4975.0 4989.0 5039.5 5042.0 5065.0 5144.5 5153.5 5170.0 5184.5 5216.0 5232.0 5266.5 5317.5 5362.5 5367.5 5399.5 5449.0 5466.5 5551. 0 5616.5 5678.0 5684.0 5783.0 5803.0 6244.0 6397.0 6502.5 6571.5 6680.0 e 4114.5 4120.0 4145.5 4154.5 4209.0 4235.0 4244.0 4275.0 4320.0 4328.5 4369.0 4386.5 4434.5 4455.0 4484.0 4516.5 4534.5 4551. 0 4564.5 4569.5 4577.0 4604.5 4629.5 4645.0 4672.5 4687.0 4732.0 4757.5 4772.5 4782.0 4802.0 4828.5 4862.5 4901. 5 4916.5 4924.5 4939.5 4952.5 4965.0 4974.0 4988.5 5040.0 5042.5 5066.0 5144.5 5153.5 5169.0 5184.5 5216.5 5230.5 5267.5 5319.5 5363.0 5367.5 5401. 0 5447.0 5464.5 5549.0 5616.5 5677.0 5683.0 5783.5 5802.5 6242.5 6395.5 6505.0 6569.0 6678.5 e 6760.5 6771.0 6787.0 6851.0 6891.5 6904.0 6933.0 6940.5 7008.5 7038.5 7086.5 7092.5 7095.0 7123.0 7185.0 7335.5 7341.0 7400.0 7428.5 7499.5 7641.5 7715.0 7762.0 7795.5 7820.0 7824.5 7851.5 7854.5 7865.5 7924.0 7934.0 7941. 0 7949.0 7952.5 7955.5 7962.5 7983.0 8041. 5 8049.0 8058.0 8066.0 8077.5 8104.5 8113.5 8118.5 8124.5 8132.5 8136.0 8141. 5 8144.5 8154.0 8160.5 8176.5 8187.5 8192.5 8203.0 8230.0 8253.5 8258.0 8264.5 8288.5 8295.5 8305.0 8336.5 8371.0 8386.5 8393.0 8403.0 6759. !' 6768.5 6785.0 6853.0 6892.5 6906.5 6934.5 6943.0 7009.5 7036.0 7086.5 7091.0 7092.0 7119.0 7185.0 7330.5 7338.5 7394.0 7424.0 7495.5 7638.5 7711. 5 7758.5 7789.0 7814.5 7820.0 7847.5 7849.0 7863.0 7913.5 7928.0 7935.5 7944.0 7948.0 7950.5 7962.5 7983.0 8037.5 8043.0 8053.5 8062.0 8069.0 8101. 0 8111.0 8113.5 8117.0 8127.0 8133.5 8140.5 8143.0 8151.0 8156.0 8173.0 8183.0 8188.0 8198.0 8224.5 8251. 5 8255.0 8260.5 8285.0 8292.5 8301.0 8332.5 8368.0 8384.0 8389.5 8399.5 e 8409.5 8419.0 8431.5 8446.0 8486.5 8517.5 8524.5 8537.0 8550.5 8554.5 8556.5 8569.0 8574.5 8584.0 8609.5 8611.0 8625.5 8644.5 8649.0 8652.5 8672.5 8677.0 8679.5 8688.5 8694.0 8709.5 8712.5 8724.0 8732.5 8740.5 8749.5 8761.5 8763.5 8766.5 8772.0 8773.5 8775.5 8779.5 8781.5 8785.5 8794.0 8799.5 8804.0 8808.0 8814.5 8819.0 8832.5 8836.5 8842.5 8848.5 8850.0 8991. 5 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ # REMARKS: 8406." 8415.0 8429.0 8443.5 8484.5 8513.5 8520.5 8533.0 8547.5 8551. 5 8556.0 8569.5 8573.5 8578.0 8605.5 8607.0 8620.0 8635.0 8639.5 8646.0 8668.0 8672.0 8675.0 8683.0 8689.0 8704.0 8706.0 8718.5 8725.0 8735.0 8743.5 8756.5 8757.5 8762.0 8765.5 8768.5 8770.0 8774.0 8776.0 8780.5 8789.0 8794.5 8799.0 8802.5 8809.5 8814.5 8827.5 8833.0 8836.0 8841. 5 8843.5 8984.5 BIT RUN NO 1 2 3 4 5 6 MERGED MAIN PASS. $ MERGE TOP 171.5 2935.0 5816.0 8016.0 8258.5 8585.0 # Data Format Specification Record e MERGE BASE 2935.0 5816.0 8016.0 8258.5 8585.0 8985.0 e Data Record Type..................O Data Specification Block Type.....O Logging Direction...... .......... . Down Optical log depth units.... ..... ..Feet Data Reference Point.......... ....Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 e Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 170.5 8991. 5 4581 17643 170.5 8991. 5 ROP MWD FT/H 0.42 931. 93 176.42 17537 223.5 8991.5 GR MWD API 22.08 257.21 82.9374 17507 177.5 8930.5 RPX MWD OHMM 0.06 2000 9.16091 17549 170.5 8944.5 RPS MWD OHMM 0.06 2000 18.2728 17549 170.5 8944.5 RPM MWD OHMM 0.06 2000 24.2574 17549 170.5 8944.5 RPD MWD OHMM 0.05 2000 28.9234 17549 170.5 8944.5 FET MWD HOUR 0.13 64.2 1.6214 17549 170.5 8944.5 First Reading For Entire File.. ....... .170.5 Last Reading For Entire File..... ..... .8991.5 File Trailer Service name....... .... ..STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/09 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..... ..04/09/09 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: 2 header data for each bit run in separate files. 1 .5000 # FILE SUMMARY VENDOR TOOL CODE FET RPX RPS RPD RPM GR ROP $ e START DEPTH 171.5 171.5 171.5 171.5 171.5 178.5 223.5 STOP DEPTH 2884.0 2884.0 2884.0 2884.0 2884.0 2892.0 2935.0 # 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............ .... ..0 Data Specification Block Type... ..0 Logging Direction............. ....Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing..... ............... .60 .1IN Max frames per record............ . Undefined e 03-MAR-04 Insite 66.37 Memory 2935.0 223.0 2935.0 .5 35.9 TOOL NUMBER 120557 59672 13.500 .0 Spud Mud 9.45 158.0 8.5 1300 12.8 1. 200 .800 4.250 3.200 66.0 102.2 65.0 60.0 e e Absent value.. . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 171. 5 2935 1553.25 5528 171.5 2935 ROP MWD010 FT/H 3.59 848.22 237.323 5424 223.5 2935 GR MWD010 API 24.59 123.43 66.8984 5428 178.5 2892 RPX MWD010 OHMM 0.06 50.97 16.2886 5426 171.5 2884 RPS MWD010 OHMM 0.06 137.71 25.288 5426 171.5 2884 RPM MWD010 OHMM 0.06 2000 35.7844 5426 171.5 2884 RPD MWD010 OHMM 0.05 2000 49.3193 5426 171.5 2884 FET MWD010 HOUR 0.13 3.11 0.511038 5426 171. 5 2884 First Reading For Entire File......... .171.5 Last Reading For Entire File.......... .2935 File Trailer Service name......... ....STSLIB.002 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation.... ...04/09/09 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.. ... ..04/09/09 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2884.5 2884.5 2884.5 2884.5 STOP DEPTH 5765.0 5765.0 5765.0 5765.0 RPX GR ROP $ 2884.5- 2892.5 2935.5 5765.0 5773.0 5816.0 # 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type. ....0 Logging Direction........... .... ..Down Optical log depth units..... .... ..Feet Data Reference Point. .... ....... ..Undefined Frame Spacing....... ... ... ....... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 _ 05-MAR-04 Insite 66.37 Memory 5816.0 2935.0 5816.0 31.8 47.5 TOOL NUMBER 120557 59672 13.500 .0 Spud Mud 9.45 120.0 7.0 600 8.4 4.500 3.170 4.000 4.750 70.0 102.2 70.0 66.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 GR MWD020 API tp 1 68 8 3 e RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2884.5 5816 4350.25 5864 2884.5 5816 ROP MWD020 FT/H 0.42 931.93 187.032 5762 2935.5 5816 GR MWD020 API 22.08 147.21 77.3654 5762 2892.5 5773 RPX MWD020 OHMM 1.18 27.44 4.65339 5762 2884.5 5765 RPS MWD020 OHMM 1. 07 30.72 4.74358 5762 2884.5 5765 RPM MWD020 OHMM 1. 01 29.08 4.74671 5762 2884.5 5765 RPD MWD020 OHMM 1. 02 23.13 4.894 5762 2884.5 5765 FET MWD020 HOUR 0.13 9.78 0.808634 5762 2884.5 5765 First Reading For Entire File... ...... .2884.5 Last Reading For Entire File... ....... .5816 File Trailer Service name........ .....STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..04/09/09 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... ....04/09/09 Maximum Physical Record..65535 File Type............ ....LO Previous File Name.. ... ..STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS FET RPD RPM GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 5765.5 5765.5 5765.5 5765.5 5765.5 5773 .5 5816.5 STOP DEPTH 7970.0 7970.0 7970.0 7970.0 7970.0 7978.0 8016.0 # LOG HEADER DATA DATE LOGGED: 08-MAR-04 e 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ... ...........0 Data Specification Block Type.....O Logging Direction.... ............ . Down Optical log depth units.......... .Feet Data Reference Point... ... ...... ..Undefined Frame Spacing............. ...... ..60 .1IN Max frames per record....... .... ..Undefined Absent value.. ................ ....-999 Depth units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 e Insite 66.37 Memory 8016.0 5816.0 8016.0 26.3 49.8 TOOL NUMBER 164580 56933 9.875 5805.0 LSND 9.70 50.0 9.0 400 6.6 4.000 1. 950 5.000 3.500 65.0 140.8 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 e e First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5765.5 8016 6890.75 4502 5765.5 8016 ROP MWD030 FT/H 1. 48 345.93 131.289 4400 5816.5 8016 GR MWD030 API 39.63 177.85 97.014 4410 5773.5 7978 RPX MWD030 OHMM 0.72 1258.36 3.16845 4410 5765.5 7970 RPS MWD030 OHMM 0.69 2000 4.0515 4410 5765.5 7970 RPM MWD030 OHMM 0.43 2000 9.08569 4410 5765.5 7970 RPD MWD030 OHMM 0.23 2000 21.3773 4410 5765.5 7970 FET MWD030 HOUR 0.21 64.2 2.08648 4410 5765.5 7970 First Reading For Entire File.... ..... .5765.5 Last Reading For Entire File.......... .8016 File Trailer Service name........... ..STSLIB.004 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation..... ..04/09/09 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...... .04/09/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 7970.5 7970.5 7970.5 7970.5 7970.5 7978.5 8016.5 STOP DEPTH 8212.5 8212.5 8212.5 8212.5 8212.5 8219.5 8258.5 # 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): 10-MAR-04 Insite 66.37 Memory 8258.0 8016.0 8258.0 e BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.... .... ..... .., .Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.......... .......... .60 .1IN Max frames per record.......... ...Undefined Absent value. .................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O e 16.7 22.9 TOOL NUMBER 164580 56933 9.875 5805.0 LSND 9.80 42.0 9.0 450 6.6 3.200 1.650 3.000 2.600 68.0 138.0 68.0 68.0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7970.5 8258.5 8114.5 577 7970.5 8258.5 ROP MWD040 FT/H 4.33 169.86 67.8887 485 8016.5 8258.5 GR MWD040 API 118 257.21 162.442 483 7978.5 8219.5 _ -7970.5 RPX MWD040 OHMM 0.66 4.1 1.50227 485 8212.5 RPS MWD040 OHMM 0.64 4 1. 45384 485 7970.5 8212 .5 RPM MWD040 OHMM 0.63 3.94 1. 42689 485 7970.5 8212.5 RPD MWD040 OHMM 0.69 3.79 1. 48581 485 7970.5 8212.5 FET MWD040 HOUR 0.57 16.5 4.36239 485 7970.5 8212.5 First Reading For Entire File......... .7970.5 Last Reading For Entire File.......... .8258.5 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/09 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...... .04/09/09 Maximum Physical Record. .65535 File Type.. ............ ..LO Previous File Name..... ..STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM RPD FET GR ROP $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 8213.0 8213 . 0 8213.0 8213.0 8213.0 8220.0 8259.0 STOP DEPTH 8547.5 8547.5 8547.5 8547.5 8547.5 8555.0 8585.0 # 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: 13-MAR-04 Insite 66.37 Memory 8585.0 8258.0 8585.0 12.1 12.9 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR EWR4 $ e DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type... ..0 Logging Direction..... ..... ..... ..Down Optical log depth units..... .... ..Feet Data Reference Point........ .., ...Undefined Frame Spacing................ .....60 .1IN Max frames per record......... ....Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 156435 156404 e 6.750 8252.0 LSND 12.90 45.0 10.0 550 6.5 2.600 1. 260 2.800 3.600 65.0 141.8 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8213 8585 8399 745 8213 8585 ROP MWD050 FT/H 21. 13 367.15 66.3613 653 8259 8585 GR MWD050 API 50.86 168.36 117.941 671 8220 8555 RPX MWD050 OHMM 0.98 2000 23.8321 670 8213 8547.5 RPS MWD050 OHMM 0.97 1628.94 30.1543 670 8213 8547.5 RPM MWD050 OHMM 0.97 2000 210.703 670 8213 8547.5 RPD MWD050 OHMM 0.97 2000 113.794 670 8213 8547.5 FET MWD050 HOUR 0.68 51. 24 8.1023 670 8213 8547.5 , d' "1- Flrst Rea lng For Entlre Fl e...... ....8213 Last Reading For Entire File...... .... .8585 File Trailer Service name........... ..STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/09 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..... ..04/09/09 Maximum Physical Record..65535 File Type....... ........ .LO Previous File Name..... ..STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 7 e header data for each bit run in separate files. 6 .5000 START DEPTH 8548.0 8548.0 8548.0 8548.0 8548.0 8555.5 8585.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 8937.5 8937.5 8937.5 8937.5 8937.5 8923.5 8985.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 15-MAR-04 Insite 66.37 Memory 8985.0 8585.0 8985.0 7.0 11.3 TOOL NUMBER 171170 171170 4.750 8584.0 # e 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..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units........ ...Feet Data Reference Point............. . Undefined Frame Spacing....... .., .......... .60 .1IN Max frames per record.... .,. .., ...Undefined Absent value. .................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O e LSND 9.00 89.0 9.5 400 6.8 1.300 .780 2.400 3.000 65.0 112.2 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8548 8985 8766.5 875 8548 8985 ROP MWD060 FT/H 6.3 146.69 86.619 800 8585.5 8985 GR MWD060 API 24.66 107.84 75.9775 737 8555.5 8923.5 RPX MWD060 OHMM 1. 23 1598.26 13.4082 780 8548 8937.5 RPS MWD060 OHMM 1.21 2000 146.489 780 8548 8937.5 RPM MWD060 OHMM 0.8 1826.72 32.2459 780 8548 8937.5 RPD MWD060 OHMM 0.42 2000 45.1412 780 8548 8937.5 FET MWD060 HOUR 0.37 48.68 5.28629 780 8548 8937.5 First Reading For Entire File.... ..... .8548 Last Reading For Entire File.......... .8985 File Trailer Service name............ .STSLIB.007 Service Sub Level Name... e version Number.......... .1.0.0 Date of Generation...... .04/09/09 Maximum Physical Record. .65535 File Type............... .LO Next File Name.... ...... .STSLIB.OOB e Physical EOF Tape Trailer Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/09/09 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............ ....UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments.... ............ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name...... ..... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/09/09 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name........... ... ..UNKNOWN Continuation Number.... ..01 Next Reel Name.......... . UNKNOWN Comments.... ............ .STS LIS writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File