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176-032
Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 09/29/2025 InspectNo:susRCN250819173946 Well Pressures (psi): Date Inspected:8/18/2025 Inspector:Bob Noble If Verified, How?Other (specify in comments) Suspension Date:3/16/2011 #310-399 Tubing:279 IA:274 OA:60 Operator:Hilcorp Alaska, LLC Operator Rep:Kyle Martin Date AOGCC Notified:8/9/2025 Type of Inspection:Subsequent Well Name:TRADING BAY UNIT G-24 Permit Number:1760320 Wellhead Condition Wellhead was clean with no drips or spills. All lines are removed and blinded with guages. Surrounding Surface Condition Condition of Cellar Well bay floor lood good. Comments Well was verified with well bay map. Supervisor Comments Photos (2) Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, September 29, 2025 2025-0818_Suspend_TBU_G-24_photos_bn Page 1 of 1 Suspended Well Inspection – TBU G-24 PTD 1760320 AOGCC Inspection Rpt # susRCN250819173946 Photos by AOGCC Inspector B. Noble 8/18/2025 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 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: 3800 Centerpoint Drive, Suite 1400 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/Pool(s): McArthur River Field / Hemlock Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,400'N/A Casing Collapse Structural Conductor 520 psi Surface 1,540 psi Intermediate Production 4,750 psi Liner 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission 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 COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Suspended Well Renewal 9,819' 5,400' 5,156' 0 psi 9,809'9-5/8" Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. N/A 2-7/8" Daniel E. Marlowe N/A & N/A N/A 10,388' N/A & N/A Tubing Grade: Tubing MD (ft): N/A Perforation Depth TVD (ft): 6.4# / L-80 5,115' 10,388' Perforation Depth MD (ft): 4,885' 829' 5,115' 20" 13-3/8" 829' TVD Burst 5,224' 6,870 psi Tubing Size: MD 1,530 psi 3,090 psi 828' 176-032 50-733-20286-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC N/A Trading Bay Unit G-24 COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017594 Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 5,400' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:11 pm, Sep 28, 2020 320-405 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.09.28 07:24:41 -08'00' Dan Marlowe (1267) SFD 9/28/2020DLB 09/28/2020 X DSR-9/28/2020 Suspended Well Renewal gls 10/6/20 No form required * Suspension valid until 2030 ( next inspection due in 2025 ) Comm. on Required? Yes 10/6/2020 dts 10/06/2020 JLC 10/6/2020 Suspended Well Inspection Data Well: G-24 Surface Location: 1810’ FSL, 1408’ FEL, Sec 29, T9N, R13W S.M. Permit to Drill: 176-032 API: 50-733-20286-00 AOGCC Inspection Date: 7/14/20 AOGCC Inspector: Brian Bixby Size Pressure (psi) Tubing 2 7/8 120 Casing 9 5/8 120 13 3/8 163 20 28 *Note: Wellhead pressures to be recorded monthly at minimum. Hilcorp Alaska, LLC submits this suspended well renewal request per 20 AAC 25.110. Trading Bay Unit G-24 was inspected on July 14, 2020 by Inspector Brian Bixby and a 10-404 was submitted on August 11, 2020. x The well was drilled to a TD of 10,400’ with 9-5/8” casing in June 1976. x G-24 was suspended in March 2011. The reservoir abandonment left the well in the following condition: cement plug # 1 consisting of 30 bbls of 15.3 ppg class G cement in the 9-5/8” casing with a tagged top at 9,310’ DPM, a 9-5/8” cast iron bridge plug (CIBP) set at 7,234’ DPM with cement plug #2 placed on top of the CIBP consisting of 22 bbls of 15.3 ppg class G cement with an estimated top at 6,935’, 9.8 ppg kill weight fluid throughout wellbore, a second CIBP at 5,400’ WLM and a 2-7/8” kill string was set to 5,224’. x The flowline has been removed and the well is not connected to the production facilities. x At this time there are no immediate plans to recomplete or sidetrack G-24. x Hilcorp requests that G-24 maintains suspended status due to it being located on an active oil and gas platform, Grayling, such that future oil and gas development opportunities can be accessed from this wellbore. x Condition of Wellhead: Good x Condition of Cellar: Good x Condition of Surrounding Surface Location: Good x Follow Up Actions needed: None Attachments: x Current Well Schematic x Picture(s) x Plat - 1/4mile radius of wellbore GRAYLING PLATFORM WELL #: G-24 Actual 4-6-11 4/6/11 BY: DR RKB to MSL = 99’ HB-1, 2 HB-3 HB-4, 5 HB-6 Fish in hole: Wireline, perf guns and slickline tools – 10,259’ dpm. Fill Tagged 10,237’ on 6/11/95 SIZE WT GRADE CONN ID MD Top MD Btm Cmt Cmt T20” 94# H-40 19.124” Surface 829’ 850 sxs surface 13-3/8” 61# K-55 Butt 12.515” Surface 2700’ 13-3/8” 68# K-55 Butt 12,415” 2700’ 5115’ N-80 8.681” Surface 7207’ P110 8.681” 7207’ 8347’ USS-95 8.681” 8347’ 10,388’ 2 7/8" 6.4# L-80 BUTT SCC 2.441" Surface 5,224' Kill String CASING AND TUBING DETAIL 9-5/8” 47# Butt 12 1/4" 1200 sxs 8200’ Hole 23” 17.5”5329 cu ft Surface17.5” May-76 9960'-9962' Sqz'd HB-4 Mar-11 10,218'-10,240' Abandoned HB-6 9748'-9768' Abandoned HB-1 10,156'-10,186' Abandoned HB-5 9905'-9935' Abandoned HB-3 10,090'-10,140' Abandoned HB-5 9965'-10,052' Abandoned HB-4 9965'-10,052' Abandoned HB-4 10,090'-10,135' Abandoned HB-5 9748'-9768' Abandoned HB-1 9748'-9768' Abandoned HB-1 9800'-9880' Abandoned HB-2 9792'-9880' Abandoned HB-2 9905'-9935' Abandoned HB-3 9880'-9935' Abandoned HB-3 9965'-10,050' Abandoned HB-4 9935'-10,061' Abandoned HB-4 10,206'-10,236' Abandoned HB-6 10,090'-10,186' Abandoned HB-5 10,156'-10,186' Abandoned HB-5 PERFORATION RECORD NO MD Top MD Btm TVD Top TVD Btm Item 1 5400' 5403' 5155' 5158' Mechanical CIBP 2 5403' 6919' 5158' 6565' 9.8 ppg Kill Weight Brine 3 6919' 7234' 6565' 6857' Cement Plug #2 4 6919' 7232' 6565' 6855' 2 3/8” Sacrificial String 5 7234' 7237' 6857' 6860' Mechanical CIBP 6 7237' 9310' 6860' 8796' 9.8 ppg Kill Weight Brine 7 9310' 9821' 8796' 9278' Cement Plug #1 8 9535' 9815' 9008' 9272' 2 3/8” Sacrificial String 9 9635 9639 9103 9107' OTIS BWH Perma-Drill Packer Suspension Details TD = 10,400’MD PBTD = 5,400’ MD Top of CaCO3 Fill estimated @ +/- 9750’ RKB = 40.48’ Rig Floor to DCB TBG Spool Top of CaCO3 Fill Tagged @ +/- 9821’ 1-19-2011 9.8 ppg KW Fluid 9.8 ppg KW Fluid Tagged Cement @ 9,310’ dpm w/ 10K Lbf Tagged CIBP @ 7,234’ dpm w/ 10K Lbf Set CIBP @ 5,400’ wlm ''''' ' ' ' ' '' ' ' ' Q ' ' ' 0 0 '' ' ' Q 0 * ' ' ' 0 '0 ' '' ' ' ' 0 ' 0 0 ' '* ' ' '* * * * * ' * * * Q * * * * * * * ' * * *' Q ' ' ' ' ' ' '' ' Q ' ' !!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!! !!!!! ! ! ! !!!!!!!!!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! !!! '''''Q'''00'''''00Q0''000*00''00'**0'''0'0''''00'Q'''''0'000'' ******'***Q**********'****'Q'0''''0'''''''Q'''' " " S009N013W Sec. 28 S009N013W Sec. 29 S009N013W Sec. 33 S009N013W Sec. 32 Grayling SteelheadTRADING BAY UNIT G- 2 4 G-02 BHL G-02RD BHL G-03 BHL G-03PB2 BHL G-03RD2 BHL G-04 BHL G-04RD BHL G-05 BHL G-05RD BHL G-06RD BHL G-07 BHL G-08RD BHL G-10RD BHL G-11 BHL G-18 BHL G-20 BHL G-21 BHL G-21RD BHL G-22 BHL G-23 BHL G-23RD BHL G-24 BHL G-26 BHL G-26RD BHL G-30 BHL G-32 BHL G-33 BHL G-34 BHL G-34RD BHL G-36 BHL G-40 BHL K-20 BHL K-21 BHL K-21RD BHL K-25 BHLM-01 BHL M-02 BHL M-03 BHL M-05 BHL M-06RD BHL M-07 BHL M-09 BHL M-10 BHL M-10PB1 BHL M-11 BHL M-12 BHL M-13 BHL M-14 BHL M-14RD BHL M-16 BHL M-16RD BHL M-19 BHL M-19RD BHL M-21 BHL M-22 BHL M-25 BHL M-26 BHL M-26-REL1 BHL M-28 BHL M-29 BHL M-29A BHL M-31A BHL M-31B BHL M-31L1 BHL M-32 BHL M-32RD2 BHL M-32RDPB1 BHL M-35 BHL M-35PB1 BHL 0 500 1,000 Feet Alaska State Plane Zone 4, NAD27 ¯ Legend Quarter-Mile Radius around Well Bore Oil and Gas Unit Boundary Map Date: 8/10/2020 MCARTHUR RIVER G-24 Suspended Well ! ! ! ")") ")")")")") ") ")") ")")") ") ") Location Map Overview Coo k I nl et Kenai Tyonek Anchorage HAK Petra Well Symbol'Other*Gas'Oil 0 INJ Q P&A Page 9 of 16 From:Juanita Lovett To:AOGCC Permitting (CED sponsored) Subject:10-403 - Trading Bay Unit G-24 PTD: 176-032 - Application for Sundry Approval Date:Monday, September 28, 2020 1:00:22 PM Attachments:10-403 Trading Bay Unit G-24 PTD 176-032 2020-09-25.pdf G-24 was suspended in 2011 and the suspension is valid until 4/15/2021. A 10-404 Suspended Well Inspection was submitted on 8/11/20. Hilcorp would like to submit a 10-403 for a suspended well renewal for this well at this time to shift the renewal schedule of G-24 to coincide with the inspection cycle of the larger group of suspended wells. We believe this will meet the intent of “20 AAC 25.110. Suspended well” regulation to group the inspection occurrences of the suspended wells. Regards, Juanita L Lovett Sr. Operations/Regulatory Tech Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 | Anchorage | AK | 99503 (907) 777-8332 | jlovett@hilcorp.com 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 have received 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 not adversely 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. 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Suspended Well Inspection 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 10,400 feet 5,400 feet true vertical 9,819 feet N/A feet Effective Depth measured 5,400 feet N/A feet true vertical 5,156 feet N/A feet Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.4# / L-80 5,224 MD 4,989 TVD Packers and SSSV (type, measured and true vertical depth)N/A & N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Daniel E. Marlowe Operations Manager Burst Collapse 520psi Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,540psi 1,530psi 3,090psi 907 777-8376 6,870psi 828 4,885 9,809 829 5,115 Conductor Surface 4,750psi 20" 13-3/8" 10,388 Size 0 Production Casing Structural Liner Length Intermediate N/A Junk 5. Permit to Drill Number: 0 McArthur River Field / Hemlock Oil PoolN/A measured 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 N/A Oil-Bbl 0 Water-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 310-399 0 Authorized Signature with date: Authorized Name: 0 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 176-032 50-733-20286-00-00 Plugs ADL0017594 Trading Bay Unit G-24 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 00 Casing Pressure 10,388 MD 829 5,115 TVD measured true vertical Packer 9-5/8" PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:14 am, Aug 12, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.08.11 14:31:23 -08'00' Dan Marlowe (1267) SFD 8/12/2020 Suspended Well Inspection DSR-8/13/2020 SUSP gls 9/29/20 ??? RBDMS HEW 8/12/2020 Suspended Well Inspection Data Well: G-24 Surface Location: 1810’ FSL, 1408’ FEL, Sec 29, T9N, R13W S.M. Permit to Drill: 176-032 API: 50-733-20286-00 AOGCC Inspection Date: 7/14/20 AOGCC Inspector: Brian Bixby Size Pressure (psi) Tubing 2 7/8 120 Casing 9 5/8 120 13 3/8 163 20 28 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: x Condition of Wellhead: Good x Condition of Cellar: Good x Condition of Surrounding Surface Location: Good x Follow Up Actions needed: None Attachments: x Current Well Schematic x Picture(s) x Plat - 1/4mile radius of wellbore GRAYLING PLATFORM WELL #: G-24 Actual 4-6-11 4/6/11 BY: DR RKB to MSL = 99’ HB-1, 2 HB-3 HB-4, 5 HB-6 Fish in hole: Wireline, perf guns and slickline tools – 10,259’ dpm. Fill Tagged 10,237’ on 6/11/95 SIZE WT GRADE CONN ID MD Top MD Btm Cmt Cmt T20” 94# H-40 19.124” Surface 829’ 850 sxs surface 13-3/8” 61# K-55 Butt 12.515” Surface 2700’ 13-3/8” 68# K-55 Butt 12,415” 2700’ 5115’ N-80 8.681” Surface 7207’ P110 8.681” 7207’ 8347’ USS-95 8.681” 8347’ 10,388’ 2 7/8" 6.4# L-80 BUTT SCC 2.441" Surface 5,224' Kill String CASING AND TUBING DETAIL 9-5/8” 47# Butt 12 1/4" 1200 sxs 8200’ Hole 23” 17.5”5329 cu ft Surface17.5” May-76 9960'-9962' Sqz'd HB-4 Mar-11 10,218'-10,240' Abandoned HB-6 9748'-9768' Abandoned HB-1 10,156'-10,186' Abandoned HB-5 9905'-9935' Abandoned HB-3 10,090'-10,140' Abandoned HB-5 9965'-10,052' Abandoned HB-4 9965'-10,052' Abandoned HB-4 10,090'-10,135' Abandoned HB-5 9748'-9768' Abandoned HB-1 9748'-9768' Abandoned HB-1 9800'-9880' Abandoned HB-2 9792'-9880' Abandoned HB-2 9905'-9935' Abandoned HB-3 9880'-9935' Abandoned HB-3 9965'-10,050' Abandoned HB-4 9935'-10,061' Abandoned HB-4 10,206'-10,236' Abandoned HB-6 10,090'-10,186' Abandoned HB-5 10,156'-10,186' Abandoned HB-5 PERFORATION RECORD NO MD Top MD Btm TVD Top TVD Btm Item 1 5400' 5403' 5155' 5158' Mechanical CIBP 2 5403' 6919' 5158' 6565' 9.8 ppg Kill Weight Brine 3 6919' 7234' 6565' 6857' Cement Plug #2 4 6919' 7232' 6565' 6855' 2 3/8” Sacrificial String 5 7234' 7237' 6857' 6860' Mechanical CIBP 6 7237' 9310' 6860' 8796' 9.8 ppg Kill Weight Brine 7 9310' 9821' 8796' 9278' Cement Plug #1 8 9535' 9815' 9008' 9272' 2 3/8” Sacrificial String 9 9635 9639 9103 9107' OTIS BWH Perma-Drill Packer Suspension Details TD = 10,400’MD PBTD = 5,400’ MD Top of CaCO 3 Fill estimated @ +/- 9750’ RKB = 40.48’ Rig Floor to DCB TBG Spool Top of CaCO 3 Fill Tagged @ +/- 9821’ 1-19-2011 9.8 ppg KW Fluid 9.8 ppg KW Fluid Tagged Cement @ 9,310’ dpm w/ 10K Lbf Tagged CIBP @ 7,234’ dpm w/ 10K Lbf Set CIBP @ 5,400’ wlm ''''' ' ' ' ' '' ' ' ' Q ' ' ' 0 0 '' ' ' Q 0 * ' ' ' 0 '0 ' '' ' ' ' 0 ' 0 0 ' '* ' ' '* * * * * ' * * * Q * * * * * * * ' * * *' Q ' ' ' ' ' ' '' ' Q ' ' !!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!!! !!!!! ! ! ! !!!!!!!!!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! !!! '''''Q'''00'''''00Q0''000*00''00'**0'''0'0''''00'Q'''''0'000'' ******'***Q**********'****'Q'0''''0'''''''Q'''' " " S009N013W Sec. 28 S009N013W Sec. 29 S009N013W Sec. 33 S009N013W Sec. 32 Grayling SteelheadTRADING BAY UNIT G- 2 4 G-02 BHL G-02RD BHL G-03 BHL G-03PB2 BHL G-03RD2 BHL G-04 BHL G-04RD BHL G-05 BHL G-05RD BHL G-06RD BHL G-07 BHL G-08RD BHL G-10RD BHL G-11 BHL G-18 BHL G-20 BHL G-21 BHL G-21RD BHL G-22 BHL G-23 BHL G-23RD BHL G-24 BHL G-26 BHL G-26RD BHL G-30 BHL G-32 BHL G-33 BHL G-34 BHL G-34RD BHL G-36 BHL G-40 BHL K-20 BHL K-21 BHL K-21RD BHL K-25 BHLM-01 BHL M-02 BHL M-03 BHL M-05 BHL M-06RD BHL M-07 BHL M-09 BHL M-10 BHL M-10PB1 BHL M-11 BHL M-12 BHL M-13 BHL M-14 BHL M-14RD BHL M-16 BHL M-16RD BHL M-19 BHL M-19RD BHL M-21 BHL M-22 BHL M-25 BHL M-26 BHL M-26-REL1 BHL M-28 BHL M-29 BHL M-29A BHL M-31A BHL M-31B BHL M-31L1 BHL M-32 BHL M-32RD2 BHL M-32RDPB1 BHL M-35 BHL M-35PB1 BHL 0 500 1,000 Feet Alaska State Plane Zone 4, NAD27 ¯ Legend Quarter-Mile Radius around Well Bore Oil and Gas Unit Boundary Map Date: 8/10/2020 MCARTHUR RIVER G-24 Suspended Well ! ! ! ")") ")")")")") ") ")") ")")") ") ") Location Map Overview Coo k I nl et Kenai Tyonek Anchorage HAK Petra Well Symbol'Other*Gas'Oil 0 INJ Q P&A Page 9 of 16 Suspended Well Inspection Review Report InspectNo: susBDB200716100419 Date Inspected: 7/15/2020 ' Inspector: Brian Bixby Type of Inspection: Subsequent Well Name: TRADING BAY UNIT G-24 Date AOGCC Notified: 7/6/2020 Permit Number: 1760320 Operator: Hilcorp Alaska, LLC Suspension Approval: Sundry N 310-399' Operator Rep: Jon Collins Suspension Date: 3/16/2011 Wellbore Diagram Avail? ❑✓ Location Verified? s❑ Photos Taken? ❑ If Verified, How? Other (specify in comments) Offshore? 91 Well Pressures (psi): Tubing: 120 Fluid in Cellar? ❑ IA: 120 BPV Installed? ❑ OA: 163 VR Plug(s) Installed? ❑ Wellhead Condition Good with good gauges and all valve handles. There is no BPV or VR plugs installed. Condition of Cellar NA Surrounding Surface Condition Good Comments Location was verified using the Grayling Platform Well Slot Schematic Supervisor Comments Friday, July 24, 2020 RECEIVED STATE OF ALASKA • ALARA OIL AND GAS CONSERVATION COMMISSION SEP 2 8 2015 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Re-enter Susp Well❑ Other: Suspended Well Inspection 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 176-032 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service El 6.API Number: Anchorage,AK 99503 50-733-20286-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017594 Trading Bay Unit/G-24 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil Pool 11.Present Well Condition Summary: Total Depth measured 10,400 feet Plugs measured 5,400 feet true vertical 9,819 feet Junk measured N/A feet Effective Depth measured 5,400 feet Packer measured N/A feet true vertical 5,156 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 829' 20" 829' 828' 1,530 psi 520 psi Surface 5,115' 13-3/8" 5,115' 4,885' 3,090 psi 1,540 psi Intermediate Production 10,388' 9-5/8" 10,388' 9,808' 6,870 psi 4,750 psi Liner Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.4#/L-80 5,224'(MD) 4,989'(ND) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1 Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP2 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: 310-399 Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Din Mario e Title Operations Engineer Signature '. ., 4 f / Phone (907)283-1329 Date /�$///�/� i 111 0'1'1 ' RBDMS 1� SEP 2 9 2015 Form 10-404 Revised 5/2015 � `�/�/� Submit Original Only • Suspended Well Inspection Data Well: G-24 Surface Location: 1810' FSL, 1408' FEL, Sec 29, T9N, R13W S.M. Permit to Drill: 176-032 API: 50-733-20286-00 AOGCC Inspection Date: 08/27/15 AOGCC Inspector: Jeff Jones Size Pressure(psi) Tubing 2-7/8" 185 Casing 9-5/8" 210 13-3/8" 130 20" 2 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • Condition of Wellhead: Good condition: No visible leaks. Valves &gauges operable. Not connected to production, no flow line. • Condition of Surrounding Surface Location: Good condition, clean. • Follow Up Actions needed: None Attachments: • Current Well Schematic • Picture(s) • Plat- 1/4mile radius of wellbore • Correspondence/Suspended Well Inspection Report • • n GRAYLING PLATFORM WELL #: G-24 Actual 4-6-11 RKB=40.48' Rig Floor to DCB TBG Spool RKB to MSL=99' 411 1CASING AND TUBING DETAIL SIZE WT GRADE CONN ID MD Top MD Btr' Hole Cmt Cmt 20" 94# H-40 19.124" Surface 829' 23" 850 sxs surface 13-3/8" 61# K-55 Butt 12.515" Surface 2700' 17.5" 5329 cu f. Surface 13-3/8" 68# K-55 Butt 12,415" 2700' 5115' 17.5" N-80 8.681" Surface 7207' 9-5/8" 47# P110 Butt 8.681" 7207' 8347' 12 1/4" 1200 sxa 8200' USS-95 8.681" 8347' 10,388' 2 7/8" 6.4# L-80 BUTT 2.441" Surface 5,224' Kill SCC String Set CIBP @s,400 wlm Suspension Details NO MD Top MD Btm TVD Top TVD Btm Item 9.8 pp KW Fluid Fluid 1 5400' 5403' 5155' 5158' Mechanical CIBP 2 5403' 6919' 5158' 6565' 9.8 ppg Kill Weight Brine 3 6919' 7234' 6565' 6857' Cement Rug#2 4 6919' 7232' 6565' 6855' 2 3/8" Sacrificial String Tagged 5 7234' 7237' 6857' 6860' Mechanical CIBP CIBP s, @ 7,234' 6 7237' 9310' 6860' 8796' 9.8 ppg Kill Weight Brine dpm w/10K Lbf 7 9310' 9821' 8796' 9278' Cement Rug#1 8 9535' 9815' 9008' 9272' 2 3/8" Sacrificial String 9.8 ppg 9 9635 9639 9103 9107' OTIS BWH Perma-Drill Packer KW Fluid LA li Tagged Cement @9,310' dpm w/10K Lbf X. - PERFORATION RECORD May-76 9960'-9962' Sqz'd HB-4 Mar-11 10,218'-10,240' Abandoned HB-6 9748'-9768' Abandoned HB-1 10,156'-10,186' Abandoned HB-5 9905'-9935' Abandoned HB-3 ,' 10,090'-10,140' Abandoned HB-5 9965'-10,052' Abandoned HB-4 9965'-10,052' Abandoned HB-4 10,090'-10,135' Abandoned HB-5 s. , 9748'-9768' Abandoned HB-1 9748'-9768' Abandoned HB-1 `' 9800'-9880' Abandoned HB-2 9792'-9880' Abandoned HB-2 ,''- 9905'-9935' Abandoned HB-3 9880'-9935' Abandoned HB-3 HB-1, 2 1..• T 9965'-10,050' Abandoned HB-4 9935'-10,061' Abandoned HB-4 Top of CaCO3 ` _' HB-3 10,206'-10,236' Abandoned HB-6 10,090'-10,186' Abandoned HB-5 Fill Tagged f 10,156'-10,186' Abandoned HB-5 @ ;- HB-4, 5 +/-9821' -._ 1-19-2011 I HB-6 r": Fish in hole: Wireline, pert guns and slickline tools—10,259'dpm. Fill Tagged 10,237'on 6/11/95 r t Ad a' '" TD= 10,400'MD 4/6/11 PBTD=5,400' MD BY: DR riF:,.,...,..,,,,,,, — • Aligg ° "4.1.P#' lA a t s s S v�&r¢°.i" i yg y ° '''''. 110ILL 1 .1 - m;e,»...... .. p fl > m , 'MMI WINo- . :f ' ''' . ' I. p 41111 • pig, 1 Alit'' w I } , y SI$ -0,044 . ' ia, . ,,..,,T,,,,:,...,,...„...,.,„,!::::4`7.:',,:. l' i Ik.Z .. ' lair Air -;.. — �v , — f ;, iiL t , .0„: , . ,,,‘"4.,4 .,,,,.., A ...4- ' '''';'-'' ' '-; '''" ' - ry{'n^'r^ g5 '""4 J t .... aiiiik .• ,, ..... . -,...::: ..... p. .. r' � ....:. t , . f..f.P4.. .‘ 41111111kirr i pilel ib di10, • 4__ t: .'4- litiNicr y, A i '4, m. Y sst v 1 ' ' ' 4411q10' '''. ,'''' ' ' :,,,,,, '' ' ' :-X—.:"::..47..*'' .. * . ' l' '''-'II,. ii,.,4;4141 '''''':' '''' 1 li '' L. .. 0 i f‘: i • , ,;,..,.,-:: -''.'.‘,."4 1.k4*- .' "I. . . T , .,..„ ,._ ,- .,..,,, ,, i , .„, ,... ., . - . i i ....., . . , ,.,,,, : . .....„... , ..,1 _..' ...i. ,:-„ ...',.:. , .,. .- ...„ . . ,„ , , , ..,. .., :I' 1/ d .,,,,„.. oir ,..., , .4.,.. ,.. .. ., . , ..,..„ . i� r , m ' ' ' 4 r:0, Aiii# .'waif. ':15-'''' ' ' r rte'= ,h,�„ .res ra vt, �r A 'K �:r.,r- �., r • • 0 'iV 7 d Li, § 1 0 FF Lo OC ilitik OD o c4 _ N3 • o rt 0 et 1 co Np vie. iii _ ii, '14%iiiquip mo i `° NodFLL0m�� O a a riin r'''' 0 ill141 . N r0 \4-41- I lipir- lir .40, ,,.....„. ,....41, ....,..s.,, ib.,...., 4,4„ Atio..„._ , N. re o I, M '.0N Irrifri I1 O aCI co Iif.°°', 1111),, 0 Cli 0 I \‘ti ' ci I � r Cg 0 D N \ rr2 0 ' / V 0 coN 4 \ 0 D N 0 1.7, ? N • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/27/15 Inspector: Jeff Jones Operator: Kenny Wingard Well Name: G-24 Oper.Rep: HAK PTD No.: 176-032 Oper.Phone: 907-776-6630 Location Verified? Yes Oper.Email: kwingard_a nticorp.com If Verified,How? Other(specify in comments) Onshore/Offshore: Offshore Suspension Date: 03/16/11 Date AOGCC Notified: l5`per.(- h Sundry No.: 310-399 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing Photos Taken? 7 3 IA OA 3� Jai,j r✓�s 1� C «..� �S C?q r i30P4;, Condition of Wellhead: D C C* P(7 t(3c4 i ,J c. 5(C' AtMES E 644(t.CSS Q e4'jrA6 4c- t4aT COt4N ErreD TO P 12onuct to , N C-, c tot) L�-,( = Condition of � ` Surrounding Surface t.��=v� Ce JO)�i j C (..011-0 Location: Follow Up Actions Needed: C Comments: Surface Location:1810'FSL,1408'FEL,Sec 29,T9N,R13W S.M. Attachments REVIEWED BY: Insp.Supry Comm PLB 12/2014 Newest Copy of Suspended Well Inspection Form • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 06/27/15 Inspector: Jeff Jones Operator: Hilcorp Well Name: TBU G-24 Oper. Rep: Ken Wingard PTD No.: 1760320 Oper. Phone: 776-6630 Location Verified? yes Oper.Email: kwingard@hilcorp.com If Verified,How? LAT/LONG Onshore/Offshore: Offshore Suspension Date: 03/16/11 Date AOGCC Notified: 08/21/15 Sundry No.: 310-399 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 185 Photos Taken? Yes IA 210 OA 2 Condition of Wellhead: Well head appears to be in good condition,no visible leaks,no flow line attached.Valves and guages are operable. Condition of Surrounding Surface Location: good condition,clean,offshore platform. Follow Up Actions Needed: None Comments: None Attachments: well head photo(1) REVIEWED BY: Insp.Supry J121C 1Z1 Z Comm PLB 06/2014 2015-0827_Suspend_TBU_G-24jj.xlsx • 0 Suspended Well Inspection—Trading Bay G-24 (Grayling) PTD 1760320 Photo by AOGCC Inspector J. Jones 8/27/15 1 .i . iisp) r .i., H I •i i t fr.-4 , vir Z• ., .� 4,44_4 1.1 11.101100001 „mg 4444« .._. Vxfic. r 410-`44106044,14.40 „, if,. s. - . ...iiiik, it., - ,;„ii. M its , rl- i ON .. ~ r tr . , ip h . „., ,.. ' „fri. .... ...Yx a t ,.- „,, tom. -Ty .1, i "7•''4 • vo" ,,, yr e+ ‘ . '''' ' -' ,..--- 1,"il, e•. ' 4 —'..r., - ~ . , ,..,„ . .,..., itioilliVT,..,0! ,4" : -,' ' ,`,,! ..-'; ''.'' .- 2015-0 827_Suspend_TBU_G-24 Jj j.docx Page 1 of 1 Chevron Fran•o Castro Chevron North Amer•xploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 .. ... - - . Anchorage, AK 99503 ...,._. _. low Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcastro@chevron.com DATE May 10, 2011 To: AOGCC Shartzer, Christine R 333 W. 7 Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL _ ..: ,..: ,--,,,;,„„;. ,,i,,,;;;WiWz1•;,,,,Afit,t,:te:k.;‘4,:tkni ,,V,,.2:.;, ,1,„ WLL:',::_ ,.:, - . - • : :;' , .' 7.i. . ;14:66 :A :' *661:5ATECF: '.:,: 'Z' .; l'.7 :..: - ,:,..,',' =.- , A.---).,'LOGGED-: ' •:' 1INE,-:' '' , . ,, „ ,,,,:„.% ,,,,, , „,.!;;;„!', ,, .' '_ ;;1=4,_Us,:isiL, ,- - ;''''r: '', ''' . - -':-: ', ' : ' TBU M-13 PRODUCTION PROFILE 20-Apr-2011 0-2862 X X TBU M-13 PRODUCTION PROFILE REPORT 20-Apr-2011 0-2862 X TBU G-24 PLUG SETTING RECORD 13-Mar-2011 306-7342 X X TBU G-24 USIT-GR-CCL 08-Mar-2011 300-9300 X X 1 ..4 4414E0 M A ,4 3 31 Ark ' ( ffil--ce-i9 /4-43C. Please acknowledge receipt b signing and returning one copy of this transmittal or FAX to 907 263 7828. Received / Date: I (51 C ( / • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg l( DATE: March 14, 2011 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: Plug Tag Petroleum Inspector Union Oil Company of California TBU G-24 McArthur River Field APR 4 MI PTD 1760320 Sundry 310 -399 Saturday, March 14, 2011: I witnessed the tag of the cast iron bridge plug (CIBP) set as a cement base for covering a suspected breach in the 9 5/8" production casing in well TBU G -24. I arrived the evening before and observed the BHA and 4" HT DP run in. The CIBP was tagged at 7234 ft with zero depth being measured at the snubbing unit basket handrail. I questioned using that as a zero and not correcting back to tubinghead flange or Braden head. It was explained that the a -line logs were all zeroed at the basket handrail and it would cause confusion to use a different reference. I checked the log that had been run to find the above mentioned breach in the 9 5/8" casing at 7144 ft. The cement job called for 300 lineal feet of cement which would be more than adequate to cover the breach. The CIBP had a tag of 10K down applied with no movement observed upon the second tag. The cement job was started and pumped with full returns. The BHA consisted of 10 joints of 2 3/8 tubing, a hydraulic disconnect was actuated after the cement was pumped and the "sacrificial" tubing was dropped on the CIBP. The plan forward was to set another CIBP on wireline above this cement plug. I left while the snubbing unit started out of the hole. Attachments: Union Oil Company Procedure Change #7 — TBU G -24 Halliburton BHA Worksheet Eline Log Section Non - Confidential Plug Tag TBU G -24 lg 3 -14 -11 1 of 1 Al4ecctime,4 ( • • w Gra lin G -24 Nember Y 9 Procedure Change `hacgeNo.. 007 Al Changes must be Risk Assessed. This form must be used to document all Well Construction Procedure Changes except for Minor Charges (refer to Page 2). This tome may also be used to generate a change from Field by the DSM. Where the Risk has been determined to be 'Material' assess whether stakeholders outside 030 are impacted, in which case use the Subsurface MOC Form. A Subsurface MOC should be used it well AFE / stakeholder objectives are impacted. Procedure Change Numbers to be allocated by the Project Operations Engineer sequentially stating at 1 for each well Number sequence to be continued for Welltest/Canptelions. Project Operations Engineer to maintain a list of procedure changes. I Request for a Procedure change I X 1 Procedure Change Drilling 1 Completion L j Testing X Intervention including WL /CT RequesuChange Tritiated by: ( David Ross (Name) Project Engineer (Position) — Programme Item Reference or Web 7 & 8 Sections: Change Details! Proposal: Based on the evaluation of the USIT log Sections 7 & 8 will now read as follows; 7.0 RIH and Set Cast Iron BP #1 Below Casino Breach 7.1. Conduct a Pre job Safety Meeting. • Review SIMOPS Checklist. • Review and sign off on Schlumberger's Cased Hole Job Preparation Form • Review explosives check list • Write and review a Job Safety Analysis sheet. ✓ Obtain work permit from authorized permit approver. 7.2 Rig up Schlumberger E -line unit and pack -off. 7.3. Test B -line for continuity prior to making up the following; • CCL . Schlumberger CPST setting tool ▪ Model N -1, 6AA CIBP Note: h$:tx rune tint OD of the C11.3P is 8.125 7 a RIH to 7,250' 7.5 P /Uto7,200'andsettheN- 1CIBP. LG: CIBP tagged at 7234' (Basket Ra 7.6. POOH andR /DE - line. Basket El. 80.55, Orig El. 40. 8 8.0 T1H with Sacrificial String and Lay in Cement Plug #2 8.1. Conduct a Pre-lob Safety Meeting. ✓ Notify AOGCC 24 hours in advance of a bridge plug tag. • Review SIMOPS Checklist • Review all applicable sections of current Safe Work Practices Manual • Write and review a Job Safety Analysis sheet. 8.2. P /U, M/U and RIH with a Halliburton BHKA assembly with a 2 318" sacrificial string as per Appendix G. Note: The length of sacrificial suing to be used will be based the tength of the i0jts cf 2 as' sooner :1a / string cu beard - 310' 8.3, Make an AOGCC witnessed tag of the bridge plug set in step 7.5. Tag plug with 10K. Record depth on morning report. .w. Page t of 5 411160 1 (ej 2 • •_ A+9 E TO 9 N David Newton t e �^w t'an. [ Sterling, Alaska 907 260 3246 (Ext 2) Company Customer Repewnlawe well Rea Dale CHEVRON USA Lafluer/Brumley iG -24 Trading Bay 3/9/2011 Plnnea 'T0 BHP BHT Well Type Met.. 776-6638 10,388' 3692 190 cuoD O136 Ann Flea welaM TobMq BHA Darialion Brine 9.8#/gal 2 3/8" eg 470#/6 304.20' _ 26.1 Tbp Flux Wet D,0 Pme Tubing 7 Brine HT -38 14#/FT 4 1/2" (a) 12.6# To 9,635' Casing casino 13 3/8" Q 61 & 68# To 5,115' 95/8" (� 47# To 10,388' 6 Run 2 It81Ci'# - Description I.D. • r Lan W Depth 16 _ 16 4" HT 38 DP to surface 3340" 4.875" 6893.80 _ 15 15 4" HT 38 DP PUP JOINT 3.340" 4.875" 4.95 6893.80 14 Cross over 2 718" EUE Pin X V147 38 Box 2.440" 4.875" 1.32 6898.75 14 13 Bottom Hole Kickoff Disconnect 1.770" 3.750" _ 1.63 6900.07 13 12 Cross over 2318" Pinto 2 7/8" EUE Box 1.995" 3.063" _ 0.75 6901.70 Hydraulic 11 1 Jt 23/8" Tubing 1.995" 3.063" 29.66 6902.45 10 1Jt2318 "Tubing 1.995" 3.063" 29.75 6932.11 Disconnect, 12 9 1 Jt 2 316" Tubing 1.995" _ 3.063" 29.50 6961.86 , 8 1 it 2318" Tubing 1.995" 3.063" 28.98 6991.36 ! 10 Jt s 11 7 1 Jt 23/8" Tubing 1.995" 3.063" 29.70 _ 7020.34 Tubing & 11 6 1 Jt 2 318" Tubing : 1.995" 3.063" 29.90 7050.04 10 5 1 Jt 2 3/8° Tubing 1.995" 3.063" 29.13 7079.94 Mule shoe p• 9 4 1 Jt 2 318" Tubing 1.995" 3.063" 28.40 7109.07 8 3 1 Jt 2 3/8" Tubing 1.995" 3.063" 29.92 7137.47 Cemented yd) 7 2 1 Jt 2 3/8" Tubes 1.995" 3.063" 29.90 _ 7167.39 in Hole 6 1 Mule Shoe 1.995" 3.063" 0.71 7197.29 5 7198.00 3 2 ... 1 A —3 '' 0i (4 L`'°J r-r- ' �4, \ . ta1r.:."lti� Zi �• l I ; w !�'.SYO= I 1. 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'1 a . n . 1 w ....s...11/111 � I � q� Il /►;�wwlw tl . k wwlwtllw 6ly0 .1, I I l _�� w t a ,r { �iw�il� ',,,,„ h 1� d tiw e� ( m fi ii, ...........:..............11;_,;,'„...-2 �.� IIIIjI1,1111 II: I I iill d "1 �wlwwiw . - , n .. . ` .In l wwiwt� Page 1 of 1 • • Aubert, Winton G (DOA) From: Ross, David A. [Swift Worldwide Resources] [rossda @chevron.com] [ 7 if 0 5 Z Sent: Tuesday, March 08, 2011 3:28 PM To: Aubert, Winton G (DOA) Cc: Kanyer, Christopher V; Tyler, Steve L; Hammons Jr, Darrell James; Brandenburg, Tim C Subject: G -24 Scope Change (Sundry # 310 -399) Mr. Aubert This message is to inform you that Chevron Alaska has decided to reduce the scope of work defined in the Approved Sundry Number 310 -399 pertaining to the Phase 1 & 2 Abandonment of well G -24. Based on the winter weather conditions, combined with significant operational problems and delays, the decision has been made to suspend the operations after achieving the primary objective of isolating the existing Hemlock bench perforations and the suspected cross flow from the Hemlock into the Grayling Gas Sands. The reduced scope of work will leave the well positioned to perform the originally planned section milling operation and isolation of the 13 3/8" surface casing shoe when a solution to the problems we have encountered can be found. At this point in time we have pulled the 4 W' completion and successfully placed and tagged the 1st cement plug. We have also completed the scraper run and are preparing to run the USIT casing and cement bond log. Following the USIT log evaluation we will proceed with the following steps prior to moving off of the well and leaving it in suspended status; • Test BOPS w/ 4" DP MAR 0 2011 • Set a cast iron BP below casing breach • Tag the CIBP w/ 10K and place a 2nd cement plug across the casing breach • Set a 2nd cast iron BP below the 13 3/8" shoe depth at +/- 5400' • Test BOPs w/ 2 -7/8" Kill String • Run a 2 -7/8" Kill String to +/- 5200' • ND BOPs and NU Tree • Skid the HWO unit. A 10-407 will be submitted at the end of this well work as required. Please advise if any additional information or documentation is required as a result of this scope change. Regards, David Ross • • Alaska Wellbore Maintenance Team Chevron North America Exploration & Production (MCA) Office: (907) 263 -7696 CeII: (907) 903 -9555 Fax: (866) 244 -1439 Email: rossda@chevron.com 3/9/2011 Regg, James B (DOA) • Page 1 of 2 • From: Regg, James B (DOA) Sent: Monday, February 28, 2011 9:35 AM j `26(! t To: 'Purugganan,Abraham'; DOA AOGCC Prudhoe Bay Subject: RE: AOGCC BOP Closure notification Plan to do full BOPE test when tubing out of hole, or just test annular and FOSV? ilt3, alz-t qt( Jim Regg AOGCC 6 o ,eeCa_ 617 - .0 u CrcOa 4 tL1 C -esi- cJke 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 t�r� 41 illaY i. (� k g q 907 - 793 -1236 ( c,rJ 1e etLe From: Purugganan,Abraham [mailto:ABRAHAMP @chevron.com] Sent: Saturday, February 26, 2011 11:23 AM To: DOA AOGCC Prudhoe Bay Cc: Brandenburg, Tim C; Bonnett, Nigel (Nigel.Bonnett); Hammons Jr, Darrell James Subject: AOGCC BOP Closure notification Date February 25, 2011 Time of BOPE Use StAINED MAR 2, 2.1% 1630 hours Well/Location/PTD Number Trading Bay Unit G - 24 /Grayling Platform /176 - 032 Rig Name DD #1 -/ 6 3 Operator Contact Abraham Purugganan, Drill Site Manager Cell 907 230 7262 Darrell, Hammons, Drilling Superintendent Office 263 -7632 Cell 907-3 82 -4225 Operations Summary, including events leading up to BOPE use After pulling joint #30 out of the hole (tubing depth 8466'), the well "burped" air and gas. Installed 2/28/2011 Page 2 of 2 • FOSV and shut annular preventer. Shut Casing pressure 0 psi. Shut in tubing pressure 0 psi. Open casing to atmosphere through gas separator. Bleed off Tubing through gas separator. Open annular preventer to monitor well and found no flow. BOPE Used Annular and Full Opening Safety Valve Reason for BOPE Use Air and gas bubbling from well. Actions Taken / To Be Taken (including the date used BOPE was tested) Check for flow, Circulate bottoms up. Flow check and continue to pull tubing. tubin .Last BOP test date 2/23/11 2/28/2011 • • Page 1 of 1 Aubert, Winton G (DOA) From: Aubert, Winton G (DOA) Sent: Monday, February 28, 2011 7:28 AM To: 'Ross, David A. [Shrift Worldwide Resources]' X 7 4 0 3 2 Subject: RE: Request for Variance Mr. Ross, Pursuant to 20 AAC 25.285 (h). altemate BOPE is approved, as described below. Vinton Aubert AOGCC 793 -1231 e FEB 2 8 ZUVV From: Ross, David A. [Swift Worldwide Resources] [mailto:rossda @chevron.com] Sent: Wednesday, February 23, 2011 4:25 PM To: Aubert, Winton G (DOA) Cc: Bonnett, Nigel (Nigel.Bo nett); Kanyer, Christopher V Subject: Request for Variance Mr. Aubert, It has been brought to my attention that the BOP stack we currently have in place for the G -24 Phase 1 & 2 Abandonment ( Approved Sundry Number 310 -399) does not comply with Regulation 20 AAC 25.285 (c) (9)(A), due to the fact that the MASP reported on the sundry application was 3283 psi and the BOP stack currently only has 2" lines and 2 - 1/16" valves connected to the choke and kill outlets. The original sundry application included a 13 5/8" stack which would have been in compliance, however in late December the decision was made to change to an 11" stack based on availability. Although we sent you an e-mail on December 22 notifying you of our desire to change the BOP stack, we failed to notice the fact that the 2" outlets on the choke line would not satisfy the requirements of the above referenced regulation. As per regulation 20 AAC 25.285 (c) (10)(A) &(B) we are in compliance with the regulation, as we do have two adjustable chokes with one being hydraulic and remotely controlled from near the drillers station. The lines on the downstream sides of the choke are 2" nominal diameter. Consequently we request a variance to regulation 20 AAC 25.285 (c) (9)(A), in order to allow us to continue operating with 2" nominal lines connected to the BOP choke outlets. Kind Regards, David Ross 4 Alaska Wellbore Maintenance Team Chevron North America Exploration & Production (MCA) Office: (907) 263 -7696 Cell: (907) 903-9555 Fax: (866) 244 -1439 Email: rossda @chevron.com 2/28/2011 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 0 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development El Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: Union Oil Company of California 5. Date Comp., Susp., or 12. Permit to Drill Number: Aband.: 3/16/2011 176 -032 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 4/6/1976 50- 733 - 20286 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1810 FSL, 1408 FEL Sec 29, T9N, R13W, SM 5/7/1976 Trading Bay Unit G -24 Top of Productive Horizon: 8. KB (ft above MSL): 99' 15. Field /Pool(s): 775' S & 247' E of NE corner (Sec 32 T9N R13W S.M.) GL (ft above MSL): McArthur River Field / Hemlock Oil Pool Total Depth: 9. Plug Back Depth(MD +TVD): 992'S & 157'W from NE corner. (Sec 32 T9N R13W S.M) 6,919' MD / 6,565' TVD 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 212274 y- 2502359 Zone- 4 10,400' MD / 9,819' TVD ADL0017594 [Grayling Platform] TPI: x- N/A y- N/A Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 213526 y- 2499577 Zone- 4 N/A N/A 18. Directional Survey: Yes U No U 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) 125 (ft MSL) N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re- drill /Lateral Top Window MD/TVD: USIT N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM / TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20" 94 H -40 0 829' 0 828' 23" 850 sxs 13 -3/8" 61 K -55 0 2,700' 0 2,662' 17.5" 5329 cu ft 13 -3/8" 68 K -55 2,700' 5,115' 2,662' 4,885' 17.5" 9 -5/8" 47 N -80 0 7,207' 0 I 6,832' I 12 -1/4" 1200 sxs 9 -5/8" 47 P -110 7,207' 8,347' 6,832' 7,897' 12 -1/4" 9 -5/8" 47 USS -95 8,347' 10,388' 7,897' 9,808' 12 -1/4" 24. Open to production or injection? Yes No Ei If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 2 -7/8" 6.4# L -80 5,224' - - j, APR. b nil ,s EV\'' , 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 9,310'- 9,821' 30 bbl 15.3ppg class G cement 6,919'- 7,234' 22 bbl 15.3ppg class G cement 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A - Suspended N/A - Suspended Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: - - Test Period —► - - - - - Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. - - 24 -Hour Rate -.► - - - - 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 13 Sidewall Cores Acquired? Yes ❑ No El If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and labors Cps r 2 071. RBDMS APR 14 2011 " ""1 C i Gas owe. of Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only • • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top N/A N/A needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base N/A N/A Formation at total depth: N/A N/A 31. List of Attachments: Schematic, Directional Survey, Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Ross 263 -7696 Printed Name: Timothy C. Brandenburg Title: Drilling Manager I� Signature:' Phone: 276 -7600 Date: 4/5/2011 ' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1b: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Chevron • • GRAYLING PLATFORIIA' %. WELL #: G -24- Actual 4 -6 -11 ;, RKB = 40.48' Rig Floor to DCB TBG Spool RKB to MSL = 99' Al — I CASING AND TUBING DETAIL SIZE WT GRADE CONN ID MD Top MD Btm Hole Cmt Cmt 20" 94# H-40 19.124" Surface 829' , 23" 850 sxs surface 13 -3/8" 61# K -55 Butt 12.515" Surface 2700' 17.5" 5329 cu ft Surface 13 -3/8" 68# K -55 Butt 12,415" 2700' 5115' 17.5" N-80 8.681" Surface 7207' 9 -5/8" 47# P110 Butt 8.681" 7207' 8347' 12 1/4" 1200 sxs 8200' USS -95 8.681" 8347' 10,388' -- 2 7/8" 6.4# L -80 BUTT 2.441" Surface 5,224' Kill SCC String Set CIBP @ 5,400' wlm Suspension Details NO MD Top MD Btm TVD Top TVD Btm Item 9 . 8 ppg KW W Fluid 1 5400' 5403' 5155' 5158' Mechanical CIBP 2 5403' 6919' 5158' 6565' 9.8 ppg Kill Weight Brine 3 6919' 7234' 6565' 6857' Cement Rug #2 4 6919' 7232' 6565' 6855' 2 3/8" Sacrificial String Tagged 5 7234' 7237' 6857' 6860' Mechanical CIBP CIBP . @ 7,234' 6 7237' 9310' 6860' 8796' 9.8 ppg Kill Weight Brine dpm w/ 10K Lbf 7 9310' 9821' 8796' 9278' Cement Plug #1 8 9535' 9815' 9008' 9272' 2 3/8" Sacrificial String 9.8 ppg 9 9635 9639 9103 9107' OTIS BWH Perma -Drill Packer KW Fluid Tagged Cement @ 9,310' dpm w/ 10K Lbf X X PERFORATION RECORD /� /� May -76 9960' -9962' Sqz'd HB -4 Mar -11 10,218' 10,240' Abandoned HB -6 9748' -9768' Abandoned HB -1 10,156'- 10,186' Abandoned HB -5 9905' -9935' Abandoned HB -3 10,090'- 10,140' Abandoned HB -5 9965'- 10,052' Abandoned HB -4 9965'- 10,052' Abandoned HB -4 10,090'- 10,135' Abandoned HB -5 9748' -9768' Abandoned HB -1 9748' -9768' Abandoned HB -1 9800' -9880' Abandoned HB -2 9792' -9880' Abandoned HB -2 9905' -9935' Abandoned HB -3 9880' -9935' Abandoned HB -3 HB - 2 9966- 10,050' Abandoned HB -4 9936- 10,061' Abandoned HB -4 Top of CaCO HB - 10,206- 10,236' Abandoned HB -6 10,090'- 10,186' Abandoned HB -5 Fill Tagged I 10,156- 10,186' Abandoned HB -5 +/- 9821' HB - 5 1 -19 -2011 ! HB - Fish in hole: Wireline, pert guns and slickline tools — 10,259' dpm. Fill Tagged 10,237' on 6/11/95 0 TD = 10,400'MD PBTD = 5,400' MD 4/6/11 BY: DR . . Chevron 1%0 Chevron-Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UVVI ChevNo Original RKB (ft) Water Depth (ft) G-24 TRADING BAY UNIT G-24 ADL0017594 5073320286 AR4484 99.00 Jobs , Primary Job Type Job Category Objective Actual Start Date Actual End Date Plug - Permanent Abandon 2/3/2011 Primary Welibore Affected Wellbore UVVI Well Permit Number G-24 507332028600 1760320 Dal 0. ratto 213/2011 00:00 - 2/4/2011 00:00 Operations Summary Well preparation. 2/412011 00:00 , 21612011 00:00 Operations Summary Begin mobilizing equpiment. 21612011 00:00 - 2/6/2011'0o:00 . . Operations Summary Continue mobilizing and rigging up equipment. 2/612011 00:00 - 2/7/2011 00:00 Operations Summary Continue mobilizing and rigging up equipment. , Operations Summary Continue mobilizing and rigging up equipment. 2/8/2011 00:00 - 2/9/2011 00:00 Operations Summary Continue mobilizing and rigging up equipment, prepare to ND Tree and NU BOPs, set BPV. 21612011 00:00 - 2/10/2011'10:00 Operations Summary Finish ND tree. NU BOP Begin rigging up CUDD hydrualic workover unit. 040iti 0000 - 211112011.007,00 Operations Summary Continue rigging up CUDD HWO unit. 2/11/2911 00:06 - 2/12/2011 Operations Summary Continue rigging up CUDD HWO unit. 2/12/2011 00:002/13!2011 06:00 Operations Summary Continue rigging up CUDD HWO unit. 2/13/2011 00:08 - . . Operations Summary Continue rigging up CUDD HWO unit. J4/2 00O0*2/1$k k!0000 Operations Summary Continue rigging up CUDD HWO unit. gOtt0002/16120fl 00;0O Operations Summary Continue rigging up CUDDD HWO unit. Gave AOGCC 24 Hr notice for upcoming BOP test. 2/16/2011 00;00,7,2/17/2011 00:00 Operations Summary Continue rigging up CUDD HWO unit. 2/17/2011 00:00 - 2/18/2011 00:00 Operations Summary Continue rigging up CUDD HWO, shell test BOP stack to 250/3500 psi , good test. 2/18/2011:09:00 - 2119/2011 00:00 Operations Summary Continue rigging up CUDD HWO unit. Operations Summary 6:- Continue rigging up CUDD FIWO unit. 2i 00;■*i 0000 Itw • perations Summary ontinue rigging up CUDD HWO unit. Prepare for BOP test. Test kill HCR and choke valves #4,13,and 14 to 250/2500 psi for 5 minutes, thaw out and eat trace stand pipe and kelly hose. Repair accumulator system. Perform AOGCC accumulator test - good test, Thaw out frozen lines from choke anifold to gas buster tank. EVIL. fl - 0 0 Operations Summary BOP test operations suspended to winterize equipment and heat trace lines, Notified AOGCC of BOP test © 17:30 hrs. Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) G -24 TRADING BAY UNIT G-24 ADL0017594 5073320286 AR4484 99.00 i1 �� 4 2/22/2011 00:00 - 2/23/2011 00:00 Operations Summary Continue winterizing rig and preparing for BOP test. Test Annular BOP to 250/2500 psi (Good Test), Attempt to test UPR and LWR pipe rams w/o success. Blew down stack and opened both sets of rams. Found 5 1/2" in UPR and worn out 2 7/8" x 5" VBR in the LWR. Changed out rams dress both with new 2 7/8" x 5" VBRs. Test UPR with 4 1/2" test joint , kill HCR and choke manifold to 250/3500 psi (Good Test) AOGCC ( Bob Noble) witnessed BOP test 2/23/2011 00:00 - 2/24 /2011 00 :00 ,. Operations Summary Pressure test BOPE, UPR and LWR VBRs, w/ 4 -1/2" test jt, choke manifold, manual kill valves and HCR valves to 250/3500 psi. All tests good, witnessed by Bob Noble with AOGCC. Pull BPV and install 2 -way check. Replace 4 -1/2" test jt. with 4" test jt. Test annular to 250/2500 psi, good test. Repeat all BOP tests to 250/3500 psi, all good tests. Change slip dies to 4 -1/2 ", test blind rams and IBOP to 250/3500 psi good test. Replace accumulator hydraulic pump and re -test same. M/U 4 -1/2" landing joint and prepare to circulate well with FIW. ¢2/24/201100:00 2/20/204 00 :00 • ..: ?zt <, Operations Summary M/U landing joint to hanger, prepare to pull tubing. Pressure test high pressure iron and stand pipe to 3000 psi, good test. Circulated well w/ FIW. Backed out lockdown screws and unseat hanger, worked pipe. Pipe pulled free . Pull hanger to work window and breakout same. Begin POOH with 4 -1/2" 12.6# L -80 completion. 2/25/2011 00:O4 ;'2. 1.1 00:00 kip..µ Operations Summary Continue POOH & UD w/ 4 1/2" tubing, had gas bubble up annulus, shut in annular, SITP =Opsi, SICP =Opsi, monitored well, circulated well clean w/ FIW. Notified AOGCC of use of BOPE closure. 4140 - 2/27/2011 OO:O Operations Summary Continue POOH & UD w/ 4 -1/2" tubing. 2/27/2011 00:00 - 2/28/2011,00 :00 r , -, :: r pat ,i Operations Summary Continue POOH & UD w/ 4 -1/2" tubing and GLMs. 2/28/2011 00t t, 3/at2 O0 :00a Operations Summary Finish POOH and UD 4 -1/2" tubing, GLMs and seal assembly, 100% recovery. Prepare for BOP test, witnessing waived by AOGCC (Jim Regg) @ 11:20 am. M/U 4" test joint. P/T annular to 250/2500 psi, choke manifold valve, kill line and kill line HCR. Low test good, high test failed. Trouble shooting choke side HCR stem. 3/1/2011 00 :00;- 3/2/2011 00:00 Operations Summary R/U 4" test jt. test Annular, IBOP HCR Kill & Choke valves to 250/2500 psi, high test failed, choke HCR leaking. Retest same w/o choke HCR for 5 mins e- good test but discovered kill HCR also leaking. Test UPR VBRs and inside manual choke and kill valves to 250/3500 psi, good test. Test LWR VBRs to 250/3500 psi, good test. Rebuild choke and kill HCRs and service valves on the choke manifold. Test choke manifold to 250/3500 psi, good test. Re -test choke and kill HCRs to 250/3500 psi, good test. Perform accumulator test, good test. Test blind rams to 250/3500 psi, good test. Pull test plug and install wear bushing. 3/2/2011 00:01'4 2 i -`, ' :00 .. ; •,,. Operations Summary P/U 2 3/8" sacrificial cement string and RIH with 4" DP to place mule shoe at 9815'. Worked through tight spot at 9404'. Space out and R/U cementing head and loaded disconnect dart. 3/4 /2011' 00.00 Operations Summary Continue rigging up to circulate, shut down for high winds. Started pumping and sacrificial string packed off. Regained circulation and began CBU w /FIW. Circulated — LCM material and sand out of well. Packed off several times while changing tanks. 34412011 00:00 - 3/5/201100:00 , .' ., `.. Operations Summary Continue circulating well at 7 BPM, shut down to transfer fluid and string packed off again. Broke circulation, pumped and displaced 30 Bbls of 15.3 ppg class G cement. Bumped dart, sheared and released from hydraulic release with 2400 psi. Cement in place at 05:20. Pulled pipe from 9535' to 8879'. CBU, no cement returns detected at bottoms up. Continue to pull out of hole. Jim Regg with AOGCC waived witness of upcoming cement plug tag. 3/5/2011 00:00 3/6/201100:0Os , .. Operations Summary Continue TOH with cement string. Prepare to P/U 9 -5/8" scraper assembly. P/U scraper assembly and TIH to 4032'. Operations Summary Continue TIH to 5067'. Rotate and reciprocate from 5068' - 5131'. TIH to 7072' and break circulation begin rotating. Encountered tight spots at 7088' and 7144' worked through both spots, continue TIH , tag TOC w/ 10K at 9310'. (AOGCC, Jim Regg waived witness of tag). P/U to 9280' and CBU at 7 BPM. 3/ 7/ 2011 00:00' - 318/.201005 :xi . Operations Summary Continue circulating bottoms up at 7 BPM. No sign of sand or LCM. Displace well to 9.8 ppg KWF (NACL brine w /starch and polymer) separated by a 50 Bbl high vis pill. TOH and UD scraper BHA. Recovered a small amount of iron from magnets and two pieces of metal from boot basket. Prepare to P/U 5" DP for E -line lubricator. Notified AOGCC of upcoming BOP test. Jim Regg waived witness. Chevron • • %O. Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) G -24 TRADING BAY UNIT G -24 ADL0017594 5073320286 AR4484 99.00 3/8/2011 00:00` - 3/9/2014 00:00 Y, .. . �`. Operations Summary Continue M/U 5" DP lubricator. Waiting on boat to offload E -line unit. M/U 4" test joint and proceed with BOP test. Test annular to 250psi low /2500 psi s^ high for 5 mins, good test. Tested BOPE to 250psi low /3500 psi high for 5 mins. Good tests, all tests recorded. AOGCC Jim Regg waived witness of BOP test. Pull test plug and install wear bushing. UD test joint. RU E -line unit. Reconfigure e-line lubricator. R/U pack off to lubricator and M/U USIT tool string. 3/9/2011 00:00 - 3/10/2011 00 :00 Operations Summary M/U USIT tool string and RIH to 9300' , logged up to 300', made several high resolution passes. Pulled out of hole, UD USIT tool. RIH w/ 9 -5/8" CIBP and attempted to set @ 7200' but had problem getting the proper voltage to the setting tool. TOH to change out setting tool and stuck BP at 990'. Attempted to release pulling up to 8800# w/o success, encountered bird nested e-line in lubricator. 3110/2014 00:00 - 3/1112014 00:00 Operations Summary Remove packoff from E -line lubricator, cut wire and remove birds nest from lubricator. Attach good wire to reel and retrieve setting tool w/o 9 -5/8" CIBP. Re -head E -line and RIH w/ GR/CCL, tagged plug @ 1008', POOH and R/D E -line. Prepare to P/U milling BHA. 4144!2011 00000.31121201'1 00 :00 Operations Summary M/U 8- 7/16" milling BHA and TIH to mill 9 -5/8" CIBP. Tagged CIBP at 1048' and milled same. Pumped hi vis sweep and CBU w /FIW . Continue to TIH to 6,237' pushing milled CIBP. 3/12/20;1100 :00 - 3/13/2011 000f ....� x.s> Fz :r. € ' Operations Summary Continue TIH to 7,427', no indication of CIBP. TOH and UD milling BHA. 3/13/2011 00 :01134 PO 1' "00:00 Operations Summary R/U E -line equipment. RIH with 8.25" GR/junk basket to 7,350'. POOH and UD tool string. RIH and set 9 -5/8" CIBP at 7,200' wlm. POOH and R/D E -line. P/U and M/U BHKA disconnect with 10 jts of 2 3/8" tubing. TIH with sacrificial string assembly to 6,704'. te r. 3/14/2011 00 :00 - 3/15/2011 00 :00 Operations Summary Continue TIH w/ sacrificial string. Lou Grimaldi w/ AOGCC witnessed the 10K tag of the 9 -5/8" CIBP at 7234' DPM. AOGCC gave verbal approval for a/ requested variance allowing for a pipe ram test in place of a full BOP test given there are 2 mechanical barriers and one hydraulic barrier /performing the full BOP test upon moving to G -25 Circulated, mixed and pumped 22 Bbls of 15.3 ppg class G cement. Displaced and landed dart, disco nect sheared at 2300 psi. Attempted to sqz cem nt through casing breach w/ no success. Circulated well, no cement at surface. TOH w/ DP and UD BI-IA. R/U E -line and RIH w/ 9 -5/8" CIBP and set at 5400', POOH and R/D E -line. M/U 2 -7/8" test jt. and pull wear bushing. 3115/2011 00:00 - 3ti01 0` t 00 :00 Operations Summary Set test plug, test 2 -7/8" VBRs, FOSV and IBOP to 250/3500 psi, Good Test. P/U and TIH w/ 163 jts of 2 -7/8" 6.4# L -80 kill string to 5224'. P/U and M/U hanger w/ BPV, land hanger and test to 5K psi for 15 mins. Good Test. Begin N/D BOP 3/ 1612011.00:00 - 3/17/2011 .. , a ., Operations Summary Finish N/D BOP, N/U Tree and test bonnet and tree to 350/5000 psi for 30 min. Good Test. Perform casing test to 1500 psi and chart for 30 mins. Good Test. Release rig at 18:00 and prepare to skid to G -25. , • • Report Name Well Date Created Position Log G -24 11/3/2010 KB Surf X Surf Y Well Name CURRENT STATUS API (ft) (ft) (ft) G -24 SHUT -IN OIL 507332028600 99 212,274 2,502,359 MD TVD SSTVD X Off Y Off X Y Inc Azimuth (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg) (deg) 0 0 99 0 0 212,274 2,502,359 0 180 100 99 0 0 0 212,274 2,502,359 0.3 162 200 199 -100 0 0 212,274 2,502,359 0.1 133 300 299 -200 0 0 212,274 2,502,359 0.2 290 400 399 -300 0 0 212,274 2,502,359 0.3 249 500 499 -400 0 -1 212,274 2,502,358 0.3 224 600 599 -500 -1 -1 212,273 2,502,358 0.4 225 700 699 -600 -1 -2 212,273 2,502,357 0.6 217 800 799 -700 -2 -2 212,272 2,502,357 0.7 224 900 899 -800 -3 -3 212,271 2,502,356 0.4 213 1,000 999 -900 -3 -4 212,271 2,502,355 0.4 221 1,100 1,099 -1,000 -4 -5 212,270 2,502,354 0.8 221 1,200 1,199 -1,100 -4 -6 212,270 2,502,353 0.6 195 1,300 1,299 -1,200 -5 -6 212,269 2,502,353 0.3 251 1,400 1,399 -1,300 -5 -6 212,269 2,502,353 0.3 193 1,500 1,499 -1,400 -5 -8 212,269 2,502,351 1.1 133 1,600 1,599 -1,500 -2 -10 212,272 2,502,349 3.1 129 1,700 1,699 -1,600 3 -14 212,277 2,502,345 5.1 116 1,800 1,799 -1,700 11 -20 212,285 2,502,339 6.7 130 1,900 1,898 -1,799 20 -30 212,294 2,502,329 8.8 141 2,000 1,996 -1,897 31 -43 212,305 2,502,316 10.7 141 2,100 2,094 -1,995 43 -59 212,317 2,502,300 12.4 141 2,200 2,191 -2,092 57 -77 212,331 2,502,282 14.2 143 2,300 2,288 -2,189 72 -99 212,346 2,502,260 16.3 145 2,400 2,384 -2,285 88 -124 212,362 2,502,235 18.1 146 2,500 2,478 -2,379 105 -152 212,379 2,502,207 20.7 147 2,600 2,571 -2,472 125 -184 212,399 2,502,175 22.8 147 2,700 2,662 -2,563 145 -218 212,419 2,502,141 23.9 148 2,800 2,754 -2,655 166 -253 212,440 2,502,106 24.3 148 2,900 2,845 -2,746 187 -288 212,461 2,502,071 24.5 148 3,000 2,936 -2,837 208 -324 212,482 2,502,035 24.9 148 3,100 3,026 -2,927 229 -361 212,503 2,501,998 25.1 149 3,200 3,117 -3,018 251 -398 212,525 2,501,961 25.6 149 3,300 3,207 -3,108 272 -436 212,546 2,501,923 26.1 150 3,400 3,297 -3,198 293 -474 212,567 2,501,885 25.7 149 3,500 3,387 -3,288 314 -512 212,588 2,501,847 25.4 149 3,600 3,477 -3,378 335 -549 212,609 2,501,810 25 150 3,700 3,568 -3,469 355 -586 212,629 2,501,773 24.4 150 3,800 3,659 -3,560 375 -622 212,649 2,501,737 23.9 150 3,900 3,751 -3,652 394 -657 212,668 2,501,702 23.4 151 4,000 3,843 -3,744 412 -692 212,686 2,501,667 22.7 151 4,100 3,935 -3,836 429 -726 212,703 2,501,633 22.5 151 • • 4,200 4,028 -3,929 447 -759 212,721 2,501,600 21.7 151 4,300 4,121 -4,022 464 -791 212,738 2,501,568 21.3 151 4,400 4,215 -4,116 480 -823 212,754 2,501,536 20.7 152 4,500 4,308 -4,209 495 -855 212,769 2,501,504 20.1 153 4,600 4,402 -4,303 510 -885 212,784 2,501,474 19.3 153 4,700 4,497 -4,398 525 -915 212,799 2,501,444 19.9 151 4,800 4,590 -4,491 541 -946 212,815 2,501,413 21.1 150 4,900 4,684 -4,585 559 -977 212,833 2,501,382 21.4 149 5,000 4,777 -4,678 577 -1,008 212,851 2,501,351 20.5 149 5,100 4,871 -4,772 594 -1,038 212,868 2,501,321 19.6 149 5,200 4,966 -4,867 610 -1,066 212,884 2,501,293 18 149 5,300 5,061 -4,962 625 -1,093 212,899 2,501,266 18.3 149 5,400 5,155 -5,056 640 -1,121 212,914 2,501,238 19.1 150 5,500 5,249 -5,150 656 -1,151 212,930 2,501,208 20.5 152 5,600 5,343 -5,244 672 -1,184 212,946 2,501,175 21.7 153 5,700 5,435 -5,336 689 -1,217 212,963 2,501,142 22.7 152 5,800 5,527 -5,428 706 -1,253 212,980 2,501,106 23.4 153 5,900 5,619 -5,520 723 -1,289 212,997 2,501,070 23.8 154 6,000 5,710 -5,611 740 -1,326 213,014 2,501,033 24.8 153 6,100 5,802 -5,703 755 -1,363 213,029 2,500,996 21.4 161 6,200 5,895 -5,796 765 -1,397 213,039 2,500,962 20.4 163 6,300 5,989 -5,890 774 -1,430 213,048 2,500,929 20.3 162 6,400 6,083 -5,984 784 -1,464 213,058 2,500,895 21.1 163 6,500 6,176 -6,077 794 -1,499 213,068 2,500,860 21.1 164 6,600 6,269 -6,170 802 -1,534 213,076 2,500,825 21.3 166 6,700 6,362 -6,263 _ 810 -1,570 213,084 2,500,789 22.3 166 6,800 6,455 -6,356 818 -1,607 213,092 2,500,752 22.1 166 6,900 6,547 -6,448 827 -1,644 213,101 2,500,715 22.3 166 7,000 6,640 -6,541 835 -1,681 213,109 2,500,678 22.5 166 7,100 6,732 -6,633 843 -1,718 213,117 2,500,641 22.1 166 7,200 6,825 -6,726 851 -1,755 213,125 2,500,604 21.9 166 7,300 6,918 -6,819 859 -1,791 213,133 2,500,568 21.6 166 7,400 7,011 -6,912 868 -1,827 213,142 2,500,532 22 166 7,500 7,104 -7,005 876 -1,863 213,150 2,500,496 20.9 166 7,600 7,197 -7,098 883 -1,897 213,157 2,500,462 20.5 166 7,700 7,291 -7,192 891 -1,931 213,165 2,500,428 20.4 166 7,800 7,385 -7,286 899 -1,965 213,173 2,500,394 20.3 164 7,900 7,479 -7,380 907 -1,999 213,181 2,500,360 20.3 166 8,000 7,572 -7,473 915 -2,033 213,189 2,500,326 20.5 166 8,100 7,666 -7,567 923 -2,067 213,197 2,500,292 20.6 164 8,200 7,760 -7,661 932 -2,101 213,206 2,500,258 20.6 164 8,300 7,853 -7,754 941 -2,135 213,215 2,500,224 20.7 164 8,400 7,947 -7,848 950 -2,169 213,224 2,500,190 20.3 163 8,500 8,041 -7,942 959 -2,202 213,233 2,500,157 20.3 163 8,600 8,134 -8,035 969 -2,236 213,243 2,500,123 21.1 163 8,700 8,227 -8,128 978 -2,272 213,252 2,500,087 21.6 164 8,800 8,321 -8,222 988 -2,306 213,262 2,500,053 20.9 161 8,900 8,414 -8,315 999 -2,340 213,273 2,500,019 20.7 161 9,000 8,507 -8,408 1,009 -2,375 213,283 2,499,984 22.1 163 9,100 8,600 -8,501 1,020 -2,411 213,294 2,499,948 21.6 160 9,200 8,693 -8,594 1,032 -2,445 213,306 2,499,914 20.3 159 9,300 8,787 -8,688 1,044 -2,477 213,318 2,499,882 20.7 159 • • 9,400 8,881 -8,782 1,055 -2,510 213,329 2,499,849 19.4 159 9,500 8,975 -8,876 1,067 -2,541 213,341 2,499,818 19.1 156 9,600 9,070 -8,971 1,079 -2,572 213,353 2,499,787 20.1 158 9,700 9,164 -9,065 1,092 -2,602 213,366 2,499,757 18.6 156 9,800 9,258 -9,159 1,104 -2,633 213,378 2,499,726 20.3 156 9,900 9,352 -9,253 1,117 -2,665 213,391 2,499,694 20.2 157 10,000 9,446 -9,347 1,130 -2,697 213,404 2,499,662 20.4 157 10,100 9,540 -9,441 1,143 -2,730 213,417 2,499,629 20.8 157 10,200 9,633 -9,534 1,156 -2,763 213,430 2,499,596 20.4 157 10,300 9,727 -9,628 1,169 -2,796 213,443 2,499,563 21.5 158 10,400 9,819 -9,720 1,182 -2,832 213,456 2,499,527 23 159 Chevron 4 10 l — Q 2 _ OBJECTIVE: • Perform permanent isolation of open perforated intervals, 9 -5/8" casing breech, and surface casing shoe. Current BHP: 4,250 psi @ 9,667' TVD Max Downhole Pressure: 4,250 psi @ 9,667' TVD (Based on 8.45ppg sea water gradient to bottom of HB -6 perfs) MASP: 3,283 psi (Based on a pressure gradient of 0.1 psi per foot of true vertical depth) PROCEDURE SUMMARY: 3 R/U slick -line. 4 RIH w/ GR and tag the top of fill. 1 Mobilize the CUDD HWO unit. 2 N/D tree, N/U BOPE, & test same. '! ED F EP, Z(Yre 5 Circulate well to filtered inlet water (FIW). 6 Recover 4 -1/2" completion down to Otis BWH packer at 9,635' (plus tubing tail down to 9,706'). 7 P/U and TIH with 2 -3/8" sacrificial string with BHKA disconnect on DP. 8 Lay in a ( + / -) 15.3 ppg cement plug from top of fill to ( + / -) 9,435' (above the packer @ 9,635'), release BHKA, POOH Note: The volume of cement will be determined after tagging the fill in step 4. 9 P/U a 9 5/8" scraper assembly a TIH and tag TOC at ( + / -) 9,435' with 10K. Circulate well to 9.8ppg kill weight fluid, POOH. 10 R/U E -line 11 RIH with a USIT tool and log 9 5/8" casing to identify a possible casing breach, POOH 12 Contingency: If breach is identified Set 9 -5/8" BP and set ( + / -) 50' below the casing breach 13 Contingency: P/U and TIH with a 2 -3/8" sacrificial string with BHKA disconnect on DP. 14 Contingency: Lay in a ( + / -) 450' [( + / -) 33 bbl ( + / -) 15.3 ppg] cement plug from the top of the bridge plug, release BHKA, POOH, apply 750 psi squeeze pressure (attempt to squeeze 10bbl cement through casing breach). 15 Contingency: WOC. TIH and tag TOC with 10K. 16 Set 9 -5/8" BP at ( + / -) 5,400' and perforate 9 5/8" casing below the future milled window. 17 RIH w/ section mill to ( + / -) 30' above the 13 -3/8" casing shoe and mill window in 9 -5/8" casing from ( + / -) 5,085' to ( + / -) 5,135'. 18 RIH with cleanout assembly to clean window and tag fill above BP, POOH. 19 RU Eline. RIH w/ downhole camera to inspect milled window. 20 RIH w/ inflatable ECP (external casing packer) assembly to ( + / -) 5,090'. 21 Lay in 15.3 ppg cement in cased & open hole on top of fill on BP up to ( + / -) 4,800', prior to setting inflatable ECP from ( + / -) 5,090' to ( + / -) 5,110'. 22 WOC. TIH and tag TOC at ( + / -) 4,800' with 10K. 23 N/D BOPE, N/U tree, and secure well. 24 RD and release CUDD HWO unit. Suspended Well Data: • Wellhead pressures will be recorded monthly at minimum. • Well has been shut in since March 2003. Operations in October 2010 included the circulation of the well to sea water. These operations demonstrated sufficient ability for the well tubing and casing pressures to remain at Opsi since the operations concluded. • It is proposed that an additional Application of Sundry Approvals (Form 10 -403) for operations related to the installation of a surface abandonment plug will be submitted at an unknown date in the future. The well will be maintained in suspended status until the Grayling Platform production is shut -in and the platform abandonment commences. • Trading Bay Unit G -24 1 -26 -2011 G -24 REVISED BY: CVK 1 -26 -2011 ` SEAN PARNELL, GOVERNOR ALASKA OIL AND GALS 333 W. 7th AVENUE, SUITE 100 CONSERVATION CO IIDIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager g g � O" Union Oil Company of California P.O. Box 196247 I Anchorage, AK 99519 Re: McArthur River Field, Hemlock Oil Pool, TBU G -24 Sundry Number: 310 -399 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, e 000 Daniel T. Seamount, Jr. Chair DATED this day of December, 2010. Encl. Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box Anchoragee, , AK AK 99519 -6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt @chevron.com December 2, 2010 RECEIVED DEC 0 3 2010 Commissioner Alaska Oil & Gas Cons. Commission Alaska Oil & Gas Conservation Commission Warne 333 W. 7 th Avenue, Suite 100 Anchorage, Alaska 99501 -3572 Re: Grayling G -24 Integrity, Application for Sundry Approval Dear Commissioner Enclosed for your approval is an Application for Sundry Approval (Form 10 -403) for the above referenced well. The outlined work is a result of diagnostic work, in which an integrity issue was identified. We suspect communication issues in this well with the Grayling water flood injection and as a result plan to perform the Phase 1 and Phase 2 abandonment. No surface abandonment will be performed at this time. The well has already been killed with an abandonment tree installed. G -24 will be maintained in suspended status until the Grayling Platform production is shut -in and the platform abandonment commences. i If you have any questions pertaining to this information, please contact David Ross at 907 -263- 7696 or Nigel Bonnett at 907 - 263 -7853. Timothy C. Brandenburg Drilling Manager Enclosure Cc: Well File David Ross Union Oil Company of California / A Chevron Company -- 0.10 c��� RECE1V .,j�tn ti STATE OF ALASKA i DEC 0 3 20 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Alaska Oil & Gas cons. O'MITI sse r 20 AAC 25.280 An dorme 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑� , Plug Perforations ❑� ' Perforate ❑ Pull Tubing E10K µ{b Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing d Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development Q . Exploratory ❑ 176 -032 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20286 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 21 Trading Bay Unit G -24 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0017594 [Grayling Platform] McArthur River Field / Hemlock Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 10,400 9,819 10,237 9,668 N/A 10,237'( fill) Casing Length Size MD ND Burst Collapse Structural Conductor 829' 20" 829' 828' 1,530 psi 520 psi Surface 5,115' 13 -3/8" 5,115' 4,885' 3,090 psi 1,540 psi Intermediate Production 10,388' 9 -5/8" 10,388' 9,808' 6,870 psi 4,750 psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,748' - 9,768', 9,792' - 10,061', 9,209' - 9,228', 9,250'- 9,503', 10,090' - 10,186', 10,206' g 531'- 9,620', 9,639'- 9,671' 4 -1/2" 12.6# L -80 9,706' 10,240' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): Otis BWH Perma Drill Packer / Otis Flapper Valve 9,635'MD (9,103'ND) / 341 'MD (341 'ND) 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Exploratory ❑ Development ❑✓ r Service ❑ 14. Estimated Date for 12/21/2010 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended Q . 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Ross 263 -7696 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276 -7600 Date 12/1/2010 COMMISSION USE ONLY q Conditions of approval: Notify Commission so that a representative may witness Sundry Number: O t Plug Integrity M l*' BOP Test 0?/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: - rt c.+ 30 1 r t0 35 0 d Subsequent Form Required: Q 01. APPROVED BY Approved by: X O I I THE COMMISSION Date: Form 10-403 Revised 1/ 1 b ULU U K N Submit in Duplicate Chevron • • Trading Bay Unit G -24 11 -18 -2010 OBJECTIVE: • Perform permanent isolation of open perforated intervals, 9 -5/8" casing breech, and surface casing shoe. Current BHP: 4,250 psi @ 9,667' TVD Max Dow Pressure: 4,250 psi @ 9,667' TVD (Based on 8.45ppg sea water gradient to bottom of HB -6 perfs) MASP. si (Based Q�1 a pressure gradient of 0.1 psi per foot of true vertical depth) PRORE SUMMARY: 1 Mobilize the CUDD HWO unit. 2 N/D tree, N/U BOPE, & test same. 3 R/U slick -line. 4 RIH w/ GR and tag the top of fill.. 5 Circulate well to 9.8ppg kill weight brine. 6 Pull 4 -1/2" completion down to Otis BWH packer a 9,6: ' 7 P/U and TIH with 2 -3/8" sacrificial string with BHKA disconnect on DP. 8 Lay in a ( + / -) 15.8 ppg cement plug from top of fill to ( + / -) 9,550' (above the packer @ 9,635'), release BHKA, POOH Note: The volume of cement will be determined after tagging the fill in step 4. 9 P/U a 9 5/8" scraper assembly a TIH and tag TOC at ( + / -) 9,550' with 10K OG POOH 10 R/U E -line 11 RIH with a USITIodrand log 9 5/8" casing to identify possible casing breach, POOH 12 Contingency: If breach is identified Set 9 -5/8" BP a1 4 set ( + / -) 50' below the casing breach 13 Contingency: P/U and TIH with a 2 -3/8" sacrificial string with BHKA disconnect on DP. 14 Contingency: Lay in a ( + / -) 300'[(+/- 22 bbl ( + / -) 15.8 ppg] cement plug from the top of the bridge plug, release BHKA, POOH, apply 750 psi squeeze pressure. 15 Contingency: WOC. TIH and tag TOC with 10K. 16 Set 9 -5/8" BP at ( + / -) 5,200' 17 RIH w/ section mill to ( + / -) 20' above the 13 -3/8" casing shoe and mill window in 9 -5/8" casing from ( + / -) 5,095' to ( + / -) 5,130'. 18 RIH w/ inflatable ECP (external casing packer) to ( + / -) 5,100' 19 Lay in ( + / -) 3 32.5'`bbl 15.8ppg cement in cased & open hole on top of BP set 5,200' up to ( + / -) 4,800, prior to setting i inflatable ECP at ( + / -) 5,100'. 20 WOC. TIH and tag TOC at ( + / -) 4,800' with 10K. 21 N/D BOPE, N/U tree, and secure well. k. 1 22 RD and release CUDD HWO unit. Suspended Well Data • Wellhead pressures will be recorded monthly at minimum. • Well has been shut in since March 2003. Operations in October 2010 included the circulation of the well to sea water. These operations demonstrated sufficient ability for the well tubing and casing pressures to remain at Opsi since the operations concluded. • It is proposed that an additional Application of Sundry Approvals (Form 10 -403) for operations related to the installation of a surface abandonment plug will be submitted at an unknown date in the future. The well will be maintained in suspended status until the Grayling Platform production is shut -in and the platform abandonment commences. G -24 REVISED BY: CVK 11 -18 -2010 Chevron hollwad GRAYLING PLATFORM WELL #: G -24 Completion 12 -2 -10 RKB = 40.48' Rig Floor to DCB TBG Spool CASING AND TUBING DETAII ' SIZE WT GRADE CONN ID MD MD Hole Cmt Cmt 1 Top Btm Top f 20" 94# H -40 19.124" Surface 829' 23" 850 sxs surface 2 13 -3/8" 61# K -55 Butt 12.515" Surface 2700' 17.5" 5329 cu Surface 13 -3/8" 68# K -55 Butt 12,415" 2700' 5115' 17.5" ft 3 9 -5/8" 47# N -80 Butt 8.681" Surface 7207' 12 -1/4 1200 sxs 8200' P110 8.681" 7207' 8347' 4 USS -95 8.681" 8347' ' 10 388' Tubing: 5 4.5" 12.6# L -80 Mod Butt 3.958" Surface 9635' w /SCC 6 JEWELRY 7 NO Depth OD ID Item 8 1 5 4" Blast A., EUE 8rd Top, Butt Bottom 9 2 341' 4.5" 3.813" Otis Flapper Valve ROTATING HRS 10 3 2403' 4.5" 3.890" Cameo MMG GLM 26" - 38 hrs 11 4 3719' 4.5" 3.890" Cameo MMG GLM 20" -112.5 hrs 12 5 4930' 4.5" 3.890" Cameo MMG GLM 13 -3/8" - 235 hrs 13 "* 6 5756' 4.5" 3.890" Cameo MMG GLM 9 -5/8" -15 hrs 14 7 6409' 4.5" 3.890" Cameo MMG GLM Rr 8 6891' 4.5" 3.890" Cameo MMG GLM 9 7384' 4.5" 3.890" Cameo MMG GLM 10 7878' 4.5" 3.890" Cameo MMG GLM 11 8326' 4.5" 3.890" Cameo MMG GLM 15 12 8823' 4.5" 3.890" Cameo MMG GLM 13 9310' 4.5" 3.890" Cameo MMG GLM 14 9553' 4.5" 3.890" Cameo MMG GLM 15 9 4.5" 3.890" Otis "XA" Sliding Sleeve 16 635'% 8.12" 5.0" Otis BWH Perma -Drill Packer w /stab thru seal assy fr 9634' 6 to 9644'. 17 9676' 4.5" 3.813" Otis "X" Nipple 18 17% 4 5" 3.883" Otis Wireline R -Entry Guide 17 5/11/76 9960' -9962' Squeezed 6/8/88 9748' -9768' Open HB -1 8 5/14/76 10,218'- 10,240' 'Open HB -6 9905' -9935' Open HB -3 5/30/76 10,156'- 10,186' Open HB -5 99065'- 10,052' Open HB -4 ` 10,090'- 10,140' Open HB -5 10,090'- 10,135' Open HB -5 6/03/76 9965'- 10,052' Open HB -4 10/22/89 9748' -9768' Open HB -1 1/30/77 9748'`9768' Open HB -1 9792' -9880' Open HB -2 9800' -9880' Open HB -2 9880' -9935' Open HB -3 HB -1, 2 9905' -9935' Open HB -3 9935'- 10,061' Open HB -4 Top of CaCO3 9965'- 10,050' Open HB -4 10,090'- 10,186' Open HB -5 Fill estimated HB- 3 +/- 9750' HB -6 Fish in hole: Wireline, perf guns and slickline tools - 10,259' dpm. Fill Tagged 10,237' on 6/11/95 TD = 10 PBTD = 10,298 REVISED: 12/02/10 REVISED BY: DAR Chevron S • GRAYLING PLATFORM WELL #: G -24 Proposed Phase 1 & 2 Abandonment RKB = 40.48' Rig Floor to DCB TBG Spool CASING AND TUBING DETAIL SIZE WT GRADE CONN ID MD Top MD Btm Hole Cmt Cmt Top 20" 94# K40 19.124" Surface 829' 23" 850 sxs surface 13 -3/8" 61# K -55 Butt 12.515" Surface 2700' 17.5" 5329 cu ft Surface 13 -3/8" 68# K -55 Butt 12,415" 2700' 5115' 17.5" N-80 8.681" Surface 7207' 9 -5/8" 47# Pilo Butt 8.681" 7207' 8347' 12 1/4" 1200 sxs 8200' USS -95 8.681" 8347' 10,388' Abandonment Details NO MD Top MD Btm TVD Top TVD Btm Item 1 4800' 5200' 4777' 4966' Cement Plug #3 2 5100' 5110' 4871' 4881' External Casing Packer 3 5200' 5204' 4966' 4970' Mechanical BP 4 5204' TBD 4970' TBD 9.8 ppg Kill Weight Brine a 5 TBD' TBD TBD' TBD Cement Plug #2 6 TBD' TBD TBD' TBD 2 3/8" Sacrificial String 7 TBD' TBD TBD' TBD Mechanical BP 8 TBD' 9550' TBD' 9023' 9.8 ppg Kill Weight Brine 9 9550' 9750' 9023' 9633' Cement Plug #1 10 9600' 10200' 9070' 9633' 2 3/8" Sacrificial String 11 9635 9639 9103 9107' OTIS BWH Perma -Drill Packer PERFORATION RECORD May -76 9960' -9962' Sqz'd HB -4 Dec -10 10,218'- 10,240' Sqz'd HB -6 9748' -9768' Sqz'd HB -1 10,156'- 10,186' Sqz'd HB -5 9905' -9935' Sqz'd HB -3 10,090'- 10,140' Sqz'd HB -5 9965'- 10,052' Sqz'd HB -4 9965'- 10,052' Sqz'd HB -4 10,090'- 10,135' Sqz'd HB -5 9748' -9768' Sqz'd HB -1 9748' -9768' Sqz'd HB -1 9800' -9880' Sqz'd HB -2 9792' -9880' Sqz'd HB -2 9905' -9935' Sqz'd HB -3 9880' -9935' Sqz'd HB -3 FIB-1, 2 9965'- 10,050' Sqz'd HB -4 9935'- 10,061' Sqz'd HB -4 Top of CaCO3 Fill estimated HB_3 10,206'- 10,236' Sqz'd HB -6 10,090'- 10,186' Sqz'd HB -5 @ I 10,156'- 10,186' Sqz'd HB -5 +/- 9750' H B -4, 5 I HB -6 " Fish in hole: Wireline, pert guns and slickline tools — 10,259' dpm. Fill Tagged 10,237' on 6/11/95 TD = 10,400 PBTD = 10,298 REVISED: 1/15/07 REVISED BY: BCA G -24 Stack Up for Cudd CUDD Jack Flow line Fill line 4- 1116" 5k gate valve 4 -16" X 2 -1/8" DSA 4- 1/16" flange w/ 6" hose 13 518" SM 2 -1/8 fig X 1502 Mud Cross 13 518" Hydril 5M Type "GK" .. Studded 13 -518" 5m Double Gate Type "SL" w/ 10" piston NfMtt lttakria�ms WI 14" pistons A B C D 4 - 1/8" 13 518' SM 4 - 1/8" YE F G H Mud Cross Flange Studded 13 518" Sm Single Gate Type "SL" w/ 10" pistons Flange Top of drill deck A 2 -1/16 5M targeted 90 Deg % B 2 1116" X 4 1/16" 5M DSA C 4 1/16" 5M Shaffer "B" HCR Valve D 4 1/16 5M Manual gate valve E 4 1/16" 5M Manual gate Kill line F 41/16" 5M Manual gate Kill line G 4 1/16" X 2 1116" 5M DSA H 2 1/16" 5M targeted 90 Deg Top of 13 5/8" Casing Head H August 3, 2009 Dale A. Haines Manager, Oil & Gas Operations Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7t" Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, L —t t� - C-_-) -2-;.'Z_ Union Oil Company of California 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com AUG, 0 b 2009 i 154skla it a bas com Gorrirnigsinp Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, I� Dale Haines _Cali N D OCT 0 9 2094 Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform I ife An -3111) 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 14-42 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Colla sed Casing 100% water production Phase I Abandon abandon at end of platform Iife GP 31-14RD42 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D40RD 1820830 Se -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase 1 Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase 1 Abandon abandon at end of platforrn life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase 1 Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase 1 Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 134 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug- i parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21A4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 2113-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 3213-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for Tyonek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -9 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -0 no known damage no flow Possible shallow gas or gas storage 2011-2014 Monopod A-10 1670760 Apr -8 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-30 1730140 Oct -91 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life -1 LC - cz. SARAH PALIN, GOVERNOR " t r ALASKA 01L AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 June 22, 2009 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 SCANNED OCT 9 9 2Clj Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubertnalaska.gov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD Union Oil Company of California 179-033 Granite Pt St 18742 14 _ Union Oil Company of California 167-077 Granite Pt St 18742 16 Union Oil Company of California 168-012 Granite Pt St 18742 18 Union Oil Company of California 100-266 Granite Pt St 31-14RD2 Union Oil Company of California 182-020 Trading Bay Unit D-06RD Union Oil Company of California 169-004 Trading Bay Unit D-18 Union Oil Company of California 188-098 Trading Bay Unit D-30RD2 Union Oil Company of California 182-083 _ Trading Bay Unit D-40RD _ Union Oil Company of California 178-045 _ Trading Bay Unit G-08RD Union Oil Company of California 176-032 Trading Bay Unit G-24 Union Oil Company of California 179-013 Trading Bay Unit D-06RD Union Oil Company of California 188-028 _ Trading Bay Unit G-34RD _ Union Oil Company of California 168-038 Trading Bay Unit K-06RD Union Oil Company of California 169-066 Trading Bay Unit K-09 Union Oil Company of California 179-016 Trading Bay Unit K-21 RD Union Oil Company of California 178-004 _ Trading Bay Unit K-23 Union Oil Company of California 165-038 MGS St 17595 05 Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 _ MGS St 17595 11 Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS St 17595 18 Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 S MGS Unit 13 Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Companyof California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 _ Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 _ Union Oil Company of California 162-031 _ Soldotna Ck Unit 43-09 Union Oil Company of California 174-066 Soldotna Ck Unit 44-04 Union Oil Company of California 160-018 Swanson Riv Unit 212-10 Union Oil Company of California 161-033 Swanson Riv Unit 212-27 Union Oil Company of California 160-041 Swanson Riv Unit 234-15 Union Oil Company of California 167-076 Trading Bay St A-10 _ Union Oil Company of California 172-020 Trading Bay St A-23DPN _ Union Oil Company of California 173-014 Trading Bay St A-30 • • Chevron April 2, 2008 Steve Lambert Advising Petroleum Engineer Thomas Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite #100 Anchorage. Alaska 99501-3509 0 3 `~-~ Dear Tom: ~ 1 Unocal Alaska Union Oil Company of California Box 196247 Anchorage, Alaska 99519-6247 Tel 907-263-7658 Fax 907-263-7847 salambert@chevron.com RGV~I V ~~ APR 0 4 2008 Alaska Oil & Gas Cons. Commission Anchorage On October 29, 2007 Union Oil Company requested approval to convert well G-24 to injection. ~ Commission approval was received and efforts have been underway to place dummies in all the gas lift mandrels and create pressure isolation between the tubing and casing. As detailed in the attached history, after numerous attempts, the gas lift valves were successfully changed out. / Unfortunately pressure integrity was not established in the tubing. A survey run on February 29, 2008 indicated a tubing leak at 7,139'. While attempting to confirm the leak, hard scale was discovered in the tubing at 41'. This scale will effectively prevent the running of any tubing patches in the well. Based on these results, it is highly unlikely that pressure integrity between the tubing and casing can be established without a major workover. The decision has been made not to pursue conversion of this well to injection at this time. Attached is form 10-404. Sincerely Steve Lambert ~ MAY ~; 2008 cc: MIT book Well File D. Cole STATE OF ALASKA APR Q 4 2008 ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ~ Oil ~ Gas Cons. Ccmtnissiorr Anch4r~ e 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ conv to injection - Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^~ Exploratory^ 176-032 ~~ 3. Address: Box 196247, Anchorage, Alaska 99519 Stratigraphic^ Service^ 6. API Number: 50-1 sp. ~,~/ ? 33' ZDG~ ' 7. KB Elevation (ft): 9. Well Name and Number: ~ g, 104' above MSL . G-24 8. Property Designation: 10. Field/Pool(s): ADL 17594. McArthur River Field, Hemlock . 11. Present Well Condition Summary: Total Depth measured 1 88 /D y00 feet ~ `tl ~ ~ Plugs (measured) true vertica ~ $,~ f@gt ~ ~.~ Junk (measured) Effective Depth measured 10,237 feet true vertical 9,668 feet Casing Length Size MD TVD Burst Collapse Structural 359' 26" 359' 359' Conductor 829' 20" 829' 829' Surface 5,115' 13 3/8" 5,115' 4,885' 3,090 psi 1,540 psi Intermediate Production 10,388' 9 5/8" 10,388' 9,808' 6,870 psi 4,760 psi Liner Perforation depth: Measured depth: 9,746 to 10,240' True Vertical depth: 9,207 to 9,671' Tubing: (size, grade, and measured depth) 4 1/2" 12.6# N-80 9,689' Packers and SSSV (type and measured depth) Otis BWH Perm Packer 9,635' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 Subsequent to operation: 0 0 0 80 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development^ ' Service ^ Daily Report of Well Operations x 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 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: 307-332 Contact Steve Lambert Printed Name JtPruG. 1.~G,,yyti ~t Title Sr. Adv Petroleum Engineer Signature Phone 263-7658 .Date 4/2/2008 ('~('~~ t~ ~ Form 105-40'4 Revised 04/2006 ~' ~ ~ (~' n ~ ~`~(~ ~ ~ Submit Origi~l Only b~ G-24 Well History • Last Update: 3/26/2008 Date Description 11/7-9/07 Ran 3.60" GR to 9800'. Did not tag. Ran 3.68" Broach to 2400' and tagged up. Worked to 4283' and fell thru to 9600'. Ran 3.72" Broach to 2400' and tagged up. Worked to 4283' and fell thru to 9600'. Made two runs with 3.75" Broach to 28' and tagged up. Worked to 475'. Unable to work deeper. Ran 4-1/2" KOT to GLM #1 (2403'). Unable to locate. CIH to GLM #2 (3719'), latched & pulled GLV. Bled off pressure on tbg and csg. Ran KOT Made 8 trips w/ KOT and recovered GLVs from GLM #1, GLM #4 (5756') and GLM #6 (6890'). Unable to pull GLVs from GLM #7 (7384'). 11/12-15/07 Made 4 runs w/ KOT to GLM #7 (7384'). Unable to latch GLV. Made 4 runs w/ KOT and set dummies in GLM #2 (3712') and GLM #3 (4918'). Made 2 runs w/ KOT and set GLVs in GLM #4 (5747') and GLM #5 (6398'). Ran KOT to 6881'. Worked tool and slipped down hole. Tools would go down, but not come up hole. Used spang jars once and tools came free. Ran KOT w/dummy GLV to GLM #6 (6877'). Unable to set dummy GLV. Ran KOT w/ 1.70" LIB to GLM #6, located, and set down. Had impression of GLV in pocket. Ran 3.72" GR to 685' and tagged up. Ran 3.68" GR to 7500' WLM. No note of tagging. Ran KOT to 2386' and set down. Hit spang jars up and wire parted. Ran 2.5" JUC PT to 2303', latched and sheared off at 300# pull. Ran 2-1/2" JDC to 2363', engaged fish and jarred up free and recovered dummy GLV and toolstring -- no wire. Ran 3.75" Braided line brush to and brushed across GLM #7, GLM #6, and GLM #2. Made 4 runs w/dummy GLV and set same in GLM #1. 12/6-8/07 RU APRS. String shot across GLM #6 and GLM #7. RD APRS. RU Pollard. Made 2 runs w/ KOT to GLM #7 (7384') and GLM #6 (6890'). Unable to latch GLVs. Ran KOT w/ 1-3/4" latch brush to GLM #7 and GLM #6 and brushed both latches. Ran KOT w/ bowen OS. Unable to latch GLV in GLM #6 or GLM #7. Made 2 runs w/ KOT w/ 1-3/4" LIB to GLM #6 and GLM #7. Both show empty pocket. Set dummy GLV in GLM #6. Ran KOT w/dummy GLV to 32' and sat down. Unable to work deeper. Beat thru tree after hung up. Lost dummy GLV. Set dummy GLV in GLM #7. 2/29/08 Ran 3.70" GR to 9750' -- did not tag. Stabilized injection at 200 BWPD. Ran spinner survey to 9650'. It appears that there are leaks in the tbg @ 7,135'. A tubing patch may solve the communication issues. Plan to set plug in tbg to confim leak. 3/26/08 Ran 3.80" GR to 41.5' KB and tagged up. Beat down, but unable to work past. Due to restrictions, it will be impossible to run a patch in this well. This eliminates the potential of setting a patch in the tbg and creating isolation between the tbg and csg. This well cannot be completed as an injector without a major rig workover. O:\NAU\MCBU1Alaska\Depts\CI_Oil_Ops\Fields\TBU\Grayling\Wells\G-24\Projects\Convert to injection\History.xls Page 1 of 1 • ~ f ~ J i, 3 v s 5..... v` L.33 M ~_..,~ i.~ ~~ ~ ~~ ~ SARAH PAL/N, GOVERNOR t.. ~ ... ~t`l_ ~5~ ~~ ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOI~IT CODiMISSIOrT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 'FAX (907) 276-7542 Steve Lambert Sr. Adv. Petroleum Engineer Union Oil Company of California ~~~~ Q 2007 PO Box 19624 ~~'~~~ ~ Anchorage, Alaska 99519 ~ ?ja-' Re: McArthur River Field, Hemlock Oil Pool, G-24 Sundry Number: 307-332 Dear Mr. Lambert: 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 far 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. DATED this ~ day of December, 2007 Encl. Sincerely, cz ~ ~ ~ Zl~ R.ECEIVED (~' ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM ON~iJf,' Q~T 3 ~ ZOQ7 APPLICATION FOR SUNDRY APPROVALS vI ~~ 20 AAC 252so Alaska Qil & Gas Cons. Cemmissinn 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ A~e(~~ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension (Conv. to injection) Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 176-032 3. Address: Stratigraphic ^ Service ^ 6. API Number: Box 19624, Anchorage, Alaska 99519 50-133-20286 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ G-24 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 17594 ~ 104' above MSL~ McArthur River Field /Hemlock 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,388' 9,815' 10,237' - 9,668' ~ 10,237' 10,244' Casing Length Size MD TVD Burst Collapse Structural 359' 26" 359' 359' Conductor 829' 20" 829' 829' Surface 5,115' 13 3/8" 5,115' 4,885' 3,090 psi 1,540 psi Intermediate Production 10,388' 9 518" 10,388' 9,808' 6,870 psi 4,760 psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,746' to 10,240' 9,207' to 9,671' 4 1/2" 12.6# N-80 9,689' Packers and SSSV Type: Packers and SSSV MD (ft): Otis 9 5/8" BWH Perma Drill Pkr, ( Packer @ 9,635' SSSV @ 341' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 11/12/2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ Q WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name c:=~~~~~ ~~,,~ Title cam; ~d °`7 , ~ ~ ~, ~, ~ Signature Phone Date ~ :~, ~.Co'~~ ~ ~ 7 q _ GG COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test `~ Location Clearance ^ Other: Subsequent Form Required: '~„~~ APPROVED BY Approved by: OMMISSIONER THE COMMISSION Date: j i r ~QQ~ i~ /~ Form 10-403 Revised 06/2006 O ~' ~ ~ ~ Submit in Du licate P • Chevron October 29, 2007 • Unocal Alaska Union Oil Company of California Box 196247 Anchorage, Alaska 99519-6247 Tel 907-263-7658 Fax 907-263-7847 salambert@chevron.com Steve Lambert Advising Petroleum Engineer DECEIVED Thomas Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite #100 Anchorage. Alaska 99501-3509 Dear Tom: oCr ~ a 2007 Alaska Dil & Gas Cons. Cammissian Anchorage Union Oil Company requests permission to convert well G-24 from an idle gas lift producer to a water injection well. Well G-24 was shut-in in March 2003 when production went to all water. Go~~ y( ~~D~ The well has been idle since that time. As detailed in the attached supporting documentation, 'S, t0~ simulation runs have indicated that an additional 338,000 barrels of oil will be recovered by the successful conversion of this well to water injection. It is planned to pull the existing gas lift mandrels and replace with dummies. A mechanical integrity test will then be performed on the well to confirm pressure integrity. If integrity is established, the well will be placed on long term injection. If pressure integrity is not confirmed, a short term injection test will be proposed to verify casing integrity, and permission for injection under administrative approval will be proposed. Sincerely, A ~~ / _~ ~ ~ ~, ~~'~ ~~ - ~~. Steve Lambert cc: MIT book Well File Chevron October 29, 2007 • © Chevron 2005 DOC ID Current Status Chevron ^ Well G-24 was shut-in in February 2003 when the well went to 100% water cut following a scale squeeze. ^ The well has been idle since that time. ^ Reservoir modeling has indicated that G-24 is in an ideal location to sweep additional oil to the central crest of the structure. • ©Chevron 2005 DOC ID 2 Chevron P^ ® ®~~~ ^ It is proposed to convert well G-24 to injection. ^ The steps to accomplish this task are as follows: ~ • Run and install dummy valves in all the gas lift mandrels. • Perform a ~~ Mechanical Integrity Test" to confirm the integrity of the tubing and casing. - If the well fails to pass the MIT, petition the state for administrative approval to inject. • Perform an infectivity test to confirm the wells capability to take injected water. ~ • Install piping to allow permanent injection into the well. ^ An injection survey will be run within the first year of injection to confirm whic h zones are ta king injection. ©Chevron 2005 DOC ID 3 Historic Well Performance G-24 ? _' Date. Feb-2003: _ _ _ Oil Rate (CD) : 1 bbl/d ,'~ ' ~ "~ ~ ~ ~~i ii ~ Gas /Oil Ratio :18 Mcf/bbl ,~ ; _ - ~~~'~' ~~~=r1 ±t~ j1(~'jE~~~~~~~j,~4~~~~Water Rate (CD) :1587 bbl/d= ' `,~~ a- ~ i a l r ~7~'lu a7 t 1~~i~ p' y ~y i ~ ~.~ 1 --- -- --- - ~~ "~,~dt~,~~~r; ~iy~.~i~a ~~~~ i~ ~hii~i' i; i , ~ - - ~~ v ~ _ ~ Water Cut :100.0 % .- ~~~~~ , ~~~ ~~, __ ,, 507332028600:1-BIALOCK _= _ __ =t~=;~= ____ _____ __ ____ __~_ __ = _ --:___- -_ ____-_ __- __ -- _ - = OiIFAte (CD)(bbUd) ~- - ---i--~y------ - ---------------~---------- ------------------------- Liquidl~ke(CDj(bbUd) _ - -- - - -- -- -- ---- -- -__- -- -~- - -- -- -_~.---- -- -- - Gas /Oil i?atio (d/bbl) - - - a - - - ---- V1~er Inj i~te (CD) (bbUd ) a7 0.9 71 7'i 75 77 79 et 63 85 87 89 91 93 95 97 99 01 03 O5 07 09 11 1315 MJF Rm ad Wr Gtgrf Date 09/2od200714:57:32 DOC ID 100 80 60 40 20 0 V1~ter Cut (%) 507332028600:1-BIALOCK - - - r . - - ' _ .. ~ ~ ; _ ~ ; _ . - . _ '~ _ ~ C4m~latrve QiI Prod ,10334 Al~bbl f- '------- - ~ _ I -- - --' 1 - rCumulatiye Gas Prod : 3637.558 MMd Cumulative VWter Prod c 32097.607 Mbb a~' 'fi9' '71' '73' '75' 'n' '7s' 'et' '83' '85' '97' '89' '91' '93' '95' '97' '99' '01' '03' 'OS' '07' '09' '11' '13' 15 10000 5000 1000 500 100 - 50 - 10 Chevron 4 • • ®~~' C~S~~~.7 Chevron ^ Justification for the conversion to injection is based on the incremental recovery pred icted by t he TBU reservoir model. ^ In the model, injection into G-24 is limited to 3,000 BWPD. • The well should have additional injection capacity, but it is believed that this is the limit of pump capacity. • Injection is distributed by bench based on the bench transmissibility's. ^ Model results indicate an incremental recovery of 338M bbls. ^ The model predicts a peak incremental oil rate of 110 BOPD as a result of this work. • ~~ © Chevron 2005 DOC ID 5 0 0 N O O U1 0 n v G-7(GH) G-2RD(H) G-20(H) M-25(GH) D-1 (H) D-48(H) G-4RD(GH) G-28RD(H) K-18RD(GH) M-32RD(GH) G-25(H) D-25RD(GH) M-29(GH) D-47(H) K-13RD2(H) D-43RD(H) M-28(GH) G-21 RD(G) A-27RD(H) K-1 RD2(GH) G-13(H) D-31 RD(G) A-15RD2L2(H) D-12RD(GH) D-46(G) K-25(H) G-15RD(H) K-30RD(G) rn Incremental Cumulative Oil (MBO) 0 0 0 0 0 0° o • n 3 ~D 7 ~_ ~C C <^^D \CJ N O W O 'D ~ -e 7 O A a~ c~ ~ ~ ~~ ~ ~ rt d ~D n 0 G ~D O O -fi ~D rt A z O 3 Offset Weilbores.ppt ~ Page 1 of 2 Maunder, Thomas E (DOAj From: Greenstein, Larry P [Greensteinlp@chevron.com] Sent: Monday, November 19, 2007 8:17 AM To: Maunder, Thomas E (DOA) Cc: Agier, Brit G; Nottingham, Derek W (DNottingham); Lambert, Steve A Subject: RE: Offset Wellbores.ppt Here you go Tom (and thanks to Derek for getting the info). These are the distances from the top of the Hemlock in each of these wells to the G-24 contv~ersion candidate well. G-02 RD ~ 1346' c~ ~c~.~~ ~ ~.5`~ti~.i ~c..) ~~`~- C:~ r~~~ ~=~ G-03RD2 ~ 1487' S~-~1~.r~a~ ~luS~c~c~,L~~ ~ ~ Z.cx~rc ~A~~'~~~ ~t~~, csLh~vc.~t.L,C~.`-1t~~~~ G-30 ~ 1109' '~'''~' ~- a ~~~`~ ~ ~`~ C`1~-}- c 9 -"3~1 ~ G-34RD ~ 1174' ~ lSs'" `-5~ C~l~~=~- iQ~`7,=~ L~p~s;~ QEt ~ i~03~ CihU,~r~ C31~., ~~ /~°{~'~ Hope this is what you were looking for. Anything else you need just give me a call ore-mail and I'll put it together. Larry From: Greenstein, Larry P Sent: Thursday, November 15, 2007 12:04 PM To: 'Maunder, Thomas E (DOA)' Cc: Agler, Brit G; Nottingham, Derek W (DNottingham); Lambert, Steve A Subject: RE: Offset Wellbores.ppt Tom, 1'fl dig around here and get that info for you. Larry From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Thursday, November 15, 2007 8:36 AM To: Lambert, Steve A Cc: Greenstein, Larry P; Agier, Brit G; Nottingham, Derek W (DNottingham) Subject: RE: Offset Weilbores.ppt Thanks Steve, Looks like a good piece of work. One further request, could you provide the specific distances of the wells from G-24 at top of Hemlock? Larry, can you help me since Steve is gone? Regards, Tom Maunder, PE AOGCC 12/17/2007 Offset Wellbores.ppt From: Lambert, Steve A [mailto:sa{ambert@ehevron.com] Sent: Wednesday, November 14, 2007 10:18 PM To: Maunder, Thomas E (DOA} Cc: Greenstein, Larry P; Agler, Brit G; Nottingham, Derek W (DNot#ingham) Subject: Offset Wellbores.ppt Page 2 of 2 «Offset Wellbores.ppt» Tom attached is a summary of the status of all the wells that offset weU G-24. Based on my evaluation, there is nothing in these wells that should prevent us from moving forward with our eva{cation of the conversion of G-24 to injection. I will be act of the office from Nov 15-26. If you have any question abut this presentation or the project please contact Larry Greenstein. Thanks. ~ zil ~izoo~ G-24 form 10-403 • Maunder, Thomas E (D4A} From: Lambert, Steve A [salambert@chevron.com] Sent: Thursday, November 08, 2007 9:55 AM To: Maunder, Thomas E (DOA) Cc: Greenstein, Larry P Subject: G-24 form 10-403 Page 1 of 1 Tom l just wanted to give you an update on your request for offset well information for the conversion of well G-24 to injection. Unfortunately a construction project in our well file room has prevented us from accessing the offset well files for the last 10 days. Hopefully we can get access to the files next week and l wilt respond to your request as soon as possible. 11 /8/2007 ~~t'= ~: ~,«y'_ November 14, 2007 .:~~.: ~~~ ~~ ~'~: <'u .~;, M • • c~~ cr,~vr-~~ zc~e~~ roc z~ chevron ~_.~ ,~ .& There are 4 wel Is within 1/4 mile of the G-24 location: G-02 G-03RD G-30 G-34RD • C~; C' cvro^ 2(l(l5 aQC ICS Z r ~ g5... s ~'" x ~ ~r7 ~r ~; ~ tr ~"' ~ • '~sG "fie' a '` ax +~ „~3 z ; ~" z ~ 3 . = . L ~ Tea's -. 2: ~, - ~~. Z .. :l ~^:. ~ L ~. - .^f gy . p ~ __` y,~.. f 4l- f ~ ". rH h R : r ~"~ M~ ~ ~ ~ . -~, --F ~t . November 14, 2007 • CCU Chcvr;~n 2C1E~5 dC7C ICS This well was redrilled and completed as a dual ~~G" and Hemlock producer in May 1979. ~- The short string was completed in the G-2, G-3 and G-4 sands. Chevron .~~ ;,, G-2 9,222-9,232 G-3 9,292-9,322 G-4 9,332-9.,422 9,432-9,434 sqz holes (sqz 250 sx) ~,v,, The long string was completed in the HB-1, HB-2, HB-3, HB- 4. HB-1 9,712-9,737 HB-2 9,760-9,770 9,876-9,878 sqz holes (sqz 300 sx) HB-3 9,880-9,920 9,922-9,924 sqz holes (sqz 300 sx) C, ..-'t ~.- ~ ~.. .The 9 5/8" casing is set Cc~ 10,910' with a DV collar @ 6,004'. i The casing was cemented with 2,100 sx of Class ~~G" cement thru shoe. An additional 1,600 sx of cement was pumped th ru the DV collar. The theoretical top of cement is 338' • All other strings were cemented to surface. C~; Chcvt';~^ 2C~~ a 4~C3C Iis 5 Cer ~ "~ ~~ '" ~: .~, «-- -- ~' ~FL~ ~~~r~ ~t'~~4~~ CASlt11G & CEMENT bETAlL . ~ f :_ ~~, y,,f YOl UaCEa SlipWk 1. qE ;P'~ ?~ {OMT. VpL.1NDlE V06.) ' 7Mo. Teo CMT a1 a0d' A-•''~~ .t,,, ors ~ri~r "f' ' ° r. 1 Tr: iM~~'''~' : ~' Y; ' :,Z:;~ ~,..j...,~?.: Ya'.PA r,M-ID CBO: i! 518'3 Sias. i~'!P ., 0/!0-i DD Ds><i ~- 1 'r5',i7~.~'1 ~:~ {51601116 aail'J I, '-'~~ N)i CST C{A C, Cf+{T'0 TOP ~ "' `~' ~.~~ .ri Dai. .~. .: ~:. :,~,... .~^i.~ • IS }511 •) ~~ { ~G Tor rLUD aD .,:~,4',. ,: .. of B'.95•,J~sa aTSC i! t746' . Tn~a. 74a CMT K1 0' . nano' °P~ 1 , ~ . ,.':. ,.r,:. .:: ..~. ...... ~ O;MT 4470' ~9 '; Dv oouha ,'- ra ara•,e,•,~-aa cso ^'~T,<' ~,~'~y (' ~ $f7 D-pa0 axr 116004' ~ T t.+t.PboonPa474rt•~ ry(S~SI ., a4ia' Tn^o. Tux cNrT Y {f61.4 Tr, '>•3 '' ?~: r~,~ .. {l. TOP T'nt 70x76' .. 8-961 k-sa k' ~6 ~ ~' 5T8C st Via? »' ~ 67dCiO80 s41 ioG 6i Dde-aa 1ost0' ~° T60Di%6 h73irr'/abae+{•} 57 AOE •f 7',IIG~,k-iD GaB ~~ aiABE xsp{s4eblt~ It OcslP) eaas~s Ss~711 `B bH'a6 T6Da9 ~. {, a4 D11~JSO49f r•) - NOTE. RLL CFA;NT TDPB ARE 7KE CI4ETlC AL 11 ~RAYLf~I~ ~'1A~`F~f~.l~ '~~.~._.. ~.; ~~_ __ - _ cASr-~c~ & cEr~errT oevar~ ~•` ~<~ _ [I , ' .. ~-~ YkrON DIL COk94kY 9f [a Ll9 ookii I • • Vic,: Ch~vrc 2Cl~S €~OC ICS 6 RKB to TBG Hngr = 38.10' Tree connection: Dual 3.1/2" EUE 8rd A 1 B G ~ L~ 2 E ~ D'.a...; ~ '~::': 3 soar i 4 ~r _ G ss 5 I - 0 ii iii 7 G•2 IV G-3 8 G-4 vi 9 vii ......... 10 11 osso• "W 112 13 14 HB•1 HB•2 HB•3 nx ®+Y,oar ~~° HB-0 ..* ~ `Z __- tom` RT to MSL ELEV = 99' TD=10,310' ETD=10,179' MAX HOLE ANGLE _ ° ~' Cheuron /;~- "~ ~ atr~~ ~ -rvNnr~ e~~~. SI7.IC iY3' t:,12A1DE t:ONN ID D4A "COP' 61:p 13'Y'iil. 1.TN'I'8: 26" 0.5" Wall Drive Pipe Surf. 366' 366' 20" 94 A-40 19.124 Surf. 616' 616' 13-3/8" 61 K-55 12.515 Surf 2145' 2145' 9-5/8" 47 N-80 Butt 8.681 Surf. S85T 8,857 9-5/S" 47 5-95 Butt 8.681 8857 10,310' 1,453' [}i' G:C)C,€,:S IZ ... ........... ........ ....... .. ...._... .. .._.............. ...... ..._.... (OtE4' 6t}Ory, 3 y4, Tubing: LS 3-112" 9.2 N-80 But[ 2.992 0' 9627' 9627' SS 3-1/2" 9.2 N-80 Butt 2.992 0' 335' 335' 2-7/8" 6.4 N-80 Butt 2.441 335' 11,572' 11,23T Dip Tube 1.66" 2.3 NU 1.38 9041' 9508' 46T Sri ti, /~ 113 sswrnLar neratc. 14•n JX.uI clw wm2hq x.ng.r. Baa nl Iv JY21 n9 OIOS am Jxzx a Y 9 .,3-In^GD l r.nn..r. J-I a^ x= 911av 2;:z 1 , n.wP x/aa"nnrl a" Port ~ ngN 6.On• - M, Lvnglh O.YIP GWt Lnglh6wl mnOLv.k ng l/3/XXSUrvvy - X"cLM, LenglM1 6.wP 1'n/N"Y°r/ a.wr u°fis r h.°o• .' ^r. ,I em awl naaa bmrnrrm.v.,~n r 4nL k.r law Jn r kel .v evJ JUmm> YO' Pbn M1xl(°(41 v.nll hl M1fi I L ll 1J , , .v°p . . Y (ulY/N9) - Ivar•Y~rr ala JX-a lt, Y.. .. .... z•nX^clM,l,.nglh fi.wr mm h.u orcLV.bu P k.Lb.u.na Jnmmr lrvrlYnl9> . X"c1,M,l..ng(h fi.wY Dnmmy ' f:I.M. L.ngIM1 O.wl' - N, Lvngln aYn' Drbve l-/fi p ., I ... 1 Jut ,. ,. ou...,._W.., ... _i.u, ulrM., a-la^Gn - 4M, LvngIM1 9.J2` LM, ~.°qm 9 Ir ng(h zor - 'GLM, LvneJ~ 9JR Ins tle g v4 Y tl/e9 fi962 mn - <:I.M, LenglT ).u2' Y." Yon GLV. Pu4eJ bvk Ivtt body 6n5/x9 - ].ui' Ifi/60"Pnrt GLV 3-In"cLM. L.ngm zar v.^Ynn cLV. Ymlra w°k,lm bOUr ane/e9 9alY »ll nfix pl3 xllfi xaen J-In^GLM, Length 9.01• 3-Irz°GLM, LengU 9.m' 3-Irz'GLM, LenXJ~9.02' °°t in F°v4et. F4hingnvek 1. po.+ibly br°4en .ci brm °[Iack IN rvn al3/x0 eb°weu bek Jag In GIM J-la^ Gl.rvl, L.ngm zax a(a xxOY veal - - bl, lxngW l.02' ..~ ... . Lng(h aso• ( valr Yxn vm 2 D" ~. n~ (a~in^x J^z2mJ YZa•mv2ar wue. J-Irs^an~.~Jmna, (o-lrz"x3°xxJ•7 azu'mYwr 3-Irz^cLnL Lng(n xsX• '-c ... wn Y kr a Y6Jfi S m29 .... z .un M°h xhov rnal Ys/X^mn.n nlnle P..k.. ExY.nsbn J°In4 YOaX'I 7 • • Chevron "`~u Water cut in both the G and Hemlock increased rapidly and by 1984 both strings were producing over 90% cut. ~~ ~- The well was shut-in in 1998 due to low oil rates. The well is currently idle. Current pressures: Tbg 9 5/8" csg 13 3/8" csg 20" csg 1450 psi 1400 psi 15 psi 11 psi • • <~~ ~hcvrt~^ 2Cf15 C~OC I~7 8 A 100 80 60 40 20 0 10 h~°-r ., ~~ Cumulative Oil Prod : 343 Mbbl Cumulative Gas Prod : 391.135 MMcf Cumulative 4fl~ter Prod : 2548.907 Mbbl Water Cut ( /o) 507332021 r, -+ :~ . ~. 1979 ~ 81 ffi 83 84 ~i ~ 86 ~ 87 ~ 86 &~3 90 91 92 93 91 95 9G 97 98 99 2000 01 02 03 04 05 06 10` 10' 10z 10t 10 Date: May-1998. `qid Rate (GD} : 5 bbi€t Water Cut :97.8 °/b. Gay 1 UPI too :_ Cfib( star to (CD} :233 bbdld • .~ Water In) Rate (Cp} . bbUd 507332021301:GZONE ~ ~ ~ ~~ O'il Rate (CDj (bbUd ) Liquid Rate (Cq (bbl/d) ,. Gas / O'il Ratio (cf/bbl ) ........... VWter Inj Rate (CDj (bbUd ) Isla w of o~ w w w w of w w ai ai x a~ a. a~ a~ ~r w w ~wv ~i ..~ 11/14/2007 09:53:28 MJF Prod and Vttr CLL.grt Date • Cc~ Chcvr°~E ~ 2C~~5 E~~C ICs 9 _. ~ ~ ~~ i ~ ~ ~~ Chew 3~, "~{~ Cumulative Oil Prod : 907 Mbbl Cumulative Gas Prod : 990.487 MMcf Cumulative Water Prod : ._698 Mbbl 100 80 Water Cut 60 40 0 - ~ i ~~ls a~ s~ az a3 ea ~ es s~ es ~ so si s2 sa ga ss ss s~ se ss 200o m oz oa oa os os 5 10 10' 103 10Z 10' 10 10' Date: May-2002: ~'}xl Rate (CD) : 5 bbl/d dater Cut :97.9 ,, f~V`~` .-- was 1 t)ll tip : 0 Mcftbbl ~ Mater Rate (CD} :1648 bblJc Vhlater Inj to (cD} : ~ bb[~ 507332021301:1-BVILOCK al Rate (Cq (bbUd ) Liquid Rate (Cq (bbUd) __ Gas /Oil Ratio (cf/bbl) ~- -Water Inj Rate (CDj (bbl/d l`J/tl iA1 8~ 8L 0.5 W W PD O/ oo w ai ai x a~ ~+ ai w ai w .-n-. cvw ..~ vc w ... .~.. .. MJF Prod ad vW Cut.grt 11!14/2007 10:03:05 Date • '~c`,~ Chcvr" 3^ 20 a f~C3C ICS 10 K ~ ..~ '. ,;;::. '~~~ ,t~' ~~ • November 14, 2007 ~~ CSC Chevr;~;-~ 2C~~S C7C~C IC7 Chevron : ~ This well was drilled and completed in May 1969 as a ~~G" and West Foreland producer. 0 The West Foreland was squeezed for abandonment in July 1969. The base of the G zone was also squeezed for isolation with 40o sx. In December 1977. Hemlock bench 6 was added to the completion. Bench 5 was added in January 1978. ~~ Hemlock Benches 1,3 and 4 were added in December 1979. `c~ cr~~~~~;~n z~~s ~~c ~~ i2 C..he rt .:. In November 1987 Hemlock benches 1,3,4,5 and 6 and G zone sands 1 thru 6 were squeezed. Hemlock benches 1 and 4 were subsequently • fracture stimulated and the G-2 thru G-5 were perforated. The short string (G zone) production was shut-in in 1993 due to wireline fish in the tubing and lack of entry. s The long string production was shut-in in 2002 due to high water cut production. ;r; ChE'vrc~n 2C)C? a C>C) TC} 13 Chan ~~' . ~~~ ~~ The well is currently idle. Short string- There is a fish in the tubing at 500` and at 9,300'. Perforations: Long String Perforations: G-2 9588-9610 G-3 9660-9681 G-4 9702-9766 G-5 9824-9857 9878-9892 HB1 10058-10088 HB3&4 10230-10280 HB4 10280-10300 HB4 10300-10390 u C C_. Ch ~^ 2ClC3S ~~C Z[~ 14 Cherr~n 1ti Wellhead Pressures ~, ~;' ,,. ~ Short String 290 psi Long String 70 psi 9 5/8" Casing 360 psi 13 3/8" Casing 330 psi Cement tops- The 9 5/8" cement top is at 2,630'. Alf shallower strings are cemented to surfiace, and the 7" was cemented to the liner top at 9,785'. ` Chevr:~r~ 20705 ~3C3C IC7 15 (r_; C~lcur'o^ 2Cl(~ a C~~C IC} rPCC CCNIJG;T?N .i-1/Z. 8-p 'ISB = '..06 TB. HGi4 @ 42.fU' IH.ai' ~~ t jf` A 2 I i -3I'~~ SP RA1 'nELD + ~ AiiO' v n a5~3yp55 - B C 15 r. H-ee ~pL a5:~w'u' I ,yfl i 5S.` ~ N-6R « a7,r ~l to s:~as' r G h a 5 e 7 9 - = C7 3 - _ Cx 0.~ - :a cs Lfi i~y Y ` P. ~~=F~' . 'n5GE0 5; 94 }" L' b 1 eul rL 9' 1.; a 1' I~OI xgs 09t x~ 'f Ltt3l\G DET:tiL; LONC 5TT3Itic: 3-tJx', s.z,p. N-80 DL'TTRE55 3HOP.P ST&[Vrv: @-7/lS;, Js.4p, N-fl0 DLTTTRESS ~~ 3-1/?.' , $.7.~1, N-BJY HUTTFlEE15 ~'~ LCNB 3TREY6 '~HOlE7 dTlt[I'IG A. GT15 S-1/c 67__ VbL'J_ 11P'LE 1. 1-:j5' ~' S-'/Z GI+GSSG4E? ®55' 8 3!~i i. CTfs 2-7/'$' &.._ Ya11'E Ni'I'L! 7E 3EJ' _ CNlCC 3JA's 3. V7_ FlSi ®SOC'. LAST 1!D3J5c GLU 9 2#95 4. CaWyO CLU's cLU ~ a ?655' GLY 't a 275=; CI u '3 9585' Clu 2 a :E33' GL4 '4 O @OS'- GLY 'S a alsz~ CLU 5 ®641E CLU ~! .8 E022 GL`A 'E ®7633' ~ C1M i 5 7171' GLu 7 H 9219 fl Y $ A .9.15E GLa .` 0 B7J3' Cl4 ~ 9 9193' GL'A ~ $ 967; 5. FIEN A BS:G', LOST 10/10;`9J 1:• ®33%7' 6. DTIf ~-+i'".' YA SLEE'.E 8 9+CU' _ CTIi 3-1/2' Y.1 St G'f'.5 @ 016' 7. CauCO •:NEV, !i'J 4W<OREL ~ 9l SS' CTIi a-S/?' +PN G!4 @ 7{~.5~ $. C1S 9-~/S N~h PK? II 9A4 `_" '. ?JtiiE= 1-1i~` ' A5- .iS rPi!A &. Ors aM `,?rIF ~ 456i' 357?' .C F.9pl' 10. NJ.~SI•DE B 31:v' C CJ•L'CO ~ u I`J. AiAYOR°_: d 9:3: rl. ;;/.I A •~'1S tvn PkR 9 27tlJ' EdUIL SIIGC a ' C,G.~' _,4'dc0 OU81 .i/a'. E7,C~=SiIATED :AiEMi_n'_ * Ul-aC II:N JML. CLak'PED TO SIIOR' 3Tar.C ' aH0'aF 5lSq' A9p -G LCnG ST%ING EfLON' °4L•0' 'c' zone. C^. 3oVit'-BE l'_ S=E~EO 7r 6i ,^,.~ :~E60"-99E1' Cf E7+FU .'/~3 G5 537+'-9~::i!' 07cti'a, 7j @$ ga;o _y832' OP-EJ%` 7j E9 C6 5955'-9777 +_C3'9 1C~f87 EILULIECfL: Ilpl t0.G56'-tO,Cd_ :WFAEJ 12!'x, c:aC'p ltjd7 Ilp: 10,215'-10,i1T SD.AU9`; Z 12/7. ne_s, I•],7y]-I::,LCU' UN:k_U ~y!a NBA 10,£AG'-10,y];.° i.P[NCC 1/s9 NB+ 10.}7:'-1G,?5+1' .PENED '2i7p, FibC'r 1'/87 HBS 1G,4i:'-IG,S.},i' 7F.L7~ :AC' TEE4T EORP.Id"J'D: 10.+-:''1'.299' dEn~JOt_n uNO~ Atvle~ . NnaL4 + Ak eJ~!Hleea l9AT ~-~--,.Ere' - ~aoK INc u~v rln,~: McARTM1R FdIYJeA FJEE~ ~k i~l`if7.S TAADIN6 BAY urElr ~~tv •~. ---- - t'a'.'3~ __. LAST W4RKOY@Fl 11!27187 V.IE 4~ : ~ L'f{[>r LLL9C vAJ] k _. _ _.. . _ ~lF ffi n':mC'7viele.f ! ..._ .• ..- _ .. ~^0 i-.: _.:. ..-_- 5:~'- R7FF .... ,p~A'AN~ Pl:l ,1JpTK Chevron .Y :~^ .G'Lw.... .~w 16 • Cumulative Oil Prod :7668 Mbbl Cumulative Gas Prod : 3920.342 MMcf Cumulative ter Prod : 7073.897 Mbbl 100 80 60 40 20 0 1000( 1000 100 10 r~~ :Date: Jun-2002. --- - - il to (CD} : 2 bblfd ~Vlklls Selected (3) 1 star but : 9$.1 °I® Oil Rate (Cq (bbUd ) Liquid Rate (C~ (bbUd ) f C7~! F~ai ; 7 tft~ Gas /Oil Ratio (cf/bbl ) atei" to {CD} : 97 bifd --- Water In' Rate ( (bbUd ~ ~) ) ~9f'9, 7f1 71 ~ 77 7'i 7d - 75 7R 77 7H 79 fl1 R1 - R7 A'~ 84 A5 f~'i 87 A4 ~ 90 91 ~ 93 94 95 96 97 96 99 2000 01 02 Q3 04 05 C6 MJF Rod grid Vur CuLgrf 11/14/2007 13:57:23 Dz<e Chevron _~ .~ .~, • Cry C}~e~ on <~~~:107 C7~C I~3 17 Cumulative Oil Prod : 3288 Mbbl Cumulative C~ Prod :1050.659 MMcf 100 80 60 40 20 0 10000 1000 100 10 4UR1UiiR3vi: YYdCU'f 1°TCHA : 0."Xt6.L 13 3YfF.7{il r...... a..a:..., un,~... 1~:. A ML.hi V1/ater Cut (%) 507332018700:F6NLOCK ..- .J'- ... ~ '. ~ ~ >: ., 1969 70 71 72 73 74 75 75 77 76 79 6U tlt ifG txi tl4 t55 tAi tsi ces tKl yU yt a[ as ~ ~ yn ai xs :b tlw vi vt w w w is 19FxJ~ 70 ' 71 ~ 72 ~ 73 ' 74 ' 75 ~ 76 ' 77 ~ 78 ~ 79 ~ 60 ~ 81 ~ 62 ~ 83 ~ 84 ' 85 86 87 86 ~ 90 91 92 93 94 95 - 9G 97 96 - 99 2000 01 02 03 04 05 O6 Date: Jun-2002. -- -- - -- C7i1 Rite (D} : bll 5W332o1s7oo:hB-nLOCK 1 stet' Gut :98.1 %_ `~ ~ Oil Rate (C~ (bbl/d) ~ Liquid Rate (C~ (bbl/d ) .. 1 ail tip ; [fl6 _ C~as /Oil Ratio (cF/bbl ) Water to {GD} : 97 blfci .,••...•• Water Inj Rate (C~ (bbl/d ) MJF Prod andNhr CU.grf 11/14/2007 14:12:08 Date Ch~vrot -~..:~ , =< • '~; CkieVY ~ 2C1~5 C7~C IC7 18 Cumulative Oil Prod : 3266 Mbbl Cumulative ras Prod ~ 2608.021 MMcf 100 80 60 40 20 0 c:umusactve vvarer rroo : ~b,t.sr,~ on+ 196' 70 71 77_ 73 74 75 76 77 78 79 80 81 82 83 84 65 86 87 88 ~ 90 91 52 S3 94 95 96 97 98 99 2000 01 02 03 04 05 08 10000 1000 100 10 1 pate: Aug-1992 - - = _-- {3"sE to {C ) : 9 bbf/d i 507332018700:GZOPE ' o ~ Oil Rate (CDj (bbl/d) 1'te r Cut :19.2 l~ Liquid Rate (Caj (bbUd ) C-a ! C3i1 E~atiq : 1 C~'1~3tSs _ (~ /Oil Ratio (cf/bbl) - star to {CD} : 2 bh(ld -••~.-- Water Inj Rate (Caj (bbl/d~ 19~~ 70 71 72 73 74 75 76 77 78 79 ~ 81 - ~ 83 84 85 ~ 87 88 89 90 91 92 ~ 94 95 96 97 98 S9 2000 01 ~ LC3 04 05 06 MJF Prod and VUr Cut.grt 11114/2007 14:14:44 Date Chevron C~~ Ch~vr•t7^ 2C}0 a ~C~C ICS 19 Chet ./y ^~, ~,. Cumulative AI Prod :1114 Mbbl Cumulative Gas Prod : 261.662 MMcf Cumulative 11Cdater Prod : 298.355 Mbbl 100 80 Vl~ter Cut (%) 507332018700:W~5T FORE r - , 60 . , ?a 20 ' ~ .t~ 0- 1959 70 ~ 71 ~ 72 73 74 75 76 77 78 79 80 81 ffi 83 84 85 86 87 ~ ~ ~ 89 ~ 90 91 92 93 ~ 94 95 9G 97 98 99 2000 01 @ 03 04 05 OG 10000 5000 1000 500 100 50 10 ..Date: Dec-1977 -oi~ to {ca, :11 ~~~ star cut :74,8 °lo 'S ! C)ti do : ct1E~F~4 dater Fite {cD) : 32 bblfd -- _ _._ _ 5o733zo187oo:we~'r IRE ~ ~,°~ Oil Rate (Cq (bbl/d ) -~-- Liquid Rate (C~ (bbl/d ) Gas /Oil Ratio (cf/bbl) -~••»~ VlFater Inj Rate (CI7j (bbl/d ) 1~9 7(] 71 7'J 73 74 75 76 77 ?8 79 ~ S1 82 Hi 94 B5 ffi 87 ffi 89 9D 9'I 92 93 94 95 ffi 97 98 ~ 200D 01 02 d3 04 ('b C5 MJF Prod and vUr Cut.grt 11!14/2007 14:16:33 Die Cc~ Chcv:~o:^ 2C~C~> (~~} ICS 20 10000 1000 100 10 1 ~~~ IMells Selected (3) al I~te (cam (ablyd) Date: Jun-02 --w- Liquid Rate (Caj (bbl/d) Oil Rate (CD} : 2 bbNid Gas /Oil Ratio (cf/bbl) ate 1` Rape f G) : 97 bll -.•»-,.~ Water Inj Rate (f~ (b61/d )_ star Cut : .1 °l° 9ss' io ' ~~ ' Tz ' ra ' is ` ~e ' is ' n ' ~a ' ~s ' eo ' a~ ' az ' as ' ea ' a5 ' as ' s~ ' ae ' as ' ~ ' ~ ' ~ ' ss ' sa ' ss ' ss ' gr ' sg ' ss ' zaoo' o~ ' oz ' as ' oa ' cb ` ~ t-Prod ad V~tr Cut.grf Date 11/01/2007 08:49:10 h: error .,~" _ ~~";~ ,.R • ~~ ~t7~'VrQn Z0~ ~ €~C9C Z1~ 21 ,r .. .. .,,,~ -..~ ter. November 14, 200? ,. ~.. • • i~' Chevr;~n 2(~~ a ~C)C II7 The well was drilled and completed as a Hemlock producer in January 1969. Ch~vrmn .:.,,. The well was shut-in in 1982, redrilled in 1983, and ~ completed in Hemlock benches 1 and 2. HB-1 10,307-10,337 HB-2 10,365-10,388 In 1984 benches i and 4 were fracture stimulated In spite of the frac. treatment, bench 2 was historically the major producer. ~ Rs the water cut increased, scale continued to be a major problem. The well was shut-in in 2004 due to lack of oil entry. (c; Ch~vror° 2C~~5 C`C}C I(7 23 Ct~~r~n ,~, ~"' , r .~ ~. The well is currently idle Current pressures Tbg 20 psi 7" Csg 176 psi 13 3/8" Csg 46 psi 20" Csg 20 psi • • '~ Chevr~;~n 2C1~ ~ C~OC III 24 chevron ~~ ,. The ?" casing is set at 11,045. The casing is cemented with 975 sx of cement with an estimated cement top of 2,080' • ~- The 9 5/8" casing was cemented with 2,725 sx of cement with an estimated cement top of 150`. ,~y~ The 13 3/8" casing was cemented with 2,000 sx of cement with cement to surface. • C~~ Chevron 2~1~5 C~~C ICt 25 ,., - -•. r' -. -~ :~' Chevr'an 2C~t15 I~C~w :v ~ TOP IIu0+1, rmP srN .ww Inr WELL TBUS G-3 ftD CASING & CE~u1~N7 p3TAIL vaw+laa aNawn ^R~ iCMT. vOL.fNOL~ 4067 ' Tor CWT, t46' M'. 1' W4L.~, rPIY[M TO ^}I, 17 111. Ir+~ J•se EAbr10 AT 1104' IIDDrn i1474N~111411P1•• • Z TOP ON1. 1010' ' ,I u i Y• fir; x•tw, 4rj J,T tT4h' IA [Y It01111Y1idq[+j; . Op11. {h 1111 ~~ nh :~ ~heru z6 • • C~~ ~he~rr~t~^ 20E~S ~C3C IC7 Ch~r~°o ,; - ~ ~: i RKB = 0.00' ~ ~ Tec HcR e aoso ' TUBING DETAIL 1 3-1/2", 9.2#, L-80 TDS. TUBING I WITH SPECIAL CLEARANCE CPLGS 13_3/8~~ 2 I 6 T# J-55 +) 4-1/2. EU ORD PIN x 3-1/2 TDS PIN X-PIER I 2j ans sssv NPPLE w/ exE BALL vAWE a so3.x9• I U 2ZO9' 3) PTA "DSO" GASLEI' MANDRELS AS FOLLOWS: 0.M /9 O 2291.64' MD a.Y 61U(•2 O 3554.43' ?.ID 0.L ~3 a 5299.05' AID av ..3 0.M ~4 O 6394.22' MD 0.M (IS O 7273.13' MD ciL 'j 0.M:~6 O 8009.46' MD ! oa t _I ~) 0.N /7 O 8484.66' MO o 30 • `~Vll I 9-5 8" 47, 43.5 / w ~o ~, rs .35 0.M je O 69 u0 ll'f J+a' 0.4 /9 O 9404.99' lAD & 47#, P- 1 10 & r cLU ~+o o ee46.2r la N-80, WINDOW a" cLU in o m+3s.7o• uo " ® 7670'- 7725' ~, 4) OTIS XA" 541DW0 9.EEVE O 10174.19' " ~ 4 5) ONE (1) JOIM 3-7/2 TOS N867C 6) 4" OD SEAL ASSY W/ STR 307 LOGTOR 5 O 10209.03' (3-1/2'TDS BOX-UP x PIN-DOWN) 6 ~ ~ 7) ONE'(1) JOOR 3-1/2" TDS TUBMO 8) OnS. "1C' LANOMC NIPPLE O 10261.07 7. 9) ONE (1) JOINT 3-7/2` TDS TUBING X 8 10) W6tELiNE RE-ENTRY OU®E O 10284.60' (BQTI'OL) 9 I t) 0715 "BWH".PERM PKR AT 10,270' Od 10 HEMLOCK PERFORATIONS: ~ 104'f8 ~ 10294'- 10296' TOP HB-1 SOZ ~~ HB-1 10307'- 10344' PROD -OPEN HB-2 10365'- 10422' PROD -OPEN PKR JUNK. \ 10652'- 10654' BASE HB-4 SOZ ~ 10627 ~OY~7' r..~.~ - raaGrvLicL j/n~93 FILL , ' ' REi~ ~ 10870' A:~ ~' in i- f~-~ (yi~Fw/~ ~ ~ 3 3 3~; 7" 29#, P-1 10 N-80 ~ 11045 ' ' WELL TBUS G-3RD2 DRAWN: DAC COMPLETION SCHEMATIC SCALE: NONE UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL} DATE: 4-23-91 OK 7/iNr 4S9t~.~C . 27 • • C~RAYI IIU['~ PI~#'nrm 60 45 30 15 0 1968 69 70 71 72 73 74 75 76 77 78 79 80 81 82 10000 5000 1000 500 °~_ Cumulative O'il Prod :13681 Mbbl Cumulative Gas Prod : 4600.983 MMcf Cumulative ter Prad ;1392.A43 Mbbl 100 50 1968 69 70 71 72 73 74 75 76 77 78 79 80 81 82 11/01/2007 09:04'.07 1-Prod and V~tr Cut.grf Date 10 Clt~~rort :~ • (' Chevr;~^ 2(lf~~ i`Cs~ TC7 28 t c~vrort tt ~,, Cumulative Oil Prod :1777 Mbbl Cumulative Gas Prod : 879.227 MMcf GRAYLING Platform ~ Cumulative iNater Prod : 7904.21 Mbb' ._ 100 80 Vl~ter Cut.(%) 507332004901:F~VILOCK 60 40 _ 20 0 1983 84 85 86 87 88 89 90 91 92 93 94 95 98 97 98 99 2000 01 02 03 04 10000 1000 100 10 1 507332004901: FAN L OCK OiLRate (CfYj (bbUd) ' Cate; Seq-2004 ~.-. Liquid Rate (CD) (:bbUd) ®il Rite {CC?) : 3 bbl/d Gas I Oil Ratio (cflbbl) ter to (CC1 : 246 bbUd star CUt :98,7 ••»•= VVater Inj Rate (CDj (bbl/d) 19S:f 84 85 tf6 8/ 88 89 9U 91 9L yS 94 95 9(i 9/ 98 ~J 2UW U1 U2 U3 U4 05 0(i 7-Prod and Vur C~t.grf 11/01/2007 08:51:01 Date • Cri Ch ' t`:~~~ 2(105 I~CjC I 29 ., .. . ~~ _~ ~' ''' °: -_ • November 14, 2007 C~7 Chevr~o~^ 2C1~a C~C}C I~ Chevrran 3 ~.. ~': This well was drilled and completed as a Hemlock producer in 1969. The water cut increased rapidly and the well was ~ shut-in in 1978 due to water production. In July 1982 the well was redrilled and completed as a Hemlock bench 1,2,3 and 4 producer. As water cuts have increased scale has become a problem in this well. The well is currently being re ted with n ctive inhibition r r m. ~ t a a a poga Current production rate: 3004/21 BPD 96% cut 249 MCFPD ,c; ~ht ; ';~^ 2C1C"a G10 IC) 31 v n a ~ ~ s~ The 7" finer was set at 10,767' and was cemented with 1,000 sx cement. The shoe of the 9 5/8" casing was set at 6,000'. The casing was cemented with 1,850 sx of cement and returns were received at the surface. 3~ The 13 3/8" casing was set at 2,011 feet and 2,600 sx of cement were pumped. The last 100 sx were pumped from the surface. Current wellhead pressures: Tbg 120 psi 9 5/8" Csg 1420 psi 13 3/8" Csg 220 psi 20" Csg 0 psi • C, Cr; Chi rr-~~ 2t'iC1S HOC ICS 32 ~ .. Chevron ~~;,„ • • Cc~ Chevr;~~ 2C}f~ a C~C?C IC7 33 ENELL TAUS G-2RD CASING & ABANQONMENT D`ETA1L I I I,- ~ f ~ V.) Kelly Bushing at 0.00' J~ ~ IL) Tuhing Hanger at 38-60' I~ ul I ~ IIIJ 13 3/8", 61+. J-55 Casing at 1300' IV.) Top T, 29:x, N-80 liner at 5491.70' ~1 Z V.) 9 5/8", 47,M, N-8.0 Casing at 6000' LM~ a VI) Cement Retainor at 10,745' VIL) 7', 29+,N-80 liner at 10;767' IV OLMI TUBING DETAIL T c M s 3 y/2", 9.2#, N-80 TUBING cM s 1.) 3 1/2' Otis XEL Ba11Valve at 293.83' 2.15 ' 1~ ) 1 2J 3 1/2" Camco Gas Lift Mantlr ei at 2203.40'. ccNl ~ 3.);`3 t/2" Camco Gas Litt PAan tlrel at 3869,68' 4:) $ 7/2`rbamco Gas Lift Manure) at 5434:84` r~M's 5.) 3 1/2' Camco Gas Lift Mandrel at 6601.25' ~ 6.)3 t/2" Camco Gas Litt Mandrel at 7470.0 Y " " ~ e 7.)-3 1!2 Camco Gas Uft Mandr at at 8028.89' 8.) 3 t/2' Camco Gas Lift Mandrel at 8483:94' '~c j. io 9.) 3 7/2' Camco Gas Lift Mandrel 'a[ 8803.58' I i 10.)3 7/2' Camco Gas Lift Mandrel a! 9175.96' -' Y ~ ~ 11.) 3 1/2' Camco Gas LifT Mandrel at 9576.69' 12.) 3 1/2" Camco Gas Lift Mandrel. at 9983.50' GLM 12 13.) Olis 'XA' Sliding Sleeve at 70,020 89' (2,7j `1,p,1 - 'i 14JBaker Locator at 10,059:95' 1 15.) Baker Motlel F-1 Prod. Packer with BO-40 Seat zA ~ 1s Assembly from-1:0.080.48' to 10,080.32' 16:) Otis 'X' Nipple at 10:085.50" La>?S'1.E",~~\ 17.)Bottom of :Mule Shoe at 10,117.82' / *~ PERFORATFON RECORD '~ ~': `~ rs DA ® lN3gERV~z CQND1710N 2 82 1365'.-1387 Tes.14HPF 5/ 1310'-.1312' Test 4HPF 15 5/26162 1330'-1332' Test 4H'PF 2020'-2022' Test 4HPF 5/31/82 2129'-2131' Test 4HPF ~~~1-~ q ~ ~~ ~.61y~gS 1390'-1x92'. Test 4HPF /~~a(1'L~ ~ 7 ;~eK~'"7~U7~360'-1362' Test 4HPF 2 p ~ ~ y~ , jp~"3~ ~ 0/01/82 2100'-2108' Test 4 HPF "'"'°^--~-`.-'-' ~ ., 7/13/82 70,343'-10;34.5' Test 4HPF _ ---- &~(.~~~'' 7/14/82 10,262'-70,264' Test 4HPF yr ~- 7!15/82 10,174<-.10,176' SQUeezed 7/21/82 1.0,345'-90,375' Reperf HB •3 4HPF Prod. vu i-0,230'-10,260'.. Reperf HB s2 4HPF Prod. 1:0.180'-10.203' Aeperf Nt3 +1 4HPF Prod. 1 1/9~PA1 G1 NS Lo~ ~ 01- e , j . /+ kstt Laos tp`k~1-~. f0;4n2 y~_u- 4t& 0"/ 1'0~ of F~~L j ?'t1C,C..*+-.'r ~ ! l9.H' 3/iL/53 /0/64 - Etisl S7s/'~) ~ . f w477... . AT 1D,b30 !a/71'-/7j A/S-/~~5~~ ~iL c) ~ L WELL TBUS G-2RD ~.~~ ,~, WELL SCHEMATIC oK ,~~~~~~ I. ____,_ UNION OIL CJMPA NY OF, CALIF CR NIA e~csn .. 34 • (~RAVI IAIR I~I~tfnrm 100 80 60 40 20 0 Cumulative Oil Prod : 2965 Mbbl Cumulative Gas Prod :1443.206 MMcf Cumulative Water Prod :99590.741 Mbbl 1982 83 84 85 86 87 ~ ~ 90 91 92 ~1 94 95 90 97 98 99 2000 01 02 03 04 OS 06 D-i 10000- 1000 100 10 ~~ 507332003801: LOCK . Oil flit (GD) (bblld) ~~~8: Step-2001. ..Liquid Rate (CD) (bbUd) ®il to {Cd) : 71 boll Gas / Oil Ratio (cf/bbl) 1llCter to ([31 : 2297 b[bll .... V1/ter CUB :97.0 °fo .W.-•-.- Water Inj Fate (Cdy (bbl/d) iaot w o4 w m of w oa ;xl ai x, a~ a. m ao ai ao m ciw vi uc w w w w 1-Prod andVW Cut.grf 11/01/2007 08:56:01 Date Chevron >.~. - ~ • • C~~ Chevr•c _ 2Q05 I~C3~ Ili 35 :: J~ J n+ ~.~~ •-. ~ yr ri • November 14, 2007 Chi ~h~vro~3 2Q€~5 ~C3C TC3 Chevron 4 ~~ ~,~ Wel Is directly offset to G-24 have wel I bore integrity. a ~. ~.~ ~ Infection into G-24 will not adversely affect the adjacent wellbores. Injection into well G-24 should benefit production in well G-oZRD. (c~ Chcvr-o;~ 2Q€l5 C7C~C IC? 37 e e ~ ¡,-, ~ . ; ; , I ,/:\ \ , ! Ü \ j.iJ~ L:::::J Li æ m 11J.\ Uu FRANK H. MURKOWSKI, GOVERNOR AI.ASIiA. OIL AlWD GAS CONSERVATlONCO~SSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAJ< (907)276-7542 Steve Lambert Advising Reservoir Engineer UNOCAL PO Box 19624 Anchorage, AK 99519 (;, '(~f Re: McArthur River Field, Hemlock Oil Pool, G-24 Sundry Number: 306-198 17â- (0" 0 \1 Dear Mr. Lambert: 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. orman Chairman DATED this 'f day of June, 2006 Encl. 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate U Waiver w Other ~ Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D Casing Test Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 Exploratory D 76-32 . 3. Address: Stratigraphic D Service D 6. API Number: Box 19624, Anchorage, Alaska 99519 50-133-20286 . 7. KB Elevation (ft): 9. Well Name and Number: 104' above MSL G-24 8. Property Designation: 10. Field/Pools(s): Grayling Platform / Cook Inlet A1>L. 17~~¡ }Dfø·(,·oÞ McArthur River Field / Hemlock . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,388' 9,815' 10,237' . 9,668' . 10,237' 10,244' Casing Length Size MD TVD Burst Collapse Structural 359' 26" 359' 359' Conductor 829' 20" 829' 829' Surface 5,115' 133/8" 5,115' 4,885' 3,090 psi 1 ,540 psi Intermediate Production 1 0,388' 9 5/8" 10,388' 9,808' 6,870 psi 4,760 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,746' to 10,240' 9,207' to 9,671' 41/2" 12.6# N-80 9,689' Packers and SSSV Type: Packers and SSSV MD (ft): Otis 95/8" BWH Perma Drill Pkr, Packer @ 9,635' SSSV @ 341' 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 0 Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/31/2006 Oil 0 Gas D Plugged 0 Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Lambert Printed :~ ~\u - C' h. ~vV\ '0 p Title Advising Reservoir Engineer ~ ., " 0 >·J't Signature ~t\ó-...... \~ 1":. 1I."i-, Phone 2G"3-ì(P'2>~ Date 5/30/ c~ J~ , COMMISSION USE ONLY . Conditions of approval: Notify Commission so that a representative may witness Sundry Number: t ~ 0 - \q~ Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: ~~\ \ ~,~ \ «<.~ ~\~-\- ~r- dO t\~ '- "ð-S '" J-1s'l SC\~ ~ ~\ "",c\. '\ 'f'\. \,)"'-.~.\- , Subsequent Form Required: ~w RBDMS BFL JUN 0 8 20D6 APPROVED BY b-l-ob Approved by: -J-'1 /' COMMISSIONER THE COMMISSION Date: \../ V '-- 4 ¿.~.(),- RECEIVED A STATE OF ALASKA &1',1-,0. '- ALA_ OIL AND GAS CONSERVATION COMM_ION P"'4{fp MAY 3 0 2006 APPLICATION FOR SUNDRY APPROVALS Alaska Oil & Gas Cons. Conmission 20 AAC 25 280 Form 10-403 Revised 07/2005 ORIGINAl ~~;t;~ e e Generalized Procedure for TEMPERATURE SURVEY Grayling Platform Well # G-24 May 19, 2006 OBJECTIVE Recent production testing of well G-24 has indicated that the well has a very small casing or packer leak which causes the well to pressure up with gas and eventually results in high pressure gas in the tubing and casing. There may some fluid production associated with the leak as well. The purpose of this test is to identify the source of the gas and possible fluid that is entering the. casing. WELL STATUS See Well Data Sheets and Platform Schematic for additional well information. Minimum ID: 4-1/2" 'X" Nipple @ 9676' MD (3.813" ID)???? Tubing Size: 4-1/2",12.6#, L-80 End of Tubing: 9,706' MD. CONTACTS 1. Steve Lambert: Ext. 7658 (Office); 339-2302 (Home); 952-4297 (cell) 2. Brit Agler: Ext. 7954 (Office); 696-3808 (Home); 440-9261 (cell) PREPARATION 1. Research and review mechanical data (gauge history, tight spots, fish, mandrel depths, etc. from well service reports and schematics). PROCEDURE 1. Conduct a safety meeting with the foreman, #1 Operator, and service company personnel. Ensure that service company personnel are familiar with the wireline procedures checklist and obtain a diagram of the tool string prior to commencing wireline operations. 2. Rig up to flow the casj,Q.g....taJest separator. Install 2 pen recorder to monitor tubing and casing pressures. Separator readings should be taken at least once every half hour during the test and recorded on well test "Hot Sheet". 3. Rig up slickline unit. M.U. tool string consisting of both Pressure and Temperature gauges, and adequate weight bars. Install lubricator and pressure test. 4. Wireline was just in this well 2/21/06 with a pressure temperature gauge to 9,992' so it is probably not necessary to run a GR before the survey unless operator prefers to. 5. Shoot a fluid level in the casing. e e 6. RIH with gauges recording static temperature and pressure. Stop at 9,900' for 15 minute static reading. 7. With the gauges on bottom, open casing to flow. Produce the well into the test separator. Maintain hot sheet and record produced gas and liquid volumes. 8. While producing the well, run dynamic pressure and temperature survey from 10,000' to 5,000' at 60 fpm. 9. When the casing pressure reaches 1,000 psi, shut-in the casing flowline at the wellhead. 10. Shoot a fluid level in the casing. 11. Return the well to production from the casing following the fluid level shot. 12. When the well is returned to production, run dynamic temperature survey from 5,000' to 9,800' at 60 fpm. 13. Leave gauges at 9,800' for the remainder of the flow period. 14. Continue to flow the casing until the casing pressure drops to 150 psi. Shut-in the casing and disconnect flowlines. 15. Shoot static fluid level in the casing. 16. Wait 6 hours and run static temperature survey from 9,800' to surface at 60 fpm. 17. Download and verify data recorded. E-mail the data to John Butler with Pollard Wireline at qaslift@alaska.net. 18. Rig down wireline unit and leave well shut-in. E-Mail the Memory Gauge Data to John Butler. Fax the Wireline Time/Depth Sheet, Well test "Hot Sheet", Wireline Well Service Reports, and copies of any other pertinent survey data to Pollard Wireline Fax #907-283-7118 - Attention: John Butler and the Unocal Anchorage Office 4th Floor Fax # 907-263-7847 - Attention: Steve Lambert. Steve Lambert Chevron Anchorage Reservoir engineer salambert@chevron.com Office: 907-263-7658 Fax: 907-263-7847 Cell: 907 -952-4297 John Butler Pollard Wireline gaslift@alaska.net Office: 907-283-7006 Fax: 907-283-7118 Cell: 907-252-5737 Home: 907-283-2033 e e Chevron === Steve Lambert Advising Reservoir Engineer Unocal Alaska Union Oil Company of California Box 196247 Anchorage, Alaska 99519-6247 Tel 907-263-7658 Fax 907-263-7847 salambert@chevron.com May 23, 2006 Thomas Maunder Alaska Oil and Gas Commission 333 W. 7th Ave., Suite #100 Anchorage. Alaska 99501-3509 Dear Tom: Unocal has recently been attempting to evaluate the cause of high tubing and casing pressure on well G-24. This well is a Hemlock producer that was shut-in in 2003 due to high water cut. The well has exhibited high tubing and casing pressure since shut-in. As detailed in the attached power point slide deck, a short flow test was performed in April to confirm the source of the pressure. Based on the results of the test, it appears that the well has a low volume casing or packer leak which is creating pressure on the annulus. Unocal would like to propose a second flow test of the annulus to try to determine the source of the leak. This second test will incorporate fluid level monitoring to confirm if fluid is entering the casing and temperature surveys to locate the source of the leak in the casing. Please review the attached information and contact me if you have any questions concerning this proposed test. f;:t~rx~ Steve Lambert cc: Well File e e Chevron === Steve Lambert Unocal Alaska 5-19-2006 Chevron 2005 DOC ID Entity Chevron III G-24 is open . In Hemlock benches 1-6 ---Á__ ----_._--~--~ ~.-~----------------+--+. ---+-~------. ,J 2 20" @ 0 3 e 0 4 0 5 0 6 13-3/8" 0 7 @ 5115' 0 8 0 9 0 101 0 11 0 12 0 13 0 14 XA 15 e Chevron 2005 61"¡Qó f¡1I@ IDZ31~ JUNK @ 10244' DIL ( 10259' DPM ) 9-5/8" @ 10388' Il' I c I l D ~~~~~ .~~ ..~~~~~~~:..~~~: -'-I I A) K&LC.Y .OSHU'¢ AT 0.00' II! CA./'ItROti SIN(';L£' Tt.l81NO KANGtk ....T .0...· CI JC". 941. tt-fO CASING AT 829" I)' lJ-J/"·, U , 6.81, I-MS CASINO "''1: $l1S' tJ '·5"~. "'t. Uas·95. ~-ao. P~UO CA$IHÇ 107 Ion,' n.1fIO DtTAn. .~111". 12.6f. L-80.Aa MQOUI£b BUTT ~JTø SP£CIAl. CLEARANce COUrt.IHC¡S U S· OD I: ... 1£1 øtAIJT n. tUE 8fW 1'01" II 1'OT'1' 8O'l'1'Oft ~ '~lJ'" OTIS' FUl>PttR VArN£' AT 341.16' )-1,u '-II'· CMCO /1fIIG G1J't'S AT; 312403.06', f' 3119.49'1 ! ) 492!1.18· 61 575ti.09'; 116409.69'/ 81 U90.83' 9' 138'.60· lOt 1'7,.O:P¡ 111 11326.60·¡ 1.21 8123.52'; 131 n09.',': 141 U53.S' 1!1 4-112- OTIS . I:"~ SLIDING st.!:"£" A't 9603.1)' 161 (JUS MIH PnHA·¡HUU PACfI:E1I: AT 9634.7" 16 111 '_1/~:A~r:-~X~~p:~\~,:::::'9' 1'0 9644.6)' lal O'J'1s RE~TR'¥ cerN: WIn BCTTOtI AT 9105.'" P£R~'I'IOX .!:COHO ......................... 5/1111' '/14/7' "'0/71 t/03/76 1130/17 618'" 10122/119 E 9960'-9962' l021"·10HO' 10lS6'-1018,' 100tO'-lOI'O' 9t6~'-100~2' 9748'·"68' 9800'·"'0' 990,'-9935' 9HS'-10050' 10090'-10140' 10lS6'-10lØ" 97U'·9768' 9905'..9935' 9965'-100s2' 10090'-101.3" 9'1-41'·976" 9'92''''880' 9810'-99)$' 993"-10Of1' 10090'-lOUoS' 10206'-102.36' WELL TBUS G-24 COMPLETION ( 11-3-89 ) UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) DOC 10 500££2.£:0 OÞIÞI ae·6 OPeN 1111-5 OPE. He-' OPO KS-4 OP¡;:If tf8--1 OPEN Ø1I·2 0.0 IIB-) OPEN Be-4 OPEN n-s OPEN BS-$ OPtlf 11'11--1 GPO IB-) OPD HIS-4 OPEN Q-!I OJ>tll1 88-J- OPtIf 0-2 onx oa-' oPal n.... Ot>U 811-$ on. aa-' DRAWN: DAC SCALE: NONE DATE: 11-5-89 Ok 7/27/'5" Ør.~~ 2 e e Current Status Chevron III · Well G-24 was shut-in in February 2003 due to high water cuts. · The well has recently exhibited high wellhead pressures when shut-in. · When the pressure is bled down, gas is produced. Chevron 2005 DOC ID 3 G-24 Casing blowdown Chevron === · On April 19, the casing in well G-24 was blown down to determine if there is a casing leak in the e well. · Due to the high casing pressure(2,500 psi), the tubing and casing were in communication thru the gas lift valves at the start of the test. · Tubing pressure and casing pressures dropped proportionately until the casing pressure dropped below the closing pressure of the gas lift valves (1,600 - 1,200 psi). e · The tbg pressure remained at 1,500 psi while the casing dropped to 110psi. Chevron 2005 DOC ID 4 I Gas lift valves start to close. AU the gas lift valves are closed. 5 G-24 Casing blowdown Chevron III e · The blowdown of the casing produced 481 mscf of gas. · Converting this volume to the casing volume under pressure is 3,025 cu. ft. · The annulus volume is estimated to be 2,894 cu. ft. · There was a small entry from outside the casing e during the test. Chevron 2005 DOC ID 6 Casing Blowdown 3.000 2.500 2.000 1.500 1,000 500 o 19-AIU 21-1\.1)1 23-1\.1)1 25-1\.lu 21-AIU 29-Apl Tubing Pressure Casing Press 1-May 3-May 5-May l-May 9-M<"lY 7 Pressure Monitoring Results Chevron III e · Tubing pressures remained at 1,500 psi until the casing pressure exceeded 1,500 psi. · This is the opening pressure for the gas lift valves. · At pressures above 1,500 psi the tubing and casing will be in constant communication. · Pressures have stabilized at 2,500 psi in the tubing and casing. e @ Chevron 2005 DOC ID 8 Test Conclusions Chevron === e · The buildup of pressure in the annulus indicates there is / a casing or packer leak. · Based on the tubing pressure performance it does not appear to be a packer leak. · The check valves in the gas lift valves appear to be holding. · The leak is low volume or connected to a reservoir -' which is tight. · The entry appears to be mostly gas. (Liquid could have been produced also.) · Future tests should include fluid level shots. · 2 gas samples taken to date indicate that the gas is not gas sands or gas lift gas, but the sample point is in question. New samples will be taken. e @ Chevron 2005 DOC ID 9 .. Recommendation Chevron III e · Perform another casing blowdown utilizing temperature surveys and fluid level shots. · Fluid levels will confirm if fluid is entering the casing along with the gas. · Temperature surveys will identify the source of the / casing leak. e @ Chevron 2005 DOC ID 10 e e Chevron Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com March 16, 2006 Steve McMains AOGCC 333 W. ih Avenue, Ste. 100 Anchorage, Alaska 99501 Re: Outstanding Sundries \1 10,611 'Y' Dear Mr. McMains, We have conducted an internal audit of regulatory filings for 2003 and 2004. As a result, several projects were found to have outstanding sundries. We have researched the work and have prepared the sundries to close out the projects left uncompleted. The list of projects includes the following: 2003 Grayling, G-12RD3, Reperforat~ Grayling, G-24, Reperforate V Monopod, A-15RD2, Perforate Steel head, M-01, Repair Casing Patch Steel head, M-05, Perforate Swanson River, SCU 32-04, Reperforate (3 Sundries) Swanson River, SRU 12-15, Recomplete Swanson River, SRU 32A-33, Reperforate 41 ( (iJ ,;:; 2004 Happy Valley, HV-A02, Coil Tubing Clean Out In order to assure that we do not have any such gaps in the future, we have implemented a database to track all drilling related AOGCC filling requirements. Please contact me directly at 263-7657 if you have any questions about these filings. Sincerely, 2¿~ Timothy C. Brandenburg Drilling Manager Attachments Cc: Well Files TB:sk Union Oil Company of California I A Chevron Company http://www.chevron.com STATE OF ALASKA _ ALAe OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U Other U Reperforate Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Name: Development [] ExploratoryD 176-032 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic 0 ServiceD 6. API Number: 50-733-20286-00 7. KB Elevation (ft): 9. Well Name and Number: 40.48' RKB to TBG Hanger G-24 8. Property Designation: 10. Field/Pool(s): Grayling Platform/Cook Inlet McArthur River Field/Hemlock 11. Present Well Condition Summary: Total Depth measured 10,400 feet Plugs (measured) 10,237' (fill 06/95) true vertical 9,819 feet Junk (measured) 10,244' Effective Depth measured 10,237 feet true vertical 9,668' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 829' 20" 829' 828' Surface 5,115' 13-3/8" 5,115' 4,885' 3,090 psi 1,540 psi Intermediate Production 10,388' 9-5/8" 10,388' 9,808' 6,870 psi 4,760 psi Liner Perforation depth: Measured depth: 9,746 to 10,240' True Vertical depth: 9,207 to 9,671' Tubing: (size, grade, and measured depth) 4-1/2", 12.6# L-80 @ 9,705.97' Packers and SSSV (type and measured depth) Otis 9-5/8" BWH Perma-Drill Packer @ 9,634.79' 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 3 2 2,558 1,110 260 Subsequent to operation: 168 164 3,002 1,140 220 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run ExploratoryD Development [] Service D Daily Report of Well Operations X 16. Well Status after proposed work: Oil[] GasD WAG 0 GINJ D WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: n/a Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature 7--=6?- c·h _0 Phone ~R 1 7 zoolr:3~_Date 2. - 2'2 -u.,. Form 1 0-404 ~ed 04/2004 p/ AFE 158081 'ì Submit Original Only e e 12/28/02 PJSM. Remove tree cap X flange XO and flange up SWS flange X Bowen XO and RU lubricator and prep for perforation jobs. PJSM and perforating/explosives check list. 12/29/02 PJSM and perforating/explosives check list. Gun run #1, arm PU and MU 2-7/8" power jet HC 20' loaded at 60 phasing with 6 SPF. RIH noting jewelry set down at 10,175'. Pull CCL/GR correlation log from 10,175' to 9,275' and tie-into dresser Atlas CBL log dated 5/11/76. RIH and place gun on depth. Perforate interval HB-5 10,105' to 10,125'. POOH (flag line at 9,900'). Bump up by hand with 41.2 ' left on counter and had production close swab valve and at 22 turns. On swab valve lost all weight. Secure well. Talk to all hands involved and break lubricator and check end of wire (stuck in flow tubes). Mobilize slick line crew and fishing tools. Mobilize slick line crew. PJSM. RU slickline on SWS lubricator and test to 2,700 psi (ok). MU BHA #2 (3.5" GR). RIH. Tool string having problems falling. Work tools to 2,350' RKB. POOH. Check tools and stuffing box and MU BHA #3. RIH with BHA #3 (3" GR) noting jewelry with no problem. Work tools from 10,100' to TD tag at 10,190' in 10' bites. Continue work tools from 10,120' to 10,170' RKB WLM with no set down. POOH and LD BHA #3 and MU BHA #4. RIH with BHA #4 (3" LIB) noting jewelry with no problem to tag at 10,190' RKB SLM and POOH. LD BHA #4 and add 3, 8' sections to lubricator (to cover fish) and MU BHA #5. RIH with BHA #5 noting jewelry with no problem. Worked tools from 10,120' to 10,190'. Had bite at 10,184' RKB SLM (bleed oil jars with 250 Ibs over) and work tools to 450 Ibs over. Lost bite and attempt to re-bite and work tools (no-go) possible sheered off. POOH to check tools. Check tools (sheared RS brass pin and left fish baited with 6.95'). Re-pin RS with steel pin. 12/30/02 RIH with RR BHA #5 (RS re-pinned with steel pin) noting jewelry with no problem and set down at 10,185' RKB SLM and latched baited fish. Bleed oil jars and work fish to 800 Ibs over and move fish +/- 7' and looks like possible 13' of fish wire movement. Continue work fish to 1,000 Ibs over and have production flow well and move fish other 9' and pull free with no extra weight. POOH to check tools (recovered 25' of E-line and end of wire shows weak point.) Check tools and MU BHA #6. RIH with BHA #6 (1-5/8" global pulling tool with bell guide) noting jewelry with no problem to 10,120'. Work tools from 10,120' to 10,180' looking for TOF. No-go unable to find TOF. POOH and suspend fishing operations. RD slickline equipment off SWS lubricator and clean up same. 1/1/03 RU on G-24. Crew rest. PJSM. Review perforating checklist with production and Schlumberger crews. Remove night cap and pick up grease head. Pressure test lubricator to 2,500 psi. Arm Gun #2, PU and MU 2-7/8" power jet HC 20' gun at 60 deg phasing with 6 SPF. 3' blank, 17' live. RIH. Gun run #2 noting jewelry with no problem. RIH and pull tie-in pass from 10,120' to 9,688'. Place gun on depth and perforate interval HB-5, 10,088' to 10,105'. POOH, mark line at 9,900' noting jewelry, all shots fired. Arm gun #3, PU and MU 2-7/8" power jet HC 5' gun at 60 deg phasing with 6 SPF. RIH with gun run #3 noting jewelry with no problem. RIH and pull tie-in pass from 10,080' to 9,786'. Place gun on depth and perforate interval HB-4, 9,948' to 9,953'. POOH. Mark line at 9,900' noting jewelry, all shots fired. Arm gun #4. PU and MU 2-7/8" power jet HC 20' gun at 60 deg phasing with 6 SPF. 5' blank and 15' live. RIH with gun run #4 noting jewelry with no problem. RIH and pull tie-in pass from 10,010'to 9,690'. Place gun on depth and perforate interval HB-3, 9,903' to 9,918'. POOH. Mark line at 9,900', noting jewelry, all shots fired. Arm gun #5. PU and MU 2-7/8" power jet HC 20' gun at 60 deg phasing with 6 SPF. RIH with gun run #5 noting jewelry with no problem. RIH and pull tie-in pass from 10,010' to 9,690'. Place gun on depth and perforate interval HB-1, 9,746' to 9,766'. POOH noting jewelry, all shots fired. Lay down spent gun and grease head, BOPs and lubricator. Install night cap on pump in sub in well head room. Release well to production for testing. G-24, 158081 morning report summary, CONFIDENTIAL: last revised 2/22/2006, Page 1. 1/7/03 e e Continue flow test well. SWS crew traveled to platform and PJSM. Re-build grease head and re-head line. Remove night cap. RU and Pressure test lubricator to 2,300 psi (ok). PJSM. Review perforating checklist with production and Schlumberger crews. Arm gun #6. PU and MU 2-7/8" power jet HC 20' gun at 60 deg phasing with 6 SPF. RIH with gun run #6 noting jewelry with no problem. RIH and pull tie-in pass from 9,950' to 9,640'. Place gun on depth and perforate interval HB-2, from 9,798' to 9,818'. POOH, noting jewelry with no problems to 300'. Pulled 300# over at 60.3' worked line and check for "bump up" shake and rattle lubricator. Attempt to close swab valve at 19-1/4 turns had residence. Close upper wire line rams (rams closed all the way) and attempt to bleed off lubricator above rams (no-go freezing off). RU steam lines and thaw lubricator and break same. Check line (ok) and dump 5 gal methanol in lubricator. Equalize pressure. Open wire line rams and work tools to -33'. Check bump up and shut swab. Bleed down lubricator. LD spent gun (all shots fired). LD grease head, BOPs and lubricator. Install night cap on pump in sub in well head room. Release well to production for testing. Cut 200' wire and clean up work area. Suspend operations for flow testing at 21:40 hrs. G-24, 158081 morning report summary, CONFIDENTIAL: last revised 2/22/2006, Page 2. Operator: Field: API: Permit: Well Type/Status: RKB to TBG Hanger: TDITVD: Unocal Alaska McArthur River 50-733-20286-00 176-032 Oil Well/Active 40.48' 10,400'/9,819' Casing Detail Size Wt Grade Type (FT) Length (FT) 20" 94# H-40 Structural 829.00 829.00 13-3/8" 61/68# K-55 Surface 5,115.00 5,115.00 9-5/8" 47# S951N80lP110 Production 10,388.00 10,388.00 Tubing Detail Size Wt Grade Type Top (FT) Btrn (FT) Length (FT) Butt wi spec. 4-1/2" 12.6# L-80 clear couplings 0 9,706 9,705.97 Jewelry Detail Type 1.5" 00 x 4" 10 blastjoint, EUE 8RO top x butt bottom 2. 4-1/2" Otis flapper valve 3-14.4-112" Camco MMG GLM's at 2,403.06'; 3,719.49'; 4,929.88'; 5,756.09'; 6,409.69'; 6,890.83'; 7,384.60'; 7,878.05'; 8,326.60', 8,823.52'; 9,309.96'; 9,553.5'. 15. Otis XA Sliding Sleeve 16. Otis 9-5/8" BWH Perma-Drill Packer 17. Stab-Thrd 34.79' to 9,644.63') 18.4-1/2" Otis X-Nipple 341.16' 9,603.72' 9,634.79' 9,634.79' 9,766 20 77,88,89 9,768 20 1 0/22/89 10,061 269 1/7/03 9,818 20 1 /30/77 9,880 80 1/1/03 6 9,918 15 77,88 9,935 30 1/1/03 6 9,953 5 5/11/76 9,962 2 16 76,77,88 HB-4 10,052 87 1/1/03 6 HB-5 10,105 17 76,77 HB-5 10,140 50 6/8/88 HB-5 Open 10,135 45 HB-5 Open 10, 96 12/29/02 6 HB-5 Open 10,125 20 76,77 HB-5 Open 10,186 30 10/22/89 HB-6 Open 10,236 30 5/14/76 HB-6 Open 10,240 22 Fill at 10,237' 6/11/1995 Junk at 10,244' Oil (10,259' DPM) ILast Revised: 12/9/2006 I Revised By: OEol STATE OF ALASKA ALASKA~--~L AND GAS CONSERVATION COI~aZ.!SSION APPLiCA. iON FOR SUNDRY AP, ROYALS 1. Type of request: Abandon __ Suspend __ Alter casing__ Repair well Change approved program __ Operation~ shutdown ~ Re-enter suspended well__ Plugging __ Time extension__ Stimulate __ Pull tubing __ Variance __ Perforate X__ Other__ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 1810' N, 1408' W of SE Cor., Sec. 29, T9N, R13W, SM At top of productive interval 2603' S, 1168' E of Surface location At effective depth 2728' S, 1222' E of Surface location At total depth 2820' S, 1259' E of Surface location 5. Type of Well: Expk)mton/ SEP 23 i994 Alaska 0il & Gas Cons, C0mmissi0r Anch0ra,~e 6. Datum elevaUon (DF or KB) KB: 103' 7. Unit or Property name Trading Bay Unit 8. Well number G-24 9. Permit number 76 -0032-0 10. APl number 50 -733-20286 -00 11. Field/Pool McArthur River/G & WF feet 12. Present well condition summary Total depth: measured 10400 feet true vertical 9815 feet Effective depth: measured 10259 feet true vertical 9685 feet Casing Length Structural 359' Conductor 829' Surface 5115' Intermediate Production 10388' Uner Perforation depth: measured true vertical Plugs (measured) Junk (measured) Size Cemented Measured depth True vertical depth 26" Driven 359' 359' 20' 1285 sx 829' 829' 13-3/8' 4834 sx 5115' 4885' 9-5/8' 1 200 sx 10388' 9804' 9748-9768, 9800-9880, 9905-9935, 9965 - 10052, 10090 - 10140, 10156 -10186, 10218-10240 9207-9225, 9255-9330, 9354-9382, 9410-9491,9528-9574, 9589-9617, 9647-9667 Tubing (size, grade, and measured depth) 4-1/2', 12.6#, N-80 @ 9706' Packers and SSSV (type and measured depth) Otis BWH perm. pkr. @ 9635'; Otis SSSV @ 344' 13. Attachments Description summary of proposal __ Detailed operations progran~__ Questions: Call Hal Martin @ 263-7675 or Ralph Holman @ 263-7838 14. Estimated date for commencing operation ~15. Status of well classifCation as: October 24, 1994 16. If proposal was verbally approved Oil X_ Gas __ Name of approver Date approved Service 17. I hore(~ c~.' .t~ ~e~i~nd corr~t to the ~ of my k~wledge."~ ~ BOP sketch Suspended_ Date ~-(~ ~C:::(~'~'- Ct~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug Integrity _ BOP Test Location clearance MeChanical Integrity Test__ S'-~bsequent form required 1-~- ,~. ~,~ ..A_ pproved by the order of the Commission original Signea By David W. Johnston Form 10-403 Rev 06/15/88 JApproval No. Commissioner Date SUBMIT IN TRIPUCATE ^pproved Copy Returned Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 September 20, 1994 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501~3192 Dear Mr. Douglas: This is to inform you of Unocal's intent, upon your approval, to pcrforat~ thc following intervals in well G-24 (API# 50-733-20286-00) on the Grayling platform. BENCH TOP (MD) BOTTOM (MD) FEEr HBI 9748 V' 9768 20 ItB3 9900 9930 30 HB4 9940 10000 60 HB4 10013 10060 47 ,/ HB5 10090 10186 96 TOTAL 283' SEP 2 S 1994 /-~JP.,,,ska Oil & t~$ Cons. Commissio~ Anchor~,,~ eptember 20, 1994 Grayl~g Platform, Well G-24 .Perforating Procedure 1. Hold safety meeting. 2. Rig up clcctric line unit. . Pressure test lubricator as directed by Unocal wimess for five minutes. Note: A pump-in sub with a valve is required. 4. Shut down all welding and radio transmissions. e Run in hole and perforate intervals as instructed by Unocal witness. (When gun is 200' below surface, welding and radio transmissions may resume.) e Pull out of hole. (When gun is 200' below surface, shut down all welding and radio transmissions.) 7. Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH INTERVAL FEET HB1 9748-9768 20 HB3 9900-9930 30 HB4 9940-10000 60 HB4 10013-10060 47 HB5 10090-10186 96 TOTAL: 283 RECEIVED SEP 23 1994. Alaska 0il & Gas Cons. Commission Anchora~/:i~ MEMORAND' ...... /I TO: THRu: · . FROM: . P'.'I. Supervisor LOU 'Grimaldi/'~ ~"~ Petroleum Inspector · . . · ,. .. State .... ?Alaska Alaska Oil and Gas Conservation Commission · DATE: May 3, 1994 FILE NO: 9U9JECBD.DOC ~ L~ ~'57\\Y~,~ SUBJECT: Verification o~~ate ~A, Unocal wel~ ~ / Grayling platform (~' ~/ McArthur River Field . ~ 0 Tuesdav,'Mav 3, 1994: I verified the No Flow state of Unocals wells # G-23 (long and short strings) and G-24 on the Grayling platform in the McArthur river field. Well # G-23 tsa dual string completion, as the two strings produce from different intervals I treated them as separate wells. The tubing and annulus had been bled to trap pressure. The wells were routed to the facility's well clean tank which was open to the slop tank and Vented to flare, this left approximately two psi on the well. The wells were observed in this state for four hours with no fluid produced. The wells were shut in and left for one hour with a five PSI buildup observed, this was in my opinion breakout of gas entrained in the crude. We bled this off and shut the wells in for thirty more minutes with no appreciable buildup. I advised John Santiago (platform foreman) Io make a formal request for No Flow well status to the Commission and reference my visit. '..:~,!/,. Recommendation: I recommend these wells be granted No Flow status due to their inability to flow, without the aid of Gas lift. · Summary: I verified the No Flow state of Unocals wells # G-23 (long and shod strings) and G-24 on the Grayling platform in the McAdhur river field. Attachment: None Unocal North Ameri( Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, Gar~. S. (~Bush Regional Drilling Manager GSB/lew CONDUCTOR GRAYLING DISTANCE & DIRECTIONS FROM SE CORNER SEC. 29, TgN, R13W "Y" COORD. "X" COORD. WELL # FSL FEL LEG #3: LAT : 60°50' 22.569" LONG :151°36' 46.519" 2,502,352.30 212,272.70 1804 1409 1 2 3 4 5 6 7 8 9 lO ll 12 2,502,346.65 212,269.32 G-22 1789 2,502,350.14 212,266.48 G-21 1802 2,502,354.64 212,266.55 G-26 1806 2,502,358.05 212,269.49 G-25 1810 2,502,358.77 212,273.94' G-24 1810 2,502,356.46 212,277.80 G-20 1808 2,502,352.20 212,279.28 1804 2,502,347.99 212,277.68 G-36 1800 2,502,345.80 212,273.75 G-34 & RD 1798 2,502,350.83 212,270.89 G-23 & RD 1803 2,502,354.60 212,272.33 G-33 1806 2,502,351.47 212,274.88 G-27 & 28 1803 1413 1415 1415 1412 1408 1404 1402 1'404 1408 1411 1409 1407 LEG #4: LAT = 60°50' 22.832" LONG =151°36' 48. 042" 2,502,380.80 212,197.90 1831 1486 13 14 15 16 17 18 19 20 21 22 23 24 LEG #1: .LAT : 60°50' 23.575" LONG =151°36' 4Z. 505" LEG #2: LAT : 60°50' 23.313" LONG =151°36' 45.982" 2,502,374.34 2,502,376.65 2,502,380.90 2,502,385.11 2,502,387.30 2,502,386.45 2,502,382.96 2,502,378.46 2,502,375.05 2,502,378.50 2,502,381.63 2,502,382.27 212,196.66 G-14A 1825 1487 212,192.79 G-19 1827 1491 212,191.32 G-13 1831 1493 212,192.92 G-15 1835 1491 21 2,196.85 G-5 1838 1487 212,201.28 1837 1483 212,204.12 G-3 1833 1480 212,204.05 G-2 1829 1480 212,201.11 G-11 1825 1486 212,198.27 G-lO 1829 1483 212,195.72 G-17 & RD 1832 1488 212,199.71 G-7 1832 1484 2,502,455.60 212, 226.40 1906 (Reserved for Compressors) 2,502,427. l0 212,301.20 1880 1458 1383 37 38 39 40 41 42 43 44 45"' 46 47 48 2,502,421.45 212,297.82 G-12, RD & 2 1874 2,502, 424.94 , 212,294.98 G-31 1878 2. 502,429.45 212,295.05 G-4 1882 2,502,432.85 212,297.99 G-1 1886 2,502,433.57 212,302.44 G-9 1886 2,502,431.26 212,306.31 G-18 1884 2. 502,427.00 · 212,307.78 G-14 1880 2,502,422.80 212,306.18 G-30 2-,-502,420.60 .............. 2i2,302.25 ................. GL8 & RD ....... 1874 2,502,425.63 212,299.39 G-6 1879 2,502,429.40 212,300.83 G-32 1882 2,502,426.27 212,303.38 G-16. 1879 1386 1389 1389 1386 1382 1378 1376 1876 ...... 1378 ....... 1 382 1 385 1 383 1381 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION _ REPORT OF SUNDRY WELL OPERATION§ 1. Operations performed: Operation shutdown ~ Stimulate __ PLugging __ Pull tubing __ Alter casing __ Repair well __ 2. Narr~J.(~er~. Company of California (UNO(~A~ype°fWell: DeveLopment ! 3. Add~§~. Box 190247, Anch, Ak., 4. ~cationdwell~surface 1810' N & 1408' ~top~productiveinterval 2603' S & 1168' ~ ~ectivedepth 2?28' S & 1222' Exploratory / 99519- 02 ,~ 7 Stratigraphic / Service W F/S.E. CDr. of Sec. 29, T9N, R13W, S.M. E of Surf location E of Surf location Att°t~18d2est'h S & 1259' E of Perforate _.~ Other __ 6. Datum,elevation_f DF or KB) 104 RT aDove MSL Surf location feet 8. Well numbe/ ~-24/,¢-~ / 9. Permit number/approval number ?6-32 10. APl number 50-- 133-20286 11. Field/Pool McArthur River Field/He 12. Present well condition summary Total depth' measured true vertical 10,400' feet 9,815' feet Plugs (measured) Effective depth: measured true vertical 10,2 5 9 ' feet 9,6 8 5 ' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured ~ngth 359' 829' 5115' 10,388' true vertical Tubing (size, grade, and measured depth) 4-1/2", Packers and SSSV (type and measured depth) Size 26" 20" 13-3/8" 9-5/8" 13. Stimulation or cement squeeze summary Uppermost: Lowermost: Uppermost: Lowermost: 12.6#, N-80 @ otis "BWM" perm -- Cemented Driven 1285 sxs 4834 sxs 1200 sx 9748' 10240' 9206' 9667' 9706' okr fa -- Measured depth 359' 829 ' 5115 ' 10,388' ~ueverticaldepth 359' 829' 4885' 9804' RECEIVED o E c 2 01989 Anchorage 9635'.- Otis SSSV ball valve 0 344' Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation Shutin - parted tbg 526 664 4784 1300 (gas lift) 200 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil-~ Gas_ Suspended __ Service 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. ' Z Signed ~?Roy ~. 'oberts ~ Title Environmental Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE UNOCAL WELL RECORD SHEET A PAGE NO. LEASE Tradinq Bay FIELD McArthur River WELL NO. TBUS G-24 LOCATION: Conductor ~5, Leq Rm ~3, Gra¥1inq Platform, 1810' N & 1408' W from SE Corner Section 29, T9N, R13W, S.M. PERMIT NO. 76-32 SERIAL NO. ADL 17594 TD 10400' TVD 9819' DEVIATION (BHL) 2820'S & 1259' E of Surf Loc. COMPANY ENGINEER Chudanov, Harness, Graham SPUD DATE 10-8-89 COMP. DATE 11-03-89 CONTRACTOR Pool Arctic Alaska RIG NO. 54 TYPE UNIT National 1320 DRILL PIPE DESCRIPTION 5", 19.5~, E&S ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR RT TO MLLW RT TO DRILL DECK RT TO PRODUCTION DECK APPROVED 125' 228' 103' 23.3' 46.6' CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 26" 1/2" wall 359' Driven 20" 94~ Butt H-40 829' 13-3/8" 61 & 68~ " K-55 5115' 9-5/8" 47~ " USS-95, N-80 10388' Cmt'd w/1478 ft 3 cmt Cmt'd w/5559 ft 3 cmt Cmt'd w/1380 ft 3 cmt P-110 PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 5/11/76 9960'- 9962' 10298' SQUEEZE 5/14/76 10218'-10240' 10298' PRODUCTION 5/30/76 10156'-10186' 10298' Sqzd w/150 sxs cmt Open HB-6 5/30/76 10090'-10140' 10298' PRODUCTION Open HB-5 PRODUCTION Open HB-5 6/03/76 9965'-10052' 10298' PRODUCTION Open HB-4 1/30/77 9748'- 9768' 10298' PRODUCTION Open HB-1 1/30/77 9800'- 9880' 10298' PRODUCTION Open HB-2 1/30/77 9905'- 9935' 10298' PRODUCTION Open HB-3 1/30/77 9965'-10050' 10298' PRODUCTION Open HB-4 PRODUCTION Open HB-5 1/30/77 10090'-10140' 10298' PRODUCTION Open HB-5 1/30/77 10156'-10186' 10298' 6/08/88 9748'- 9768' 10298' PRODUCTION Open HB-1 9905'- 9935' 10298' PRODUCTION Open HB-3 INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS TYPE: Cameron WELL HEAD ASSEMBLY ,ask Oil & A, horage CASING HEAD: Cameron "WF", 20" 2000~ x 20" SOW CASING HANGER: Slip & seal ass¥ - CA 12" x 9-5/8" OD CASING SPOOL: WF 20" 2000~ x 12" 3000~ w/2ea 2" 5000~ outlets TUBING HEAD: DCB 12" 3000~ x 10" 5000~ w/2ea 2" 5000~ outlets TUBING HANGER: Sinqle DCB-FBB 10" nominal w/4-1/2" EUE 8RD (Top & Bottom) TUBING HEAD TOP: 10" 5000~ MASTER VALVES: Cameron "F" Gate CHRISTMAS TREE TOP CONN: 4-1/2" EUE 8RD UNOCAL WELL RECORD sHEET A PAGE NO. LEASE Tradina Bay WELL NO. TBU8 G-24 FIELD McArthur River LOCATION: ,~O~uctor #5, Lea Rm ~3, Gravlina Platform, ~8~0' N & 1408' w from SE Corner section $9t TgN, R13W, S.M. PERMIT NO. 76-~ SERIAL NO. ADL 17594 TD ~0400' TVD DEVIATION (BHL) 28~0'8 & 1259' E of Surf Loc. COMPANY ENGINEER Chud~nov, Harness, Graham SPUD DATE ~Q-8-89 COMP. DATE 11-03-89 CONTRACTOR Pool Arctic Al&ska RIG NO. 54 TYPE UNIT N~onal 1320 DRILL PIPE DESCRIPTION 5", 19.5#, E&S ELEVATIONS~ WATER DEPTH* , 125' RT TO OCEAN FLOOR aT TO MLLW RT TO DRILL DECK ~3~3' RT TO PRODUCTION DECK 46,6' APPROVED ~ERFORATING RECORD DATE ~NTERVAL 6/08/88 9965'-~005~' 6108188 10090'-1013~' 10/22/89 9748'- 9768' ~0/22/89, ~79~'- 9~80' 10/22/89 9~0'- 99~' 10/22/89 9935'-~0Q~%' 10/22/89 10090'-10~86' 10/22/89 10206'-10236' E.T.D. REASON 10298' PRODUCTION 10298' PRODUCTION ~0~59'(JUNK) ,'" ~RODUCTION 10259' PRODUCTION 10259' PRODUCTION ~0259' ~RODU~TTON 10259' P~0DUCTION 10259' PRODUCTION ~RESENT CONDITION Open ~-4 Open HB-5 Open HB-~ , Open H~-2 Open H~-3 OPen ~$-4 open ~S-5 Open HB-6 ~' DEC20'[ 9 LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 1 of WELL NO. G-24WO FIELD McARTHUR RIVER DATE 10/08/89 10/09/89 10/10/89 ~0/11/89 E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 10298' Commenced Operations at 1200 hours on 10/08/89. Skid rig #54 from G-21 to G-24. Bled tubing and annulus to 0 psig. Rigged up on tubing to kill well. Mix 3% KCL workover fluid. Pump 670 BBLS down tubing while intermittently bleeding air, gas, and traces of oil from annulus to well clean tank. Observe well-dead. Install BPV. Remove production tree. 57'(TBG Finish removing production tree. Nipple up riser FISH) and BOPE. Changed pipe rams to 4-1/2". Test BOPE to Unocal specifications. Modify bell nipple and trip tank lines. Fill annulus and unloaded tubing. Found tubing parted right below the tubing hanger. Made up an overshot on 4-1/2" tubing and ran into 57'. Attempt to engage fish-no good. Ran in with hollow mill and dressed top of fish. Ran in with overshot and engaged fish. Rigged up wireline and ran 3-7/8" gauge ring-stopped at top of fish. Ran 2-3/4" impression block-showed one side curled in. Ran 3.42" OD swage-no good. Ran 2" sinker bar-no good. Ordered and wait on fishing tools. 57' Continue to wait on fishing tools. Made up 3.75" flat bottom mill on 2-7/8" drill pipe. Ran in fishing assembly and tagged top of fish at 57'. Milled on fish for 7-1/2 hours. Rigged up wireline and ran an impression block (showed junk near center). Ran in with 3.75" flat bottom mill to 57' and milled through restriction. Cleaned out to 122'. Dressed ID of fish with 3.815" tapered mill. Rigged up wireline and ran in with 3.75" swage and magnet to ball valve at 281'. Pulled out and recovered junk. Made two more magnet runs to recover junk. Made up ball valve retrieving tool and pressured tubing to 700 psi with injection gas. Ran in with retrieving tool-stopped at 53'. 57' Ran in with 3.815" tapered mill and redressed ID of fish from 57' to 62'. Rigged up wireline with ball valve retrieving tool. Pressured tubing to 700 psi with injection gas. Ran in and tagged ball valve at 281'. Retrieved ball valve. Tubing unloaded 70 BBLS of fluid and some gas to well clean tank. Hemlock taking over 1-1/2 BPM of fluid. Mixed and bullheaded a 50 bbl sized salt pill into the perforations. Rigged up wireline and ran 2.75" swage to 9640' WLM. Trip for 3.75" swage. Ran in and set down at 8190' WLM. Worked down to 8210' WLM. Rigged up Schlumberger to shoot circulation holes. Ran in and tied in with "X-A" at 9600' TM. Shot 7 holes from 9613' to 9615' TM. Displaced well to Pipeline at 4 BPM. Pumped one complete circulation and checked for flow. Attempt to pull tubing free with 170K pull-no good. Rigged up Schlumberger and ran in with 3-9/16" tubing cutter. RECEIVED Anchorage LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 2 of WELL NO. G-24WO FIELD McARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 10/12/89 9637' Continued running in with tubing cutter and tied in with locator sub at 9636' and "XA" at 9600' TM. Spotted cutter at 9620' TM and fired same with 40K overpull-tubing did not pull free. Attempted to log cut but could not get down. Pulled out and found shock sub above cutter parted leaving 1' of tool in hole. Attempt to work tubing apart for 3 hours with 190K pull-could not get tubing to part. Found out Schlumberger did not have replacement tool. While waiting on tools, pulled to 190K and circulated at 14 BPM. Tubing came free after 2 hours of circulation. Layed down completion-recovered entire string. String pulled wet after #10 GLM (had 20 PPM H2S reading and masked up to pull remainder of pipe). Schlumberger tubing punch did not perforate tubing and their tubing cutter did not penetrate the tubing. Changed top and bottom pipe rams to 5" and tested same. Ran in with packer retrieving tool. 10/13/89 9954' Continued running in with PRT to 9634' DPM. Cleaned out fill to 9637' DPM and milled on perm packer to 9639' DPM. Packer started moving down hole. Pulled out and layed down packer core. Ran in with mill shoe to 9691' DPM. Cleaned out fill to 9954' DPM and tagged packer. Mill packer to 9956' DPM and tools started packing off with very little penetration rate. Trip for new mill shoe. 10/14/89 10155' Continue trip for new mill shoe. Found one complete G/L valve and part of a second wrapped up in the mill shoe. Ran in with new mill shoe to 9954' DPM and mill over packer. Chased packer down hole to 10155' DPM. Trip for spear to recover packer body. Ran in with spear to 10155' DPM and attempted to engage several times with no indication of getting a latch on the packer. Trip to check tools and found spear had backed off from bottom of extension. 10/15/89 10214' Down for 3-1/2 hours with drawworks electrical problem. Repaired air supply to switch gear. Ran in with overshot. Slipped and cut 90' off drilling line. Continued in to 10155' DPM and engaged packer body. Pulled out and recovered packer body and spear. Ran in with mill shoe to mill over permanent packer #3. Tagged fill at 10164' DPM and cleaned out to 10211' DPM. Milled over packer from 10211' to 10214' DPM. Packer started moving down hole. 10/16/89 10249' Chased packer to 10234' DPM. Milled over entire packer bUt could not make any hole. Trip for over shot to recover packer body. Ran in and attempted to catch fish. Did not get a good indication of latching fish. Trip to check tools-no recovery. Ran in with 8-1/2" X 7" mill shoe to 10249' DPM. Milled on packer from 10249' to 10254' DPM. Had some high torque. Trip to check tools-shoe worn on bottom and Made up new shoe and run in hole. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 3 of WELL NO. G-24WO FIELD McARTHUR RIVER DATE 10/17/89 10/18/89 10/19/89 10/20/89 10/21/89 E.T.D. 10254' 10253' 10259' 10261' 10261' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Continued in with shoe and tagged fish at 10249' DPM. Mill on packer, but could not make any hole. Tripped to check tools-recovered 2.67' of packer body and 7' of 1-3/4" sinker bar wedged inside mill shoe. Packer tail assembly still in hole-approx 11' long. Perform weekly BOPE test to Unocal specifications. Set wear bushing and ran in with new mill shoe to 10249' DPM. Mill on fish to 10254' DPM and could not make anymore hole. Trip to check tools-mill worn on face and inside. Ran in hole with bit and casing scraper. Continued in with scraper and tagged junk at 10247' DPM. Rigged up Schlumberger and ran gamma ray correlation log to tie drill pipe measurement to DIL. Found drill pipe measurement 15' deep to DIL (15' DPM = 0' DIL). Rigged down Schlumberger. Worked down from 10247' to 10253' DPM. Started getting 20 to 35 K overpull in pickup weight. Trip for concave junk mill. Ran in with 8-1/2" junk mill and set down with 60 K at 9505' DPM. Jarred out w/ 70K overpull. Attempt to work through tight spots-no good. Trip for casing swage. Ran 8-3/8" swage to 10227'-no tight spots. Ran 8-1/2" swage and found tight spot at 8444' DPM. Worked through tight spots at 8444' DPM, 9505' DPM, and 9606' DPM and ran in to 10220' DPM. Pulled out and could see tight spots at 9606' DPM and 8444' DPM. Had to jar up with 70 K overpull to get through tight spot at 9505' DPM. Worked back through all three tight spots-still required jarring at 9505' DPM. Waited 30 minutes and ran through again with no problems. Trip for junk mill. Ran in with 8-1/2" concave junk mill-stopped at 9505'. Pulled out and layed down mill. Made up RTTS and run into 9700' DPM. Set RTTS and pressure tested casing to 3000 psi-ok. Trip for 8-3/8" junk mill. Ran in with 8-3/8" concave junk mill to 10254' DPM and worked down to 10261' DPM (10246' DIL). Circulated from 0930 hrs. to 1700 hrs. before production could take fluid. Built and filtered 500 BBL FIW with 3% KCL. Displaced well with clean FIW sending returns to production. Clean active pits and trip tank. Finished cleaning active system and trip tank. Displaced hole with filtered 3% KCL fluid. Built volume for active system and tripping. Circulated and filtered one hole volume. Well taking 20 BPH fluid. Spotted a sized salt LCM pill across perforations. Trip for perforating assembly. Made up 4-1/2" tubing conveyed perforating assembly. Ran in filling the first 51 2/3 stands of drill pipe for perforating cushion. RECEIVED LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 4 of WELL NO. G-24WO FIELD McARTHUR RIVER DATE E.T.D. 10/22/89 10261' 10/23/89 9702' 10/24/89 9717' 10/25/89 4948' 10/26/89 9739' Oil & ~.s Cows. C~m,,,~,-:- DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Finished running in hole with perforating assembly. Rigged up Schlumberger and ran GR/CCL correlation log. Spaced out guns and set packer. Reran correlation log-ok. Perforated Hemlock underbalanced as follows: HB-1, 9748'-9768': HB-2, 9792'-9880'; HB-3, 9880'-9935'; HB-4, 9935'-10061'; HB-5, 10090'-10186'; and HB-6, 10206'-10236'. Performed impulse test. Attempt to reverse out and Schlumberger MIRV did not function. Reversed out by locking open PCT and opening the packer bypass. Attempt to unseat packer-no good. Circulated the long way through the packer bypass with free circulation. Packer would not come loose. Rigged up APRS on Schlumberger line for free point. Continued in with free point. Could not get below bundle carrier-pipe free to this point. Trip for 1.375" OD tool string. Ran in and tools set down at 9701' (bottom of PTS assy) - pipe free to this point. Worked below packer but could not get tool to set. Made up string shot and ran into back off at 9601'. String backed off while building left hand torque. Pulled out of hole. String backed off at top of packer at 9702'. Wait on tools for 2 hours. Ran in and attempt to screw into fish-no good. Trip for overshot. Made up 8-1/4" overshot with a 5" grapple and ran in hole. Continued running in and engaged fish at 9719' DPM. Jarred on fish at 135 K with overpull to 185K-no good. -Released grapple and trip for mill shoe. Perform weekly BOPE test to Unocal specifications. Ran in with 8-3/8" x 7" mill shoe to cut over perforating packer. Cut upper gauge ring off after 30 minutes. Slacked off and milled on upper slips for 30 minutes. Trip for new mill shoe. Ran in and milled for 40 minutes to cut through upper slips of the packer. Trip for overshot. Run in with 8-3/8" overshot with a 5" grapple and engaged fish at 9717' DPM. Hit jars twice at 150 K overpull and fish came free. Pulled out of hole and fish hung up at 4961' DPM. Worked by tight spot and continued out of hole. Found overshot bowl split, leaving 5" basket grapple and 8-3/8" OD guide on top of fish. Waited on tools for 4 hours. Made up 3-1/2" EUE cut lip screw in sub and ran in to top of fish at 4948' DPM. Screwed into fish and jarred with 70 K overpull. Spent 4 hours working first 60' out of hole. Fish hung up at every casing collar. Continued pulling very slowly out of hole. Still hanging up at every collar. Had to pump fish out of hole for 3 singles at one point. Recovered packer, 0.24' x-over, and approx 27# junk. Made up overshot with 4-1/2" basket grapple and ran in 9700' DPM. Jarred on guns with 120K overpull. Pulled to 175K overpull with no movement. Released grapple to pull out of hole but drill string still plugged. Sheared out pump-open sub and circulated bottoms up from 9715' DPM. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 5 of WELL NO. G-24WO FIELD McARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 10/27/89 10218' Continued to pull out with grapple and recovered 72.12' of fish (flow tub, firing head easy, and 42.07' guns). Made up 448' of 7-5/8" x 6-3/4" wash pipe and ran into 10207' DPM (TOF at 9781' DPM). Attempt to washover fish, but could not make any hole. Trip for new wash shoe. All teeth worn off saw tooth shoe. Ran in and tagged up at 10207' DPM. Washed over from 10207' DPM to 10218' DPM with intermittent high torgue. Trip for new wash shoe. 10/28/89 10218' Continue trip for new wash shoe. Cutting structure worn off shoe, but water courses were still intact. Ran in with new shoe and tagged up at 10218' DPM. Washed over from 10218' DPM to 10223' DPM with high steady torque. Trip for overshot. Ran in with overshot with 4-1/2" grapple to 5200' DPM. Cut 100' off drilling line. Continued in and engage fish at 9782' DPM. Jarred on guns at 150K overpull for 1 hour and fish came free. Sheared out pump out sub and tripped to check recovery. 10/29/89 10232' Continued pulling out with fish and recovered 441' of guns. Top of fish at 10229' DPM (23' guns left in hole). Ran in with wash shoe and tagged up at 10222' DPM. Washed over to 10241' DPM. Trip for new wash shoe. Shoe had a lot of ID wear. Ran in with new shoe and tagged up at 10241' DPM. Washed over with high torque to 10249' DPM. Trip for overshot. Ran in with overshot and engaged fish at 10232' DPM. Tripped jars one time at 130K overpull and fish came free. 10/30/89 10259'DPM Pulled out with overshot and recovered entire 10244'DIL fish (21.39' perf guns). Ran in with 8-1/2" bit and two junk subs. Tagged junk at 10248' DPM and cleaned out to 10259' DPM. Circulated well clean. Had a lot of fine metal shavings. Trip for production packer. Made up Otis 9-5/8" x 5" BWH permanent production packer and hydraulic setting tool and ran into 9637' DPM (9622' DIL). Pressured up and packer set with 1850 psi. Setting ball sheared out 500 psi low at 2500 psi. No way to pressure test packer. Set 30K pipe weight on packer with no movement. Sheared off packer with 45K overpull and tripped for seal assembly. Ran in with seals and stabbed into packer at 9634' DPM. Pressure tested casing, packer, and seal assembly to 2000 psi. Trip for production equipment. 10/31/89 10259' Continued trip for production equipment. Changed top pipe rams to 4-1/2" and pressure tested. Rigged up hydrotest and tongs. Plug tested from mule shoe to "XA" sleeve. Running completion string. Found that GLM #6 had not been descaled on the inside of the mandrel. Looked like gas lift valve was not-properly V~D seated in the mandrel. Shutdownwirelineand cleaned and#6 ~F%'~,_! through #12 GLM. Had Myers comeout reset valve in GLM #6. Continued running ~C ~ (~ ~9~~ completion string. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 6 of WELL NO. G-24WO FIELD McARTHUR RIVER DATE 11/01/89 11/02/89 E.T.D. 10259' 10259' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Completed running and.hydrotesting 4-1/2", 12.6#, N-80 buttress single gas lift completion string. Spaced out and landed in CIW DCB spool. Tested seals and installed back pressure valve. Nippled down BOPE. Installed and tested single 4-1/2" CIW tree. Installed flowlines and turned well over to production at 1700 hours. Skidded rig 54 to TBUS G-34. Rigged up and pumped one tubing volume down long string. Well on vacuum. Pulled tree cap to look at SSSV lodged in tree. Valve was broken up into several pieces. Could not retrieve major portion of valve from tree. Valve was not retrievable if it had gone back down hole. Mixed sized salt pill and bull headed down G-34 long string to stop fluid losses. Pill slowed losses to an acceptable rate. Rigged up on G-34 short string and bull headed one tubing volume. Well on vacuum. Rigged up on 9-5/8" x tubing annulus and filled with filtered inlet water. Prepared to change out tree. Installed BPV in short string. Removed tree and installed BPV in long string. Installed and tested new dual production tree. Returned well G-34 to production. Skidded rig 54 to TBUS G-22. Released rig from TBUS G-24 at 2400 hours on 11/02/89. 20" @ 829' //] @ 5115' JUNK @ 10244' ( 10259' DPM 9-5/8" @ 10388' 1 0: 3 O 4 O 5 0 6 Q, 7 O' 8 0 9 Oi 10 0 11 0 12 O 13 0 14 'IA 15 x 17 ---- ---- B CASING AND ABANDONMENT DETAIL KELLY BUSHING AT 0.00' B) C~ERON SINGLE TUBING HANGER AT 40.~8' C) 20', 94~, ~-40 CASING AT 829' D; 13-3/8", 61 & 68~, K-55 CASING AT 5115' 9-5/8', 47~, USS-95, E-80, P-ll0 CASING AT 10388' TUBING DETAIL 4-1/2', 12.6~, L-BO,AB MODIFIED BUTT WITH SPECIAL CLEARANCE COUPLINGS 1) 5' OD x 4" ID BLAST JT, EUE 8RD TOP x BUTT BOTTOM 2) 4-1/2" OTIS FLAPPER VALVE AT 341.16' 3-14) 4-1/3" CA/~CO MMG GLM'S AT: 3) 2403.06'; 4) 3719.49'; 5) 4929.88'; 6} 5756.09'; 7) 6409.69'; 8) 6890.83'; 9) 7384.60'; 10) 7878.05'; 11} 8326.60'; 12) B822.52'; 13) 9309.96'; 14; 9553.5' 15) 4-1/2" OTIS "XA' SLIDING SLEEVE AT 9603.72' 16) OTIS BWH PER.A-DRILL PACKER AT 9634.79' STAB-THRU SEAL ASSY FROM 9634.79' TO 9644.63' ~ 17) 4-1/2' OTIS "X" NIPPLE AT 9675.68' 18) OTIS REENTRY GUIDE WITH BOTTOM AT 9705.97' PERFORATION RECORD 5/11/76 9960'-9962' SQUEEZED 5/14/76 10218'-10240' OPEN HB-6 5/30/76 10156'-10186' OPEN HB-5 10090'-10140' OPEN HB-5 6/03/76 9965'-10052' OPEN HB-4 1/30/77 9748'-9768' OPEN HB-1 9800'-9880' OPEN HB-2 9905'-9935' OPEN HB-3 9965'-10050' OPEN HB-4 10090'-10140' OPEN HH-5 10156'-10186' OPEN HB-5 6/8/88 9748'-9768' OPEN HB-1 9905'-9935' OPEN HB-3 9965'-10052' OPEN HB-4 10090'-10135' OPEN HB-5 10/2~/89 9748'-9768' OPEN ~B-1 9792'-9880' OPEN HB-~ 9880'-9935' OPEN HB-3 9935'-10061' OPEN HB-4 10090'-10186' OPEN HB-5 E 10206'-10236' OPEN HB-6 UNION OIL WELL THUS (3-24 COMPLETION ( 11-3-89 ) COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN' DAC SCALE' NONE DATE: 11-5-89 TUBING DETAIL TBUS G-24 JTS 12 12 11 ].2 12 16 2O 31 33 51 7 X-OVER DESCRIPTION REENTRY GUIDE SHOE 4-1/2",12.6#,L-80,BUTT OTIS X LANDING NIPPLE 4-1/2",12.6#,L-80,BUTT OTIS SEAL ASSY 4-1/2",12.6#,L-80,BUTT OTIS XA SLIDING SLEEVE 4-1/2",12.6#,L-80,BUTT CAMCO MMG 4-1/2",12 CAMCO MMG 4-1/2",12 CAMCO MMG 4-1/2",12 CAMCO MMG 4-1/2",12 CAMCO MMG 4-1/2",12 CAMCO MMG 4-1/2",12 CAMCO MMG 4-1/2",12 CAMCO MMG 4-1/2",12 CAMCO MMG 4-1/2",12 CAMCO MMG 4-1/2",12 CAMCO MMG 4-1/2",12 CAMCO MMG 4-1/2",12 GLM .6#,L-80,BUTT GLM .6#,L-80,BUTT GLM .6#,L-80,BUTT GLM .6#,L-80,BUTT GLM .6#,L-80,BUTT GLM .6#,L-80,BUTT GLM .6#,L-80,BUTT GLM .6#,L-80,BUTT GLM .6#,L-80,BUTT GLM .6#,L-80,BUTT GLM .6#,L-80,BUTT GLM .6#,L-80,BUTT OTIS SSSV X-PROFILE 4-1/2",12.6#,L-80,BUTT 4-1/2"BUTT x 4-1/2"EUE CAMERON TBG HANGER LANDED BELOW ZERO LENGTH BOTTOM TOP 0.70 9705.97 9705.27 27.9'7 9705.27 9677.30 1.62 9677.32 9675.68 31.0!5 9675.68 9644.63 9.84 9644.63 9634.79 26.59 9634.79 9608.20 4.48 9608.20 9603.72 41.213 9603.72 9562.49 8.99 9562.49 9553.50 234.96 9553.50 9318.54 8.58 9318.54 9309.96 478.91 9309.96 8831.05 8.53 8831.05 8822.52 487.46 8822.52 8335.06 8.46 8335.06 8326.60 439.57 8326.60 7887.03 8.98 7887.03 7878.05 484.92 7878.05 7393.13 8.53 7393.13 7384.60 485.17 7384.60 6899.43 8.60 6899.43 6890.83 472.63 6890.83 6418.20 8.51 6418.20 6409.69 645.05 6409.69 5764.64 8.55 5764 64 5756.09 817.121 5756.64 4938.88 9.00 4938.88 4929.88 1201.80 4929.88 3728.08 8.59 3728.08 3719.49 1307.89 3719.49 2411.60 8.54 2411.60 24(33.06 2059.05 2403.06 344.01 2.85 344.0]_ 34]_.16 290.52 341.16 50.64 9.41 50.64 41.23 0.75 41.23 40.48 40.48 40.48 0.00 1) CAMERON HANGER IS 4-1/2" EUE 8RD THREAD (TOP & BOTTOM) PACKER DETAIL DESCRIPTION LENGTH BOTTOM TOP OTIS "BWD" PERMA-DRILL 12.70 9647.21 DPM 9634.51 DPM OTIS 9-5/8" x 5" "~P' PERMA I~YIZJ PACKER W~,: G-24 ~: OCIOBER 30, 1989 .37' .64' .35' .63' ,, ~ '2J21' I --[--3.34' 4.35' 7.72' 4.98' 12.70 ' 8 0 --11 --12 --13 --14 --15 16 --17 18 --19 2O --21 22 --23 24 --25 --26 --27 28 --29 34 --35 36 --37 --38 NAME: Trading Bay Unit -" ~ 30~ [989 (907) =83-753~ EE~SC2IIPTTC~ I.D. O.D. ~ ~ 1. K.B. 40.50' -O- 2. Ca~e_wo~ Tubing Har~er 3.95" .75' 40.50' 4-1/2" EU x 4-1/2" BTC 3. One (1) Blast Joint 3.95" 9.41' 41.25' 4. Seven (7) Joints of Tubing 3.95" 5.2" 290.52' 50.66' 5. Otis 1/4" Stainless Steel .25" Control Line .049" Wall (P/N 22 SXX 31050) 6. Otis '~(EL" Safety Valve 3.813" 5.02" 2.85' 341.18' Land~ Nipple Ecc. (P/N 11 XEL 38105) 5.73" 7. Fifty-One (51) 'Joints of 3.95" 5.2" 2059.05' 344.03' 8. Gas Lift Marx~ #12 6.84" 8.54' 2,403.08' 9. ~Lirty-qllree (33) Joirfcs of 3.95" 5.2" 1307.89' 2,411.62' 10. Gas Lift Mandrel #11 6.84" 8.59' 3,719.51' 11. ~hirty~ (31) Joints of 3.95" 5.2" 1201.80' 3,728.10' 12. Gas Lift Mandrel #10 6.84" 9.0' 4,929.90' 13. Twenty (20) Joints of 3.95" 5.2" 817.21' 4,938.90' 14. Gas Lift Mar~ #9 6.84" 8.55' 5,756.11' 15. sixteen (16) Joirfcs of 3.95" 5.2" 645.05' 5,764.66' 16. Gas Lift Mandrel #8 6.84" 8.51' 6,409.71' 17. Twelve (12) JoJ3fcs of 3.95" 5.2" 472.63' 6,418.22' 18. Gas Lift Mandrel #7 6.84" 8.60' 6,890.85' 19. Twelve (12) Joints of 3.95" 5.2" 485.17' 6,899.45' 20. Gas Lift Mar~ #6 6.84" 8.53' 7,384.62' 21. Twelve (12) Joirfcs of 3.95" 5.2" 484.95' 7,393.15' 7 8 10 --11 12 --13 14 --15 16 --17 --18 --19 20 !2 24 --25 --26 --27 --28 -- 29 3O --31 --32 --33 __34 35 36 --37 --38 ~ 1~): 431/1046/00/89 DA~: October 30, 1989 22. Gas Lift Mandrel #5 23. Eleven (11) Joints of 24. Gas Lift Mandrel #4 25. Twelve (12) Joints of 26. Gas lift Mar~ #3 27. Twelve (12) Joirfcs of 28. 29. six (6) JoiaTts of T~i~ 3o. Gas Lift Mandrel #1 31. One (1) Joint of Tubing 32. Otis "XA" Sliding Side Door (P/N 121 X~ 126) 33. One (1) Joint of Tubing 34. Otis Str. Slot Seal Assembly a. Str. Slot Locator (P/N 212 S 50000-a) b. Seal Assembly (P/N 212 MSN 50000-a) c. Extension (P/N 212 X 50000-A) (P/N 212 ~SN 50000-a) e. Extension (P/N 212 x 50000-a) f. SeaX ~ly (P/N 212 MSN 50000-A) g. Seal Assembly (P/N 212 MSN 50000-a) h. Adaptor - 4-1/2" x 4-1/2" BTC BxP I.D, 3.95" 3.95" 3.95" 3.95" 3.95" 3.813" 3.95" 3.96" 3.96" 3.85" 3.85" 3.85" 3.85" 3.85" 3.96" 6.84" 5.2" 6.84" 5.2" 6.84" 5.2" 6.84" 5.2" 6.84" 5.2" 5.26" 5.78" 5.05" 4.96" 5.05" 4.96" 5.05" 5.05" 4.96" 8.98' 439.57 ' 8.46' 487.46' 8.53' 478.91' 8.58' 234.96' 8.99' 41.23' 4.48' 26.59 9.86' (1.3') (1.o2') (2.02') (1.o2') (2.02') (1.02') (1.o2') (.44') 35. One (1) Joint of Tubing 36. Otis t,~, Selective Landing Nipple (P/N 11 X 138) 37. One (1) Joint of Tubing 38. ~ Mule Shoe Wireline (P/N 212 M 37) 3.95" 3.813" 3.95" 3.96" 4.96" 5.2" 4.96" 31.05' 1.62' 27.97 ' .70' PAGE2 7,878.07' 7,887.05' 8,326.62' 8,335.08' 8,822.54' 8,831.07' 9,309.98' 9,318.56' 9,553.52' 9,562.51' 9,603.74' 9,608.22' 9,634.81' 9,644.67' 9,675.72' 9,677.34' 9,705.31' 9,706.01' NO: 431/1046/00/89 October 30, 1989 I.D. O.D. PAGE3 A. Otis "~' Perma-Drill 5.0" Set c~ Drill Pipe W/Hydraulic Setting Tool 9-5/8" 36-54.9 LB (P/N 212 ~H 95500-A) B. Otis Seal Bore Extension 5.0" (P/N 212 B 9264) Bot~ Of Packer and Seal Seal Bore Extension * Drill Pipe Meam~ment 8.12" 4.98" 6.28" 7.72' T-up of Packer 9,633.66'* 9,638.64' 9,646.36' OTIS 9-5/8" X 5" "~P' PERMA ~ PACKER WRT,T,: G-24 O2~SmTETED: OCTO~ 30, 1989 .37' ! , .64' ! .63' i, 2.21' 3.34' 4.35' 7.72' 4.98' 12. lO' * Top of Packer: 9,633.66' Drill Pipe Measurement BIT RECORD COUNTY Cook Inlet FIELD MqArthur River STATE AK SECTION TOWNSHIP RANGE LOCATION WELL NO. G-24 CONTRACTOR Pool Arctic Alaska SPUD REACHED T.D. RIG NO. #54 PUMP NO. 1 OPERATOR Unocal TOOLPUSHER LINER PUMP NO. 2 LINER PUMP POWER TYPE MUD DRILL PIPE TOOL JOINTS Size Type O.D. NUMBER DRILL COLLARS O.D. I.D. LENGTH DRAWWORKS POWER NO. SIZE MAKE TYPE 1 8 - 1 / 2 T SA JUNK JET 32 nd DEPTH IN SERIAL OUT FEET HOUR FT / HR TSA 576 ACCUM WT. PUMP SPM DRLG 1000 PUMP OPER- HRS LBS R P M PRESS ,PUMP ~ ~ MILLS MUD DULL. COND. FORMATIONS WT VIS WL ~ ~ G OTHER REMARKS 1RR 8-1/2 TSA JUNK TSA576 2 8-3 / 8 TSA JUNK TSA 4299 75% USED 3 8-3/8 TSA WASHSHOE 5399 30% USED 4 8-3/8 TSA WASHSHOE 6240 20% USED BIT RECORD COUNTY FIELD STATE SECTION TOWNSHIP RANGE LOCATION WELL NO. Cook Inlet McArthur River AK G-24 CONTRACTOR RIG NO. OPERATOR TOOLPUSHER Pool Arctic Alaska ~54 Unocal SPUD REACHED T.D. PUMP NO. 1 LINER PUMP NO. 2 LINER PUMP POWER TYPE MUD DRILL PIPE Size Type O.D. NUMBER O.D. TOOL DRILL JOINTS COLLARS I.D. LENGTH DRAWWORKS POWER JET ACCUM WT. PUMP SPM 32nd DEPTH DRLG 1000 PUMP OPER- NO. SIZE MAKE TYPE IN SERIAL OUT FEET HOUR FT/HR HRS LBS R P M PRESS PUMP ~ ~ BITS 1RR 8-1/2 SEC M44N 401232 MUD DULL. COND. FORMATIONS WT VIS WL ~ ~ G OTHER · 6 3 I REMARKS c/o run 1RR 8-1/2 SEC M44N 401232 c/o run 1RR 8-1/2 SEC M44N 401232 Scraper run Baroid Drilling Fluids, Inc. November 13, 1989 Mr. Don Chudanov Unocal Oil & Gas Division P.O. Box 190247 Anchorage, Alaska 99519-0247 Re: Workover Fluids Recap G-24 Workover (Grayling) Dear Mr. Chudanov: Attached is the workover fluids recap for the above referenced well. Approximately 6,838 barrels of Filtered Inlet Water (FIW) were used to workover this well. Of this total, 3,603 barrels were lost to the well, 2,015 barrels were shipped to the production facilities for disposal and 1,220 barrels were discharged to the Inlet. The fluid discharged to the Inlet met sheen test and pH requirements and samples were submitted for oil and grease testing. The fluid shipped to the production facilities was to oily for discharge to the Inlet and was treated with polymer breakers to minimize disposal problems. Two Litesal pills were used to control losses to the well. Please refer to the recap for specific details. If additional information is required, please advise. Very truly yours, BAROID DRILLING FLUIDS, INC. District Engineer cc: Bush/Neve' Rig Copy (Mud Engineer) File Attachments RECEIVED 2000 West Int'l. Airport Rd., Suite A-10 (99502) · RO. Box 102492 · Anchorage, Alaska 99510 (907) 248-3511 · Fax (907) 248-5390 Baroid Petroleum Services COMPANY Unocal 0il & Gas Division STATE Alaska CASING PROGRAM 20 inch at 829 ft. WELL G-24 Workover COUNTY Kenai 13 3/8 inch at 5115 CONTRACTOR Grayling Platform LOCATION Cook Inlet SEC TWP RNG 9 ,5/8 inch at 10388 STOCKPO~NT Rig Tenders Dock DATE 11/2/89 BAROIDENGINEER Kerr, Wolfe TOTALDEPTH 10,4.00 DATE DEPTH WEIGHT .,VISCOSITy, , , YP GELS FILTRATION RETORT SAND CEC pH FILTRATION ANALYSIS feet lb/gal Sec APl PV 10 sec/ mi HTHP Cake Solids Oil Water TU r Mud Strip ~ Pm Pfl KCL Cl j CA REMARKS AND TREATMENT 989 __cF _~F 10 min APl ~°F 32nds % % % NTU me/mt Meter ~ Uf ppml ppm (See Operations Sheet) !0-9 10388 64 ...27 FIL.TER[D INLE' WATER 0 8.5 0 1~000 Ri.q up, FIW 10-10 57 63+ 27 FI[iTER~D INLE' WATER 0 8.5 0 15000 Fish for tubin¢ ., _10-11 122 63+ 27 FI[.TER D I_N~LE' WATER 0 8.5 0 14500 Run tb§ swed _10-12 9615 63+ 27 FI[~TER~ D INLE' WATE..R 0 TR 8.5 0 14500 ...Spot Litesal !.0-13 9637. 63+ 27 F.I[~TER~D INLE' WATER 0 TR 8.5 0 14500 .Lay dw tubing____ 10-14 9954 .... 63+ .... 27 FI.[!TERED INLE WATER TR TR 8.0 0 15000 Fish out F-lpa~ 1.0-15. 10155 6.3+ 27 FI[[TERED...INLE WATER TR TR 8.0 0 14500 Fishing f/DBpa( !0-16 10211 63+ 27 FI[iTER~D INLE' WATER TR TR 7.2 0 14500 Fish out 1st DP packer ........... !0-17 10254 63+ 27 FI[[TERID INLE' WATER TR TR 7.0 0 13500 Fish f/2nd DB ... packer !0-___1-8! 1_0_2_54 63+ '27 FI['~TER~'D INLE __WATER TR TR 7.0 ..0 1350_0 ..Recovered 2nd'~ packer LO_~_i- 9. 1_0_2J_6 6..~+ 27 FI[ TEREiD INLE' WATER TR TR 7.0 0 13500 Restrictions in_ ~0~_20 ~ !_0_2._4_6 63+ 27 FILTERED INL_E]_W. ATER TR TR 7.0 0 13000 Run 8½" csg sw_e 10-21 10261 64+ 27 FI[TEREiD INLE1 WATER 0 0 7.5 3.0 280001 Mill junk t/102 1.0-22. 19_261 64+ 27 FI[TER~iD INLE' WATER .. 0 0 16 7.5 3.0 26500 Displace hole w/3% KCl 10-23 10261 64+ 27 F'I[TERE'.D...INLE' WATER 0 TR 200 8.5 3.0 27000 Shoot perfs, -1Q:2_4_~ 64+ 27 FI[ TEREiD.. INLE1 WATER TR TR 260 8.5 _2.0 255001 Man_al~_]__b~~_~]'. .....I at; paqker COST I COST COST MATERIAL AMOUNT MATERIAL AMOUNT MATERIAL AMOUNT $ $ I"iteplug-R 35 2,276.75 Workover A ditives 18,811~87 ._ Liteplug-F 27 1,756.35 Tech. Service 25 10~125.00 ~JJJtJ Baroid Liteplu.q-X 42 2,732.10 D_a.ys @ $40~,/Day/Man ~ ,,,,~ Petroleum Services Litesal 49 4,244.87 Rework Chartqes ~-~-0-'~ Polybreak- 3 1,125.00 Kenai Boroqqh Tax 65.53 Pol.ytech-S 5 956.70 6 @ $10 & ] @ $5.53 PAC-L 2 387.74 ._ MUD MATERIALS SDI Defoam i 94.37 Used (Total) KC1 175 5,106.50 ... Salt 4 43.72 DRILLING MUD RECORD - Sapp 1 TOTAL COST 29,074.40 PRINTED IN US.A, Drilling Mud Record Petroleum Services Page 2 COMPANY Unocal Oil & Gas Division ST^TE Alaska WELL G-24 Workover COUNTY Kena i CONTRACTOR Grayling_ Platform LOCATION Cook Inlet SEC STOCKPOINT Ri9 Tenders Dock DATE 11/2/89 BAROIDENGINEER. . Kerr, Wolfe CASING PROGRAM 20 inch at 13 3/8 inch al . . 829 ft. 5115 n. TWP RNG , 9 5/8 inch at 10388 ., TOTAL DEPTH 10,~ 400~__ DATE ,,,DEPTH WEIGHT VISCOSITY Yp, GELS FILTRATION ...... RETORT ,,SANDI CEC pH FILTRATION ANALYSIS feet lb/gal Sec APl PV 10 sec/ mi HTHP Cake Solids Oil Water mu r Mud Strip ~( Pm Pfl CI 1 CA REMARKS AND TREATMENT !,989 __=F _"F 10 min APl ~°F 32rids % % % NTU me/mt Meter ,-1 Mf KC1 PpmJ ppm (See Operations Sheet) 10-25 1020'i ,64+ 27 FIL:EREI INLET WATER i ...... TR',,' .TR,,, ' ...... 200 ..... 8.5 i,i 3.0, 25000 vliil packer 10-26 10261 64.+.. 2.7. FILi EREI INLET WATER ......... TRC TRC 220 8.5 3.0 25000... Pull fish t/4948 .!0,27. 10261 64+ 27 FIL' ER.El. !..NLET WATER .... TRC TRC 230~ 8 5 3.Q., 27500 qetrieved pac' .!g,28 10261 64+ 2.7 FIL'EREI INLET WA..TER ..... TR .TRC. 330 .... 8.5 3.0 25500 :ayed down 72 ..~ ~f fi sh 1012_____9.. i.'.0261 64 2.7 FIE' 'EREI iNLET WATER TRC ~R 40'' 8.5 ....3.0 .... 2606'0 ~ash over fish ..... 10-30 1.02.61 64~ ..... 27FI..L"EREI INLET WATER TR TRC .60 8.5 .. 3,.. 27...000 Layeci dn'441' of fish 10-31. 10261 64+ .... 2'7 'Fi'LI'EREI INLET WATER ~R~; TR~ .... 60. 8.5 .... 3 2550.0. ... Ran Jacker and tested 11-1 10261 64+ .27 .. FIL"EREI INLET WATER fR. TRC 40.. 8.5 3 ']2500C~ Ran 4½" pr.o. ducti string. ,. 11-2 10261' 64+ "2.7 ,FIL"EREi) iNLET' WATER ... TR TR ...... 40 8.5 .. 3.. .'.25..00C " ..' Move rig .... ........ .... .............. ..... ............ j ,. .,~ )n Uncoal Oil & Gas Division INVENTORY G-24 Workover Beginning InventorS Received Barazan 10 0 Baravis 20 0 Liteplug-R 22 60 Liteplug-F 12 31 Liteplug-X 78 0 Litesal 24 50 Polybreak-S 0 6 Polytech-S 2 8 PAC-L 4 0 SDI Defoam 1 2 CaC12 35 0 KC1 184 60 Salt 132 0 Sapp 0 Used 0 0 35 27 42 49 3 5 2 1 0 175 4 1 Ending InventorS 10 20 47 16 36 25 3 5 2 2 35 69 128 0 Order Document Numbers: Charges- Q27116 Q27118 Q27123 Q27112 Q27113 Q27124 Q27134 Q27141 Q27149 Q27192 Credits: Q27122 Q27160 Q27161 Q27162 Amount: $17,783.46 4,774.41 2,593.46 5,038.00 7,888.77 282.04 1,760.80 1,135.00 9,325.00 820.00 Total Charges $ 1,780.86 14,795.40 1,533.18 4,217.10 Total Credits $51,400.94 $22,326.54 Total Well Cost - $29,074.40 OPERATIONS · Unocal Oil & Gas Division G-24 Workover Dote Depth, Ft. Tour 10-9 10-10 10-11 .o-RECEJVEO Ri.q down tree and valves~ riq up riser and BOP's, test BOP's, choke, kill lines, hook up trip tank lines, pull back pressure · valve, fill well bore .with filtered inlet water, pull tubing hanger, tubing was parted at 57', attempt to catch fish with overshot, no go. Polish off 8' of fish with mill, latch fish with overshot, rig up meyers wireline and run 3 3/4" swedge, stopped at top of fish, run impression block, run 2½" swedge with 2" weight bar, no go. Hole took 720 barrels fluid loss. Pick up tools and mill on top of fish @ 57', rig up Meyers and run impression block, mill from 57' to 60' with 3 3/4" tapered mill, clean out inside tubing to 122' with stinger, rig up Meyers and run swedge and magnet to top of ball valve to retrieve junk, attempt to retrieve ball valve, only got to 53', no go. RIH with 3 3/4" swedge and magnet and fish for junk, POH wi th wi reline. PU mill and mill in top of fish f/97' to 60', POH, rig up Meyers_ pull ball valve, bleed off pressure from 550 psi and bullhead 20 bbls FIW down tubing, mix and spot 41 bbls of Litesal pill by bullheading it down the tubing with FIW with hydrill closed until pressure built up to 1600 psi, Wireline run with 3" swedge, got to 9600'. Wireline run with 3 3/4" swedge, only got to 8210', rig down Meyers, rig up Schlumberger, shoot circ holes f/9613' to 9615', displace well volume with FIW with returns to production pipeline, monitor well, attempt to pull tubing free from packer, no go, circ two tubing volumes, returns {o mud tanks, RIH w/tubing cutter. Fi re tubing cutter @ 9620', pull on tubing, no go. Ci.rc tbg, seal assembly pulled loose while circulating, POH laying down 4½" tubing, recovered' 9652' of tubing (string pulled wet below GLM #10 @ 7616', neither circ holes nor cutter had penetrated thru tubing), change top and bottom BOP rams to 5" and test same, OK. Pick up PRT and fishing tools and RIH wi th DP. Page 2 Unocal Oil & Gas Division G-24 Workover OPERATIONS · Date Depth, Ft. Tour 10-13 Mill on "F-I" packer @ 9637', circ, POH, retrieve PKR, pickup 10-14 10-15 10-16 10-17 10-18 mill shoe and RIH, tag scale @ 9691' and clean out to first "DB" packer @ 9954', mill over pkr (fluid loss to formation increased from 1.4 bbls/hr average to 17 bbls/hr once packer slips were milled out), circ btms up, POH w/mill, (Recovered gas lift valve, jammed up inside of mill shoe). Make up new mill shoe and mill over same "DB" pkr and push down hole to 10,155', circ, POH, lay down shoe and service boot basket, pick up spear and RIH, spear pkr @ 10,155', circ hole clean with both pumps, POH, no recovery, spear backed off inside oi= pkr, wait on fishing tools, (Brine losses have dropped off to 8.8 bbl/hr/avg). Wait on tools and work on draw works power, make up overshot and RIH, fishing and POH, recovered spear and packer, pick up new mill shoe, extension and boot basket and RIH. Tag fill @ 10,164' and clean out to second. "DB" packer @ 10,211', mill around packer (4.0 bbls/hr losses). Push pkr from 10,211' to 10~234'~ circ btms up, POH and lay down shoe, extension, boot basket. Make up overshot and RIH~ Fish for pkr @ 10,249', POH, no recovery, lay down overshot, pick up shoe text and RIH to 10,249', mill over junk and pkr @ 10,249' to 10,254', POH with mill shoe, change BHA, tools and RIH w/new shoe. Mill over junk @ 10,249', POH, junk dragging up ho!e, tight @ 9848', lay down shoe and boot basket, recovered sinker bar and packer, Test BOP's, pick up shoe and extension and RIH, mill over junk @ 10,254', POH and lay down shoe, pick up cas.ing scraper and 8½" bit and RIH to 10,246'. Circ bottoms up, rig ~p and run collar locater inside of DP, circ, POH and lay down csg scraper, pick up 8½" mill and boot baskets and RIH to 9505', attempt to work mill past casing restriction, no go. POH and lay down ~2~" mill, pick up 8 3/8" casing swedge and RIH to 10,227', POH and lay down 8 3/8" swedge Pick up 8½" cas'ing swedge and RIH. .? OPERATIONS ' Page 3 Unocal Oil & Gas Division G-24 Workover Date Depth, Ft. Tour 10-19 10-20 10-21 10-22 Work tight spot in cs$ @ 9505', RIH with swedqe from 9505' to 10,228', POH to 8400', RIH f/8400' to 10,200', work tight spots @ 8444', 9505' 9706', .POH to 8400', wait 30 minutes, RIH to 9505', OK. POH and lay down swedge, Pick up 8½" mill and RIH to 9505', couldn't work mill past 9505', POH and lay down mill, pick up RTTS and RIH to 9700', set RTTS and pressure test casing to 3000 psi for 30 minutes, held OK. POH and lay down RTTS, pick up 8 3/8" mill and boot basket and RIH. Mill f/10,254' to 10,261', circ hole clean and build 412 bbls of filtered 3% KC1/FIW brine in reserve tank, ship surface, and first circulation of hole volume to Trading Bay Facility vis production pipeline, circulate hole volume twice with clean filtered inlet water with returns overboarded (passed sheen test) while cleaning pits 3 and 4 flowline ditch. Displace hole with filtered 3% KC1/FIW and clean pits #1 and #2, and sand trap. Circulate and filter KC1 brine/complete circulation. Pull 21 stands (hole was taking 15-20 bbls of brine loss/hour), RIH again, mix and spot 50 bbls of Litesal . pill across perfs, POH, lay down mill, jars and bumper sub, pick up Schlumberger perf gun assembly, 2 stand of drill collars and drill pipe and RIH, fill pipe. Finish RIH with perf assembly to 9748' (leave approximately 4200' of drill pipe dry), rig up test head and Schlumberger wireline and run in hole wi th wireline, set pkr @ 9702', POH w/wireline, Rig down wireline equipment, test surface equipment to 5000 psi, pressure up on annulus to fire guns, attempt to flow well, shut well in, fill DP and attempt to function MIDRV, no go. Open bypass at packer and reverse circulate 3500 strokes (tbg volume almost 3 times), got back some Litesal pill with 3% crude oil in it, (let Litesal returns co-mingle with filtered KC1 in mud tanks), rig down Schlumberger manifold and test head and lines, attempt to un-seat pkr, no go. Rig up Schlumberger and APRS, run free point, stuck somewhere below 9698' (picker is @ 9702' DIL). OPERATIONS · Page 4 Unocal Oil & Gas Division G-24 Workover Date Depth, Ft. Tour 10-23 10-24 10-25 10-26 10-27 10-28 10-29 11-1 11-2 POH w/wireline, circ and WO freepoint tools~ run free point, circ, RIH with back off shot, make blind back off (backed off at sub on top of packer @ 9708'), POH with wireline and ri9 down wireline equipment, POH with DP and DC's, strap, Make up Tri-state screw in sub, jars, and bumper sub and RIH, Tag fish, circ bottoms up, fishing with screw in sub, no go. POH, make up overshot and start back in hole, (Brine losses 2.5 bbl/hour average). RIH w/wireline, run free point, POH, pick up Tri-state, RIH, circulate btms up, could not get on fish, POH RIH w/overshot, no go, POH, RIH with milling shoe, mill on gage ring and packer slips, POH, RIH with new mill. Mill packer slips, POH, lay down shoe, latched on to fish, started out of hole, hung up @ 4948', POH, pick up jars and overshot, working pipe out of hole, slow. Worked fish out of hole, retrieved packer, make up fishing tools, RIH, latched on to fish at 9759', got off at fish circulated bottoms up, POH. Lay down fish, got 72.12' of fish, lay down fishing assembly, PU washover assembly and was to 10,207', POH PU new wash on shoe, wash from 10,204'. POH, change out shoe and TIH to 10,218', wash to 10,223', circulate bottoms up, POH, lay down wash pipe, RIH w/overshot, latch on'to fish at 9782', POH w/fish. Layed down 4441.41' of fish, PU washover, TIH to 10,222',~wash down 10,226' to 10,241', POH, Change mill and junk basket, RIH washover, POH, lay down washover and mill shoe, TIH w/jars and overshot. ' POH, lay down fish, P'U drilling assembly, TIH to 10,248', clean out to 10,254', circulate hole clean, POH lay down BHA, pick up Otis packer, RIH set at 9637', RIH, test packer POH, lay down seal assembly, pull wear bushing and change top rams, PU complet{on string, trip crowomatick and run 4½" production string, hydro testing same Nippling G-24 down and Move rig. BIT RECORI) COUNTY __~C_oo. k. I n l et FIELD STATE SECTION McArthur River AK TOWNSHIP RANGE LOCATION WELL NO. CONTRACTOR ~Pool Arctic Alaska SPUD REACHED T.D. RIG NO. OPERATOR ff54 Unocal PUMP NO. 1 LINER TOOLPUSHER PUMP NO. 2 LINER PUMP POWER TYPE MUD DRILL PIPE Size Type O.D. NUMBER O.D. I.D. LENGTH TOOL DRILL JOINTS COLLARS DRAWWORKS POWER JET ACCUM WT. PUMP SPM 32nd DEPTH DRLG 1000 PUMP OPER- ~ SI~A~ TYPE It_~ SERIAL OUT FEET }{OUR FT!HR }IRS LBS R P M PRESS PUMP ~ ~ MUD DULL. COND. FORMATIONS WT VIS WL T B G OTHER ~MARKS BIT RECORD COUNTY cook Inlet FIELD STATE SECTION McArthur River AK TOWNSHIP RANGE LOCATION WELL NO. CONTRACTOR __Pool Arctic Alaska SPUD REACIIED T.D. RIG NO. OPERATOR f54 Unocal PUMP NO. 1 LINER TOOLPUSllER PUMP NO. 2 LINER PUMP POWER TYPE MUD DRILL PIPE Size Type O.D. NUMBER O.D. I.D. LENGTH TOOL DRILL JOINTS COLLARS DRAWWORKS POWER JET ACCUM WT. PUMP SPM 32nd DEPTH DRLG 1000 PUMP OPER- ~_~ ~ A~ TYPE I__N SERIAL OUT FEET }{OUR FT/HR }{RS LBS ~ P M pR.ESS PUMP 1 2-- MUD DULL. COND. FORMATIONS W__T VIS WI___~, ! ~ G OTIIER REMARKS ~:~., Alaska Drilling District GRAYLING PLATFORM ~u~.L # G-24 11-01-89 Reworked well and installed old tree back on well but used new DCB Tubing Hanger _ 41,, 4½" EUE Top x ~ EUE Bottom w/control line prep. x-prep CIW -WF CIW-W~ /_ r,1 11" 5000 RX-54 Ring Gasket ~' !3 5/8" ,3000 ~w_q7 211 I! : ~. 2000 Rx-73 ~inq Gasket 13 ~/8" 9 5/8" MEMORANDUM State uf Alaska AZLAS~& OIL AND GAS CO~aSERVATION COMMISSION TO: J~onnze C. Smith ?::-~ DATE: October 24, 1989 Commissioner FILE NO: D. BDF. 1 ! 2 THRU: FROM: i',Iichael T. Ninder '~../,- Sr. Petroleum Engineer Bobby D. Fo;ter~}'~=~ Petroleum Inspector TELEPHONE NO: SU BJ ECT: BOP Test rS~ Uno c a 1-~-~ayl G-24 Permit 'No. 76-32 McAt thur Rv Fie 1 d ober 17, 1989, I traveled this day to the Grayling ~£~ l-~ BOP tests on Rig 54. As the attached BOP test report shows there was one failure which ~was replaced and tested before I departed the platform. The kill line has threaded connection in it and I requested that these be removed. The Unocal Rep, agreed and said it would be done as soon as material could be acquired. In summary, I witnessed the BOP Test on Unocal's G-24. Attachment STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report DATE Location (general General h°usekeeping Reserve pit MUD SYSTEMS: Trip tank Pit gauge ~ ! F1 ow monitor /J' I Gas detectors /" ! Wel 1 sign ~ Rig BOPE STACK: Annul ar preventer Pi pe rams B1 i nd 'rams Choke line valves HCR valve Kill line valves Check valve ft Visual Audio Test Pressure ACCUMULATOR SYSTEM: Full charge pressure Press after closure Pump incr clos press 200 psig Full charge press attained Controls: Master C~. ~ Remote~/~ Blind switch cover~,,,~ _ KELLY AND FLOOR SA/ETY VALVES: Upper Kelly Lower Kelly (~ 0 0 psig _ ~min Ball type 1 t / Test pressure~'~ / Test pressure~-~-~'~ Test pressure Inside BOP / Test pressure Number valves I /I~ Number flanges ~ ~ Adjustable chokes I Hydraulically operated choke ~ TEST RESULTS: ,,..~- ~? Failures I Test time ~ [/'7~ hrs Repair or replacement of failed equipment to be made within days and Inspector/Commission office notified. C.004 (rev 03/17/89) ...... . STATE OF ALASKA ..... ~? ';!~ ' ;~ A ,KA OIL AND GAS CONSERVATION COMk ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon m Suspend ~ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Ptugg. i_ng ~ Time extension __ Stimulate __ Change approved program m Pull tubing ~ Variance ~ Perforate ~ Other [ 2. NameofOperator Union Oil Company of California (UNOCAp 3'A~d~s~ Box 190247, Anch, Ak., 99519-0247! 4. Location of well at surface 1810' N & 1408' W f/SE cor., Sec. 29, At top of productive interval 2603' S & 1168' E of surface location At effective depth 2728'N & 1222' E of surface location At total depth 2820' S & 1259' E of surface location 5. Type of Well: ) Development Exploratory Stratigraphic Service 12. Present well condition summary Total depth: T9N, R13W, S.M. measured 10,400' feet Plugs (measured) true vertical 9,815 ' feet 6. Datu, m elevation IDF or KB) 104 RT ABOUE MSL 7 nit rProp rt n a '~a:~Ing ~a~ ~n~t 8. Well number 6-24 9. Permit number ?6-32 10. APl number 50-- 133-20286 11. Field/Pool McArthur River Field ~emlock feet Effective depth: measured 10,298' feet Junk (measured) true vertical 9, ? 21 ' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: ~ngth Size Cemented Measureddepth 359' 26" Driven 359' 829' 20" 1285sxs 829' 5115' 13-3/8" 4834sxs 5115' 10388' 9-5/8" 1200sxs 10388' measured true vertical 10,218'-10,240'; 10,156'-10,186'; 10,090'-10,144'; 9965'-10,052'; 9905'-9935'; 9800'-9880'; 9748'-9768' 9650'-9671'; 9592'-9620'; 9531'-9581'; 9413'-9495'; 9357'-9385'; 9259'-9333'; 9210'-9229' Tubing (size. grade, and measured dep~th~/2,, , 12.6#, N-80 @ 9689' Baker F-1 pAr @ 9637'; Baker "DB" pAr @ 9940' Packers and SSSV (type and measure~P.l~tB) "DB" pkr @ 10,196'; Otis ball valve @ 281' True vertical depth 359 ' 829 ' 4885' 9804' 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 115. Status of well classification as: October 6, 1989 16. If proposal was verbally approved Oil ~ Gas ~ Suspended ~ Name of approver Date approved Service 17. I herebE certify that the fqreggi ng i¢ true and correct t_o the best of my knowledge. Signed arts Title Environmental Engineer Date ,,/~) . ' ~' FOR COMMISSION USE ONLY Conditi~fi~ of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commissioner lAppr°va'N°' Date ORIGINAL SIGNED BY Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL PROCEDURE TBUS G-24 10-6-89 1. MOVE RIG 54 OVER TBUS G-24, LEG 3, CONDUCTOR 5. 2. KILL WELL WITH 3% KCL COMPLETION FLUID (TBG PARTED @ 45') 3. iNSTALL BPV'S, NIPPLE DOWN TREE, NIPPLE UP BOPE. 4. PULL AND LAY DOWN G/L PRODUCTION STRING. 5. MILL OVER AND RECOVER PERM PACKER AT 9637'. 6. MILL OVER AND RECOVER PERM PACKER AT 9940'. 7. CLEAN OUT FILL TO PERM PACKER AT 10196'. 8. MILL OVER AND RECOVER PERM PACKER AT 10196'. 9. RUN BIT AND SCRAPER TO 10298' ETD. 10. PRESSURE TEST 9-5/8 CASING WITH RTTS PACKER. 11o CHANGE OVER TO CLEAN COMPLETION FLUID. 12. REPERFORATE HEMLOCK BENCHES 1 THROUGH 6 WITH TUBING CONVEYED GUNS AS FOLLOWS: HB-1 HB-2 HB-3 HB-4 HB-5 HB-6 9748'-9768' DIL 9792'-9880' DIL 9880'-9935' DIL 9935'-10061' DIL 10090'-10186' DIL 10206'-10236' DIL 13. RUN SINGLE G/L COMPLETION. 14. REMOVE BOPE AND INSTALL DUAL TREE. 15. RETURN WELL TO PRODUCTION AND MOVE OFF. NOTE: SBHP ANTICIPATED TO BE 4025 PSI AT 9450' TVD. WORKOVER FLUID WILL BE FILTERED INLET WATER WITH NACL AS REQUIRED FOR WELL CONTROL. BELL NIPPLE I FLOWLINE 2" KILL LINE WITH (2) 2" 5~ VALVES d'; KILL LINE FROM MUD PMP ~ CEMENT UNIT 12" 5000 PSi ANNULAR J I, 1 BLIND RAMS PiPE RAMS ,! ! ti I i I' i PIPE RAMS RISER [ i J ,, J 15-5/8" 5M FLANGE ADAPTER 5M x 5M 15-5/8" 5M FLANGE DOUBLE GATE 5M 13-5/8" 5M FLANGE 4" CHOKE LINE WITH ONE REMOTE & 1 MANUAL 4" 5M VALVE CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) 15-5/8" 5M FLANGE SINGLE GATE 5M 13-5/8" 5M FLANGE 10" 5M x 1.3-5/8" 5M ADAPTER CAMERON 5M DCB SPOOL 15-5/8" DOPE 5M STACK ALL DRILLINO OPERATIONS UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) · ',,~ ,,~f-~. , -'~'r ,;.' .. DRAWN' CLL APP'D' GSB SCALE: NONE DATE: 3/12/89 20" @ 829' ~ 5115' 9-5/8" / @ 10:388' 5 TUBIN6; DETAIL 4-1/2", 12.6#, L-80 TB6;. )sssv 2) 6;LM's 3) XA SL~ 4) PERM. PACKER @ 9650' 5) "'X" NIPPLE 6) RE-ENTRY 6;UIDE HB 1 9748'-9768' HB 2 9792'-9880' HB 3 9880'-9935' HB 4 9935'-10061' = HB 5 10090'-10186' HB 6 10206'-10240' WELL TBUS 6;-24 PROPOSED COMPLETION UNION OIL COMPANY OF CALIFORNIA (dba UNOOAL) DRAWN: DAC SCALE: NONE DATE' 10-2-89 IIl!v! HB-1 " HB-2 HB-3 ~ HB-4 }t1~-5 WELL TBUS G-24 CASING & ABANDONMENT DETAIL !.) Rotary Table Measurement at 0.00' IL) Tubing Hanger at 36.66' III.) 26', 0.500' Wall Drive Pioe at 359' IV.) 20°. 94,~, H-40 Casing at 629' V.) 13 3/8°. 61~ & 68,~, K-55 Casing at 5115' VI.) 9 5/8', 47~, USS-95,N-80 & P-110 Casing at 10,388' TUBING DETAIL 4 1/2"~ 12.6#, N-80 TUBING 1.) Otis Ball Valve at 281.44' 2-16.) Camco 'MMG' Gas Lift Mandrels at: 2) 2018.43'. 3) 3624.90°, 4) 4928.58', 5) 5896 63', 6) 6305.81'. T.) 6627.39', 8} 6946.62','9) 7296.15', 10) 7615.78', 11) 7036.14°, 12) 8289.41°. 13) 6607.15°. 14} 8926.00°. 15) 9274.36', 16) 9561.95' 17.) Otis 'XA° Sleeve at'9600.25' 20.) 21.) 23.) 24.) 25.) 26.) 18.) Baker Locator Sub at 9636.59' 19.) Baker Model 'F-1° Packer with Seal Assembly from 9637.49' Io 9655.75' Otis *X° Nipple at 9655.75' Bottom of Baker Mule Shoe at 9689.00' Baker Model 'DB' Packer from 9940.00' to 9943.93' 4 1/2' Buttress Crossover at 9943.g3' Otis 'XN' NiDple at 9950.05' Bottom of Baker Bell NioPle at 9952.22' ' Baker Model 'DB' Packer from 10,196.00' to 10,199.54' 27.) 3 1/2' Buttress Crossover at 10,199.64' 28.) Otis 'XN' Nioole at 10.208.68' 29.) Bottom of Baker Bell NiDPle at 10,210.35° PE DA TE INTERVAL 5/14176 10218'-10240° 5/11/76 9960'-10060' 5/30/76 10156'-10186° 5/30/76 10090'-10144° ~103/76 9965'-10052' RFORATION RECORD CONDITION HB-6 3hpf Production SQueeze Zone Isolalion HB-4 HB-5 3hpf Pro0uction HB-5 3hpf Production HB-4 3hPf Production 1/30/77 9748'-9768' HB-! PRODUCTION 1/30/77 9800'-9880' HB-2 PRODUCTION 1/30/77 ..... 9905'-9935' HB-3 PRODDCTION' 1/30/77 9965'-10050' HB-4 PRODUCTION 1/30/77 10090'-10140' HB-5 PRODUCTION 1/30/77 10156'-10186' HB-5 PRODUCTION 6/8/88 9748'-9768' HB-1 PRODUCTION 6/8/88 9905'-9935' HB-3 PRODUCTION 6/8/68 9965'-10052' HB-4 PRODDCTION 6/8/88 10090'-10135' HB-5 PRODUCTION WELL TBUS 6-24 WELL SCHEMATIC EXISTING COMt~LETION .. , WELL TBUS 6-24 CASING & CEMENT DETAIL CMT TOP AT 5982' COMPLETED 6-4-76 -, VOLUMES SHOWN ARE (CMT VOL/HOLE VOL) 26' 1' WALL. DRIVEN TO 359' 20', 94~. H-80 AT 828' 850sx$ ( 1478ff=/675tt~) CMT RETURNS TO SURFACE CSG TESTED OK TO 500psi 13 3/8°o 61~ & 68-~, K-55 AT 5115' (5559tt~/3822tt~) CMT RETURNS TO SURFACE CSG TESTED OK TO 3000;~s~ SEAT TESTED TO 0.65psUtt E~UlVALENT 9 5/8'o 47*~. USS-95, N-SO, P-110 AT 10,388' 1200sx$ (1380tt~/3437tt~) GRAYLING PLATFORM CASING & CEMENT DETAIL. UNION 011. COuP/~Ny OF' CALIFORNIA, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,oSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate/~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator Union Oil Company of California (UNOCAL) . 3. Address P.O. Box 190247~ Anch~ Ak.~ 99519-0247 4. Location of wellatsurface 1810'N & 1408'W from SE cor., Sec. 29, TgN, R13W, SM 5. Datum elevation (DF or KB) 99' RT above MSL Feet 6. Unit or Property name TBU 7. Well number G-24 8. Approval number 8-344 9. APl number 50-- 133-20286 10. Pool Attop ofproductiveinterval 2603'S & 1168'E of surface location Ateffective depth 2728'N & 1222'E of surface location At total depth 2820'S & 1259'E of surface location Hemlock 11. Present well condition summary Total depth: measured true vertical 10,400' feet Plugs (measured) 9,815' feet Effective depth: measured true vertical 10,131' feet Junk (measured) 9,56.5 feet Casing Structural Conductor Surface Intermediate Production Liner Length 359' 829' 5115 ' 10,388 ' Perforation depth: measured true vertical Tubing (size, grade and measured depth) Size Cemented Measured depth 26" Driven 359' 20" 850 SX 829' 13 3/8" .5115' 9 5/8" 1200 sxs 10,388 ~ue Verticaldepth 829' 4885' 9808' 10,218-10,240'; 10,156'-10,186'; 10,090'-10,144'; 9965'-10,052'; 9748'-9768'; 9800'-9880'; 9905'-9935' 9650'-9671'; 9592'-9620'; 9531'-9581'; 9413'-9495'; 9210'-9229'; 9259'-9333'; 9357'-9385' 4 1/2", 12.6# N-80 8 9689' Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary 13. Baker F-1 pkr ¢ 9637': Bake~ "pB~'.pkr_~ 9940' Baker "DB" pkr ~ 10,196'; Otis ca±± valve ~ 281' Intervals treated (measured) Treatment description including volumes used and final pressure Prior to welt operation Representative Daily Average Production or Injection Data Ar~chor3O9 OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 488 671 ~576 i200 1~0 585 935 5267 1215 160 Subsequent to operation 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [l 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /M Roy D. Roberts Title Environmental Eng Oat~6/16/88 Form 10-404 Rev. 12-1-85 Submit in Duplicate~..- G-24 Perforation On Oune 8-10, 1988 the following intervals were perforated using Schlumberger 2 1/8" Flow Oet charges. HB-1 9748'-9768' HB-3 9905'-9935' HB-4 9965'-10,052' HB-5 10,090'-10,135' STATE OF ALASKA ALASI~A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~. Suspend © Operation Shutdown .~ Re-enter suspended well ~ Alter casing ~ Time extension .~ Change approved program~ Plugging ~ Stimulate ~ Pull tubing 5: Amend order ~_,r'~ Perforate ~. Other 2. Name of Operator Union 0il Company of 6aliforn±a (UNOCAL) 3. Address P.O. Box 190247, Anch, Ak., 99519-0247 4. Loca~§~.l~i~i,~ve~l ~t4~j~t~efrom SE cDr., Sec. 29, TgN, R13W, ~ 5. Datum elevation (DF or KB) 99' RT above MSL 6. Unit or Property name TBU 7. Well number G-24 8. Permit number 76-32 9. APl number 50-- 133-20286 10. Pool Attop of productiveinterval 2603'S & 1168'E of surface location At effective depth 2728'N & 1222'E of surface location At total depth 2820'S & 1259'E of surface location Hemlock feet 11. Present well condition summary Total depth: measured true vertical Effec. tive depth: measured true vertical 10,400' 9,815' 10,131' 9,565 feet Plugs (measured) feet feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Length 359' 829' 5115' 10,388' Perforation depth: measured true vertical Tubing (size, grade and measured depth) Size Cemented Measured depth 26" Driven 359' 20" 850 sx 829' 13 3/8" 5115' 9 5/8" 1200 sxs 10,388 ~ue Vertical depth 359' 829' 4885' 9808' 10,218-10,240'; 10,156'-10,186'; 10,090'-10,144'; 9965'-10,052'; 9748'.-9768'; 9800'-9880'; 9905'-9935' 9650'-9671'; 9592'-9620'; 9531'-9581'; 9413'-9495'; 9210'-9229'; 9259'-9333'; 9357'-9385' 4 1/2", 12.6# N-80 ~ 9689' Packers and SSSV (type and measured depth) Baker F-1 pkr @ 9637'; Baker "DB" pkr ~ 9940' Baker "DB" pkr ~ 10,196'; Otis ball valve e 281' 12.Attachments Description summary of proposal r- Detailed operations program ~-',_, BOP sketch 13. Estimated date for commencing operation 5-01-88 14. If proposal was verbally approv~ubscquent Work Reported on Form No. ~ Dated _~_/~/.~ Name of approver Date approved 15. I hereby certify that th~.~foregoing is trt~e _/a/hd c~orrect to/the best of my knowledge Signed r/~L~¢~ ,/~,. .... Roy D. Rob~.rt~ ' Title -'Environmental Spec. ///'~' Use Only C°mmission Date 04/28/88 Conditions of '~pproval Notify commission so representative may witness [] Plug integrity ~ BOP Test © Location clearance Approved by 1~,,~~. ~~__ Form 10-403 Rev [ Approval No. (~)~,~)~>' ~i.;~' , &pproved Copy Returned by order of Commissioner the commission Date lo e G-24 ,~~PERFORATION PROCEDURE Rig up E-Line Unit. Pressure test lubricator to 2500 psi. RIH with 2 1/8" perforating guns, 4 SPF, 0° phasing, erforate underbalanced or flowing as follows: B-1 B-2 B-3 8-4 B-5 B-5 9,748'- 9,768' DIL'/ 9,800'- 9,880' DIL/ 9,905'- 9,935' DIL~ 9,965'-10,052' DIL/ 10,090'-10,140' DIL'/ 10,156'-10,186' DIL~/ Rig down E-Line Unit. 4. Flow well to test separator. V~ HB-4 HB'5 V WELL TBUS G-24 G kt'4" j 5 GLM I 6 G Utc, 'i 7 GLt4 j g I t G'..~ j11 ~LM i 12 , ,., ~3L.~, i1,4 ..~ ~ i × ! 20 -'r 21 \ /23 i',r ' 24 ~26 1 19 22 CASING & ABANDONMENT DETAIL I.) Rotary l'able Measurement at 0.00' I1.) Tubing Hanger at 36.66' II1.) 26", 0.500" Wall Drive Pipe at 359' IV.) 20", 94,~, H-40 Casing at 829' V.) 13 3/8", 61~. & 68'~-, K-55 Casing at 5115' VI.)9 518", 47.,*, USS-95,N-80 & P-110 Casing at 10,388' TUBING DETAIL 4 1/2', 12.6#, N-80 TUBING 1.)Otis Ball Valve at 281.44' 2-16.) Camco 'MMG" Gas Lift Mandrels at: 2) 2018.43', 3) 3624.90', 4) 4928.58', 5) 5896 63', 6) 6305.81'. 7) 6627.39', 8) 6946.62', 9) 7296.15', 10) 7615.78', 11) 7036.14', 12) 8289.41',.13) 8607.15', 14) 8926.00', 15) 9274.36', 16) 9561.95' 17.) Otis 'XA" Sleeve at'9600.25' 18.) 19.) 20.) 21.) 22.) 23.) 24.) 25.) 26.) 27.) 28.) 29.) DA TE 5/14/76 5/11/76 5/30/7'~ 5/30/76 6/~3'/76 Baker Locator Sub at 9636.59' Baker Model 'F-I" Packer with Seal Assembly from 9637.49' to 9655.75' Otis 'X" Nipple at 9655.75' Bottom of Baker Mute Shoe at 9689.00' Baker Model 'DB" Packer from 9940.00' to 994S.93' 4 1/2" Buttress Crossover at 9943.93' Otis 'XN" Nipple at 9950.05' Bottom of Baker Bell Nipple at 9952.22' Baker Model 'DB' Packer from 10,196.00' to 10,199.54' 3 1/2' Buttress Crossover at 10,199.84' Otis 'XN" Nipple at 10,208.68' Bottom of Baker Bell Nipple at 10,210.35' PERFORATION RECORD INTER VA L 10218'-10240' 9960'-10060' .~o156'-.~o186' 10090'-10144' - 9965'- 10052'"' O,,'7c'?- q7G~ q?o5 - qqz~ CONDITION HB-6 3hpf Production Squeeze Zone Isolation HB-4 HB-5 3hpf Production HB-5 3hpf Production HB-4 3hpf Production /% , - S/.,'// ..-, '-,-- /:D/, 'i . ; / 'WELL TBUS 6-24 WELL SCHEMATIC Document Transmittal Union Oil Company of California unlen DATE SUBMITTED ACCOUNTING MONTH 4-16-82 TO F'ROM Mr. Harry. Kugler R.C. Warthen x'+ .... Sta'te 0il and Gas ' 'AT Cons.· Commission PO Box 6247 t'lllg, llUl O. LJ~:~ /-~1\ TELEPHONE/'~IC~.k.,IIUI (..lt.jc: } t"~l\ 22,.Juc. TRANSMITTING THE FOLLOWING: i , lull,,, Ill ,,,I 1 ~n M~nn~f~r fnn~ C~-/1 RR ~R2R C~ 1 ea ,, ,, G_o~ Dn #62;'37 .. 1 , eal, " ", G-24 #62732 .... .... ~ .... PLEASE SIGN AND RETURN ONE COPY RECEIVED' - .... .................... , ..... , ............. , ......... ,~ ,, ............. FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. 74~. Union Oil and Gas Di' '3n' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 union S. eptember 3, 1976 Mr. Hoyl e Hamil ton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 RE- TBUS G-24 GRAYLING PLATFORM Dear Mr. Hamilton- Enclosed for your files are two (2) copies of the Well History for well Trading Bay Unit State G-24, Grayling Platform, Cook Inlet, Alaska. Very truly yours, ~im R. Callender District Drilling Supt. sk Encl. (2) cc: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Co. Skelly Oil Co. Phillips Petroleum Co. Standard Oil Co. Rodney Smi th-USGS jUiq ~ 4:!976 Union Oil and Gas ~ion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 union June 11, 1976 Dear Mr. Hamilton: Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 RE: TBUS G-24 GRAYLING PLATFORM Enclosed for your files are two (2) copies of the Sub-Surface Survey for the above captioned well. Very truly yours, ~&m R. Callender District Drlg. Supt. sk Encl. (2) cc: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Co. Phillips Petroleum Co. Skelly Oil Co. Standard Oil Co. USGS - Rodney Smith Union Oil and Gas D~sion: Western Region ~Jnion Oil Company o, California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 June 10, 1976 Mr. Hoyle Hamilton. Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 RE: 'TBUS O-12 Rd. WO TBUS G-24 TBUS D-28 Dear Mr. Hamilton: Enclosed for your files are two (2) copies of the Monthly Report of Drilling & Workover Operations (Form P-4) for each of the above captioned wells and two (2) copies of the Well Completion or Recompletion Report (Form P-7) for TBUS G-24. Very truly yours, R. Callender District Drlg. Supt. sk Encl. (8) cc: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Co. Phillips Petroluem Co. Skelty Oil Co. Standard Oil Co. USGS-Rodney Smith Pedro Denton-G-24 only Form ~o, P--4 REV, 3- I-?0 STATE OF ALASKA SuBMrr n~ ~u?ucAr~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. NAME OF OP~%ATOR UNION Oil, COMPANY OF CALIF. 3. ADDRESS OF O~R, ATO1R P~ O. Box 6247, Anchorage, Alaska 99502 4 LOCATION OF WELL Conductor #5, Leg #3, Grayling Platform, 1810'N & 1408'W, from the SE corner. Section 29: T9N, R13W, S. M. APl NIJAiERICAL CODE 50-133-20286 ~ L~SE DESiG~A~ON AND S~IAL NO. ADL-17594 IF INDIA],~ ALO*F-I-EE O~ TRIBE NAME ~,~ rAr~ oR LEAS'~ ,~E Trading Bay Unit 9 WELL NO State G-24 (14-32) 10 FIF~L,D AND POf)L. OR '~VILDCAT McArthur River Field n sEC, T.. R. ~ mO~O~ Hou~ Section 32: T9N, R13W, S. M. PEP.MIT NO 76-32 13. REPORT TOTAL DEl'TH AT E, ND OF MON'i'H. CI-LA~NGES IN HOLE SIZE, CASING AND CEIVIE. NTING JOBS INCLI;DING DEPTH SET ~ VOL~ USED. P~OP~TIONS, ~TS ~ ~SULTS FISHING JO~ JL~K ~ HOLE AND SIDE-~.ACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~. HO~ ~!TIONS 26 5/1/76 9105'TD 27 5/2/76 9515'TD 28 5/3/76 9775'TD 29 5/4/76 9944'TD (Footage 300') TIH w/ bit #27 on BHA #16. Drilled from 8805' to 9048', Dropped survey & Pooh. All bits ran prior to this depth are mill tooth bits type (1-1, 1-2 & 1-3). Encountered top of "G" Zone @ 8945'DPM. PU 12 1/4" Smith 2JS insert bit #28 type (5-1-5) on BHA #16. RIH & drilled from 9048'-9105'. Survey: 9006' 21 1/4© S20E (Footage 410') Continued drilling 12 1/4" hole from 9105' to 9515'. (467'-29 hrs.-16.1'/hr.) (Footage 260') Drilled 12 1/4" directional hole w/ bit #28, Smith 2JS (Type 5-1-5) on BHA #16 to 9650'. (Total run 602'-37 hrs.- 16.3'/hr.). Dropped survey & Pooh. Survey 20°S23°E. Hole dropped 1 1/2© in angle & turned 3© left in 600'. Ran bit #29 Smith 2JS (Type 5-1-5) on BHA #17 (slight build assy.) Hole cond, good, Drilled 12 1/4" hole from 9650' to 9775'. Survey: 9608' 20© S 23E (Footage 169') Drill from 9775' to 9873' w/ insert bit #29. Bit torqueing (223'-13 hrs.) Dropped survey. Pooh. Bit ok w/ some broken teeth, Trip in hole w/ mill tooth bit #30 on BHA #18. Drilled from 9873' to 9944' w/ high torque conditions (71'-4 1/2 hrs.) Pooh. Bit worn & out of gauge. 14. I hereby c~rt~y that the £o~egoj~j is ~ ~r?.e and COI'Te~ mst. ..... Sup:,.__:__ NOTE--Report on this fora is required for each calendar ~nth~ regardless of th~ status of oDerations, and must ~ filed in duplicate with the oil and gas conservation commiffee bythe 15~ of the suec~diflg mon~, u~le~ otherwise d~r~cted. TBUS G-24 (i4-32) MONTHLY REPORT -2- June 10, 1976 3o 5/5/76 31 5/6/76 32 5/?/?6 33 5/8/?6 34 5/9/76 35 5/10/76 10,106'TD 10,299'TD 10,400'TD 10,400'TD 10,400'TD 10,400'TD 10,298'ETD FC Survey: 9831 ' 20° S 23E (Footage 162') TIH w/ insert bit #31 (Type 5-1-5) on BHA #18. Reamed undergauge hole from 9884' to TD @ 9944'. Drilled 12 1/4" hole from 9944' to 10,106'. (162'-21 hrs.-7.71'/hr.) (Footage 193') Continued drilling 12 1/4" hole w/ insert bit #31. on BHA ~[18 from 10,106'-10,190' (Total run 246'-27 hrs.-9.11'/hr.) Dropped survey & Pooh. (Bit worn 1/4" out of gauge-stab, worn 1/2" out of gauge & skirt on junk sub worn off). Changed out stab. Ran insert bit ~32 (Type 5-1-5) on BHA #17. _.~eamed underguaged hole from 9944' to TD @ 10,190'. Drilled 12 1/4" hole from 10,190'- 10,299'. Very abrasive drilling-high torque conditions. Hole cond. good. Survey: 10,148' 21° S 25E (Footage 101') Drilled 12 1/4" directional hole w/ insert bit #32 on BHA #17 from 10,299'-10,400'. (Total run 210'-14 1/2 hrs.- 14.5'/hr.). Hoel abrasive through Hemlock w/ high torque cond- itions. Circ. btms. up. Made wiper trip to 13 3/8" csg. shoe. Pooh for logging. RU Schl. Schl. checked TD @ 10,392'WLM- 10,400'DPM. Ran Sperry Sun Gyro-Survey from TD to surface. (Footage 0') Ran Dual Laterolog, DIL, BHC-Sonic & CNL-FDC-GR Logs from TD to 13 3/8" csg. shoe. (Note: Hole took fluid @ 1 bbl./hr, for 31 hrs. while logging). (Footage 0') RD Schl. J~.IH w/ 12 1/4" bit to 10,400'TD. Circ. btms. up. Pooh-hole cond. excellent. RU to run 9 5/8" csg. Note: BHL~G__yro Survey: 10,400'TMD-9819.24'TVD-3068' closure. 2793.73'S & 1266.79'E of surface location. (approx. 110' right of Drillers Magnet Survey) BHL-Drillers Magnetic Survey: 10,358'TMD (inst.) 9777.57'TVD-3050' closure 2742.09'S & 1370.45'E of surface location. (Footage 0') Ran 258' its. of 9 5/8" 47# N-80, P-110 & USS-95 Buttress Csg. w/ centralizers & depth orientation markers to 10,388'. FC @ 10,298'. Pumped 200 cu. ft. of SAPP wtr. followed by 200 cu. ft. fresh wtr. Mixed & pumped 1200 sx. of Class "G" cmt. w/ 0.75% D-31 & 0.3% D-19. Bumped plug w/ 2500 psi. Floats held pk. CIP @ 6:30 am, 5/10/76. PU BOPE & landed 9 5/8" csg. on CIW slip type hgr. Installed CIW 12" 3000# X TBUS G-24 (14-32) MONTHLY REPORT June 10,1976 36 5/11/76 37 5/12/76 38 5/13/76 39 5/14/76 40 5/15/76 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC 10" 5000# tbg. spool. PU 8 1/2" bit & 9 5/8" csg. to FC @ 10,298'. Installed BOPE & tested to UOCO specs. csg. scraper on 6 1/4" DC. CO 9 5/8" Circ. btms. up. Pooh. (Footage 0') Pooh w/bit & scraper. Laid dwn. 5" HWDP. RU DA. DA tagged ETD @ 10,279'DIL (FC @ 10,298', csg. meas. was tagged @ 10,290'DPM). Ran GR-CBL-VDL Log from 10',279'-7800'. Had good to excellent bonding except from 9840'-10,060' where bonding was fair to medium. RIH w/ 4" sqz. gun &perf. from 9960'-9962' 04 hpf for zone isolation sqz. between Hemlock Benches #3 & #4. Ran & set Baker 9 5/8" cmt. ret. @9900'. RIH w/ stab-in stinger on 5"DP. (Footage 0') RIH w/ stab-in stinger on 5" DP. Stabbed into cmt. ret. @9900'.. Broke dwn. perfs, from 9960'-9962' (top of Bench #4) w/ 3800 psi-0.90 psi/ft, gradient & pumped in @ 18 cfm w/ 3000 psi. Sqz'd. perfs, from 9960'-9962' for zone isolation between Hemlock Benches #3 & #4 w/ 150 sx. of Class "G" cmt. w/ 0.75%D-31, 0.3% D-19 & 10% sd. to a final pumping press, of 5500 psi & standing press, of 5000 psi (1.03 psi/ft, gradient). Slurry wt. ll9#/cu, ft. of cmt, contaminated mud. Pooh w/ stab-in stinger. .RIH w/ 9 5/8" Baker cmt. ret. picker to cmt. ret. @9900'. Unable to latch spear into ret. Pooh. RIH w/ 8 1/2" bit. Drilled on cmt. ret. @9900' for 5 1/2 hrs. Bit locked. Pooh. (Footage 0') Tripped for bit. Drilled out cmt. ret. @9900' & cmt. to 9972'. RIH to 10,291'. Circ. & cond. mud. Pooh. RU DA. Had electrical failure on control panels in logging unit. t~epaired same. Ran GR-CBL-VDL Log from 10,279'-9200'DIL. Had excellent bonding (100%) from 9350'-10,279'. Perf. Hemlock Bench #6 from 10,218'- 10,240' w/ 4" csg. gun @ 3 hpf. (120° phasing). RD DA. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper. (Footage 0') RIH w/ 8 1/2" bit & 9 5/8" csg. scraper to 10,291'. Circ. well clean. Pooh. RU DA. lq_an WL gauge ring & junk basket to 10,280'. IRan & set Baker 9 5/8" X 4 3/4" perm. pkr. #1 @ 10,195' w/ tbg. tail @ 10,210'. Ran & set Baker 9 5/8" X 4 3/4" perm. pkr. #2 @ 9940' w/ tbg. tail @ 9952'. iR. an & set Baker 9 5/8" X 6" perm. pkr. #3 @ 9622'. Changed out pipe rams & RU to run 4 1/2" tbg. (Footage 0') Ran 4 1/2" 12.60# N-80 Buttress tbg. w/ side pocket gas lift mandrels as programed. Stabbed into perm. pkr. @ 9622' & tested pkr. to 450 psi. Spaced out tbg. PU out of perm. pkr. & displ, mud w/ FIW. Landed tbg. installed BPV. Removed B©PE. Installed & tested x-mas tree-ok. Placed well on gas lift to production test Hemlock Bench #6 perfs, from 10,218'-10,240'. Gas lift out FIW in tbg. & annulus. Laid dwn. 5" DP. TBUS G-24 (14-32) MONTHLY' REPORT -4- June 10, 1976 41 5/16/76 42 5/17/76 43 5/18/76 5/19/76 5/2O/76 5/21/76 5/22/76 5/23/76 10,400'TD 10,298'ETD FC 10,400'TD 10,298 'ETD FC 10,400'TD 10,298'ETD FC. 10,400'TD 10,298'ETD 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC (Footage 0') Production tested Hemlock Bench #6 perfs. Production Test - 1-2 hrs. Gross Net Cut Tbg. Press. C_sg. Press. 864' ~' 454 47-Y~ 200 860 (Footage 0') Making rig turnaround for TBUS G-12 Rd. WO to Leg R.m. 02 while production testing TBUS G-24. Production Test: Gross Net Cut Tbg.Press. ~sg'Press' 120 70--6- 3T.. 170 800 (Footage 0') Continued making rig turnaround for TBUS G-12 Rd. WO. SI TBUS G-24 @ 3:00 pm, 5/18/76 for Btm. Hole Press. Survey. Released rig from TBUS G-24 @ 12:00 Midnite, 5/18/76. (Footage 0') 'SI for Btm. Hole Press. Survey. Pulled survey @ 6:00 pm, 5/19/76. Stab. well for acid treatment. (Footage 0') RU Dowell to Claylok treat Hemlock Bench #6. Bull- headed 2000 gal. of 15% HCL acid dwn. tbg. to tbg. tail. Returned well to gas lift & gas lifted out HCL acid. Pumped 1000 gal.. of 2% KCL wtr. folloWed by 2000 gal. of Dowell Claylok treatment (2% F-75) & 1000 gal. of 2% KCL wtr. dwn. tbg. Initial pumping rate-2 BPM @ 2000 psi. With 2% KCL wtr. @ formation-rate lowered to 3/4 BPM @ 2500 psi. With Dowell Claylok @ formation- pumping rate continued to lower to 1/4 BPM @ 3000 psi. With 1500 gal. of Dowell clay displaced-pumping ceased @ 3000 psi & press. held 15 mins. 1R~eturned well to gas lift & gas lifted out remain- ing Claylok & KCL wtr. in tbg. (Footage 0') Gas lifted well on production test following CJaylok stab. treatment. Production Test: Gross Net Cut Form. Gas GOR GLR Gray. TP CP 216 62 71% 19 300 11,755 30° 140 650 RU DA. Differentially reperf. Hemlock Bench #6 w/ 2 1/2" Jumbo Jet @ 2 hpf. Placed well on gas lift production test. Gross Net Cut Form. Gas 360 173 52% 161 GOR GLR Gray. TP CP 931 6785 30° 200 820 TBUS G-24 (14-32) MONTHLY REPORT -5- June 10, 1976 5/24/76 5/25/76 5/26/76 5/27/76 5/28/76 5/29/76 5/3o/76 44 5/31/76 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC Continued production testing Bench #6 & prep. to acidize. (Footage 0') Production tested Hemlock Bench #6 @ an average rate of 360 bbls/day w/ 52% cut. RU Dowell. Pumped acid as follows: Quantity~ Initial Pumping Rate 2000 gal. of 2 1/2% HCL @ 1.0 BPM w/ 2500 psi 2000 gal. of' 12-10 HCL-HF @ 0.6 BPM w/ 2600 psi 1000 gal. of 2 1/2% HCL @ 1.5 BPM w/ 2600 psi Final pumping rate - 1.5 BPM w/ 2000 psi. Placed well on gas lift for production test: Gross Net Cut Form. Gas GOR 60----'6-- 28--~- 5~'~~ 45 160 GLR Gray. TP CP 4978 23 5° i~0 7~'0 (Footage 0') Production tested Hemlock Bench #6. Gross Net Cut Form. Gas GOR GLR Gray. 576 28--'~' ~i%--- --- 4795 31.00 TP CP 160 750 (Footage 0') Production Testing Hemlock Bench #6. Gross Net Cut Form. Gas GOR GLR Gray. TP CP 576 28---8 50--~ 197 694 546---~- 30° 2~ ~ (Footage 0') Production testing well. (Footage 0') Skidded rig over well TBUS G-24. RU DA & differentially perf. Hemlock Bench #5 while producing well @ 200 BPD w/ 3 1/2" carrier gun @ 3 hpf as follow~: · B enc h Int er v al F oota g e #5 10,156'-10,186' 30' #5 10,~90!-I0,144' 54' (Footage 0') Production tested TBUS G-24 w/ Hemlock Benches #5 & #6 commingled while running profile log on TBUS G-22 & activating rig. TBUS G-24 (14-32) MONTHLY REPORT -6- June 10, 1976 45 6/1/76 , 46 6/2/76 47 6/3/76 48 6/4/76 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC. 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC (Footage 0') Attempted to fish out WL running tools. Rec. WL jars & sinker bar. Unable to rec. running tool. WL plug seated in nipple @ 10~211'. Put well on prod. test. Plug holding. Production tested Hemlock Ben'ch #5. Gross Net Cut Form. Gas GOR GLR Gray. TP CP 2544 2508 1,4% .... 1063 '33.8° 175 880 RIH w/ press, bombs for 24 hrs. build-up survey. (Footage 0') RIH w/ WLpress. bombs. SI well @4:00 am, 6/2/76 for 24 hr. Btm. Hole Press. Build-up Survey on Hemlock Bench #5. (Footage 0') Completed running Btm. Hole Press. Build-up Survey on Hemlock Bench #5. Final SI press, was 3316 psi. I~D slickline unit. RU DA. Differentially perf. Hemlock Bench #4 w/ 3 1/2" carrier gun @ 3 hpf from 9965'-10,052'. !~.D DA. Placed well on prod. test, (Footage 0') Production tested Hemlock Benches #4 & #5 while per- forming WL work on TBUS G-12 ]RD (WO). Released rig @ 12:00 Midnite, 6/4/76 to well TBUS G-25. Gross Net Cut Form. Gas GOR GLR Gray. TP CP 3372 3311 1.8% 573 173 1283 33.6° 140 1000 FINAL REPORT SUBMIT IN DUPLICATE* STATE OF ALASKA <See other im st ructions on OIL AND GAS CONSERVATION COht~MITTEE reve,'~ i i ,i i i I iii WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: On,WELL [] .aS WELL [-~ DRY ~-~ Other' b. TYPE OF COMPLETION: w EI,I, OVER E N BACK P, ESVR. Other 8. UNIT.FAtI1VI OR LEASE 2..~A~I~ o~ o~ATO~ Trading Bay Unit UNION OIL COMPANY OF CALIF. ~. w~,L~o. ~. A~D~ O~ O~,ATO~ State G-24 (14-32) P. O. Box 6247, Anchorage~ Alaska 99502 4. LOC^~OS oF W£LL (Report location clearly and in accordance with any State requirements)* At,~r~c~ Conductor 5, Leg 3, Grayling Platform, 1810'N, 1408'W from SE corner. Section 29: TqN, R13W, S. M. At top prod. Interval reported below2588,S & l161'E of surface Loc. or 775'S & 247'E of NE corner Section 32: T9N, R13W, S M At total depth ' ' ' 2802'S & 1251'E of surface Loc. or 992'S & 157,B from NE 12. r~IT~o. corner. Section 32: TqN, R13W, S.M. ¢~ 76-32 4/6/76 5/7/75 6/4/76 RT 99' above MSL ! I~OW 1VI. A~Y* ROTARY TOOLS CABLE TOOLS 10,400'TMD/9819'~VD 10,298'TMD/97~4'TVD 0-10,400' 22. PRODUCING INTERVAL(S), OF THIS COMPLETION--TOP, BOTTOM, NAME (1VID AND TVD)* 23. ~,VAS DIRECTIONAL ! SURVEY ]~/iADE Hemlock Zone: Top - 9742'TMD 9209.'TVD Btm.- 10,270'TMD 9708'TVD j Yes -~. API N~CAL CODE 50-133-20286 LEASE DESIGNATION A2qD SERLa. L NO. ADL-17594 7. IF INDIA.N, .AI.J~O~ OR T]glBE NAME 10. FIELD A2q'D POOL, OR WILDCAT McArthur River-Hemlock Section 32: T9N, R13W,SM 24. TYPE ELI~CTRIC AND OTHER LOGS RUN DuM Laterolog, DIL., B_HC-Sonict, CNL-FDC-GR~ GR-CBL-VDL . 25. CASING RECORD (Report all strings set in well) 26" 1/2" Wall t~ickne~s 359' 20" ,94# / H-401 82q'i 13 3/8" 61 & 68# 1. K-551 5115, i ..... 9 5/8" I 47# I m-s01 0,sa8, 2~. LIN~ m~COlm P-110 USS-95 28. PERFORATIONS OPEN TO PRODUC~ON (Interval, size and number) Bench #6-10,218-10,240/22' @ 3 hpf w/ 4" csg. gun. Bench #5-10,156-10,186/30' @ 3 hpf w/ 3 1/8 csg. gun. *Cont. on back. 30. Pi%ODUCTION HOLE SIZE [ C~X{LNTING RECOlqD i A~WfOUNT PULLET) 26" Predriven to 350' None 23" cm,'ct tn. $~3_rface-!478 cf ~ None ]7 ]/2"[Cmf'd to ~f~.~-5559 cf ] None 12 1/4"IC~t'd w/ 1380 cf ] Nonv SCR~ (MD) SIZE 'DEP~ SET (MD) ] PACKER SET (MD) i · 4 1/2" 9690' 9622' 29. ACID, SHOT. F~CT'U~, C~55E:NT SQUeeZE, ~C. D~-I INT~V~ (~D) ] A~fOUN'r P~D KIND O,F I 11 II 9960~-996~~ 1~ ~ ~/ ~0 ! ~ ~000 BM. o~ ~-~0 ~-~ DATE FIRST PI~ODUCTION Bench #6-5/17/76 DATE OF TEST. }lOLl'RS TESTED '[CHOKE SIZE [PROD'N FO'l% '! t 1 6/4/76 24 l PLOW, TUBING ~A~I.NG PI:UgSSURE gALC~dI.d[~ OII..,~BBL. GAS~C'~. m-aoua ~ [ r-rmss. 140 , 1000 ,, .! > )' 3311 I 574 31. DISPOSITION OF 0A8 (Sold, used for Juel, vented, etc. 32. LIST OF ATTACHMENTS PRODUCTION MEiIiO.D (Flowh~g, gas lift, pumping--size and type of pump) Gas Lift OIL--~BBL. G.~S--1V~CF. [WELL STATUS (Producing or [ ~ut-in) ! 'Producin~ WATER--~BBL. [ GAS-OIL 1~1'IO 574 [ 61 i 173 WA~BBL. ~ OIL GRAVITY-A~I (COtt,R.) I61 ] 33.6° TEST WITNESSED BY Jim Watson '- 33. I hereb~ t the forJ~oing and attached information is complete and correct as determined from all;available records t'~2l'~l._,/ D~st Drl sIs~/, A~. rIT,~E ' · . g.. Supt. ~,rz 6/10/76 .. v~/~ 'R.-C-aIFe-n-dei~- , · (See Instructions and Spaces I:or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end fog or~ all types of lanJs and leases irt Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise showr'~) for depth measure- ments given in alher spaces on this form and in ar~y attachmer~ts Items 20, and 22:: If this well is completed for separ~tc:, prcct'~ction from more th;~n one interval zone (multiple completion), so state ~n item 20, and in item 22 show the p~cJuci~,g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interv~I ref~arted ir~ item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce:.t, show- ing the acktitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~:l. (See instruction for items 20 and 22 above). 35. G ~OLOG IC WATY.2/t AND MUD ~.AM~: , , , ~28 Cont. Perforations Open to Production. ~,~AS, O~t ~V~X. ~'~ Bench g5 - 10,090-10,144/54' 0 3 hpf w/ 3 1/8" gun. Bench g4 - 9,965-10,052~/ 87~ ~ 3hpf w/ 3 1/8" gun. , , ~. ('OI~ DATA. A'I'FACII B~IEF D~C~PI~O~S O? L1T}IOLOGY. POnOSI'TY. FII~C~RB. AP?~T ANI> I~'FE{?T~D ~IIOWS OF O1[~. G~S O11 .... , , ,, , ...... SH L-S;ZT A PAGrz IHO. £;;.~ASE TRADING BAY UNIT ~ :_WELL NO. G-24 yIBLD_ M_c:_Ar t h_~_r .. R i ver LOCATION_ Conductor {5, Leg~. ~3~Gr~vlinQ TYPE UN~ .... ~%~_]~20 UE _~ Platform~ 1810'N & 14~8"W from the SE D~LL ~IP~ DESCriPTiON, 5"..19,5~ corner. Section 29: TgN, R13W, S, M. ELFWATiONS: V/ATEII DE~I'iI PEi~MIT NO.. 76-32 SER!.~ NO.ADL-17594 ~T. TO OCEAN FLOOR T.D. ]0,400' " T.V.D. 98]9' B.T. TO MLLW DEVIATION (BHL~ Section 32: T9N, R}3W, S.M. R.T. Y~R[LL DECK COMPANY ENG. D~EER Hess/Wester/W~on _ __ R.T. ro PRO~U¢'~LQN ~~_~- _- ~ ~ ~ CA~!NG ~ TUBING EECO~ (Dist. Drlg. Supt.) SIZL WEIGHT THREAD GRADE f DEPTH REMARKS 26" ]/2" Wa Il' ' ~ 359; Dmiven. 20"' 94~ Buttress H-40 829' Cmt'd to surface w/ ]478 cu. ft. Class "G".cmt. ]3 3/8".6l & 68~ Buttress g:~ ~5]]5' [Cmt'd to surface w/ 5559 cu. ft. Class "G" cmt. 9 5/8" 47~ _Buttre~ [[ss-qs. N-R~a.3RR' ~ ~ ~ I~R0 n,,_ ft of..~la~ "G" nmt j P]iio--..-]--' -' C _ __, ............. ._. l PERFORATING RECORD SPUD DATE 4/6/76 COMP. DATE 6/4/76 COi',iTRACTOR_~_0/ik~_ Drlg~ Co.. _RIG NO. 54 5/14/76 5/11/76 5/30/76 _ 5__/30/76 6/3/76 -_ 10,218'.-1 0.240') 9,960'-1 0'060'! 10,156'-10,i86'i _ !].0,090'-1 0,144' 9,965'-10,052't .,,f Production !3 hpf w/ 4" carrier gun. Bench #6. Squ~aTe !7~n~ i~olatinn__ Rmnch ~4. ! F):?q8 'FC II " Production g hnf w/ 3 1/8" carrier gun.. Bench. #5. " _Production _~ h~f w'/ .3 172" carrier gun. Bench #5 '" Production . h~f w'/ 3 1~2" carrier oun. Bench #4. DATE 6L4/76 t INITIAL P.,OD [iq, i IODI I ' ( NET OILt CUT I c, Rxv. t331] I].8 133.6 ]73 IZITERVAL i t 1 000 '140 · , V/E L_L_I-LE~_$~SJ~i D~L Y TYPE: Cameron 573 CASING HEAD' .Cameron "WF" 20" 2000#WP X 20" slip on weld. CASING HANGER: slip & seal assy. CA 12" X 9 5/8" OD, "WF" 20" 2000# X 12" 3000# w/2 2" 5000# Std. outlets. CASING SPOOL: DCB 12" 3000# WP X.10" 5000# WP w/ 2 2" 5000# Std. outlets. TUBING HEAD: DCB FBB w/ 7"0D ext. seal neck + 1 1/2" NPT prep. control line. TUBING HANGER: 10" 5000# WF + 4 1/2"0D EUE top w/ "H" BPV thd. alloy steel TUBING tIEAD TOP' 10" 5000# WP. MASTZR VALVES: Cameron "F" 9ate 2 X 2 1/16" 2000#'WP D/F. ~ .. CHR!,STMASTRI~]ET©P C'ONN.:~ 4 1/2" EUE 8rd. STA~ SEC./ COUNTY JETS - 32nds SERIAL Reg. R or RO NO. BiT RECORD RIG PUMP NO. PUMP NO. ~UD TYPE COLLARS: OD X ID X LENGTH ~X ~X ,TOOL JOINT. MO. / DAY / YR. TOTAL DEPTH ./ / Page, / _ of,,, : T.P.-DRILLERS EI/¢/~ ~ , WATER SOURCF FUEL $OURCF DEPTH OUT PUMP NO1 PUMP NO. MUD PROPERTIES Dull. Cond. 1/4 1/8 35'739 Triplicate Form GET ~IN YOUR DRILLING Form No. SES 51 (Rev. 9/631 FILE NO. BIT RECORD SALESMAN: Page CONTRACTOR ~o,,,,,,,,,,¥ L,L 0 e...o_~ '--i-- "~ g,. :S s~c./ T'$HIP/RANGF RIG NO._ _..~. ~ fi£'r~ WELL NO~ ~ '" '~ COUNTY SERIAL NO. JETS - 32nds Reg. R or RO RIG MAKE RIG SIZE DEPTH OUT COLLARS: OD X ID X LENGTH DRILL PIPL~/~ TOOL JOINT. SPUD UNDER SURFACE UNDER INTER. TOTAL DEPTH PUMP NO 1 PUMP NO. MUD PROPERTIES Dull. Cond. 8_! ~7 53 Triplicate Form GET ~IN YOUR DRILLING Form No. SES 51 (Rev. 9/65) UNIg'I OIL CCt'P/ 'IY OF CALIFOF ,IIA I ECOt LEASE TRADING BAY UNIT STATE I'~LL NO, G-24 FIELD McArthur River Field DATE i 4/6/76 2 4/7/76 3 4/8/76 4 4/9/76 5- -4/10/76 6 4/11/76 597'TD 855'TD 855'TD 1200'TD 1665'TD 1960'TD DETAILS OF OPERATIONS, DESCRIPTIOrlS ~. RESULTS (Footage 597') Completed rig activation. Commenced operations on TBUS G-24 @ 12:01 am, 4/6/76. Ran 17 1/2" bit on BHA gl & CO 26" drive pipe to 369'. Ran Gyro Survey-btm. of 26" Conductor out 1.66' S23°E. Ran 24" OD watermelon mill on BHA #2 & dressed out 26" drive pipe to 369'. Ran 17 1/2" bit on BHA #3. Drilled 17 1/2" hole from' 369'-597'. Surveys: 92' 187 3O8 369 434 527 616 1/4° S26E 0 0 1/2° S24E o 1/2 S59W 1/4° S21W 1/2° S34W 1/4° S66W (Footage 258') Drilled 17 1/2" hole from 597' to TD @ 855'. Pooh. PU 23" hole opener in tandem w/ 17 1/2" bit. Opened 17 1/2" hole to 23" from 369' to TD @ 855'. Made cond. trip. Circ. & cond. hole to run 20" csg. Surveys: 638' 1/4° S66W 730' 1/2° S81W 855' 1/2° S45W (Footage 0') Pooh. RU & ran 19 jts. of 20" 94# H-40 Buttress Csg. Landed csg. on 24 3/4" X 20" flow thru hgr. w/ 20" guide shoe @ 829' & 20" stab-in FC @ 782'. Circ. hole clean. Pumped 200 cu. ft. of caustic wtr. for preflush. Mixed & pumped 650 sx. of Class "G" cmt. w/ 2 1/4% pr'ehydrated gel mixing wtr. to a 98#/cu. ft. slurry. Had good cmt. returns @ surface. Followed gel cmt. w/ 200 sx. of Class "G" w/ 2% CaCI_ to a ll7#/cu, ft. slurry. Displ. cmt. to FC 782' w/ mud. Pulled~out of stab-in FC. Float held ok. Pooh w/ 5" DP. Removed 26" riser. Installed 20" SOW X 20" 2000# csg. hd. (Footage 345') Installed 20" SOW X 20" 2000# csg, hd., 20" riser & 20" 2000# hydril. RIH w/ 17 1/2" bit on slick DC to FC @ 782'. Tested 20" csg. to 500 psi. Drilled out 20" FC & cmt. to 800'. Re- tested 20" csg. to 500 psi. Drilled out cmt. & 20" csg. shoe @ 839'. CO rat hole to 855' & drill 17 1/2" vertical hole from 855'-915'. Displ. Dril-S WO fluid w/ gel-Inlet wtr. mud. Tripped for BHA change. RIH w/ 17 1/2" bit & 17 1/2" stab. Drilled & surveyed 17 1/2" vertical h01e from 915' to 1200'. (Footage 465') Drilled vertical hole from 1200' to KOP @ 1500'. Circ hole clean. Pooh. RIH w/ 17 1/2" bit on turbodrill to 1500'. Oriented turbodrill @ KOP of 1500'. Turbodrilled 17 1/2" hole & surveyed w/ Gyro from 1500'-1665'. SurveyS: 1478' 1/4° S08W 1547' 1 1/2° S37E 1577' 2° S48E 1638' 3° S49E (Footage 295') Turbodrilled 17 1/2" hole & surveyed w/ Gyro £rom 1665' to 1751'. Unable to build angle w/ turbodrill as desired. Hole direction lined up ok. Made bit trip @ 1751' & reran turbodrill. PAGE I,b, LEASE TRADING BAY UNIT ST'ATE UNI( i OIL CCFPN,N OF CALIFOPCIIA I,, ]LL IiECORD I'ELL ~'~0, G-24 ,~' FIELD McArthur River Field DATE ? 4/12/76 8 4/13/76 9 4/14/76 104/15/76 11 4/15/76 12 4/16/76 3020'TD 3660'TD 4353'TD 4663'TD 4914'TD 5116'TD DETAILS OF OPERATIONS, DESCRIPTIOIIS & RESULTS Turbodrilled 17 1/2" hole & Gyro Surveyed from 1751' to TD @ 1960'. Hole angle build up ok to run cony. angle building assy. Hole direction falling off to the right, Pooh w/ turbodrill. Surveys: 1702' 4 3/4° S51E 1764' 5 3/4° S59E 1827' 6 1/4° S52E 1900' 9° S44E (Footage 1060') RIH w/ 17 1/2" angle building assy. Drilled & surveyed 17 1/2" directional hole from 1960' to 2615'. Pooh for BHA change. RIH w/ 17 1/2" tandem stab. locked assy. Drilled & surveyed 17 1/2" directional hole from 2615' to 2961'. Had washou Pulled & found cracked pin 192' below rotary table. RIH & continued drilling w/ locked assy. from 2961' to 3020'. Surveys: _. 2054' 11 /4° S50E 2178' 14° S41E 2331" 17°' S40E o 2517' 21 S40E 2675' 23 1/2° S39E 2859' 24 1/2° S38E (Footage 640') Drilled & surveyed 17 1/2" directional hole from 3020' to 3266'. Twisted off pin connection @ 284' (new pipe). Left 2982' of fish in hole. RIH w/ OS & latched onto fish @ 284'. Pooh. Rec. total fish. Laid dwn. all Grade E pipe for inspection & PU S-135 DP. RIH w/ 17 1/2" bit on locked tandem stab. BHA. Drilled & surveyed 17 1/2"-hole from 3266' to 3660'. Surveys: 3393' 25 1/4° S38E 3740' 24 1/2° S39E (Footage 693') Drilled & surveyed 17 1/2" directional hole from 3660' to 4353' w/ bit trip @ 4043'. Surveys: 3740' 24 1/2° S39E 3960' ' 23 1/'4° S36E 4311' 22° S37E (Footage 310') Drilled & surveyed 17 1/2" directional hole from 4353' to 4663' w/ bit trip @ 4553'. Surveis: 4511' 20 1/2° S36E 4657' 19° S36E (Footage 251') Drilled 17 1/2" directional hole from 4663'-4914' w/ bit trip @ 4700'. (Footage 202') Drilled & surveyed 17 1/2" directional hole from 4914' to 5116' w/ bit trip @ 4950'. Hole failed to turn right as anticipated. Unable to run turbodrill for right turn below 4400' due to high torque & abrasive formation. Hole turning left-will UNIal 0IL C[IqPP¢IY OF CALIFORrlIA ¥,£LL I:ECORD LEASE TRADING BAY UNIT STATE I'~LL l']O, G-24 " FIELD McArthur River Field BATE 13 4/17/76 14 4/19/76 15 4/20/76 16 4/21/76 17 4/22/76 5116'TD 5116'TD 5218'TD 5846'TD 6093'TD DETAILS OF OPERATIONS, DESCRIPTIOHS g RESULTS require tool runs below 13 3/8" csg. Made conditioning trip @ 5116' to run 13 3/8" csg. Surveys: 4915' 22° S40E 5080' 20° S39E (Footage 0') RU & ran 127 jts. of 13 3/8" csg. Set csg. w/ shoe @ 5115', FC. @ 5030' & DV tool @ 2611'. Circ. hole clean. Cmt'd. btm. stage as follows: Pumped 200 cu. ft. SAPP wtr., 200 cu. ft. FIW & 2443 cu. ft. slurry Class "G" cmt. w/ 2.5% prehydrated gel mixed @ 98#/cu. ft. followed by 230 cu. ft. Class "G" neat. Bumped plug w/ 2000 psi-held ok. CIP @ 4:55 pm, 4/18/76. Opened DV tool @ 2611' w/ 1200 psi @ 5:20 pm. Circ. out approx. 330 cu. ft. of excess cmt. from above DV tool. Cmt'd. top stage as follows: Pumped 200 cu. ft. SAPP watr., 200 cu. ft. FIW w/ 2656 cu. ft. slurry Class "G" cm't. w/ 2.5% prehydrated gel mixed @ 98#/cu. ft. followed by 230 cu. ft. Class "G" neat. Bumped plug w/ 1600 psi & closed DV tool ok. Press. 13 3/8" csg. to 2500 psi-ok Had approx. 540 cu. ft. excess cmt. to surface. CIP @ 9:50 pm, 4/18/76. Washed dwn., removed riser & 20" hydril. Hung off 13 3/8" csg. (Footage 0') Cut 13 3/8" csg. Removed 20" riser & hydril. In- stalled 20" 2000# X 12" 3000# csg. hd. spool & tested seal to 2000#. Installed 13 3/8" 3000# BOPE & riser. Tested blind rams to 3000 psi. RIH w/ 12 1/4" bit on slick DC to 13 3/8" DV collar @ 2611'. Tested hydril to 1500 psi & upper & lower pipe rams to 3000 psi, Tested kill & choke lines to 3000 psi. All tests witnessed by 'State DOG. (Footage 102') Drilled out 13 3/8" DV collar @ 2611'. Tested 13 3/8" csg. to 2500 psi. Drilled out 13 3/8" FC @ 5030' & cmt. to 5050'. Tested 13 3/8" csg. to 3000 psi. Drilled out cmt. & float shoe @ 5115'. Drilled 12 1/4" hole from 5116'-5126'. Tested csg. seat to 0.650 psi/ft, gradient. Drilled 12 1/4" hole from 5126'-5218'. Pooh. Laid dwn. 5" S-135 DP. RU Sperry Sun, Ran Gyro survey from 5080' to surface @ 100' stations. PU 12 1/4" stab. BHA. RIH picking up 5" Grade E DP. (Made up, broke, redoped & remade each connection). (Footage 628') RIH. PU 5" Grade E DP. (made up, broke & re- made each connection). Reamed from 5127'-5218'. Drilled & surveyed 12 1/4" hole from 5218'-5846'. Tripped for bit. Surveys: 5080' 20° S39E 5293' 18 1/2° S38E 5479' 20 1/2° S38E 5667' 23° S34E 5810' 24 1/2° S34E (Footage 247') Tripped for bit @ 5846'. Drilled 12 1/4" hole from 5846'-6008'. Hole not turning right as anticipated. (Note: Gyro Survey showed BHL @ 4800' approximately 150' to the right (SW) of BHL plotted from magnet surveys while drilling). Pooh 0 6008'. PU turbodrill & TIH. Attempted to orient turbodrill @ 6008' w/ BJ Tele-orienter. Tool failed to function. Ran conventional WL PAGE t'.~, 7 TRADING BAY UNIT STATE UI'lIO 't OIL COHPANY OF CALIFOPCIIA J, LL i ECORD t'~LL IlO, G-24 FIELD McArthur River Field DATE 18 19 2O 21 22 23 24 4/23/V6 4/24/76 4/25/76 4/26/76 4/27/76 4/28/76 4/29/76 ETD 6117'TD 6700'TD 7208'TD 7512'TD 7975'TD 8345'TD 8543'TD DETAILS OF OPERATIONS, DESCRIPTIOI'IS & RESULTS Magnetic survey & Oriented turbodrill for right hand turn. Turbo- drilled 12 1/4" hole from 6008'-6032'. Pooh w/ turbodrill. (Footage 24') Finished Pooh w/ turbodrill. Had lost 1 cone off bit during turbodrill run. RIH w/ 12 1/4" bit #15 on BHA #14 (follow-up assy). Drilled on junk cone from 6093'-6100'. Had indication of being past junk. Pooh. Ran bit #16 & drilled from 6100'-6113'. Running on junk cone & unable to break-up cone. Pooh. Ran Bowen junk basket on BHA #15. Cored 4' from 6113'-6117', Pooh. (Footage 583') Pooh-rec. lost cone (in tact) & junk in hole + 2' of rm. core. Ran 12 1/4" bit #17 on BHA #14. Drilled from 6117'-6162'. Ran survey w/ instrument @ 6127'. Hole direction had turned from S34°E @5810'MD to S22°E @6127'MD through turbodrillrun, Drilled to 6578' & Pooh for bit change, Ran 12 1/4" bit #18 on BHA #14. Drilled 12 1/4" hole from 6578'-6700', Surveys: 6127' 21° S22E 6313' 21° S21E 6520' 22 1/2° S20E (Footage 508') Drilled 12 1/4" hole from 6700'-6807'. Pooh for bit change, Ran 12 1/4" bit #19 on locked BHA #16. Drilled 12 1/4" hole from 6807'-7208'. Pooh for bit change. Surveys: 6771' 22 1'/4° S18E 7172' 22° S18E (Footage 304') Compl. bit trip @ 7208'. Drilled from 7208'-7459' w/ bit #20 on BHA #16. Dropped survey. Pooh for bit change. TIH w/ bit #21 on BHA #16. Drilled from 7459'-7512'. Survey: 7417' 21 3/4° S18E (Footage 463') Drilled 12 1/4" hole from 7512'-7736' w/ bit #21 on BHA #16. Tripped for bit. RIH w/ bit #22 on BHA #16, Drilled 12 1/4" hole from 7736'-7975'. Pooh for bit change. (Note: Hole turning left-unable to hold w/ locked assy.) Surveys: 7693' 20 1/2° S20E 7934' 20° S21E (Footage 370') Tripped for bit change. RIH w/ bit #23 on BHA #16. Drilled 12 1/4" hole from 7975'-8345'. Elec. motor on rotary table shorted out. Pooh to repair rotary table. Replaced elec. motor on Rig #54 w/ motor from Rig #55. (Survey on bit trip-no good). (Footage 198') Repaired rotary table. RIH w/ bit #24 on BHA #16. Reamed from 8285' to 8345'. Drilled .12 1/4" hole from 8345' to 8543'. Ran WL survey. Hole direction turned to S18E. Unable PAGE th, 8 LEASE TRADING BAY UNIT ST'ATE OIL COFPANY OF CALIFOF 'IIA I'£LL I ECORD ~'~LL l'~O, G-24 FIELD McArthur River Field DATE 25 4/30/76 26 5/1/76 27 5/2/76 28 5/3/76 29 5/4/76 30 5/5/76 31 5/6/76 8805'TD 9105'TD 9515'TD 9775'TD 9944'TD 10,106'TD 10,299'TD DETAILS OF OPERATIONS, DESCRIPTIOIIS & RESULTS to drill after taking survey. Pooh. All three cones missing from bit. RIH w/ Bowen junk basket on BHA #15. Cored 4' from 8543' to 8547'. Pooh. Survey: 9608' 20° S23E (Footage 262') Pooh w/ Bowen 12 1/4" junk basket. Rec, 3 cones left in hole off bit #24 plus 2' of cored section. TIH w/ bit #25 on BHA #16. Drilled from 2500 psi to 1700 psi. Pooh looking for washout. Found washout in counter bore of bit sub. TIH w/ bit #26 on BHA #16. Drilled from 8572' to 8805'. Dropped survey & Pooh. Survey: 8763' 21 1/2° S20E · (Footage 300') TIH w/ bit #27 on BHA #16. Drilled from 8805' to 9048'. Dropped survey & Pooh, All bits ran prior to this depth are mill tooth bits type (1-1, 1-2 & 1-3). Encountered top of "G" Zone @ 8945'DPM. PU 12 1/4" Smith 2JS 'insert bit #28 type (5-1-5) on BHA #16. RIH & drilled from 9048'-9105'. Survey: 9006' 21 1/4° S20E (Footage 410') Continued drilling 12 1/4" hole from 9105' to 9515'. (467'-29 hrs.-16.1'/hr.) (Footage 260') Drilled 12 1/4" directional hole w/ bit #28, Smith 2JS (Type 5-1-5) on BHA #16 to 9650'. (Total run 602'-37 hrs.- 16.3'/hr.). Dropped survey & Pooh. Survey 20°S23°E. Hole dropped 1 1/2° in angle & turned 3° left in 600', Ran bit #29 Smith 2JS (Type 5-1-5) on BHA #17 (slight build assy.) Hole cond. good. Drilled 12 1/4" hole from 9650' to 9775'. Survey: 9608 ' 20° S 23E (Footage 169') Drill from 9775' to 9873' w/ insert bit #29. Bit torqueing (223'-13 hrs.) Dropped survey. Pooh. Bit ok w/ some broken teeth. Trip in hole w/ mill tooth bit #30 on BHA #18. Drilled from 9873' to 9944' w/ high torque conditions (71'-4 1/2 hrs.) Pooh. Bit worn & out of gauge, Survey: 9831' 20° S23E (Footage 162') TIH w/ insert bit #31 (Type 5-1-5) on BHA #18. Reamed undergauge hole from 9884' to TD @ 9944'. Drilled 12 1/4" hole from 9944' to 10,106'. (162'-21 hrs.-7.71'/hr.) (Footage 193') Continued drilling 12 1/4" hole w/ insert bit #31, on BHA #18 from 10,106'-10,190'. (Total run 246'-27 hrs.-9.11'/hr.) Dropped survey & Pooh. (Bit worn 1./4" out of gauge-stab, worn 1/2" out of gauge & skirt on junk sub worn off). Changed out stab.' PAGE LD SE TRADING BAY UNIT STATE UI,IIOH OIL CCt"P , ' OF CALIFORHIA IfCOt® I'ELL l,lO, G- 24 FIELD McArthur River Field DATE 32 5/7/76 33 5/8/76 34 5/9/?6 35 5/10/76.. 36 5/11/76 ETD 10,400'TD 10,400'TD 10,400'TD 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC DETAILS OF OPEPJ~TIONS, DESCRIPTIOIiS g RESULTS Ran insert bit #32 (Type 5-1-5) on BHA #17. Reamed underguaged hole from 9944' to TD @ 10,190'. Drilled 12 1/4" hole from 10,190'- 10,299'. Very abrasive drilling-high torque conditions. Hole cond. good. Survey: 10,148' 21° S25E (Footage 101') Drilled 12 1/4" directional hole w/ insert bit #32 on BHA #17 from 10,299'-1'0,400'. (Total run 210'-14 1/2 hrs.- 14.5'/hr.). Hole abrasive through Hemlock w/ high torque cond- itions. Circ. btms. up. Made wiper trip to 13 3/8" csg. shoe. Pooh for logging. RU Schl. Schl. checked TD @ 10,392'WLM- 10,400'DPM. Ran Sperry Sun Gyro-Survey from TD to surface. (Footage 0') Ran Dual Laterolog, DIL, BHC-Sonic & CNL-FDC-GR Logs from TD to 13 3/8" csg. shoe. (Note: Hole took fluid @ 1 bbl./hr, for 31 hrs. while logging). (Footage 0') RD Schl. RIH w/ 12 1/4" bit to 10,400'TD. Circ. btms. up. Pooh-hole cond. excellent. RU to run 9 5/8" csg. Note: BHLTGyro Survey: 10,400'TMD-9819.24'TVD-3068' closure. 2793.73'S & 1266.79'E of surface location. (approx. 110' right of Drillers Magnet Survey) BHL-Drillers Magnetic Su~r. vey: 10,358'TMD (inst.) 9777.57'TVD-3050' closure 2742.09'S & 1370.45'E of surface location. (Footage 0') Ran 258' jts. of 9 5/8" 47# N-80, P-110 & USS-95 Buttress Csg. w/ centralizers & depth orientation markers to 10,388'. FC @ 10,298'. Pumped 200 cu. ft. of SAPP wtr. followed by 200 cu. ft. fresh wtr. Mixed & pumped 1200 sx. of Class · 'IG" cmt. w/ 0.75% D-31 & 0.3% D-19. Bumped plug w/ 2500 psi. Floats held pk. CIP @ 6:30 am, 5/10/76. PU BOPE & landed 9 5/8" csg. on CIW slip type hgr. Installed CIW 12" 3000# X 10" 5000# tbg. spool. Installed BOPE & tested to UOCO specs. PU'8 1/2" bit & 9 5/8" csg. scraper on 6 1/4" DC. CO 9 5/8" csg. to FC @ 10,298'. Circ. btms. up. Pooh. (Footage 0') Pooh w/bit & scraper. Laid dwn. 5" HWDP. RU DA. DA tagged ETD @ 10,279'DIL (FC @ 10,298', csg. meas. was tagged @ 10,290'DPM). RanGR-CBL-VDL Log from 10,279'-7800'. Had good to excellent bonding except from 9840'-10,060' ~vhere bonding was fair to medium. RIHw/ 4" sqz. gun &perf. from 9960'-9962' @4 hpf for zone isolation sqz. between Hemlock Benches #3 & #4. Ran & set Baker 9 5/8" cmt. ret. @9900'. RIH w/ stab-in stinger on 5"DP. ......P^G t'b, UI'IIOI' OIL COI' AI',5' OF CALIFOf ,IIA ¥,ELL I ECOt LEASE TRADING BAY UNIT STATE I'~LL l,lO, G- 24 FIELD McArthur River Field gATE z 37 5/12/76 38 5/13/76 39 5/14/?6 40 5/1.5/7.6 41 5/16/76 42 5/17/76 ETD 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC DETAILS OF OPERATIONS, DESCRIPTIOI.IS & RESULTS (Footage 0') RIH w/ stab-in stinger on 5" DP. Stabbed into cmt. ret. @9900'.. Broke dwn. perfs, from 9960'-9962' (top of Bench #4) w/ 3800 psi-0.90 psi/ft, gradient & pumped in @ 18 cfm w/ 3000 psi. 'Sqz'd. perfs, from 9960'-9962' for zone isolation between Hemlock Benches #3 & #4 w/ 150 sx. of Class "G" cmt. w/ 0.75%D-31, 0.3% D-19 & 10% sd. to a final pumping press, of 5500 psi & standing press, of 5000 psi (1.03 psi/ft, gradient). Slurry wt. ]19#/cu. ft. of cmt. contaminated mud. Pooh w/ stab-in stinger. RIH w/ 9 5/8" Baker cmt. ret. picker to cmt. ret. @9900'. Unable to latch spear into ret. Pooh. RIH w/ 8 1/2" bit. Drilled on cmt. ret. @ 9900' for 5 1/2hrs. Bit locked. Pooh. (Footage 0') Tripped for bit. Drilled out cmt. ret. @ 9900' & cmt. to9972'. RIHto 10,291'. Circ. &cond. mud. Pooh. RUDA. Had electrical failure on control panels in logging unit. Repaired same. Ran GR-CBL-VDL Log from 10,279'-9200'DIL. Had excellent bonding (100%) from 9350'-10,279'. Perf. Hemlock Bench #6 from 10,218'- 10,240' w/ 4" csg, gun @3 hpf. (120° phasing). RD DA. RIH w/ 8 1/2" bit & 9 5/8" csg, scraper. (Footage 0') RIH w/ 8 1/2" bit & 9 5/8" csg. scraper to 10,291'. Circ. well clean. Pooh. RU DA. Ran WL gauge ring & iunk basket to 10,280', Ran & set Baker 9 5/8" X 4 3/4" perm. pkr. #1 @ 10,195' w/ tbg. tail @ 10,210'. Ran & set Baker 9 5/8" X 4 3/4" perm. pkr. #2 @ 9940' w/ tbg. tail @ 9952'. Ran & set Baker 9 5/8" X 6" perm. pkr. #3 @ 9622'. Changed out pipe rams & RU to run 4 1/2" tbg. (Footage 0') Ran 4 1/2" 12.60# N-80 Buttress tbg0 w/ side pocket gas lift mandrels as programed. Stabbed into perm. pkr. @ 9622' & tested pkr. to 450 psi. Spaced out tbg. PU out of perm. pkr. & displ, mud w/ FIW. Landed tbg. installed BPV. Removed BOPE. Installed & tested x-mas tree-ok. Placed well on gas lift to production test Hemlock Bench #6 perfs, from i0,2i$'-10,240'. Gas lift out FIW in tbg. & annulus. Laid dwn. 5" DP. (Footage 0") Production tested Hemlock Bench #6 perfs. Production Test - 1-2 hrs. _ Gross Net Cut 864 45~ 4~-. ~'~ Tbg. Press. C_sg', Press. 200 860 (Footage 0') Making rig turnaround for TBUS G-12 t~d. WO to Leg Rm. #2 while production testing TBUS G-24. Production Test: Gross Net Cut ,Tbg. Press. Csg. Press. 1120 700'" 3-~-. 5% 170 800 UNIC 'I OIL COMPANY OF CALIFORNIA LEASE TRADING BAY UNIT STATE I'~LL l'~O, G- 24 FIELD McArthur River Field DATE 43 5/18/76 5/19/76 5/2o/76 5/21/76 5/22/76 5/23/?6 5/24/76 10,400'TD 10,298'ETD FC. 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC DETAILS OF OPERATIONS, DESCRIPTIOIIS & RESULTS (Footage 0') Continued making rig turnaround for TBUS G-12 Rd. WO. SI TBUS G-24 @ 3:00 pm, 5/18/76 for Btm. Hole Press. Survey. Released rig from TBUS G-24 @ 12:00 Midnite, 5/18/76. (Footage 0') SI for Btm. Hole Press. Survey. Pulled survey @ 6:00 pm, 5/19/76. Stab. well for acid treatment. (Footage 0') RU Dowell to Claylok treat Hemlock Bench #6. Bull- headed 2000 gal. of 15% HCL aci~ dwn. tbg. to tbg. tail. Returned well to gas lift & gas lifted out HCL acid. Pumped 1000 gal. of 2% KCL wtr. followed by 2000 gal. of Dowell Claylok treatment (2% F-75) & 1000 gal. of 2% KCL wtr. dwn. tbg, Initial pumping rate-2 BPM @ 2000 psi. With 2% KCL wtr. @ formation-rate lowered to 3/4 BPM @ 2500 psi. With Dowel] Claylok @ formation- pumping rate continued to lower to 1/4 BPM @ 3000 psi. With 1500 gal. of Dowell clay displaced-pumping ceased @ 3000 psi & press. held 15 mins. Returned well to gas lift & gas lifted out remain- ing Claylok & KCL wtr. in tbg. (Footage 0') Gas lifted well on production test following Claylok stab. treatment. Production Test: Gross Net Cut Form. Gas GOR GLR Grav. TP CP 216 62 71% 19 300 11,755 30° 140 650 RU DA. Differentially reperf. Hemlock Bench #6 w/ 2 1/2" Jumbo Jet @ 2 hpf. Placed well on gas lift production test. Gross Net Cut Form. Gas 360 173 52% 161 G©R GLR Grav. TP CP 931 6785 30° 200 820 Continued production testing Bench #6 & prep. to acidize. (Footage 0') Production tested Hemlock Bench #6 @ an average rate of 360 bbls/day w/ 52% cut. RU Dowell. Pumped acid as follows: Quantity Initial Pumpin~ Rate 2000 gal. of 2 1/2% HCL @ 1.0 BPM w/ 2500 psi 2000 gal. of 12-10 HCL-HF @ 0.6 BPM w/ 2600 psi 1000 gal. of 2 1/2% HCL @ 1.5 BPM w/ 2600 psi Final pumping rate - 1.5 BPM w/ 2000 psi. Placed well on gas lift for production test: Gross Net Cut Form. Gas GOR 600 282 53% 45 160 GLR Gray. TP CP 4978 23.]° 160 7--~0 PA6 No, LEASE TRADING BAY UNIT STATE UNION OIL CCtiPANY OF CALIFO ,IIA I,,£LL I ECORD ~'~ELL NO, G-24 FIELD McArthur River Field DATE 44 45 46 51251?6 5/26/76 5/2?/?6 5/28/?6 5/29/76 5/3o/?6 5/31/76 6/1/76 6/2/?6 10,400'TD 10,298'ETD FC 10,400'TD 10,298 'ETD FC 10,400'TD 10,298'ETD FC 10,400'TD 10,298 'ETD FC 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC. DETAILS OF OPERATIONS, DESCRIPTIOHS g RESULTS (Footage 0') Production tested Hemlock Bench #6. Gross Net Cut Form. Gas GOR GLR Grav. TP CP 28-- --- 7 -o (Footage 0') Production Testing Hemlock Bench #6. Gross Net Cut Form. Gas GOR GLR Grav. TP CP 576 28---~ '5~u% 197 694 5469 30° 24 73~ (Footage 0') Production testing well. (Footage 0¥) Skidded rig over well TBUS G-24. RU DA & differentially perf. Hemlock Bench #5 while producing xvell @ 200 BPD w/ 3 1/2" carrier gun @ 3 hpf as follows: Bench Interval FootageT #5 10,156'-10,186' 30' #5 10,090'-10,144' 54' (Footage 0') Production tested TBUS G-24 w/ Hemlock Benches #5 & #6 commingled while running profile log on TBUS G-22 & activating rig. Gross Net Cut Form.Gas GOR GLR Grav. TP CP 2544 2188 14% --- 1032 33.4° 140 850 Released rig toTBUS G-24 @ 12:01 am, 5/31/76. RU Camco. 3 1/2" plug to set in isolation pkr. @ 10,211' above Hemlock Bench #6. Running prong backed off. RIH w/ (Footage 0') Attempted to fish out WL running tools. Rec. WL jars & sinker bar. Unable to rec. running tool. WL plug seated in nipple @10,211'. Put well on prod. test. Plug holding. Production tested Hemlock Bench #5. Gross Net Cut Form.Gas GOR GLR Gray. TP CP 2544 2508 1.4% 1063 33.8° 175 880 RIH w/ press, bombs for 24 hrs. build-up survey. (Footage 0') RIH w/ WL press, bombs. SI well @4:00 am, 6/2/76 for 24 hr. BSm. Hole Press. Build-up Survey on Hemlock Bench #5. ~E _T_R_A_DI~G BAY_~.U.BIT STATE UNIO['t OIL CCt~PANY OF CALIFORt~IA ¥£LL I~ECORD I'~LL ~0, G- 24 FIELD McArthur River Field ]:)ATE 47 6/3/76 48 6/4/76 ETD 10,400'TD 10,298'ETD FC 10,400'TD 10,298'ETD FC DETAILS OF OPERATIONS, DESCRIPTIOIIS g RESULTS (Footage 0') Completed running Btm. Hole Press. Build-up Survey on Hemlock Bench #5. Final SI press, was 3316 psi. RD slickline unit. RU DA. Differentially perf. Hemlock Bench #4 w/ 3 1/2" Carrier gun @ 3 hpf from 9965'-10,052'. RD DA. Placed well on prod. test. (Footage 0') Production tested Hemlock Benches #4 & #5 while per- forming WL work on TBUS G-12 RD (WO). Released rig @ 12:00 Midnite, 6/4/76 to well TBUS G-25. Gross Net Cut Form. Gas GOR GLR Gray. TP CP 3372 3311 1.8% 573 173 1283 33.6° 140 1000 FINAL REPORT OIL CCF AHY OF CALIFORNIA WELL I LCOI, LEASE TRADING BAY UNIT STATE I'~LL IlO, G-24 FIELD McArthur River Field DATE ET~ JTS. 1 17 1 19 TOTAL JTS. JTS. 60 64 126 TOTAL JTS. JTS. 1 2 1 47 28 180 1 260 262 TOTAL JTS. DETAILS OF OPERATIONS, DESCRIPTIOIIS & RESULTS 20" CASING DESIGN DESCRIPTION LENGTH BOTTOM TOP Baker Guide Shoe 20" 94# H-40 Butt. Csg. Baker Stab-in FC 20" 94# H-40 Butt. Csg. 20" 94# H-40 Butt. Csg.. w/ CIW fl ow thru hgr. Landed below table 1.65 829.26 827.61 43.00 827.61 784.61 2.75 784.61 781.86 704.48 781.86 77.38 34.78 77.38 42.60 42.60 42.60 -0- Note' Centralizers lO', 30', 132', 217', 260', 303', 348', 386', 469' 506' & 622' above shoe Cmt.baskets are 326' & 549' above ~ · shoe. Total of 12 centralizers & 2 cmt. baskets. 13 3/8" CASING DESIGN DESCRIPTION LENGTH BOTTOM TOP Dowell Guide Shoe 1.73 13 3/8" 68# K55 Butt. Csg. 81.31 Dowel 1 FC 1.60 13 3/8" 68# K-55 Butt. Csg. 2415.11 Dowell DV Collar 2.93 13 3/8" 61# K-55 Butt. Csg. 2563.63 13 3/8" 61# K-55 Butt. Pup. 8.70 Landed below table 40.44 5115.45 51!3.72 5113.72 5032.41 5032.41 5030.81 5030.81 2615.70 2615.70 2612.77 2612.77 49.14 49.14 40.44 40.44 -0- Note: Ran 13 3/8" X 17 1/2" centralizers 10' & 30' & 601 above shoe. Ran 1 centralizer in the middle of every other jt. to 2700' Ran DV stage cmt. tool @ 2615' w/ a centralizer 10' above & 10' below tool. Ran 13 3/8" × 17 1/2" centralizer every other jt. to 400'. Ran Dowell cmt. basket @ 700' & 500' w/ centralizers above & below baskets. 9 5/8" CASING DESIGN DESCRIPTION 'LENGTH BOTTOM TOP Howco Cmt. Guide Shoe 1.92 9 5/8"'47# USS95 Butt. Csg. 86.44 Howco E FC 1.56 9 5/8" 47// USS95 Butt. Csg. 1950.55 9 5/8" 47# P-110 Butt. Csg. 1140.51 9 5/8" 47# N-80 Butt. Csg. 7134.90 9 5/8" 47# N-80 Butt. Pup. 33.82 Landed below table 38.30 10,388.00 10,386.08 10,386.08 10,299.64 10,299.64 10,298.08 10,298,08 8,347.53 8,347.53 7,207.02 7,207.02 72.12 72.12 38.30 38.30 -0- 9 5/8" 47# N-80 Butt. Cut off 9 5/8" 47# N-80 Butt'. landing jt. w/ 5.01' above table. 5.81 38.30 32.49 37.50 32.49 -5.01 Note: Ran 9 5/8" X 12 1/4" centralizers 10' & 30' above float shoe & 1 centralizer in the nliddle of everyu~*t~ to 8411' Ran radioact- -tive csg. collar locators 20' above . #8 & #2(~-located @ 10,067' & 9567'. UNIO[ OIL CCltPAI'h' OF CALIFORNIA ¥, LLL I LCORD '-LEASE TRADING BAY UNIT STATUE I'ELL NO, G-24 FIELD McArthur River Field DATE ETD JTS. 1 1 1 1 1 9 1 ll 1 10 1 10 1 11 1 10 1 1 1 1 10 1 1 1 1 11 1 1 1 1 10 1 1 1 1 10 1 1 1 1 13 1 1 1 1 31 1 1 1 1 42 1 1 1 DETAILS OF OPEP~qTIONS, DESCRIPTIOIIS & RESULTS TUBING DETAIL DESCRIPTION Baker mule shoe 4.00"ID, 5.2"0D 4 1/2" bts. tub Otis "X"-nipple 3.812"ID, 4.60"0D Baker Seal Assy. Baker 6.00"ID pkr. Baker Loc. sub. " 4 1/2" Butt. Tbg. 4 1/2" Otis "XA" sleeve 4 1/2" Butt, Tbg. 4 1/2" Camco MMG Mandrel 4 1/2" Butt. Tbg. 4 1/2" Camco MMG Mandrel 4 1/2" Butt, Tbg, 4 1/2" Camco MMG Mandrel 4 1/2" Butt. Tbg. 4 1/2" Camco MMG Mandrel 4 1/2" Butt, Tbg, 4 1/2" Camco MMG Mandrel 4 1/2" Butt. Tbg. 4 !/2" Camco MMG Mandrel 4 1/2" Butt, Tbg, 4 1/2" Butt. X 4 1/2" EUE 4 1/2" Camco MMG Mandrel 4 1/2" EUE X 4 1/2" Butt, X-over 4 1/2" Butt, Collar 4 1/2" Butt. Tbg. 4 1/2" Butt. X 4 1/2" EUE X-over 4 1/2" Camco MMG Mandrel 4 1/2" EUE X 4 1/2" Butt. X-over 4 1/2" Butt. Collar 4 1/2" Butt, Tbg. 4 1/2" Butt. X 4 1/2" 'EUE X-over 4 1/2" Camco MMG Mandrel 4 1/2" EUE X 4 1/2" Butt. X-over 4 1/2" Butt, Collar 4 1/2" Butt. Tbg, 4 1/2" Butt, X 4 1/2" EUE X-over 4 1/2" Camco MMG Mandrel 4 1/2" EUE X 4 1/2" Butt, X-over. 4 1/2" Butt, Collar 4 1/2" Butt. Tbg. 4 1/2" Butt. X 4 1/2" EUE X-over 4 1/2" Camco MMG Mandrel 4 1/2" EUE X 4 1/2" Butt. X-over 4 1/2" Butt, Collar 4 1/2" Butt. Tbg, 4 1/2" EUE X 4 1/2" Butt. X-over 4 1/2" Camco MMG Mandrel 4 1/2" EUE X 4 1/2" Butt. X-over 4 1/2" Butt, Collar 4 1/2" Butt. Tbg. 4 1/2" Butt. X 4 1/2" EUE X-over ~ 1/2" Camco MMG Mandrel 4 1/2" EUE X 4 1/2" Butt. X-over 4 1/2" Butt, Collar ~ 1/2" Butt, Tb§. ~ 1/2" Butt, X 4 1/2" EUE X-over 4 1/2" Camco MMG Mandrel 4 1/2" EUE X 4 1/2" Butt. X-over LENGTH TOP BOTTOM · 90 9688.1 0 9689. O0 31.30 9656.80 9688.1 0 1.05 9655.75 9656.80 18.26 9637.49 9655,.75 .90 9636.59 9637.49 31.74 9604.85 9636.59 4.60 9600,25 9604.85 29.75 9570.50 9600.25 8.55 9561,95 9570.50 278.81 9283.14 9561.95 8.51 9274.63 9283.14 340.11 8934.52 9274.63 8.52 8926.00 8934.52 310.30 8615.70 8926.00 8.55 8607.15 8615.70 309.29 8297.86 8607.15 8.45 8289,41 8297.86 344,72 7944.69 8289.41 8.55 7936,!4 7944.69 311,36 7624.78 7936.14 .17 7624.61 7624.78 8.83 7615.78 7624.61 .17 7615,61 7615.78 .80 7614.81 7615.61 309.69 7305.12 7614.81 .14 7304.98 7305.12 8.83 7296.15 7304.98 .19 7295.96 7296.15 .80 7295.16 7295.96 339.53 6955.63 7295,16 .16 6955.47 6955.63 8,85 6946.62 6955.47 .17 6946.45 6946.62 .80 6945.65 6946.45 309.28 6636.37 6945.65 .17 6636.20 6636.37 8.81 6627.39 6636.20 · 15 6627.24 6627.39 .80 6626.44 6627.24 311.87 6314.57 6626,44 .27 6314.30 6314.57 8.49 6305,81 6314.30 ,32 6305.49 6305.81 .80 6304.69 6305,49 398.97 5905.72 6304.69 .28 5905,44 5905.72 8.81 5896.63 5905.44 .30 5896.33 5896.63 .80 5895.53 5896.33 957.95 4937.58 5895.53 · 17 4937.41 4937.58 8.83 4928.58 4937.41 ,17 4928.41 4928.58 .80 4927,61 4928.41 1293.71 3633.90 4927.61 .17 3633.73 3633,90 8.83 3624.90 3633.73 .17 3624.73 3624.90 UNiOI OIL C[ P/V Y OF CALIFOPC,IIA ~ ~E TRADING BAY UNIT t'~LL I'lO, G-24 - FIELD McArthur River Field DATE ElD JTS. 1 52 1 1 1 1 57 1 8 1 375 JTS. DETAILS OF OPERATIONS, DESCRIPTIOIIS & RESULTS TUBING DETAIL (cont...) DESCRIPTION LENGTH 4 1/2" Butt. Collar 4 1/2" Butt. Tbg. 4 1/2" Butt. X 4 1/2" EUE X-over 4 1/2" Camco MMG Mandrel 4 1/2" EUE × 4 1/2" Butt. X-over 4 1/2" Butt. Collar 4 1/2" Butt. Tbg. 4 1/2" Otis Ball Valve 4 1/2" Butt. Tbg. Cameron Tbg. Hgr. Landed below Rotary Table TOP BOTTOM TOTAL JTS. OF TBG. Notes: WL measurement - DIL. Baker Model "F" Pkr. w/ 6" bore 9622'. Tbg. measurement 9637.49 WI 9622. O0 15.49 CO measurement drill pipe were 15' long to WL. Sqz. pkr. chock 15' low to WE measurement. 4 1/2" Mandrel (MMG) 3.890" ID & 7.031"0D. .80 3623.93 3624.73 1596.88 2027.05 3623.93 · 17 2026.88 2027.05 8.45 2018.43 2026.88 .14 2018.29 2018.43 .80 2017.49 2018.29' 1733.49 284.00 2017.49 2.56 281.44 284.00 244.04 37.40 281.44 .74 36.66 37.40 36.66 -0- -0- 17. TBG. DETAIL t. 4 1/2" Otis ball valve. Top @ 281.44, Btm. @ 284.00 (2.51 2. 4 1/2" Camco MMG Mandrel Top @ 2018.43, Btm. @ 2026.88 (8.45') 3. 4 1/2" Camco MMG Mandrel Top @ 3624.90, Btm. @ 3633.73 (8.83) 4. 4 1/2" Camco MMG Mandrel Top @ 4928.58, Btm. @ 4937.41 (8.83') -- 5. 4 1/2" Camco MMG Mandrel Top @ 5896.63, Top @ 5905.44 (8.81) 6. 4 1/2" Camco MMG Mandrel Top @ 6305.81, Btm. @ 6314.30 (8.49) 7. 4 1/2" Camco MMG Mandrel Top @ 6627.39, Btm. @ 6636.20 (8.81) 8. 4 1/2" Camco MMG Mandrel Top @ 6946.62, Btm. @ 6955.47 (8.85) 9. 4 1'/2" Camco MMG Mandrel 7296. 5, Btm. @ 7304.98 (8.83) 10. 4 1/2" Camco MMG Mandrel Top @ 7615.78, Btm. @ 7624.61 (8.83). 11. 4 1/2" Camco MMG Mandrel Top @ 7936.14, Btm. @ 7944.69. (8.55) 12. 4 1/2" Camco MMG Mandrel Top m. $289.41, Btm. @ 8297.86 (8..45) 13. 4 i/2" Camco MMG Mandrel Top @ 8607.15, Btm.'@ 861 5.70 (8.55) 14. 4 1/2" Camco MMG Mandrel Top @ 8926.00, Btm. @ 8934.52 (8.52) 15. 4 1/2" Camco MMG Mandrel Top @ 9274.63, Btm. @ 9283.14 (8.51) 16. 4 1/2" Camco MMG Mandrel Top @ 9561.95, Btm. @ 9570.50 (8.55). 18 19 20 . t17. 4 1/2" Otis XA Sleeve Top @ 9600.25, Btm. @ 9604.85. (4.60') 18. Baker Locator Sub. Top @ 9636.59, Btm. @ 9637.49. (,90'), 19. Baker Seal Assy. Baker 6.00"ID Pkr. Top @ 9637.49, Btm. @ 9655.75. (18.26'). '" 20. Otis X Nipple-3.812"ID & 4.60"0D. Top @ 9655.75, Btm. @ 9656.80, (1.05'). 21. Baker Muld Shoe 4.00"ID, 5.2"0~r Top @ 9688.10, Btm. @ 9689.00, (.90'). 22. 4 1/2" Model "DB" Pkr. 4.75"ID, 8.125"0D. Top @ 9940.00, Btm. @ 9943.90. (3.90'). 23. 4 1/2" Butt. X-over..78"ID, 5.37"0D. Top @ 9943.90, Btm. @ 9944.64. (.74'). 24. Otis "XN" Nipple. 3.725"ID. Top @ 9950.05, Btm. @ 9951.35. (3.725"). 25. Baker Bell Nipple 4.00"iD, 8.125"0D. Top @ 9951.35, Btm. @'9952.22, (.87'). 26. 4 1/2" "DB" Pkr. Baker. 4.75"ID 8.125"0D. Top @ 10,196.00, Btm. @ 10,199.84. (3.84') 27. 3 1/2" Butt. X-over Top @ 10,199.84, Btm. @ 10,200. (.78') 28. Otis "XN" Nipple. 2.635"ID. Top @ 10,208.68, Btm. @ 10,209.55. (.87'). 29. Baker Bell Nipple 3.00"ID 8.125"0D. Top @ 10,209.55, Btm. @ 10,210.35. (.80') ~EY. .j DATE DRAWN ~ C. KD. ...... ].I_..---'.~"'-~. Started: 4/6/76 " ' ' Completed: 6/4/76 .._.'~.iL]~ ." _]] TRADING BAY UNIT STATE WELL G-24' ~, _ ..... UNION OIL COMPANY OF CALIFO',-~t(IA sHl~'~,~' ..... j FORM 247 (NEW 5/66l SOB No A-~.-8-75 f ~ r? DATE o-~-~ REPORT and PLAN of SUB-SURFACE SURVEY ~ '~ OF ~ - ~ UNIO~ ()ii,, CO. ~,ALiFO~IA T.B.U.- ~ONPLEfION REPORT ....... JUNE 8~ 1976 UNION OIL CO. OF CAL. TRADING BAY UNIT WELL G-26 (LEG 3 SLOT 5! M-~GNETIC' SINGLE SHOT SURVEY K. Be ELEVe.?9._FT., ........... DE~L.!~.AT[ON ..2.~...DEG. EAST ~X~U$ OF' CURVATURE HETHOD oF-COHPUTATION ........................... P~EPARED FOR ADDCO BY F. H. LiNDSEY &ASSOC. ..... ........... RECORD OF SURVEY ALL CALCULATIONS PER.FORMED...B~..! .... ..... TEUE . HEA's. DRIFT VERTICAL SUB DRIFT .... TOTAL .COORDINATES ........ C L O $ U R E $ DEPTH ANGLE ....... DEPTH ' SEA DIREC D.I.~TANCE ............ ANGLE DoG'-LEG SEVERITY SECTION DEG/IOOFT ............. D I STANC ............ o 'o '--0 ......... 0,o0 '-ge,oo '626,o0E ............. 0',00 -s ........ 0'-00~'~ .............. O'O0-'"s ...... o'"o .... 0" ~v o'O0o .:: .... O',oc 92 0 ].5 9]..(79 -7.00 $26.0.OE ........ 0'"].8' S ...... O',O'8"E .......... 0.20~S"25 59 59 E 0.272 .. 0.2¢ '187 0 0 185.99 87.99 S26.00E OeD6 ~ 0.17 E 0.¢0 S 25 59 59 E 0.26~ . 0.6C '-'~08 0 30 307.99 208.99 526.00E '" 0.8~ S .... o'~O~E ' 0.9~ S 25 26 9 E ...... ~690 30' ' 368.99 ...... 269.~9 559.00W ......... ~'~0 S 0,25"E ................. 1,~ ..... g"~ 0 15 ~3.99 ....... ~e99 $2leO0W ..... 1.62 '$ ..........O'Oi~"W ................ 1.62 ....... '~'y ...... -0 5O ......... -52'6-,99 .............. 427.99 S~.OOW .......... 2.[6S ............. 0"2'9"--W ........ 2.18 ' -'"'y~8 "0' '30 ........ 707.98'- 608,98 S8~.OOW .............. 2-,70 S .............. ~'.~O'-'--W 3.00 .... ~-3'3 0 30 ....... B32"98 ....... 733.98 5~5.00~/ .... 3"Z9 'S ..........2'26-W .............3'91 : :-J"~'~ ......... ~"-~'J---iY~';'~'~ .... i-~-~'~-~ ......... ~j~-;-OOE ................. i"~-~-?~""S ........ : .......... ~';-~Y-~ .................. :?";~"~'"'-S ~900 9 0 1898.~6 1799.46 54~.00E 26.g4 $ [7.[9 E ~x.ee..s._.~2 .... - 2..8= - - , -. ............................................. ~ ~-5'17--'2'i ' 0 ......~-6~-','~'9 ....... -2"39-5~'29 .... S~O,OOE ........i41"8~'"S ............. -i'2'1'"~7-6--E ............... -i86.93 s ~0 38 41 E 2.151 183.0: .................................... REC:ORD OF SURVEY ...................... TRUE ................................................................................................ DO6-~LE6 ~E-A$'*'- DRIFT VERTICAL ...... SUB DRIFT .... TOTAL COORDINATES ................ ~-'L'O"s U R E S"- SEVER'ZTY SEcT[ON' ~-P'¥~-ANGLE ....... D"EDY'H ................. SEA DZRE¢ .................................................................... ~]-~'YXN¢E .........A'N'~L'~ ..... OEG'~"i~ ..... Di$TAN~'E D M DEG, D M 5 .~9 2k 30 2808,61 2709,5~ 538,002 2~6,56' S 2~6"39~"E ........ 32'~,55 s 39 ~5 57 E 0,551 3~5,70 3393 25 15 3293,06 319~,06 $39,002 ~22,35 S 3~6,22 E 5~6,12 S 39 20 36 E 0,1~5 537,22' 37~0'2~ 30 '-3607,87 3508,87 539,002 535'78 $"~ ~38,08 E 692,08 S 39 16 ~5 E 0,2~6 '' 680,96'- 3960 23 15 3809,0~ 3710,0~ $36,002 606,~1 5 ~92,28 E 781,07 $ 39 ~ 9 E 0,607 7~9,01 ~31~ 22 0 ~133,02 403k,02 S37,002 7~4e95 $ 572,59 E ..... 9~5,98 S 38 ~1 26 E 0,358'-' 902,88 -~657 ~9 0'" ~457,07 "358,07 $36'002 812,35'5 ...... 6~4"66"E i037,06 S 38 26 5 E 0,868 .... ~915 22 0 ~598.71 ~599,71 S~O,OOE 883,52 S ' 700*27~E .... 1127,38 5 38 23 59 E 1.183 1112,20 5080 20 0 ~852,7~ ~753.7~ $39,00E 929.15 $ 737,88 E 1186,50 $ 38 27 17 E 1.214 1170,3~ 5299 18 30 5053,82 495~.82 S38.00E 98~,10 S 781,59 E 1256.72 $ 38 27 26 E 0,706 1239,59 ...... . .... 5&79 20 30 5229.15 5130*15 $38.00E 1033,03 $ 819.82 E 1318.81 $ 38 26 8 E 1,075 1300,91 566'7 23 0 5~03.75 5304,75 S3&,OOE 1089.37 S 860,75 E 1388,39 $ 38 18 ~8 E ' 1.369 1370,0~ '5810 24 30 553~,63 5435.63 $34.002 1137,12 $ 892'96-"E ..... 1445,83 S 38 8 30 E 1.0~9" 1~27*41' '6'127" 2~ ....O' 5826.'93- 5727,93 S22,002 12~5,14'"S .... 950'.39""E ...... 1'566,~ $ 37 21 1~ E ~.206 1549.73-' 63~3 21 0 6000.57 5901,57 $2Z.OOE 1307,~6 S 97~.82 E 1630,63 $ 36 42 50 E 0.193 1615.82 6530 21 30 5202.82 6103.82 $20.002 ~380*82 S ~002.37 E 1706.29 5 35 58 3~ E 0.239 ~693.6~ ~'.79! 22 1'5 6~26.~6 6327.46 ~16*002 ..... ~66'.20"'S '1030'1~ .... E ......... I79~,89 $ 35' 5-26 E 0.392 ....... '~ Z 2~ 0 6797,9~ 6698.9~'" S~8.00E 1"610'63'S ..... 107~'"26' E .... 1936,02 & 33 ~2 9 E' 0.094 ..... 1929.'96 7417 21 95 7025.29 6926.29 518*002 1697,~ S 1102,~7 E 2029.04 $ 33 0 ~2 E 0*Z02 ......... 2019,07 "~'~'3 20' 3'0 .... 728'2"7~ ......7183"7%' $20,002 ~79'~.99-"S ' 1134"8'5'E .......... 2120'69 s 32 21 Ii" E .... 0,'~6'~ .......... 9'9'3~ ...... 20 0"' 7508,84" 7409',8'~' &21.00E'" ~869.62"S 1164'06'.E~.i'i~".2202.,39 5 31' 5~"26' E ........ 0,2'1~."i'ii-i 219'9."53- 8~98 19 30 8039.67 7940.67 S18,002 2049,25 5 1227.68 E 2388,85 S 30 55 30 E 0.107 2387,~9 -~"6'3 ..... 2'Z ..... 0 ....... 828'8";"2'8 .... 8~8"9;28 S20,OOE .... 2i3~'97'5 ..... 1257,53'E ....... 2~78,66 S 30 29' t'3 E ......0'*'5'7'~ ............ 9'006'21'15 851~,95 8~5,95 520,005 2218,26 $"1287,~9'E ....... 256~,82 S 30 7 5~ E 0,103 256~,31 9~.08. 20.. 0'i ' 90?8,35 ...... 89?9,35 $23,002 ........ 2.~15.,5,....S ...... 1365720....E'i'~i..iii...277~.,.63..S..i. 291..28 .2~ .E 0.'.'2.~6.1.iii'. 9831 20 0 9287.91 9188,91 523.00E 2~85,7~ 5 1395.00 E 2850,~3 $ 29 18 ~ E 0,000 ..... 2..850,39 ~-O~"a ZZ 0 959~,83 9~85.93 $25,00E 2587,15 $' 1,,0,15E ..... 29609'98 S 29' 6'" 9 E 0.326 2960e97. 303~,~28 ,~.,~? AT 5 28' 59"12'E ............................. .~A.u._R.,E..D_..,~,E?_T_H...3NP_?.T~E_R.. D_A.T.._A._.FOR.. EVE. R.Y_._E.~E~ ...... TRUE ......... HEASURED VERTICAL SUB MD-TVD VERTICAL 199 199. 100 0 0 0.3? $ 0.18 E 299 299. 200 0 0 0.77 S 0.37 E 399 399. 300 0 0 1.~5 & 0.07 E ~99 ~99. ~00 1'97 $ ........................................ 0 0 .............. 0-17 699 699e 600 0 0 2.69 $ 1.23 799 799. ?00 0 0 3.00 $ 2.0~ ............ ~99 ..... e99...i.i"'~ coo ...... o ..................... 0 .............................................. ~;e~'~ z.72 ............. -~o9'9 ................. ~099. .... lOOO ........... o .................... o ............................. ~,~'s "- ~.sz'w 1199 llg9. 1100 0 0 5,76 $ 5,31 1299 1299e 1200 0 0 6.30 S ~e89 1399 1399, 1300 0 0 6.87 $ ~.18 1499 1499~ 1~00 0 0 7.~3 S 6e2~ ...... ................ ~699 ........ ~699"-~ ~600 0 0 13'33 ~ 0.25 ..................... 1800 ............. 1799' ......1700 0 .................. 0 18.73 ~ 7.69 E'" ~901 1899. ~800 ~ ~ 27.00 $ 17.2~ 2002 ~999. ~900 3 2 38.93 $ 29.6~ 210~ 2099, 2000 5 2 52,21 S ~,60 g ................... 2207 ......................... 2'i'99'. ............ 2100 ..... 7 2 ~9"'7~~-& 60,97 E .... l23~ ..................... 2299~' ......... 2200 ..... ~i ~ 90.96 $ 79.06 E 2~22 2~99. 2~00 23 ? 1~3.21 $ 122.91 E 2630 2599. 2500 30 ? 17".28 $ 1~8.6~ E ............. 2739 ................. 2699' .... 2600 39 ............................. 9 208.01'$ 175.9'2'E .............. 2958 2'899.- ' 2800' 59 10 ............................................... 2'?'8,'96"'S ........... 2~1,79 E 3068 2999. 2900 69 10 31~.06 $ 260,29 E · ......... , .......................... · ....................... : ................................ , .......................... .............. . ................ ........................................ ................. . .... . 3179 3099. 3000 79 10 351.60 S 289.3~ E 3289 3199. 3100 90 ................. 11 3~7191 $ ...... 318.~., E .............. 3~'00 ........... 3299' 3200' 101 11 ~2~,~Z S 3~7.98 ................... ~'0 .......................... ~3'~", .......... ~'~'00 ..... 1'11 ....................... i0 .................................................. ~0;'95" $ ............. ~'?'~'~'~ E ........... 3620 ................... 3~'99e ..... 3400 ' 121 ....... i0 ~96'99 5 ...... ~06.67 E ........ TRUE MEASURED VERTICAL SUB HD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE ..... CORRECTION ............. fOTA'L" COORDINATES ......... 3840 ............. 3699, ..... 3600' 141 .................... 1'0 ......................... ~67,9~""$ ...... ~63"'49'E ~ ~ ~ ~ .................. ~ ~ ~ ~ i,." 7' _.i.3 ? oq i.. 1 ~ oli.-Y.L' 2.' .L .'_.i.i.~.i. i/'.L ~.2.211~i~L~.'i..i~..'.L, ~i,.~ ~.~i i~,~o.~ is. i..i...' ~....~.., ~i'~i~..i' 4058 3899. 3800 159 9 637.37 $ 514.88 E 4166 ............ 3999, 3900 167 ................ 8 ................................ 671.,.03 $ . 539,73 E 427~ 4099, 4000 175 8 703,85 $ 564,24 E ~382 ~199, 4100 183 8 735,94 $ 588,35 E ~89 4299, 4200 190 7 766.62 5 611,17 E 4595 4399, 4300 ' 196 ........... 6 ............................ 795,94'$ 632,72"E ...................... ~?ol ................. 4'499'' 4400 202 ........................................................... 6 ~'2~'.o~"s - ~53.26 E .... 4808 4599, 4500 208 6 853,26 5 675,68 E ......... 4915 5023 5129 5235 4699. 4600 216 ~799. 4700 224 ~899. 4800 230 ~999. 4900 236 5~41 5099, 5000 241 5447 5199. 5~00 247 5554 5299. 5200 254 8 883.52 8 913e69 6 .................. 969',50 5 996.19 ....... 6 700,27 E 725,29 E 748.35 E 770,L3 E 791,04 E 81'2.97 E 836.07 E ............ 5662 ....... 5399. 5300 262 .......................................................... 8 1'0'87*7i $ .... 859'62 E ...................... . 5771 5499. 5400 271 9 1123,81 5 883.98 E 5881 5599. 5500 282 11 1161,36 $ 908.51 i 5989 5699. 5600 290 8 1198,62 $ 929.37 E ..... ( 6097 ........ 5799' 5700 298 ....... 8 ........................ i"235'12'5 .... 946'33 E .......... 620~ ........ 5899, 5800 305' 7 .................. 1'270,'76 & 960,64 E 6311 5999, 5900 312 7 1306,~9 5 974,57 E 6~18 ............................ 6099, ......6000 3i9 .. 7 ...................... 134.~,54.$ 988.,23 E 6~26 6199. 6100 326 ? 1379,11 $ 1001.85 E 6633 6299. 6200 334 8 1416.74 $ 1014.83 E 6741 6399. 6300 342 8 1~55.33 $ 1026.93 E ............. 6'8~9 ...... 6499. 6~00 '350 .................. 8 ................................. 1'~94'54-'$ 1038.34 E ................... 6957 ....................... 65'99'; ......... 65~0 ........... ~5'8 8 ................................................... i~.~3..,58.,,.$ ...... iO'SO'02'E ..... . 7065 6699. 6600 366 8 ~572.39 5 ~062.03 E .... 7173 6799. 6700 37~ 8 16Z0e98 & 1074.38 E . . 7389 6999. 6900 390 8 1687.45 $ 1099.22 E AND' OTHER DATA FOR EVERY .................................... TRU[ HEASURED VERTICAL SUB ~D-TVD VERTICAL DEPTH .............. DEPTH .....sEA' .DIFFERENCE ............ ............. ?603 ................. 7199.' ' 71oo ' .o4 ................................................... 7 X'7~'1;-~3"~ ........ ~Z~,;*f~'-"E ............ 7710 ...... 7299. 7200 .... ~11 ............................................................... ? i79-7,-07' S .... i136'8'9 ..... .......... 7923 ...... 7~99.'' 7~00 ~24 ......... 6 ............................. 1'866.10 $- 1'162.72' E .... ~ .~8030 ........ 7599' 7'500 431 .......... 7 ............................... !900,23 5 1~.75,.66. 8136 7699. 7600 637 6 193~.07 $ 1188.11E 82~2 .... 7799. 7700" ',43 ......... 6 ..................1967.8~ S 1200.16 ..... 8349 7899. 7800 450 7 2001.80 S 1211.91 ......... 8,55 .............. 7999' ' 7900 ,56 .....................6 ..................................... 2'0'3'5';5~'$ ..... 1223'.20~E ......... 8561 8099. 8000 462 6 A069.~0 S 123,.31 E 8668 8199. 8100 468 6 2104.1~ S 12~6.19 E . 877~ 8299. 8200 ~75 7 2139.67 S 1258.88 E 8~82 8399. 8200 4~2 7 ' 2176.03 S 1272.12 E 8~89 8~99. 8400 ~89 7 2212.4~ S 1285.37 .... 9095 8599. 8500 497 ..... 8 22~8.78 & 1298.7~ ............... 9203 8699. 8600 50k 7 228~.60 $ 13~2.28 E ...... ' -' 9310 8799. ..... 8700" 511 ...... 7 2319.87 S 1326.00 E '" 9523 - 8999. 8900 524 ......................................... 6 2388'62'$' 1353.87 E ....... ...... 96~0 9099, 9000 531 7 2~22.~5 S 1368.13 E "( 98.3 ....... ~299' ..... 9200 5.3 ................. 6 ........................................ 2'~89.~b'$' 1~96.~8 E ....................... 9949 9399. 9300 550 7 2523.12 $ 1~11.15 E .................... ~oo~6 .... 9~9, ....9,o0 ~'' ~? 7 ~?..o $ 1~26,.7 10~63 9599. 9500 56~ 7 2592.03 $ 1~2.~2 E ...... ~0270 ......9699' 9600 57~ ........ 7 ................................... 2627"27'$ .... ~'58.60 ....... P. EASURED VERT I CAL SUB 2000 1997. 1898. 38.69..`5 ..... 3000 2936. 2837. 292.73 ~000 38~5. 5000 ~777. ~678. 6000 5708. 5609. i 7000 ........... 6638... 6539. 8000 7570. 7~71. . 9000 8509, 8~10, _ 907./+6 S . 720.1_7_ 1202,28 $ ....... 93],.20.E 15~9.06., S ........1 1890.69 S 1172,08 ..................... 400 800 1200 1600 VERTICAL SECTION SCALE I" ' : I000 UNION OIL CO. OF CALIF. WELL G-24 (LEG :5 SLOT 5) .~4oo ARE TVD. 5200 \ RADIUS OF CURVATURE METHOD) MAGNETIC SINGLE SHOT SURVEY 20~8°0 o 6400 "~ 6800 .~7600 ~r~t 8000 '~8400 8800 '~9200 9600 TVD = TMD = 9,780' 10,:558' :~800 3200 ,3600 4000 ,4400 4800 5200 5600 6000 6400 7200 7600 8000 ,8400 HORIZONTAL VIEW SCALE 1"=500' UNION OIL CO. OF CALIF. WELL G-24 (LEG 5 SLOT 5) RADIUS OF CURVATURE METHOD MAGNETIC SINGLE SHOT SURVEY ALL DEPTHS SHOWN ARE TVD 8800 9200 TVD = 9,780' 9600 TMD = 10,358' COMPL£T]ON .REPORT ........................................................ JUNE--8-e- UN~ON._.O.~L~ ..CO~..OF.~ CALe MAGNE.T.IC $ ].NGLE_.$HQ.T.._.SURVEY TANGENTXAL AVERAGING .METHOD OF COMPUTATION PREPARED. FOR._ ADDCO ................................................................................. RECORD -OF...SURVEY ............................ ALL-.- CAL. CULAT, I GN$ .-.PEREORMF. D BY ..i ,--~,M .-~ELECI:RON.I ~.EAS. DRIFT VERTICAL ....... SUB DRIFT :'.."-'.'T°TAL'c0°RDIN'A?E'~'-:-::'-':'-.': .... ~'L'0-$ u. R'E $ SEVERLTY.-- DE:P. IH._ANGLE. ._ DEP,T.H............. ,SEA ..... DIR.EC...................................................................... D.T~IANCE .... ANGLE ....... DEG/iO.OFJ. .... .................... D-- M ............................. DEG, D-- H $ ..... SECT iON-- DISTANCE ._. 92 0 15 187 0 0 308 ..0 30 369 0 30 ..... .... .4.3.~. 0 !5 .... 527 ........ 0 30 ....... 616 0 15 7.08 0 30 ..... 0'o0 ..... '99,00 s . o..oo,s .... o...oo., w ........ o.oo s o o o 91.99 -7.00 S 26 E 0.18 S 0.08 E 0.20 S 25 59 59 E 0.272 156,99 87,99 S 26 E .... Oe3&.. S 0,17... E._ 0,~0 S 25 59 59 E 0,26~-. 307,99 208,99 S 2~ E ..... O. m8~ 5 .... 0,40 E .......... 0,93 S 25 26 9 368,99. 269,99 S 59 W . . 1135 ~ 0,2~ E ..... ~,~7 G~3,99 ..... 3~,99 ~ 2~ W ........ 1,67..$ ..... O,03..W ............... 1,67.~ ~ ~ 37 W 0,5~3 ..... 52.6.,99 .... 427.,99 S ~ W ........ 2,21.~ ................. O.,31....W .................. 2,2~ .S 8. ~ 13....W ...... 0,282 ........... 615,99 5~6,99 S 66 W Z,~9 .S ._0,75 W .... 2,70 S ~6 18 ~1 W. 0,356 707.,98 608,98 S 8~ W .... 2,76. ~ ....... 1,3~ W ~,07 $ 25 ~7 57 W 0,290_ ....... 8.33._ 0 30 .... 832,98 ......... ~D3.,9.8 S..¢.5...W ............. D.,25. S ................... 2,~O.-..W .............................. 3,99..~ ~(. 5.. 0 ¢5 98~,97.. 885,97 S 49 W ~,~9 S .3,52. W ............. 5,62 $ ~8 ¢3 ~2 W 0,167 ........ ~ 0 30. 1~98,96-'- .... 1099,96 S 55 W 5,82 ~ .. 5,3~ W ......... 7,91 ~ 4~ ~6 33 W 0,~2% ..... ..1.~18 ....... O. 15 ~7.7,.95 ....... 1378.,95.. ~ ...... 8....W ............................ 7.,38....5 ...................... 6..,.3~.-.~ ..................... 9.,.7~.. S ~0 ~2 ......2..W .. 0,135 ...... ..1577 .... 2..- .163.8 ......... 3. ...... 0 ...... 163.1,.8.7 ........ 1.5.38., 8.7 ..... $. 17.02 ....~ ~5 .1.701,72 ........ 1602,72 .$ ..176.~ 5.~5. 1763,.~6...1.66~,~6 S ..1827 ...... 6..- 15 ....... 1826.,.~2 ...... 172.7.,.12 ........ 1900 9 0 1898,~7 ~799~¢7. S .205~_~Z 15. 20.50,0.~ .... ~95~,0~ 2178. 1~ ....... 0 ........ Z171,.-0~ ....... 2072. .23~1...17 0 ..... 23~e~.Z .......2219~51 $ 30_ 15/+6,94 .1/+47,9/+ 5.37. E ..... 8_.,/+0 $ .............. 6.,.05- W ................. 1.0,35-.5 35 /+5- 3....W 51. E 13,62...S .......... 0,12- W ............... 13,62 $ 0 31 39-.-W 59 .E 16,87. $ ......... z+,SZ. E ............ 17.,/+7..S 1/+ 59. 5/+ E- 50.E ............ ~5,5~ ~ ..... 36,9% E ............. 58,65....&.~9 -2 eZ.E.. .~0 ~ -- 9D,6~ S ........ 82,83-..E .............. ~6,5~ S ~0 D~ ~D E .... 1,9.3.5 ............. 2 . 1.. (~.A.I ...... 2.7.~2- i.-9.95-.. 1 *,~.05 ..- 1.'.612 .... 2..7.20 le968 0,00 0.20 0.40_ t.30 ..... 1.~5- 1.78 .... 1.90 1.77-._ 1.73. .... 2,13- 2 3,39 .... 5,31.-- 7 .,81.... 11.8.5 .1.6 .-95- 22 83,73..- 12 ...................... . ........ ........................ RECORD OF SURVEY .................... ALL CALCULATION5 PERFORAED BY I. -B-M E-LECTRON[¢.- CONPUTER ............................ /_RUE DOG-LES ................. MEA$,.. DRIFT- VERTICAL ..... SUB... DRIFT ................. TOTAL...COO. RDINAIE5 ..................... DEPTH ANGLE DEPTH SEA DIREC DI6TANCE .... ANGLE- . DEG/iOOFT-. DISTANCE ...... D M - DEG, ....................................................... D. 2675 23 30 26~0.62 25~.62 S 39 E %88-,[9 S- [59,81-5 ........ ~2859.,2~. 30 ..2808.71 .... 2709.71 $ 38. E 2~,.6.7.6 .... 3393-25 15 3293~17 319~.17 5 39~ E -~2-2.55 5 ..... 3~6.22 E .......... 5~6~28 5.39 19 ~9 E 3~0 2~ 30 3607.97 3508.g7 5 39 E . 535.98 5 3960 23 15 3809.15 37~0.~5 5 36 E 606.62 5 ~92,29 E ,781.2~ 5 39 3 36 E ~311 22 0 ~133.1~ ~034.1~ 5 37 E 715.17 5 ~72~61 E 916.16 5 38 ~0 58 E ~657 19 0 ~57.23 ~358.23 5 36 E 8~2.57 5 6~.68 E ....... 1037.25 5 38 25 ~0 E ~.915 22 0 ~698.89 4599.89 $ ~0 E 883.77 5080-20 0 ~852,93 ~753.93 5 39 E 929.40 5 737.92 E 5293 18 30 505~.02 ~955,02.-5 38 E 98~.36 5 781064,.E ...... 1256.95 5 38 27 5 E 5~79 20 30 5229.35.. 5130.35- 5 38 E 1033.28 .5667 23 0 5~03.97 530~.97 S 3~ E 1089m64 ,5810 2A 30 553~.86 5~35.86 S 34 E 1137.39 S 893.0~ E 1~6.08 $ 38 8 13 E .6127 2~ 0 5827.19,. 5728.19 $ 22 E 1245.63..,5 .... 950,,,57~,,,E ........ 1566.90 5 37 20 53, E ~ ~0 21 30 6203.09 .... 6Z0~.09 $ 20 E 1381.3~ S ~002,5~ E. -17.06.79 S 35 58 18 E ~,~72 22- 0 6798.2~ 6699.2% 5 18 E 16~1,1~.5 ~07-~.~,.E ............ %936.55 5 33 41 55,.E .-.7-~1.7 21 ~5 70.25.57- 6926.57 $ 18 E 1697,96 5. 11.02.65..E .... 202~,57 5 32 59 58 E .1693-20,.~30 ..... ~283..02 ......... 718~,..02 5. 20~.E 1792,01.5 .... ~135.0~,E ........... 2~21.23 5-32-.20-.~8 E 793~ 20. 0 7.509.~2 74~0.12 $ 21 E ....~870,~..S ..... 116~,25-E .... 2202.93.5 31 5~.-~5 g B~98. ~9. 30- 8039.9~ 79~0.9~ S 18 E 20~9,7g.$ %~27.87..E ..... 2389,~2 S 30.55. 20 E- 8163. 21 .,0-. 8288.57 .... 8189,57 5 20 E 2~36,52.-5 - 1257,e73 5 .......... 2~79,23 $ 30 29 ~ E ~006 21 15 85~5.23 8~6023 5 20 E 2.2~8,8~ .$ 1287.68 E 2565,~0. $ 30..7 ~3 E 9608 20 0- 9078e65 8979.65 ~ 23 5 2/+~6,11 5 9831.-20 .0 ...... 9288.20- 9~89.,20 5 23 E 2~.86.,32 5 1395.20 E ....... 285~,03 S .29 17 56 E 101~8 21 0 9585.13 g~86.13 5 25 E 25.8707~ 5 1A~Oe.36 E 2961e59 5 29 6 2 g 10358 21 ~.5 9780e.68 ...... 9681,68 S 26..E 2657,39 5~. 1~72.10 E 3037e89 S. 28 ~9 5 E 0.285 ..... 1694.11 0.692. 0.1-98 ..... 1930.00- 0.1.02 0.523 2117.5~ 0.252 ..... 2200.07 0.2.00 2388,05 0.623- 0-103 2~6~.89 0.2-72 2775,-t3 OeO,O0 2850-e99- 0.385 g961.59 0,397 3037,89 O.5.8.~ ..... 315'8'~' 0'1r61 ..... 537*40 0.216 - 681.1/+ 0*792 769,20. 0.373 903.07 0.873- . 1023.20 i.283.- 1112.43 1.2-31 .... 1170.57 0.721. 1239.83 1.0~5 .......... 1301.15- 1.5~5 1370.29 1,0/+9 1~27.67 1.82.~ ........ 1550.24 0.193.- 161.6.32 BOTTOM..HOLE ..CLOSURE ..... 3037..89 .F.EET.._AT 5 28. 59_f..5 E . ..................................... TRUE HEA~URED -- VERTICAL SUB . ~D-TVD ........ VERTICAL OEP TH ......................... 29.9 399 - - ~99 ....... 599 ........... '799 '799... ?OOe ............... $gg ....... 899. 800... ............ 999 .. 999e 900e 1099 1199 1299 1399 1~+99 159.9 1099. 1000. .1199t 1100. 1299., 1200. 1399. 1300. 1599., 1500., 0 ....... 0 .................. 2.74 S 1.27 0 ......... 0 ........................... 3.12 S 2.04 W ...... 0 ............................. 0 ..................................................... 3e?"5 S 2.83. ~ .... 0 0 0 0 0 0 0 0 ................ ,,.fi,. 3.5 $ 0 .......... 5.,82 $ 0 6.38 .._ O ............. 6.9~ S 0 ............... 7.69 $ 0 ................... 9.,.71..5 1 ............. 1 ............................................ 18.99. & 2 1 ....................27 ,-t .5 ~ .... I ..... 39.33 S 5 .....................2 5~..23-& .......... ,/+/+. 76--E 8 3 _7'0,.,/,+3 .S 61.30 E 12 ............ 4 ................ 9],."52 S ?9.33. E .................. ...................... 241.6 ................. 2399". ....23.0.0. .... ]..7 ............................... 5 ............................................... 1.]..6. 8.6. S ,.. 10.D..6.4.,. E ............. 2.522 2/+99', .. 24.+0.0. 23 ................ 6 ............................... ],,~,3.~8. & 122.95 E ...................... .... 2630 2599., 2"500. 31 ........ 8 t'7~. 05_..5 .1,, ~8 ,~ 98. E ........ ..................... 2739 ............................ 2699. ......2600.". .... 40 ........................................ 9 108.53.,~ S ........... 3,, ....... 28~+8 ......... 2799, _2700". 49 ..... 9 .................. 2z+3,37.$ . 203,70 E ....... 2959 2899. .28,00". 60 .... 11 ............................... 279.~2..$ .. 2,~2e.4,g E ...... ........... 3069 ......... 2999. ...... 2900a 70 ..................10 ................................................... 3.1,~.~8,.0.. S 26.t,,,.32 E .......... 31,79 3099e 3000.: 80 .... 10 ........................ 3.52.09 S 290e18 E ... ...... 32,89 31..99o_ 3.100e 90 .... .1.0 388.3_1it ~ ..... ,..-319..0~ E .............. ~.399 ...... 3,299., ..... ,:~2,00., ],00 ................... 10 ~.,2.~...6~, .$ ...... 3~7,.93 E ..... 3~10 ................... 3399.,_.. 3300., 1.1.1 ....... 1]. .................................... ,~60...68 ,5. . 37.?.10. E ....... ., ...... 3620 .............. 3/+99.e 3400. 12.1 ............... 10 ......................... ~96..._.71 ~ ,/+06.28 ..................... ,3?30 ................... .~.5.99e. ........ :35.00..". 131 ........................... 10 ............................ :~.32.7,g..,~. ....... ~35,,,~6 E ......... 169.9 .......... 1699". .1600. .................. 180.0 ..... 1799. 1700. ...... 1901 - 1899, 1800". ......... 2002 1999, 1900". .............. 2.104 ......... 2099, 2000, 2.20~ ...... 1199". 2100~ .... ! 2211 2299.,.. 2200, 5.70 6.23 ~,70 0.26 7,59 --17.21 30.27 MEASURED. D£PTH AND. OTHER_DATA FOR EVERY MEASURED ......... DEPTH E V EN.. 1 O.O...FEEI _OF...SUB, .SEA.,., DEPTH · . DEPTH .SEA_DIF.FERENCE ._.CORRECTION ....... TOTAL COORDINATES 38~0 .... 3600. 1~+1 3949 3700e. _ .150 ~057 38000 158 ~+166 3900. 167 ~. . ...~ ~274 ~,000. 175 ~+381 ~+100, 182 . ~k88 ~200e 189 ...... ~595 4300. 196 4702 . . _ ~00. 203 ..... ~08 ~500. 209 ..... 5022 ~700~ 223 5129 ~800~ 230 5235 ~900. 236 5341 ...... 5000, 2~2 5447 ........ 51008 248 566Z 5300. 263 577~ 5~00. 272 _ 5880 550~. 281 _ ( 5988 5600. 289 ........ 6096 5700. 297 ....................... 620.~ .................. 5889. 5800. ........305 ........ 6311 .. 5999e 5900, 312 651.8 60998 6000, 319 ..... 6526 ................. 61.99* ....610.08 327 6633 6299, 62008 33~ 67~1 63998 63.008 69~? .... 6599. .... 6500. 7065 6699e 6600. 7173 ....... 6,799e..,6700e 728! 6899, 6800, 7388 .... 6999e 6900, 7¢96 7099, _.7000e ............. 6~99, ~.6400e .... 350 358 366 37~ 382 389 _.397 3799, ................ 9 ........................ 603.,O6.~.$ .... ~89.e.D.5..E 3899. . _.8 ............. 636,72 $.. 51~_.56 E ..... 3999, 9 . .. 670.23 &.. 539,35 E ...... 4099, 8 703,73 $, 56~,14 E ~199. ? 73~,96 S 587,25 E ~299, 7 ............ 765,02 S 609,49 E 4399, .7 ........... 795,07 S ,. 631e73..E ¢4998 7 ................... 82~,88~ $ 654,30 E .854_.34 5. 677832 E ........... ~599. 6 4699. 7 .883.80 5. 700,3~.E ~79g. 7 913.4~ 5 72~.75 E 4899. 7 ..... 9~1.99 5 . 747e9~ E ~999, 6 ........... 969,3~ $.. 769.67.E 5099, 6 996.91S . 7918#~ E 5199, ..... 6 1024.81.5 813.2~ E 5299. 7 ...................... 1055.,76S. ~ 836,1,9 E .............. 53998 8 1088.04 5 ~ 859.6~. E 5499. 9 112~.31 $ 88~·19 E . 5599. ...... 9 ............ lZ61,.Z~ S, 905.64 E 5699. 8 .. Z~98.16 $ .... 9Z5.33 E 5799, 8 .... Z235.Z9 5 ~ 945.01 E ........................... 8 ............................................. 1271.,2~.$ .... 960e6.7. E 7 .................. 1306,9g. $ 97~e74 ..E ......... .... ~ 7 13~3,40 & . 988·36 .E _ 8 1~56·12 5 ~ 1026,8~ E ...... 8 ............. %533.69._5 1050.76 8 ..... 157~,57.& 1062865 E 8 1649,63 5 1086.95 E 7 1687881 $ lQgg..35 E ....... 8 ......... 1.724.78 S 1111.89. E ...... . ........ . . - _MEASURED . VERT[.CAL_..SUB HD-TVD D~P. TH .._ DEPTH SEA DIFF. EREI~CE ...... CORRECTION ..... TOTAL _COORDINATES ?299., ...... 720.0~ ....... ~ ............... 18~2,09 ~ 1150.02 7?10 ..7817 7923 . 7499, 8029 ?599, 8135 _ ?699, 8242 7799, 834.8 ................. 7899e 8456 7999. 8561 8099. 866S 8199. 87?4 8299. 888! 8399. 8989 8499. 9095 8599. 7399, .... ?300- 9202 ...............8699. 9309 . . 87.99. 9416 8899, 9523 8999* 9630 ...... 9099, 9?36 9199. 9843 9299* 99~9 ............... 9.39.9. 10056 ..... 9499. 7400, . ~2~ ........ 6 ........... 1866.64 7500. 430 . . . 6 ...... 1900.~6 7600. 437 7 7700, 4~3 ..6 .... 1968,2~ 7800, 449 .... 6 .... 2002,09 7900. 455 . 6 ..... 2035.93 8000. ~62 ...... 7 2070.39 8100. 469 7 2105.27 8200. 475 6 2140.30 8300. 482 7 2176.61 8~00. 490 .. 8 .., 2212.92 8500. 496 6 2248.15 8600, 503 7 . 2283.16 18700. 510 ......... 7 , 2318.18 8800. 517 7 2353.20 8900. 524 7 2388.22 9000. 531 . ~. 7 _. . 2422.93..5 9100, 537 6 9,200, 544 ? 9300, 5.50 9~00. 55? 1162,g4 1175,02 1187,00 119B.99 1210,97 1222.96 1234.96 1246,97 1272.32 1299.24 1313,03 1~26,82 1340.62 1354e41 1368,~9 1396.84 1427.26 TRUE~ DEPTH ........ DEPTH ..... SEA .... TOTAL ...... COORD ]NATES ................... 2000 .... ~g~e .... ~897~ ................. .............. 6000 57~0, 5611, 7000. 66~8, 6539, ...... 15~9,19. S 1055,50..E 8000 ..... 7571, 7672, . 189~,16 9000 8509, 8A~O, 2216.,~8_ .S. ~2.~,96 E . ...................... ......................... 400 ~o0 1200 VERTICAL SECTION SCALE: I" = I000' leO0 UNION OIL CO. OF CALIF. WELL G-24 (LEG 3, SLOT 5) 2000 ...... TANGENTIAL AVERAGING METHOD MAGNETIC SINGLE SHOT SURVEY 2800 · $200 ' ' ...... :5600 .............................. ' ................................................ 4 O0 ..... 4400 4800 ................................. ':: ............................... '"'[ I .......... ............... ' .............. . - ~ooo ~' ' ' -~6400 ~r~68oo 7200 7600 ALL DEPTHS SHOWN ARE T.V.D. 8000 8400 8800 9200 9600 TVD = 9,781 ' TMD= 10,3,58' 20OO 2400 2800 3200 3600 .4000 ,400 4800 HORIZONTAL VIEW SCALE !" UNION OiL CO. OF CALIF. WELL G-24 (LEG :5 SLOT 5) ................ TANGENTIAL AVERAGING METHOD MAGNETIC SINGLE SHOT SURVEY .................................. ALL: DEPTHS SHOWN ARE T.V.D. : . . · 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 ,9200 9600 TVD = 9,781' TMD= 10,358' . FOR UNION 0II, OF CA!;IFOR~;..T.A : TANGENTIAL TYPE OF SURVEY- Gyros c o'p~¢ SURVEY DEPTH: FROM 0 LEASE: Trading Bay Unit FIELD: McArthur River ,. FT. TO lO,h00. .WELL NO. O-2h .. COUNTY/PARISH Kenai Peninsula Borough , STATF DATE OF SURVEY M,ay 8¢ 1976 ]OB No. SU3-1607)4 Anch orsge, Alas ka 27h-6696 OFFICE: AK . _. UNION OIL CO?qPANY OF L~ALIFO;{NIA PAGE .1 '- WELL i'~Ur, ScR GRAYLING-G-24 FIAY 5~975 SURVEY DATE FICARTHUR RIVER VERTICAL SECTION COnPU ED ALONG CLOSURE - ALASKA SPERRY~$UN WELL SURVEYING COMPANY RECORD OF SURVEY TRUE .... INCLINATION "DIRECTION DOG-LEG MEARURED VERTICAL SUB-SEA SEVERITY VERTICAL DEPTH DEPTH DEPTH DES ~IN BEG ~iN BEG/100 SECTION O, 0,00 - '~99.00 ORIGIN AT KELLY BUSHING 100. 9~,9~ 0,99 0 20 S ~7.32 E 0.00 0,57 200. 199.99 100,99 '0 -7 S ~7.30 E '0.2~ ..... 0,76 SUS-1GO7B RECTANGULAR COORDINATES 0.00 N 0.00 W 0.55 S 0.17 E 0.69 S ...... 0.~2 E 300. 200,99 400, 300,99 500. ~00,9~ 299.99 399.99 ~99,99 ..- ~00,- 599,99 ' =00,99-. 700, 699,98 600.98 800, 799,97 700,97 900, 1000, 1100, 1200,' 1~00, 0 12 N 70,26 W 0 18 S 68.82 W 0 20 S ~,9! W 0 25 -- S [[5,1B W 0 34 S 36.51W 899,97 999,97 1099,95 .800.97 900.97 1000,96 0 22 S' ~0,7I W -0 %9 $ ~!,19 W 1199,95 1299,95 1399,95 1100,95 1200,95 1300,95 0 ~6 0 15 0 21 S 15, 2 W S 70,82 W S 1Z,lq W 0,31 0,52 0,57 S 0,00 0,19 O,R'9 0.76 S 0,~9 O,lq 0,71 1,18 S 0,89 0.08 .... 0,97 ' - 1,69 S 0,16 1.~5 2,~9 S 2,00 0,15 1,90 ~,36 S 2,85 ...... 0,30 2.30 3,97 S 3,25 0,07 2,57 ~,q5 S O,q5 '3,17 .'' 5,53 S 0,38 0.30 6,5~ S ~,&8 W 6,6~ S 5.29 7,27 S 5,. 1500. 1600, 1700, 1499,93 1599,75 1699,39 1400.95 1500.78 1600.59 1 5 S %7, 5 E 5 5 S 63,82 E 0,95 6.17 8.56 S -- ~.05 2,05 II,OG 12,01 S 0,19 2,1~ 17,85 15,92 S 8,lq /' 1~00. i900, 2'; O0, 179$,70 !597 ~ ic'''' 79 10 u'3 ],2 2o S %9,90 E ,-, 2,~7 S 59~q. 6 E S ~S~77 E 28.40 23.47 S I7.!I E q. 3~07 55.~21 S 2~,76 E 65 ~g5 4,9, /I S 3L;.~.,~ . ~:::o E i,7! 8!¢$0 -. ': .:'"' t- i 77 ~%:5,'73 S t;4, 9:3 E 2~L, ~:"i; 2?5 UNION OIL COMPANY OF CALIFORNIA PAGE WELL NUNBER GRAYLING G-.-2q MAY 8,1976 SURVEY DATE-- MCARTHUR RIVER VERTICAL SECTION COF'IPUTED ALONG CLOSURE ALASKA SPERRY-SUN WELL SURVEYING COMPANY' . .... TRUE ..... MEARURED VERTICAL SUB-SEA DEPTH DEPTH DSPTH 2500. 2q7%,99 2575.99 2~00. 2567,15 "2~68,15 ....... 22 50 ........ S' 32,56 E' SU~-1607~ RECORD OF SURVEY INCLINATION 'DIRECTION DOG-LEG ................................... RECTANGULAR SEVER~¥Y VERTICAL COORDINATES DEG MIN DEG ~IN DEG/iO0 SEC¥ION 18 8 S-5~,~O E 1.8~ 163.8~ 13~,71 S 100.1~ E 20 ~2 S ~2,67 E 2.61 19~.77 16~o~0 S 119.37 '2,15 .......... 237,15 ..... 197,11~ S ......... 1~0.25 E 2700. 265~,5~ 2559,58 25 5~ S 52,~9 E 2500. 27~9.73 '2650.75 2~ 17 S 52.19 E 2900, 28~0.70 27%1o70 2~ 52 S 32,11 E 3000. 2931,q~ 2852.~ 3100. 5022.01 2923.01 3200. 5112.2i 5015.21 1,O& 277.22 231,28 S 162°0! E O.qO 517.93 '265,08 S 185,92 El 0.25 ~59o05 501.25 S 205.99 E 2~ 5! ........ $ 52, 5-5 .... 0.51 25 5 S .31.15 E 0,~5 25 55 $ 51. 6 ~ 0.50 ~00.66 556.87 S '228.29 q%2.75 573,16 S 250.21 685.59 ~10,15 S 272,q. 9 3300, 520!.99 ~I02,99 26 8 ' S 30~ 9 E 3~00, 5292,11 ~195.11 25 ql $ ~0,95 E ~500. ~82,~5 328~,~5 25 25 S 31,50 E ~GO0. 5~73,06 537~,06 25 0 S 29,69 E ~700. 556%.15 3~55.13 2% 2~ S-29,80 E 3800. 5~5=.5~ 355A,5~ 25 55 S 29.7~ E 0.69 529.39 0,58 572,42 0.51 ..... 61q.99 0,73 657.0~ 0.60 698.1% O.&;8 738.q8 q68~26 S 29q,57 ~485,q~ S ~16.85 522,11 S -559,15 558,75 S 560.21 59~,60 $ 380,7~ 629,80 S ~00,85 3900. 57q7,32 36~5.~ ,32 23 2q "$ 29~5 E qO00. ~$39,58 37~0.58 22 %1 S 29,15 E ~!00. ~952,00 ~8~B,O0 22 27 S 28,90 E 0,53 778.02 gGq.~9 S q20,3& E' 0,72 81~.43 698°07 S 439,15 E 0.25 S 29,29 E,. ~ 0~79 S 29~23 E 891,~o 765,70 ~ '",P, 6 0 a "" ",_: ~. ~ UNION OIL CO~qPANY OF CALIFORNIA - ' PAGE $ .. WELL NUr-IBER GRAYLING G~2~ MAY g~!975 SURVEY DATE-' MCARTHUR RIVER VERTICAL SECTION CO~qPU1ED ALONG CLOSURE :- ALA,.~A SPERRY-SUN WELL SURVEYING COHPANY SU3-1607~ RECORD OF SURVEY TRUE MEARURED VERTICAL SUB=SEA ~' SEVERITY VERTICAL DEPTH DEPTH DEPTH DEG ~IN DEG HIN DEG/iO0 SECTION iNCLINATION DIRECTION DOG-LEG ' RECTANGULAR COORDINATES ~500. ~587,52 ~88.52 21 6 S ~0, 0 E 1.25 1099.56 ~900. ~680.~ ~581.g~ 21 2~ S 50.92 E 0.~5 1155,76 5000. ~77~,15 ~675.13 20 28 .... $ 50,92 E 0,91 1170.q7 5100. ~868.~ ~769.5~ 19 55 S 30,89 E 0.88 1205.75 5200. ~96~,q5 ~86~.~5 ~8 0 S ~0,91 E 1.58 5500. 5058,~2 ~959.~2 18 15 S ~1.19 E 0.26 1265.50 5~00, 5152,92 5055,92 19 .5 S 29,57 E 0,98 1295,05 5500, 52~6,61 5!~7o61 20 28 S 27,76 E 1.51 ~5~2.9~ 5600. 55~9.55 5~0,55 21 ~0 S 27.57 E 1.20 1569.80 ~q. 7.~1 S 575.19 E 978,69 S 593.92 E 1008o68'S 611,89 E 10~7.l~5 S 629,10 E 10~5.9G S 6~,97 E 1090.75 S 661,19 E 1119.19 S 1150,1~ S 1182.91 S 677.32 E 693.61 E 710.58 E 5700. 5~51,76 55~2.7~ 22 ~ S 26,76 E 1.09 1~08.~0 5~00. 552~, 5q 5~2~. 5~ 23 25 S 27. 9 E 0,69 1~8,08 5900. 5615,01 5516.01 25 50 S 25,57 E 0.75 1~88.~8 6000, 5705,85 5606°63 2~ q5 S 27.31E 1.16 1530.28 6100. 579~,91 50~9.~1 21 26 S 18,65 E ~o75 156~.G6 6~00, 5892,b¢. 5793.62 20 26 S 16.5~ E 1.25 1601.27 12!7.~2 S 1252.80 S 1289,25 S 152&,~5 S 13ol. 07 S 1B~, 5~ S 727.98 E 7~}6.08 E 765.52 F 782,73 E 79q.,1~.2 E 80q, o35 E 6300. 59~6,59 58~7.59 20 20 'S 17,~! E O.q5 1655.61 6~00. 6079~7! 59G'0.71 21 ~ S 16~53 E 0,86 1671°t~5 6500. 6173,01 60Y~.O1 21 5 S 16,15 E 0.13 1707.08 1~27,62 S ~-~,OG S 81.,93 E 825,2! E 835,22 E UNION'OIL COMPANY OF CALIFORNIA PAGE ~" WELL NUMBER GRAYLING G=26 MAY 8,1976 SURVEY DATE:' MCARTHUR RIVER 'VERTICAL SECTION COMPUTED ALONG CLOSURE ALASKA ........................................... - SPERRY-SUN WELL SURVEYING COMPANY SU3-1607~ RECORD OF SURVEY ....... TRUE ............... INCLINATION DIRECTION DOG-LEG ................. ' ...... RECTANGULAR MEARURED VERTICAL .SUB-SEA SEVERITY VERTICAL COORDINATES DEPTH DEPTH DEPTh DEG MI.N DES MEN DEG/IO0 SECTION 7200, G821.80 -u~22.80 21 51 8.15.85 E 0~22 1965.80 7500, 69[~.77 ~o15,77 21 57 S.[~,37 E 0.50 2002,11 7~00. 7007.~8 6~08.~8 ~22 0 ....... S'15,98 E "0.~0 -2059.00 !751.66 S 898.59 E 1787.55 S 907,75 E 1825,70 S 916.78 E 7500. 7100,89 7001,89 7600. 719~,59 7095.59 7700, 7288.35 7189.35 7800. 7900. 6000. 8100, 8200. 8300. 20 55 S Zff.36 E 1.09 20 27 ...... S ~.33 E .... 20 23 S 1~.35 E 7382.10 7263.I0 20 20 'S 16. 2 E 7ff75.92 7376.92 20 15 S 1~,12 E 7569.59 7~70,59 20 ~0 S 1N,39 E 20'7%.19 1858,29 S '2108,63 1892.1~ S 0,06 21~2.96 1925,88 S 0.58 2177,37 0,66 2211.~6 0.2~ 22~5o99 925.6~ E 93~.28 E 9~2.92 E 1959,28 S .... 952.50 E 1992,85 S 960,95 E 2026.77 S '969.65 E . . 76G5,20 756~.20 7756.79 7657,79 7850,~5 7751,35 20 35 -- S 15.85 E 20 58 S 16.1~ E 20 ~0 '- S 1G. 0 E 0.51 2260.79 2060.59 S '979.25 0.1~ 2~15.69 209~.~ S 989.05 0,05 '2350.6~ 2128.37 S · '998,78 8~00, 79~.1% 78q. 5,1~ 8500. - 8037.93 7938,9,3 8600. 8131.21 8032.21 20 18 S 16.75 E 20 18 S 16.65 E 21 7 S 16.61 E 8700. 822q.16 8125.16 21 39 8800. 8317.59 821B.59 20 53 8900. 8~11.1~ 8312.1q 20 / 9000. 8503,80 8~0~.80 22 5 ~5.00, 859j~80 8%97~60 21 o~uO. ..... 8690. g300, 678~,t% 8665,!~} 20 ~0 5~0-0~ 9500° 8~72,93 0.~5 2~85.05 2161.59 S 1008.78 E 0,0`3 '2~19.~5 219~.8~ S 1018.72 E 0.81 2~55,18 2229.35 S 1029,02 E -- S 15.90 E S 18,80 E S 19, 1 E 0,59 2~}91.70 1.30 2527.20 0.19 2562.%1 S 17,~6 E -- , 1.~9 S 20.10 E 10!0 S 20.87 E 1,27 S 20,,55 S 2q, o 7 2599.76 267i:09 27'06 ~ 52 22&~.83 $ ' 1059,12 E 2298.58 S 1050,61 E 23~2,00 S 1062.12 E 2=~ oo7.86 S 2~02,5~ $ 2~q.82 S 1073°q0 E 3. O(:q$,OZ; E 109~o°~;,1 E UNION OIL CO~qPANY OF CALIFORNIA ' ' .............................. PAGE 5' '-- .-i WELL NUr'~E GRAYLING G-'2~ MAY ~1976 SURVEY DATE ' F, CA~I'~,U,'~ RIVER V~RTICAL SECTION COHPUTED ALONG CLOSURE .' ALASKA ' SPERRY-SUN NELL SURVEYING COHPANY SU5-1607~ RECORD OF SURVEY -. . .................. 'TRUE ........................ INCLI~IATION- L-DIRECTION DOG-LEG ' RECTANGULAR - ~EARURED VERTICAL SUB-S~A SEVERITY VERTICAL COORDINATES DEPTH DEPTH DEPTH DEG ~IN DEG MIN BEG/lO0 SECTION 9600, 9700. 9800. 9066,87 - 8967,87 20 5 S 22.23 E 1,17 2806.57 93.61.65 9062.65 18 ~5 S 23.97 E 1,60 $255,~-G 9156.~4S ....... 20 16 ...... S 2,3.70 E 1,66 ........ 2873.07 2560.52 S 11~9.~7 E 2569o6% S 1162.12 El -262~,36 S 3.~76.0~ E 9900, 10000. 10100, 10200. 1O3OO° lOqO0, ~3~9,33 9250°33 20 10 S 22.83. E 0,32 9~3.05 95~.05 20 25 S.25o37 [ 95~6,52 9q37,52 20 q9 S 22.86 E ~630.2~ 95~1,2~ 20 25 .... S-22,56 E 0.~1 972S.28 9G2q.28 21 30 S 22.18 E 1,09 ~815.35 9716.~$ 25 0 S 21,17 E 2907,5~ 29~2,~2 2977.95 3012o83 ~088,~8 2653.1~ S 2665.16 S 2717°91 S 1189.~0 E 1203.2~ E 1217,05 E 2750.12 S 1230,~;3 E 278~,06 S 12~.~,27 E 2820.50 S 1258,38 E .. THE CALCULATION PROCEDUR£S ARE BASED'ON THE USE OF THE TANGENTIAL OR CHORD METHOD EHORIZONTAL DISPLAC',-~NT = ~088,~8 FEET AT SOUTH 2~ D£G, 2 MIN. EASTITRUE) FOR irli . ill 'ii .... . .'~ . , , RADIUS OF Cb~VATU~E TYPE, OF SURVEY: Oyroscopi~ SURVEY DEPTH: FROM O L'E~.~E:i. I Tradin~ 'Bay Unit F~EB:): NaAr~hur River FT. TO lO;hO0 FT. I ,WELL NO. O-2h COUNTY/PARiSH, Xena[ ?enf~Ds',:la ~?orouFh STATE ~ 0~ -. DATE OF SURVEY Ma.V a, ~,, .JOB NO. s~13-16o7)~ AnchoraFe, Alaska 27~-6d76 OFFJOE: SPERRY-oU4 WFLL SURVEYING CO~tPAIJY PAGE 1' ' ANCHORAGE' ALASKA U~ION OIL COF~PANY OF CALIFORNIA DA~5 OF ~UKV~Y .AY GRAYLING G-2~ CO?iPUTAT!ON DATE SURWEL GYROSCOPIC MUI. TtSHOT SURVEY FiCARTHOH RIVER ; F~AY 10~ ~97& . ....... dOB ALASKA KELLY 8USH]NG LLEV, = 99,00 FT. TRUE SUB SEA COU~,~E cOURSE DOG-LEG TOTAL ~ 'T "~ ~' TANGULAR ~EASURED VERTICAL V~R ICAL INCLINATION DIRECTION o~.VERI TY REC . cOORDINATES VERTICAL ........... ~ N ..... SECTION DEPTH D~PTH DEPTH ...... DEG HIN DEGREES DEC/IOO ORTti/SOUTH EAST/WEST . 0 O,O0 -99,00 0 0 8 O, 0 E 0,00 0,00 0,00 0,0. 100 99,99 0,99 O ~O S 17.32 E 0,33 0,27 S O.O8 E 0.28 200 19~,99 I00,99 0 7 S ~7,30 E 0,23 0,62 S O,2q. E 0,67 300 299.99 200.99 0 12 Fi 70.2~ ~ 0,51 0o65 S 0,15 E 0,6q. ............ ~00. "~9~o99 .... ~00o99 ........ 0 -[8 - S 68~82 W ........ 0,19 ......... 0,67 S .............. 0'2~ W ................ 0.5~ DO0 ~99o99 600 ~99o99 700 699,98 800 799,98 900 899.97 ..... lO00 .... 99¥,97 g00.99 0 20 S g5,91 W 0,1~ 0,97 S 0,69 W 0,60 500.99 0 25 $ g5,16 W 0,08 1,~q S 1.15 W 0,8~ 600,98 0 ~8 S 3G,51W ' 0.16 2.09 S 1,70 W ' 1,2I 700,98 0 ~2 S ~,33 W ' 0.15 2,92 S 2,~2 W 1,68 800,97 O' 25 S ~.~0 W 0,30 -' ~,66 S ~,05 W 2.10 900.97 ...... O 22 S ~0,71 W 0,07 ............. q,21 S ..... 3,~6 W ...... 2.q5 1100 1200 1300 lqO0 1500 .... 1600 1700 1800 1900 2000 2100 - -2200 2300 2qO0 2500 2¢ 270 O 1099.96 1000.96 0 ~9 S ~1.19 W 1199.96 1100,96 0 ~6 S 15, 2 W 1299.95 1200.95 O 15 S 70,82 W 1399,95 1300.95 0 21 S 13.1~ W lq99.gq lq. O0.gt~ 1 5 S ~7, 5 E 1599.8~ ' 1500.86 3- 8 S 50.9~ E 1699,59 1600.59 5 5 S 6.3,62 E 1799.05 1700,05 6 ¢~.~ S q9,90 E 1898,12 1799.12 8 45 S 39,i.'.6 E 1996,~6 1G97.66 lo q3 S 58.77 E 209q G2 1995,62 12 2G S ~8,5G [- 2191~95 2092,9~ 1~ 10 S ~¢oo~99 22SOeq-1 2169,41 16 15 S ~%,95 E 2~7~:..23 2370.23 20 q-2 S 52.87 E 25'/1..09 2~;.-/2'.0'¢ 22 50 S 52:55 E O.q5 q.99 S 0.$8 6,03 S ' 0.50 ....... 6.6! S 0,30 6,98 0.95 7,92 2.05 ...... 10.29 2.iq 15,9G 2.17 19,69 2,~5 29°3% 1.97 q2. ~,~6 1,71 58,13 1,77 76.52 ~,15 97,5'~ 1,89 12!.07 2.51 i~9.56 "' '2 ~ ].3 I&0~76 ~.lq W 2,87 %,79 W 3.57 ' 5,08 W 3,96 5.36 W ~.7q W 5.30 1.92 W 8.6 q,16 E 12.62 E 25.15 2t.9% E 35.7q 32.60 E 52~07 q5,15 E 59.20 E 93,55 SPERRY" q'i i,~'~ %-,iELL $ijRV£YING COPiPANY b~,"-~- 2 -.~ ~ r ~-~ -- . NiO['; O~L COPiPANY OF CALIFORNIA DATE OF SURVEY ~AY 8~ 1976 RAYLING G-2~ CO~'4PUTATION DATE 8URWEL GYROSCOPIC ~iULTiSHOT SURVEY CAATHUR RIVER ~'- ................ ~ HAY ~0~ 1976 dOB NU~qE~ER SU3~1807~ LASKA KELLY BUSH N : 99 O0 FT Ii'G ELEV. , , TRUE SUB-SEA COURSE EASUR£O VERTICAL VERI'ICAL INCLINATION EPTH ......... DEPTH DEPTtt ........ OEG 'MiN COURSE DOG DIRECTION SEVE DEGREES DEG 310 520 3qO ~50 ~70 390 qO0 ...... q20 q500 ~600 -- ~700 ~600 ~900 ' 5000 5200 5300 5~00 5500 5700 6!C 0 0 0 0 0 . 0 - 0 0 0 0 0 0 0 0 5026.7q 2927,7~ 25 5 3117.13 ~018.~ .... 2555 5207.~! 3297.0& 5q77,76 5566,61 ~ 85 3~z9, 5751.qq 58q5,~6 ~935,81 ~121.55 ~30~.66 3108,I! 26 8 5198.06 25 ~288.28 .... 25 25 ~378.76 25 0 ~q69.61 2~ 24 ~5&0.~5 25 55 5652.q.q 25 2~ 57qff.q& 22' " 3836.81 22 27 5~29.q9 21 40 ~022,~g 21 16 q209,66 20 5 S 51.15 SSI. 6 $ S 29.89 S 29.80 'S 29.7~ S 29.~3 S 29.15 S 28.90 S 29.29 S 29~23 'S 28. ! S'27,25 qq02,82 ~59D,69 q683.90 q777.50 q871.25 q. 965.9i 5060,95 5155,69 ,,o .~-,,. 09 57~ ' %SOp ~$03.82 19 15 S 27,20 qSgO.Ot~ .... 1~ 55 S 28.8, ~q91,69 21 6 S 30, 0 L~58~.90 21 23 S 30.92 .&78.30 20 28 S 50.92 q772,~o 19 $5 S o0~89 o~ t8 '0 S 30,91 q666~ 505o,o~ i9 5 S 5150~76 20 28 S 27,75 5j:q, 4 ~ 09 21 q,O S 27.37 " 9~ '" E' 76 5~3.~, ~ 6 ~:~ .... 4',' , 26. Vt ." = :..~, -'. ', l, ¢'i , ,-, -is' .-- .; ~ -, -'LEG TOTAL RITY RECTANGULAR COORDINATES VERTICAL /100 'NORTH/SOUTH ...... EAST/WEST .... :-' SECTION' E O, E O, E O. E O, E .......... O. E 0,73 E 0,60 E 0,~8 E 0,53 E 0.72 E ....... 0.25' E 0,79 E 0,~0 E ' 0.72 E 0,65 E 0.83 E .... 0.86 E 1,25 E 0.~3 E 0.91 E 0.88 ~.:¢ E 1,u6 £ 0,26 0,96 E "-:'1.09 E 'O~Tb 85 355.02 S 259,25 £ q21.72 50 391,6& 'S 261,55 E q6%.19 69 q29,2i S 263.53 E 507.-2 31 .........503.7S $ ............328.00 E 593.7~ 6q7.10 S "651.2q S '71q.79 S 7q7.61 $ 779.5% S 810.95 $ 841.81S 871o73 S 5qO.~ S 3q9.68 E 636.05 576,68 S 370.~7 E 677,65 " 612,21 S' ~90,79 E 718,35 q!0.61E 758.29 q29,76 E 797.27 "qqS,3S E 6~5.50 ~66,6~ E 501,67 E 517.63 E 533.22 E 901.32 S ....... 5q8,97 E 951.52 S 566.!9 E 963.05 S 58~.56 E 993.69 S 602,91E 1023,07 S 620.5(! 1050.71 S 637. Oq. 1077.3G S 655,0,.3 110z~,97 S 669,26 i~34.66 S 6L~.3. ~; 7 ~' 872,91 909.35 945,03 979.79 lO13.qO lOq, 6,83 1081.71 11!7.71 1153,!7 1187.17 1219.15 1250.02 1281.83 1309,!6 i b O 5:, ~-;. 4 . . .. SPERRY,~,SUil {4ELL SURVEYING COMPAD,JY PAGE AN~t"~O~A~E, ALASKA NION OIL cOMPANY OF CALIFORNIA DATE OF SU;~VEY MAY 6, 1976 RAYLIMG 0-~% COMPUTATION DAI'E SURe, EL GY~,O~COFIC fIULTIS}tOT SURVE CARTi!UR RIVER NAY 10~ 1~76 OOg NU~%~,ER SU3-I~07~ LASKA KELLY BUSHIr46 ELEV, : 99,00 TRUE SUB-SEA COURSE coURSE DOG-LEG TOTAL EASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES EPTH DEPTH DEPTt4 DEG HIN DEG,EES DE5/100 NORfH/SOLITH EAST/WEST 6200 5895.83 5796.85 20 26 S 16.5~ E 1.25 1377,85 S 799,40 E 6300 5989,57 '5o90."~ 57 .... 20 20 S 17,81 E 0,~5 1~i1.11 S 809.68 E 6400 6085.12 5984,12 21 ~ S IG.5~ E 0.86 1q~.88 S 820,11E VERTICAL .... SECTIOR 158~,84 '~ 62 6500 6176.~5 6077.~3 21 5 S 16.!5 E 0.15 1679,59 S 830.22 E 1689,3~ 6~00 626~.65 6170,65 21 20 S 15,9! E ........ 0,8~ ...... 1514,32 $ 839,60 E 1725.06 6700 6562,50 6263,50 22 15 S 1~,32 E 0,92 1550,32 S 848,66 E 1761o63 6000 6q55,!1 6356el1 22 5 S 13,91 E 0,22 1586.91 S 857,86 E ' 1798.79 6900 65~7,72 6q~8o'72 22 16 S 15,58 E 0,25 1623,58 S 866 8]. E I ~*' 92 7000 66q. O.!8 6541,18 22 30 S 1~,10 E 0,31 1660.55 S 875.91E 1873,39 7100 6752,71 6633,71 22' 4 S 1~, 5 E O,q'3 1697,53 S .885.13 E i910,7% - ' 0~' - ,! E 19q'7.55 7200 o8~0,~6 6726o~6 ' 21 51 ~ S J~S,85 E 0,22 1735.62 S '- 89% q 7500 6918,35 6819,~5 21 ~7 S 1~.37 E 0,30 1769,53 $ 905.~7 E 198%.02 7~00 7011.!9 6912,19 22 0 7500 7106.26 7005,26 20 55 7600 7197.81 7096,81 20 27 7700 7291,53 7192.55 20 23 'TaO0 7385.28 ' 7286.28 20 20 7900 7~79.08 8000 7572.82 6100 820U 7768.06 6300 7fiT, 3, · 6%00 79q. 7,31 8500 :-. ~ ~ '~ ~,'/00 8227,75 7380,08 20 15 . 7q. 73o82 20 30 7567,46 .20 35 7661,06 20 775 t'... 6q- 20 qO · ~1 7i3a 8 ~., . 7942,~0 20 15 8055,6q, 2i 7 ~:.!2S~76 13.98 E 0.40 1605.55 S 9~2.27 E 2020,62 1%.S6 E 1.09 l&~;i. O2 S 921.22 E ' 2056.65 S'1~,.$3 E 0.46 1875.2~ S 929,97 E 2091,47 14,35 E 0,06 1909.0~ S 938.61E 2!25.g5 16, 2 E ' 0.58 '19~2e61S 9q7,72 E 2160,22 S I%,12 E 0,66 1976,09 S 1~}.59 E 0,2& 2009,8% S 15.85 E 0.51 20%3,71 S 16.1~ E 0,!1 2077,5% S 16. 0 [ C.05 211!.kS S 16.75 E 0,~i-5 · 2!4-5,00 16,65 E 0,0:3 2!70,2~ S !8.61 E Oog! 2212.11 S 2.5,90 E. 0,59 22~:7,i2 S J,$,SO E "' ~,o50 22.0J,,,75 S I-D, ! E 0~j,9 " 956,7~ E 219k,q7 ~'~-~-~ E 2228°77 9 7"-i-, q. ~:~ E 2263,45 9¥o, 9Z, E ~ooo, 2J. 1003,79 E 2587,88 10~,5,76 E 2~i-02,29 ~-023,o,-, E 2q'o7,ou L.:I -e ~,j · . __ SF~r,,~, ~ -.qU~'..,,~ . ELL our~ .......... vt., ~ .... COMPANY ANC~O~AGE~ ALASKA ' UNION OIL CO;~PANY OF CALIFORr~IA DATE OF SUr~VEY NAY B~ 1~7~ GRAYLINL~ G-2~ CO~PUTAT[ON DATE ~'~ GYROSCOPIC ~tULTISHOT SUF:tVDY ~CARTHUR RIVER MAY lO, I97~ UO~ ALASKA KELLY BUSHING ELEV. = 99.00 FT. ~EASURED DEPTH TRUE SUB-SEA COURSE COURSE DOG-LEG TOTAL VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH ...... BEG MIN DEGREES BEG/lO0 NO~TH/SOUTH EAST/~EST .... SECTION 9~00 9500 9600 ......... 9700 9~00 9900 10000 101o0 10200 10~00 lOqO0 8787,q5 8688,4~ 20 ~0 S 20,55 E 0.~6 2451,57 $ 110~,61E 2688,7~' 8081,36 8782,~6 .... 19 26 $ 21,25 E 1.25 2q. OS,qO $ 1116.85 E 2722.97 8975,77 8876,77 19 5 S 2~, 7 E 0.99 2515,85 S 1129,52 E 2755,95 906~.98 $970.98 20 5 S 22e2~ E 1.17 25~.65 S 11~2,68 E 2789,q~$ 916',$3 9065.~$ ..... 18" ~5 '-$ 23,97 E 1.60 -'-2575.11S ' 1155.65 E .......... 2622.53 9258,65 9552.47 9qt~6,26 9726,~ 9159,6~ 20 16 S 25°70 E 1,68 2605.53 $ 1165,09 E 2655.79 9253,%7 20 10 S 22,81E 0.~2 2657,27 S 11&2,73 E 2~90,~ 95~7,26 20 25 S 25.~7 E 0.51 2669.1'7 S 1196,$5 E 2925,01 9qqO,SS 20 ~9 S 22.86 E O.q~ 2701.56 S 1210.15 E 2960.22 95S~.q5 2U' 25 S 22.56 E 0.~1 27~4.0q S 12~S,75 [ 299~.q2 9~27.8S .... 21 ~0 S 22~18 [ .... 1,09 2767.12 9720,~8 25 0 S 21,17 E 1,Sq 2602~50 S 125!,$5 E 5069,00 ....... HO,~qIZONTAL DISPLACE~qENT : S069.00 FEET AT SOUTH, 2~ DEG. $ ~:IIN. EAST AT ,~':D = 10~00 TIlE CALCULATION PROCEDUHES ARE BASED ON l'ttE USE OF THHEE DIFIENSIONAL RADIUS OF CURVATURE HETHOD. UNIO~J OIL COi'~PANY OF CALIFORNIA 6RAYLti:!G G-~q- HCARIHU,R RIVER HAY 10, 197.5 ALASKA . . .. SPERRY-$U~I WELL SURV£YING CO~iPANY PAGE.- 5 DATE OF SUEVEY [qAY e,~ 1976 COPiPUiATION, DATE SUR'-'-. ~cL ¢~vPn~:rn°IC~ -,,~o~, FiULTI SHOT SURVEY. KELLY ',: e = 99 O0 FT. uUcHiNG ELEV, ALASKA ......................................................................................... KELLY BUSHf~';:,,,~ ELEV, = 99,00 Fl', . . I~TERPOLATED V.,LU~S FOR EVEN ZOO0 FEET OF MEASUR£D DEPTH TRUE SUB-SEA TOTAl,. MEASUREO VERTICAL VFRTICAL R~:,CTA~,~uULAR COORDINAI'ES F]D-TVD VFRTICAL DEPTH DEPTH DEPTH NC)kilt/SOUTH EAST/WEST DIFFERENCE C ''~ Ot, RECTiON 1000 2000 3000 ~000 5000 .... 0,00 ...... ;-99,'00 ......... 0'00 .... 0.00 O,O0 999.97 900,97 q.2l S ~.%6 ~.,,! '0.02 0,02 1996.66 1897.66 q2.~6 S 52.60 E ~.3~ 5,30 2956.09 2857.09 ' 51g~07 S 217.15 E 63~90 60.57 38q, 5,t~6 37~,t~G 681.24 o N29.7' E 156 53 92,6~ %777.50 %678e30 '99~,G9 S 602.91 E 222,-69 66.16 5611.q~ ' ' 1507.8& S ' 775.15 E 6000 5710.~q, 7000 66~0o18 65~,~!.J, 8 1660.,;,u S 875.91E 8000 7572,82 7~73.82 2009~8~; S 965.3i E 9000 &SOT.Sq. 8q. OC.$ff 25q-9095 $ 1067.76 E lO0,JO ~q. 6.26 95~,~7.26 2669.17 S .1196,55 5 lCqOO 9819.38 9720.38 2602.30 S 1251.33 E 289.55 359.81 70.25 ~27.17 67.56 ~92,~5 65~28 ...... 555.75 580.61 26.88 .... ¢ .... ' ~',AL RADIU~ OF CUi:.;VATURE f1ETHOD, TtiE CAtCL!L~.TIO?,] P F, OCEOU,~,LS ARE BAboO ON THE USE OF TFi~::EE DIm~NSIO*~ ~ ' iN!ON OIL J:~A YL I J'~G iCAKI"HUR LASKA SPERR¥-SU.N WELL SUHVEYING CO~4PANY PAGE- 6 ANCHORAGE~ ALASKA , DATE OF SURVEY HAY 8~ ~976 CO~IPAN'~ OF CALIFORNZ~ ,- e ~ G-2~ COPiPUTATION D4TF 8URF~L GYRO COPiC MULTISHO'f c, URVEY RIVER ..................................................................... MAY i0, 1976 dOB NU~:':~S-R SU~-iG07~ .................. KELLY BUGH1NG ELEV. : 99.00 F~. FEET OF SUB-SE^ DEPTH INTERPOLAT£D VALUES FOR EVEN i00 ............................... TRUE ....... SUB-SEA ................... TOTAL ,EASURED VERTICAL VERTICAL RECTANGULAR CO0~-IOI NATE MD-TVD VERTICAL EPTH DEPTH DEPTH NORTH/$OUI'H EAST/WE:ST OIFFERENCE CORF~ECTION ..... , , . 0 O.O0 ;99.00 0.00 99 99.00 0.00 0.27 199 ..... 199.00 -100.00 ............... 0.62 299 299.00 200.00 0.65 599 39~.00 ~O0.OO 0.66 ~99 ~99.00 ~O0.'O0 0.97 599 599.00 500.00 1,~3 699 699.00 600°00 2,08 ........... 799 .... .799.00 700.00 2.9! ~99 899.00 800.00 3o~6 999 999,00 900.00 ~.21 1099 1099,00 1000.00 ~,98 1199 1199,00 1100,00 6,02 1299 1299,00 1200,00 6,61 1~9 ' 1399.00 1500,00 ......... 6.97 1599 1599,00 1500,00 ]0.2~ 1699 i699,00 1600eGO 1~,94 1799 1799.00 1700,OD ..19o69 0,00 0,00 0,08 E 0o00 0,2N E 0.16 E 0o00 0.00 0.2q W 0.00 0.69 N 0.00 0.00 1,15 W 0,00 0,00 1.70 W 0.01 0,00 2,q2 W 0o01 ...... 0,00 ~.05 W 0.02 '0o00 3.~6 W 0.02 0.00 q.l~ W 0.03 0.00 ~.Tg W 0.05 O.O0 5.08 W 0.0~ 0.00 5,36 'd ..... 0.0% ......... 0.00 ~,75 W 0.05 O'.O0 1,96 W 0,13 0.06 ~,12 E 0.~0 0.27 12,62 E 0,94 SPERRY'"SU¢'.i I~.IELL SURVEYING '"n~:':~'~''~v PAGE 7 ANCHORAGE, ALA"K -~ "- .... ' Jr..~IO~:~. OIL COFiPANY OF CALIFORNIA DATE OF SU~-~VEY ~-iAY 8, 1~76 ~RAYLING G-2q CO;~iPUTAT~ON DATE SU~x~.,EL GYROSCOPIC ~.~ULTISHOT~r.°'l'"'~"~.q,~_ ~ .~C.~R~HLI-~ R~V~N MAY ~0, ~76 T-dOG F;U;'"i~[LR SU~6OTff ......... ' ..... ALA2KA KELLY LUoHI G ELEV, . INTERPOLA ......................TRU~.I ~ ........... SUB iqEASURED VERTICAL VERTI DEPTH DEPTH DEP I'EO VALUES FOR EVEN'lO0 FEET OF SUE~-SEA DEPTH · SEA ......................... TOTAL CAL RECTANGULAR CO0~OINATES P!D-TVD V£RTICAL " TH NORTH/SOUTH EAS~'~'~''T i ~' · .~o- DIFF~R~,'~CE COR~ECTION 1~00 1899,00 2002 1999.00 1900,00 .... 210q 2099.00 2000,00 2207 2199,00 2100,00 25~1 229~,00 2200,00 2~15 ~39-~,00 2000,00 252'2 24,99,00 2qO0,O0 2GSO 25~,00 2500,00 2739 269~,00 2600,00 28¢-~9 279~,00 2959 289~,00 2800.00 3069 2999,00 2~00,00 5~7q ~09~ O0 5000 O0 3290 5199,00 5100.00 3~02 3299.00 ~200, 3512 3B9~,00 3~'00, 3623 3q99.00 3733 35~9,00 ~500, 38~;2 ~69~.00 ~600, O0 O0 O0 O0 O0 29,q5 S 22.05 E ~2,8& S 32,88 E 58,88 S ~5.73 E 77,75 S 60.28 E 100.09 S 76,35 E 126,01 S 9~,2i E 156,!5 S 11~,05 E 190o66 S 1~6,15 E 227,70 S Z59,75 E 265,82 S 165.75 [ 50%,5! S 208.05 E 3~.~5,90 S 232o5~ E ~8~,25 $ 25~o87 E q25,77 S 28io5~ E ~67.65 S 306,J. 9 E 508o5~ S 330,89 E 5t~9,02 $ $5~o61 g 580,6~; S 377,32 E 627.27 S 359,q0 E 1.88 3,3'1 5o~7 ........................ 2,10 8,28 2, 12,02 16,87 23.19 6. 31,28 8, 50,18 9, 60,12 70.~6 80,89 10, 91,95 11, 105,18 ...... 11' 115,96 10. 12~,65 10, 13~.36 9, 1~3,6! 9. 80 73 85 OS 21 68. 55 05 82 ~5 JNION OIL. CO,rqPANY OF CALIFORNIA 3P, AYLI?,~G G-2~ COJqPUIATION DATE qCAP, THUR RIVER ~iAY 10, 1975 ~LASKA ~EA.UREO SP~zRRY SUN N~LL SU~VEYING CO;~PANY PAGE 8 ANC H""'u r,~,.', :.' "'~', ALAS~'~ DATE OF SURVEY MAY ~ 1976 SU,-,W~L GYROSCOPIC HULTISHOT SURVEY .............................. -dOG NUF;o~'R SU~-1607~ KELLY DUSHI~'¢'~,~o ELEV, : ~9,00 FT, _ INTERPOLATED VALUES FOR EVEN 100 FEET OF SU~-SEA DEPTH ............ TRUE ......... SU~-SEA ........................................ TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTZCAL DEPTH DEPTH OEPTH NORTH/SOUTH ~951 ~799.00 3700,00 66~,96 S q060 3899.00 ~800,00 701,~G S ~168 ~999.00 ....... ~900,OO .......... 757,~9 S 4275 q099.00 ~000.00 77106~ S ~302 ~199.00 ~100,00 605o6~ $ ~595 q$9~.00 ~00,00 .870,55 S g702 ~9S,00 ~q. O0,O0 ~01,9~ S ~608 q59~.00 ~500,00 9~o60 S q916 ~69~.00 ~600,00 968,12 S 5025 ~79~,00 ~700,00 lO00,6q S 5129 ~89~,00 ~GO0,O0 .1051,5q. S 52~ q999,00 ~900,00 I059,9~ S 55~0 509~,00 5000,00 10~5.09 $ "56~5 5199,00 5100,00 ' lll6,Og S 5552 5299,00 5200,00 1151,05 S 5660 5599,00 5S00,00 115~,q. 5 S 57~o ~acq O0 5~00 O0 122~,0~ S 587'7 559~.00 5500,00 1262,9~ S EAST/ WEST DIFFERENCE R l COR ECT ON ~20, ~60, ~80.2~ ~98.85 516.21 5~2,61 549,32 567.79 587.60 607,07 '625,5g 6~2,56 659,5~ '' 676,66 69~.08 712,$7 750,9~ 67 E 152,78 6,96 03 E 161,16 8,38 90 E .......... 169.26 ............................. 8.09 176.79 183.97 190.71 196,94 203.06 209,89 217.21 224.15 250,~ 235.78 2~1.05 2q6.85 255,57 2G~,22 270,80 7.53 7.17 ''' 6.73 6.2~ 6.1~ 7.51 6.9~ ~'' 6,29 5.53 5.27 ...... -6.72 7.6q ~.5~ 9,06 ._ P~.R,,-,,Y-oU~,J WELL SURVEYING COMPANY PAGE .......... ANCHOE<AGE, ALASKA ur., OIL CO;'iPANY OF CALIFORNIA DATE OF SUR~J~Y MAY 8, 1976 GRAYLING G-2~ CO~qPUTATION DATE SURWEL GYROSCOPIC HULTISHOT SURVEY 'HCARTHUR RIVER MAY ZO~ ZgT6 : dOB NU?;~ER SU3-~07~ .... ALASKA KELLY DUSHZUG ELEV. = 99.00 FT. INTERPOLATED VALUES FOR EVEN &O0 FEET OF SUB-SEA DEPTH _ . TRUE .......... SUB-SEA ...................... TOTAL MEASURED DEPlH 5987 , ,,' 6090 6203 651U 6q17 652~ 6631 6739 68q, 7 6955 7O63 7171 7279 7G~1 77o7 7~ 7~2L VERTICAL VERTICAL RECTANGULAR COORDINATES MD-I'VD VERTICAL DEPTH DEPTH NORTH/oOUTH EAST/,,~E ST DIFFERENCE CORRECTION 569~000 5799,00 589~.00 5999,00 6199.00 6299,00 6~99,00 6699.00 6799,00 689~.00 6999.00 709~.00 719~,00 7299.00 7~99.00 7q99.00 5600.00 1~03,17 S 5700.00 15~2.49 S 5800.00 ....... 1~7B,96 S 5900,00 1~1~.~3 S 6000.00 1~50.7q S 6100.00 1%87,7q S 6200.00 1525'~4 S 6300.00 156~.78 S GqO0.O0 '160~.21S 6500.00 1644.01 S 6600.00 168~.07 S 6700,00 1723.32 S 6800.00 1762.10 S 6900,00 1800,77 S 7000.00 ' 1839,07' 5 7100.00 1875.67 S 7200.00 1911.75 S 7500,00 19~7,~9 S 7t~00.00 19a5.22 S 770.7I 788.12 ..... 799.7~ 810.75 821.85 832.6q 842.$5 852.55 862.15 871,76 881.81 891,60 901.27 911.0~ 920.72 930.0g 939.30 949,12 955,53 288.q0 9.59 297.29 8.89 30q.57 ............... 7.07 ~ll.O~ 6,67 ~18,01 6.96 ~25,18 - 7,].7 352.49 7.31 ~qO.~2 7.92 356.q2 8.06 36~.6! 8.19 372.q8 ' 7.87 ~80.17 7.69 ~87,84 7,66 ~95,56 7.52 q02,26 6,89 ~0~,95 6,70 ~i5.62 6,~5 q22,25 6,60 ',iIOH OIL cO?'iPANY OF IAYL I {',~G G.,- 2 ~ 'ARTHUR RIVER SP£RRY ........ -oU~<~ ~'~r. LL SURVEYi~',~G COMPANY PAGE IO- ANCHORAG[, ALASKA -. CALIFORNIA DATE OF SU~VEY RAY 8~ ~976 COb'~PUTATION DATE SURUEL GYROSCOPIC ¢~iULTISHOT SUj-~VEY' MAY lO,' 197& .................................... dOG NUb~ER SUE-I&07~ KELLY BUSHING ELEV, : 99,00 F~, INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ................... TRUE ........ SUB-SEA rASURED VERTICAL VERTICAL :'PTH DEPTH DEPTH . 8027 759~.00 7500,00 81~ 7699,00 7600,00 --82A. 1 ' '779~.00 -'7700.00 85q8 789¥.00 7800,00 8q55 7999,00 7900.00 8561 6099,00 8000,00 8669 ~199.00 8100.00 8776 8~9~.00 8200.00 '-- 8503 G399.00~ 8300.00 8990 6~97,00 8qO0,O0 ~098 659~,00 8500,00 9205 8699.00 8600.00 9512 87~9.00 8700.00 9q18 88~9.00 8800.00 ~52~ '- 8999.00 8900.00 9650 909~.00 9000,00 97~6 9199.00 9100.00 98q~ ~299.00 9200.00 99q9 9399.00 9300.00 ...................... TOTAL .................................................................................................. RECTANGULAR COORDINATES MD-TVD VERTICAL NORTtI/SOUTH EAoT/,~EST DIFFEREr~CE CORRECTION 2019,31 S 967.74 E ~28.9q 6,71 2055.q6 S 977.80 E q35,75 6.80 209!,62 S 988e2~ [ ~2.60 .................. 6.6~ 2127,8~ S 998,65 E ~¢,~6 6,86 2163,31S 1009,29 E 956,10 6,63 2190,92 S ~019.9~ E ~62,78 .... 6,68 223~,!, S ~030,95 E ~70005 7.26 227S.80 S 10q2,i8 E 2509.80 S ~05~.q8 E .... ~8~,q9 ................. 6'99 23q6.65 S 1066.7~ E ~91o78 7.28 238~.6q S 1079.55 E q99.52 2~20.4-~ S ~092.92 E 506,58 -- - 7.06 2q55.*~6 S 110~.1[~ E 513.56 6.77 2q89,20 S 1.119,08 E 519,69 6,33 2521.17'S .... 1132.80 E 525.58 ................... 5,88 255!~.q7 S 11q6.70 E 531,89 6,31 2585.76 S 1160.39 E 537,57 5.67 26!9.&7 S 1175.07 E 5q~.03 6°~5 2653,0q S 1169,58 E 550,57 6.5~ SPERRY-SUN WELL SURVEYING COMPANY PAGE-ll ................................................................ ANCHORAGE, ALASKA .................................................................. JNIOf~ OIL cOMPANY OF CALIFORHIA DATE OF SURVEY HAY 8, 1976 SRAYLING G-2q CO~iPUTATION DATE SURW£L GYROSCOPIC ~ULTISHOI SURVEY ~CARTHUR RIVER MAY 10, 1976 ......................................... dOB NUMBER SU3-1GO7~ ALASKA KELLY BUSHIHG ELEV. = 99°00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ........................... TRUE ---SUP-SEA .......................TOTAL ~EASUREO VERTICAL VERTICAL RECTANGULAR COORDINATES ~D-TVD VERTICAL '}EPTH DEPTH DEPTH NORTH/SOUTH EAST/W~$T DIFFERENCE CO,R~CTION 10056 9~99.00 9q, O0oO0 I0165 9599.00 9500.00 10270 9699.00 9600.00 ~0577 979~.00 9700,00 10~00 9819.35 9720.38 2687.26 S 120~.I2 E 557.29 6.7! 2722.20 S 121~,~5 E 56~.23 6.9~ 2756.96 S 279~,2~ S 12~8,21 E 578,85 7,77 2802.~0 S 1251.33 E 580.61 1.76 THE CALCULATION PROCEDURES USE A LI~JEAR IHTERPOLATION F,]ET~'''-'''~,,;r.,,r_,,~ THE NEAREST 20 FOOT ;'lB (FROf'q RADIUS OF CURVATURF~) POINTS SPERRY-SUN t4ELL..$URVEYiNG COMPANY PAGE 12 ANCHORAGE, ALASKA UNION OIL COHPANY OF' CALIFORNIA DATE OF SURVEY HAY 8~ 1976 ERAYLING G-2~ CO~qPUTATION DATE SURWEL GYROSCOPIC ~iULTISHOT SURVEY ~'iCARTHU~ RIVER HAY ~0~ ALASKA KELLY bUSHING ELEV. : ~9.00 FT. INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS .................. Ti{UE ............SUB-SEA MEASURED VERTICAL VERTICAL REC'TANGLILAR COORDINATES DEPTtt DEPTH DEPTH NORTH/SOUTI! EAST/WEST MARKER G610 6276,97 6179,97 1517,85 S 8q0.~7 E POINT 76iq 7210.95 7111,9~ 1879.98 S 951.18 E POINT ......... 892:8 8~0,G2 ' 83~,62 92~! 8732.21 86~,21 97q. 2 920q,lq 9105,1, 2587,34 S 1161.09 [ POINT , ' ~' ~ 9~ S 12M~,21 E POINT 10270 9698 92 9599,92 b C P T t-I D g P T i-I . _ O~ O~O0 -99~ O0 lOOo 99°99 0~99 200, 199o99 100,99 1200e 1199o94 !200o9~ 0 2G 0 1'~ 0 16 0 0 0 0 q'O ! 5 ,5 20 ' 5 .2::, VERI!CAL. Cu~, ~,DiNAI'ES O,OS 1~!9 S I,,C,! H O,~$ I~62 S 2o00 W 2 ~ 6., W S .'c~ R~.CO~',D OF SU?.VEY SL o ~ DE 2 q, 00o VE ~q T i C A L D E P'i'H 25~0 ~GG 247;~ ~ 02 25GG~07 D E P T 2375~02 !8 ~O S ~5~6 E 21 0 S 52°95 E 25 0 S ~n ~S E S?VE!';ivTY DEg/&OO 2~01 ~,,, -.CLL 170~ . 206 o T5I COORDi 75 S 96~59 ~' 1!6~07 27 29 00. 00o 2657 ~ t-;-9 26S9 ~ 55 65 S .t. 60 ~ 29 U 202~05 E 5! 00~ ~;-5S. 67 65 00o tjO ~ ~0~ ..... ~, S ~0~ - - ,', 7S t-,, , c -o32°75 25 ~'* " 92 E O~ o~ ~8 627 90 SST~!G E 00~. 00~. O0 o 55'J, ~.;. ~ 79 670~0:: 75!o97 t-;,- 5 7O 559~2J. E 2 S '-:" '-' ¢,.o S SO~L, 3 E 0 0~'~ 79 '~ v S "-' 0 * , 6,'50 ~ ::>7 L"::, & g 0 o 5' RECO,-~D OF' ... KY ~,u,,~..,. AYES HORIZONT£~L DZSPLACEPlENT -'.~J1~,~o57. FEEl' AT SOUTH 51 D~'~-~:.~.,~ 3~,~ f,i~N., o EAST(TRUE) T ............. , ........ ; 4 .i __. , , I FOR RADIUS OF C[FRV~TUilE WELL NO. 0-2)! COUNTY/PARiSH .T(ensi Peninsula 8oro?,~h STATE_______ ~AT~ OF SURWY,, April 20. 1976 OFF~CE: - AnchoraFe~ A~ 27~-66~6 0 tJ. O 0 100 93o .,. 500 29S;~99 2000 5~;~C, 5v "¢, ~i ",' 2:;':.'i ~.: ~.i""3.v ¢ r, 2 ,f:; 08 2. 2 ,'q Y ~ ~:.., (1 ~'" 0 (} ~.' 3'; L ,5 ¢ 5, :: " f' '1 (? ~..- ~' < .. ' . ' C 0 0 0 0 0 0 0 0 0 O 0 0 0 :L .'L 2 ~ .:.-;, 0~25 0 o,!.& 0 ~20 0050 2~23 :. 7, :; ~ '[:,, 5 r .. CO~'~FUTAT!O;,~ DATE TRUE SEcTI 0200 5700 o::o,-~ ~ '-, ..... ?590 (} c E O~ . ' z;''~'~- ~<3 q.:~,-- o.n ZS: -30 S 27025 E 0,71 5 ~ 255~<::: E 62 ,~ ,:~o S ..... ' " 5f1~:L9 S b2b~77 E [;::, 7~ 59 6!,5 6~''' 48 ()C~t , , , . .. h ~ 1~""~.~ .... t h"U ~, ''~ ~ t ~ ~:" ~?v: .... ~r' ,-~r:.. :,, .. L 2. '::' ~ ..:976 'dO~ ~'~,..~?~o~z h~'~ ........ "" E':~ 3 ~.' "' ' ~ ~':~.:, u ~.~ ALASKA ,,r-,--) VERTZCA~ VEF~TiC~.~ Rt'-'C-T~:r'~C, LILAR COO-'[:~"ff, '~ ' A VL, hTIC L SE'..,.5 ['i L)" T V O .. TF:UE SUB- F*' ~' '"'; '" '" V E R T i t. znour~r_u VERTICAL CA 2207 2611 229U~00 2200~80 <~.. 25 2a ,-.o ,, 0 2050 27~s~00 2. YoO ~.OO 2SSO 2G9~,00 2800.00 3070 299s~00 2OO0~OO ~101 309'~ O0 ~;O00~O0 VALUES FOR E T REC-f ..... ~: UL ~,, NORI'H/SOUT 62~21 105,27 162~76 I97~7! q-7 :':, ~ ¢,~ YE" '~00 FEE'f OF S " S q, 2 ~ [-;9 E 5,63 S '56 ~ 8U E 8~66 S 72089 E 12~57 ,- ~ :: S 156~56 S 229~ 23. S 279~0':-,- E S3~55 S 3~?~....'':"' ~b E I3.5,77 S 55:6~77 E '"'~ 52 COn,," ?~ ~: A S U ,',: D V r~ ,, T: C A L. {: R 'i": C A [ .. 'i"OTAL, - · Ti, I:": NrZ ':" .... ' ..... .,, LJ')u'' TLIr'' . '~'S , Document Transi'hi*'-I Union 0il Company oi (, ~rn~a union DATE SUBMITTED A C C O~J N ~'l N (~ "MON T H"' 6- 3.-76 ,, TO FROM Mr. H, W, Kugler P.. C. Wartl-:en AT State Div. of O~ Anch. " Anch. . TELEPHONE NO. TRANSMITTING THE FO~EOWlNG: U..~ION--~.~,,_.~IN~ BAY UNT~ G- :4 1 ea.2" 1 ea. 2" ~ 5" D~ 1 ea. 2n h 5" S~mltan~us Dual La,terlog 1 ea. 2n FDL-~ ., 1 ~. 5~ Com. paus,ted N-FD Please sign ~ re~rn one copy to ~is offi{ e: ... Date: . .. ,., FORM 369 (REV 2/70) PRINTED IN U.S,A. INDUSTRIES BAROI D D V SI ON Anchorage, Alask~ May 13, 1976 Mr. J. R. Callender, District Drilling Superintendent Union Oil Company of California 909 West Ninth Avenue Anchorage, Alaska 99501. Re: TBUS G-Z4. Dear Mr. Callender: TBUS G-24 was drilled to an intermediate casing depth of 5,115', using a low- solids, Inlet water, CELLEX fluid. From intermediate casing point to T. D. (lO,dO0'), cross-linked XC-POLY~ was added to facilitate hole cleaning and enhance penetration through it's shear-thinning characteristics. This system proved effective in minimizing hole problems normally encountered with Inlet drilling, while allowing high penetration rates. Each component played a significant part in keeping the system inhibitive. Filtered Inlet water was the primary inhibitor by virtue of it's constituent diavalent and monovalent salts. A core s~mple was recovered from a jurJ~ basket x,~n at a depth of 6,]-17' to 6,119'. Pieces of this core sample were soaked in fresh water and filtered Inlet w~ter over a two day period. Within one hour, the sample in fresh water was reduced to a fine powder, while the sample in In- let water maintained it's original form throughout the 48-hour test period. CE~.~.EX, REGULAR, a medium viscosity cmc, was used to control the rate of filtra- tion. Due to the hard make-up .w~ter, the concentration of cmc needed to bring the filtrate within program specifications was two to three titles the recon'~ended amount. It is theorized that this quantity of cmc ~s sufficient to prevent capillary invasion and subsequent hydration of formation clays through a coating action on these clays, coupled with a minimal amount of free w~ter to become attached to the surfaces of the low-yield shale. Additions of cross-linked XC POLY~'~R further limited the amount of free w~ter while providing rheological advantages needed to insure adequate hole cleaning under low annular velocities. Testimony to the lifting capacity of this polymer was several large pieces of coal - some l~" in length, weighing in excess of ~ lbs., and st~_ll secreting gaseous bubbles from it's core - were recovered from the flowline ditch only days after XC POLY~R Was added to the system. Although each product complimented the objectives of the drilling mud program, certain engineering procedures were necessary to maintain the system within a reasonable degree of stability. Due to the contaminants present in the mzke-up ~mter, it was virtually impossible to make additions at the flowline without drastically affecting filtration, filter cake quality, and flow properties. The onl~ recourse for this situation was to run a half-inch stream of fresh ~ter at the flowline over alternating circulations in order to prevent dehydration while P. O, Box 167.5, Houston, Texas 77001 · (713) 524-6381 · Cable Address: Baroid-Houston Division of N L Industries, Inc. Ym. J. R. Callender -2- May 13, 1976 conditioning 5OO~bbls. of new mud to be compatible'with the active system. This mud was then strung in over a period of time deemed necessary (experimentally) to maintain all properties within proEram specifications and the use of fresh water was discontinued. Another very important aspect of cor~rol~ing this type of fluid has to do with keep- ing the pH in a range of 9.0 - 9.5. · Due to the magnesium content ( 500 ppm) of the Inlet water, CAUSTIC SODA has little effect on the pH as the hydroxil ion combines with magnesium to form .insoluble magnesium hydroxide. This phenomenon theoretically occurs at a pH above lO, however as CAUSTIC SODA is added there is an inm'~ediate re- action at the point of contact and consequently little or no Pf activity is achieved when the treatment is spread over a circulation. The amount of CAUSTIC SODA to be added as the pH drifts downward should be determined as accurately as possible through pilot tests. Should the pH be allowed to fall below 8.5 gel strengths, flow properties, filtration, and filter cake quality are all detrimentally affected and reconditioning can be expensive. On the other hand, if enough caustic is added to raise the pH to lO or above, the amount of magnesium precipitated will reduce the inhibitive nature of the mud, while the effectiveness of cross-linked XC-POL~R will be lessened. The solids control equipment aboard the Grayling was found to be capable of handling undesirables throughout most of the 12 1/&" hole. However, the ~volume of solids to be removed Ln +~ 17 ~/o., ~ and t~e ~o~,,~ ~,,+.~n~ ~qu~d to m~nt. ain the weight below 72 pcf indicate that the addition of a third Sweco Unit or 12-cone de- silter may prove economically beneficial. Also, a maxinum of only 5% flow could be directed to the second high-speed shaker while 80-mesh screens were being used. The efficiency of this unit could be increased significantly by installing 50-mesh screens and in turn the efficiency of the remaining surface equipment would be im- proved by r.educing the flow required qver the rhumba shakers. We would like to take this opportunity to express appreciation for the ~uvaluable cooperation and incentive provided by top-notch drilling personnel, namely Bill Hess, Don Wester, and Jim Watson, and to Union Oil's Anchorage drilling staff for allowing Baroid to be part of an effort to improve drilling standards in the Cook Inlet. Very truly yours, LJM:b Leonard J. ¥orales ¥dchael P. Forman GELS CASING PROGRAM'. SEC _..___._TWP____ RNG ~ FILTRATION FILTRATE ANALYSIS RETORT REMARKS AND TREATMENT , ~-dO J Inc. COUNTY _ CO~_~_~~ 7' .... LOCA T ION ,~/'?.,9..~//*.,,FG SEC, TWP~ . _ CASINO PROGRAM: ~inch et_~--~ f -'- ~ ~.,/c~_ ;nth :~ ~_~.~,~' ~,~co~,~, ~ o~ j~. ~,~,o. ~,~.~c×.~.s,s ls~.~ .~.o~ Icrc ~.., ,--."' ~ OF ~ OF ~O~.',U.,.~,,,~P, I~ ,,,oq~., Pm /MrI pp,n t ppm % % % I m,/~t , ,,, -~ . _ ~_lD~O . ?a ~9 Z~_l~J~ ~.z [&~ -- ~ - /z n~ 3o0 r~ /o d ~ ~x~ cz~'cs~-~~~~ ,,, .... .... ...... ,, , . ....... ,, , ..... ,, ........... _ ,, ~ ,, , , , ,, ....... _ ,,, ~ , ._~tC -Z. ~ ~ ...... =~ ...... , ~__ ~, .... ~...c_~_~ ..... Z~z~ . ~Z~ ' . ..... Used (Total) Union Oil and Gas P~'-'~sion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 union May 11, 1976 Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 RE: TBUS G-24 GRAYLING PLATFORM Dear Mr. Hamilton: Enclosed for your files are two (2) copies of the Directional Survey Report for Trading Bay Unit State Well G-24, Grayling Platform, Cook Inlet, Alaska. Very truly yours, David A. Johnson Drilling Engineer sk Encl. (2) cc: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Co. Skelly Oil Co. Phillips Petroleum Co, Standard Oil Co. Rodney Smith-USGS MAY 1 4 1976 DIVISION OF OIL AND GAS Union Oil and Gas D~;~sion· Western Region Union Oil Company u, California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 union May 14, 1976 Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Hamilton: Enclosed for your files are two (2) copies each of the fo]lowing monthly and completion reports for operations during the month of April. TBUS G-11 (32-32)-Grayling WO P-4 & 10-403 TBUS G-24 (14-32)-Grayling Drlg. P-4 TBUS D-7 (24-33)-Dolly WO P-4 & 10-403 TBUS D-28 (23-32)-Dolly Drlg. P-4 sk Encl. (12) CC: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Co. Phillips Petroleum Co. Skelly Oil Co. Standard Oil Co. V~_~truly yours, David A. Johnson Drlg. Engineer Rodney Smith-USGS STATE OF ALASKA suBMrr IN mmL,CA~ OIL AND GAS CONSERVATION COMMII~EE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS ~'~m ~u.~RlC~ boDE 50-133-20286 LEASE DESIGNATION AND SEi~IAL NO. ADL-17594 1. ? IF INDIART, ALO'I'I~;I~ OR TRIBE NAME OIL, [~ 0~. W~LL W~LL 0THOR 2. N~E OF OP~TOR 8, L~IT FA~ OR LEASE UNION OIL CO. OF CALIF. Trading Bay Unit 3. ADDRESS OF OPhiR 9 WE~ NO P. O. Box 6247, Anchorage, Alaska 99502 State G-24 (14-32) 10 FIF~D AND P~L, OH %VILDCAT 4. IX)CATION OF WELL Conductor 5, Leg 3, Grayling Platform, 1810'N, 1408'W, from SE corner. Section 29: TgN, R13W, S. M. MCArthur River Field-Hemlock I1 SEC, T.. R., M. (BOq'TOM HOLE Benches 1-6 O~JF~r~ Section 32: T9N, R13W, S. M. 12 PEP. MIT NO 76-32 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~NGE. S IN HOLE SIZE, CASING AND CLWIF2~TING JOBS INCLUDING DEPTH SET A3qD VOLU1VIES USED, PEt~FOi~ATIONS. 'rESTS A/ND I:EESULTS FISHING JoB~ JI3T~K I/~ HOLE AND SIDE-TRACKED HOLE A.ND ANY OTI-IER SIGNIFICANT CH. ANGIg5 IN HOL]~ CONDITIONS 1 4/6/76 597'TD (Footage 597') Completed rig activation. Commenced operations on TBUS G-24 @ 12:01 am, 4/6/76. Ran 17 1/2" bit on BHA #1 & CO 26" drive pipe to 369'. Ran Gyro Survey-btm. of 26" Conductor out 1.66' S23°E. Ran 24" OD watermelon mill on BHA #2 & dressed out 26" drive pipe to 369', Ran 17 1/2" bit on BHA #3. Drilled 17 1/2" hole from 369'-597'. 2 4/7/76 855'TD (Footage 258') Drilled 17 1/2" hole from 597' to TD @ 855'. Pooh. PU 23" hole opener in tandem w/ 17 1/2" bit. Opened 17 1/2" hole to 23" from 369' to TD @ 855'. Made cond. trip. Circ. &cond. hole to run 20" csg, 3 4/8/76 855'TD (Footage 0') Pooh. RU & ran 19 jts. of 20" 94# H-40 Buttress Csg. Landed csg. on 24 3/4" X 20" flow thru hgr, w/ 20" guide shoe @ 829' & 20" stab-in FC @ 782'. Circ. hole clean. Pumped 200 cu. ft. .of caustic wtr. for preflush. Mixed & pumped 650 sx. of Class "G" cmt. w/ 2 1/4% prehydrated gel mixing wtr. to a 98#/cu, ft. slurry. Had good cmt, returns @ surface. Followed gel cmt, w/ 200 sx. of Class "G" w/ 2% CaC12 to a ll7#/cu, ft. slurry. Displ. cmt. to FC @ 782' w/ mUd, Pulled out of stab-in FC. Float held ok. Pooh w/ 5" DP. Removed 26" riser. Installed 20" SOW X 20" 2000# csg. hd. 4/9/76 1200'TD (Footage 345') Installed 20" SOW X 20" 2000# csg. hd., 20" riser & 20" 2000# hydril. RIH w/ 17 1/2" bit on slick DC to FC @ 782'. Tested 20" csg. to 500 psi. Drilled out 20" FC & cmt. to 800' Re- tested 20" csg. to 500 psi. Drilled out cmt. & 20" csg. shoe @ 839'. CO rat hole to 855' & drill 17 1/2" vertical hole from 855'-915'. Displ. Dril-S WO fluid w/ gel-Inlet, w_tr. m_u_c!. Tripped for BHA 14. I hereby ce~l$ify that the f~o~g ~ t~e ~ ~ s,a~ ~~~~ ~ ~~ ~ D i s t. D r 1 g. ~Up %. ~ ~ 5 / 14 / 76 ' 'd~. ~lle~o~ ................ NOTE--Report on this form~ required for .each calendar ~nth~ regardless of t~ status of operation~, and must ~ filed {n duplicate with the oil and gas conservation commi~ee by the 15~ of the suec~ding mon~, ~le~ Otherwise d~rected. TBU$ G-24 (14-32) MONTHLY REPORT -2- May 14, 1976 5 4/10/76 1665'TD 6 4/11/76 1960'TD 7 4/12/76 3020'TD 8 4/13/76 3660'TD 9 4/14/76 4353'TD 10 4/t5/76 4663'TD 11 4/J5/76 4914'TD 12 4/].6/76 51i6'TD change. RIH w/ 17 1/2" bit & 17 1/2" stab. Drilled & surveyed 17 1/2" vertical hole from 915' to 1200' (Footage 465') Drilled vertical hole from 1200' to KOP @ 1500'. Circ. hole clean. Pooh. RIH w/ 17 1/2" bit on turbodrill to 1500' Oriented turbodrill @ KOP of 1500'. Turbodrilled ].7 1/2" hole & surveyed w/ Gyro from 1500'-1665' (Footage 295') Turbodrilled 17 1/2" hole & surveyed w/ Gyro from 1665' to 1751' Unable to build angle w/ turbodrill as desired. Hole direction lined up ok. Made bit trip @ 1751' & reran turbodrill. Turbodrilled 17 1/2" hole & Gyro Surveyed from 1751' to TD @ t960'. Hole angle build up ok to run cony. angle building assy. Hole direction falling off to the right. Pooh w/ turbodrill. (Footage 1060') Rill w/ 17 1/2" angle building ass¥. Drilled & surveyed 17 1/2" directional hole from 1960' to 2615' Pooh for BHA change. Rill w/ 17 1/2" tandem stab. locked assy. Drilled & surveyed 17 1/2" directional hole from 2615' to 2961' Had washout. Pulled & found cracked pin 192' below rotary table. RIH & continued drilling w/ locked assy. from 2961' to 3020'. (Footage 640') Drilled & surveyed 17 1/2" directional hole from 3020' to 3266'° Twisted off pin connection @ 284' (new pipe). Left 2982' of fish in hole. RtH ~v/ OS & latched onto fish @ 284'. Pooh. Rec. total fish. Laid dwn. all Grade E pipe for inspection & PU S-!35 DP. RIH w/ 17 1/2" bit on locked tandem stab. BHA. Drilled & surveyed 17 1/2" hole from 3266' to 3660'. (Footage 693') Drilled & surveyed 17 1/2" directional hole from 366'0' to 4353' w/ bit trip @ 4043' (Footage 310') Drilled & surveyed 17 1/2" directional hole from 4353' to 4663' w/ bit trip @ 4553'. (Footage 251') Drilled 17 1/2" directional hole from 4663'-4914' w/ bit trip @ 4700'. (Footage 202') Drilled & surveyed 17 1/2" directional hole from 4914' to 5116' w/ bit trip @ 4950'. Hole failed to turn right as anticipated. Unable to run turbodrill for right turn below 4400' due to high torque & abrasive formation. Hole turning left-will require tool runs below 13 3/8" csg. Made conditioning trip @ 5116' to run 13 3/8" csg. TBUS G-24 (14-32) MONTHLY REPORT -3- May 14, 1976 13 4/17/76 14 4/19/76 15 4/20/76 16 4/2]./76 17 4/22/76 5116'TD 5116'TD 5218'TD 5846'TD 6093'TD (Footage 0') RU & ran 127 jts. of 13 3/8" csg. Set csg. w/ shoe @ 5115'. FC. @ 5030' & DV tool @ 2611'. Circ. hole clean. Cmt'd. btm. stage as follows: Pumped 200 cu. ft. SAPP wtr., 200 cu. ft. FIW & 2443 cu. ft. slurry Class "G" cmt. w/ 2.5% prehydrated gel mixed @ 98#/cu. ft. followed by 230 cu. ft. Class "G" neat. Bumped plug w/ 2000 psi-held ok. CIP @ 4:55 pm, 4/18/76. Opened DV tool @ 2611' w/ 1200 psi @ 5:20 pm. Circ. out approx. 330 cu. ft. of excess cmt. from above DV tool. Cmt'd. top stage as follows: Pumped 200 cu. ft. SAPP watr., 200 cu. ft. FIW w/ 2656 cu. ft. slurry Class "G" cmt. w/ 2.5% prehydrated gel mixed @ 98#/cu. ft. followed by 230 cu. ft. Class "G" neat. Bumped plug w/ 1600 psi & closed DV tool ok. Press. 13 3/8" csg. to 2500 psi-ok. Had approx. 540 cu. ft. excess cmt. to surface. CIP @ 9:50 pm, 4/18/76. Washed dwn., removed riser & 20" hydril. Hung off 13 3/8" csg. (Footage 0') Cut 13 3/8" csg. Removed 20" riser & hydri]. In- stalled 20" 2000~ X 12" 3000~ csg. hd. spool & tested seal[ to 2000#. Installed 13 3/8" 3000~ BOPE & riser. Tested blind rams to 3000 psi. 1RIH w/ 12 1/4" bit on slick DC to 13 3/8" DV~ collar @ 2611'. Tested hydril to 1500 psi & upper & lower pipe rams to 3000 psi. Tested kill & choke lines to 3000 psi. All tests witnessed by State DOG. (Footage 102') Drilled out 13 3/8" DV collar @ 2611'. Tested 13 3/8" csg. to 2500 psi. Drilled out 13 3/8" FC @ 5030' & cmt. to' 5050'. Tested 13 3/8" csg. to 3000 psi. Drilled out cmt. & float shoe @ 5115'. Drilled 12 1/4" hole from 5116'-5126'. Tested csg. seat to 0.650 psi/ft, gradient. Drilled 12 1/4" hole from 5126'-5218'. Pooh. Laid dwn. 5" S-135 DP. RU Sperry Sun. Ran Gyro survey from 5080' to surface @ 100' stations. PU 12 1/4" stab. BHA. RIH picking up 5" Grade E DP. (Made up, broke, redoped & remade each connection). .(Footage 628') RIH. PU 5" Grade E DP. (made up, broke & re- made each connection). Reamed from 5127'-5218'. Drilled & surveyed 12 1/4" hole from 5218'-5846'. Tripped for bit. (Footage 247') Tripped for bit @ 5846'. Drilled 12 1/4" hole from 5846'-6008'. Hole not turning right as anticipated. (Note: Gyro Survey showed BHL @ 4800' approximately ].50' to the right (SW) of BHL plotted from magnet surveys while drilling). Pooh @ 6008'. PU turbodrill & TIH. Attempted to orient turbodrill @ 6008' w/ BJ Tele-orienter. Tool failed to function. Ran conventional WL Magnetic survey & oriented turbodrill for right hand turn. Turbo- drilled 12 1/4" hole from 6008'-6032'. Pooh w/ turbodrill. TBt~S G-24 (14-32) MONTHLY REPORT -4- May 14, 1976 18 4/23/76 6117'TD 19 4/24/76 6700'TD 20 4/25/76 72081TD 21 4/2(i/76 7512'TD 22 4/27/76 7975'TD 23 4/28/76 8345'TD 24 4/'29/76 8543'TD 25 4/30/76 8805'TD (Footage 24') Finished Pooh w/ turbodrill. Had lost 1 cone off bit during turbodrill run. RIH ~v/ 12 1/4" bit #15 on BHA #14 (follow-up assy). Drilled on junk cone from 6093'-6100' Had indication of being past junk. Pooh. Ran bit 316 & drilled from 6100'-6113' Running on junk cone & unable to break-up cone. Pooh. Ran Bowen junk basket on BHA 315. Cored 4' from 6113'-6117'. Pooh. (Footage 583') Pooh-rec. lost cone (in tact) & junk in hole + 2' of fro. core. Ran 12 1/4" bit #17 on BHA #14. Drilled from 6117'-6162' Ran survey w/ instrument @6127'. Hole direction had turned from S34°E @5810'MD to S22°E @6127'MD through turbodrill run. Drii[led to 6578' &Pooh for bit change. Ran 12 1/4" bit #18 on BHA #14. Drilled 12 1/4" hole from 6578'-6700'. (Footage 508') Drilled 12 1/4" hole from 6700'-6807' Pooh for bit change. Ran 12 1/4" bit #19 on locked BHA #16. Drilled 12 1/4" hole from 6807'-7208' Pooh for bit change. (Footage 304') Compl. bit trip @ 7208' Drilled from 7208'-7459' w/ bit 320 on BHA #16. Dropped survey. Pooh for bit change. TIH w/ bit #21 on BHA #16. Drilled from 7459'-7512' (Footage 463') Drilled 12 1/4" hole from 7512'-7736' w/ bit #21 on BHA #16. Tripped for bit. RIH w/ bit #22 on BHA #16. Drilled 12 1/4" hole from 7736'-7975' Pooh for bit change. (Note: Hole turning left-unable to hold w/ locked assy.) (Footage 370') Tripped for bit change. RIH w/ bit #23 on BHA #16. Drilled 12 1/4" hole from 7975'-8345'. Elec. motor on rotary table shorted out. Pooh to repair rotary table. Replaced elec. motor on Rig #54 w/ motor from Rig #55. (Survey on bit trip-no good). (Footage 198') Repaired rotary table. RIH w/ bit #24 on BHA #16. Reamed from 8285' to 8345' Drilled 12 1/4" hole from 8345' to 8543'. Ran WL survey. Hole direction turned to S18E. Unable to drill after taking survey. Pooh. Ail three cones missing from bit. RIH w/ Bowen junk basket on BHA #15. Cored 4' from 8543' to 8547' Pooh. (Footage 262') Pooh w/ Bowen 12 1/4" junk basket. Rec. 3 cones left in hole off bit #24 plus 2' of cored section. TIH w/ b~t #25 on BHA #16. Drilled from 2500 psi to 1700 psi. Pooh looking for washout. Found washout in counter bore of bit sub. Till w/ bit #26 on BHA #16, Drilled from 8572' to 8805'. Dropped survey & Pooh. Union Oil and Gas I''~ Sion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 union April 27, 1976 Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 RE: TBUS G-24 GRAYLING PLATFORM Dear Mr. Hamilton: Enclosed for your files are two (2) copies of the Gyroscopic Survey for Trading Bay Unit State G-24, Grayling Platform, Cook Inlet, Alaska. sk Very truly yours, Callender District Drlg. Supt. cc: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Co. Phillips Petroleum Co. Skelly Oil Co. Standard Oil Co. USGS-Rodney Smith 024)01B of ALASKA Division of Oil and Gas TO: ~ O. K. Giibreth, Jr.~) ~ Director ~'~ FROM: hOyle ~,. Hamit ton Chief Petroleum Engineer Russell A. uouglass t, Petrol eum Engi neeri ng Consul rant SUBJECT, Witness ~OPE test, Union ~-2~'? Grayl inp ~la,~for,~,, gffshore~ ,~ Cook Inlet ~uo,,dav. ,,pr~ 1w, ,:~,70 - Trave,ed co ~.,e Jn~on ¢;ravlin~ Platform via . , .t~or,~ approximately q.~n · Kena~ and N~k~sk~ hel~por~ arriving on ~ne ola Purpose of m,y trip was to witness BOPE testing on the G-24 well. Bill Hess was thC Union drilling supervisor. The test was successful and only minor delays were enco,ntered. Someone had misplaced the tool that was used to open the upper kelly valw~. There was a three to four hour search before it was finally found. Testi~? had begun at approximately 8:00 Pi-~ and was finished shortly after midni~ht. ~" '~fk I completed a field insmection report and qave On ~ne morning of the it to Bill Uess. A copy was sent to Jim Caitender in Anchorage and a co?y i s attached. In summary, I witnessed the BOPE '~*-~'~ ,.~:~ on the Union ~ ~'~ ~" ~?-~.. well in une Cook Inlet. All testing was satisfactory. Drlg. Permit No,~ · Operator ~_~/.! ~ ~ _ Ala ~ Oil and (~as Conservation Commii Field Inspection Report Represented by~t~.~_ ~$$ Name &--Number satisfactory Type Inspection Yesj~ No Item ( ) 'Location,General (~)~,() 1. Well Sign (~/~ ( ) 2. General Housekeeping () () (~Y~ ( ) 3. Reserve Pit-( )open( }filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data () () () () ( ) ( ) 7. Well Nos. , , , __ ( ) ( ) 8. Hrs. obser , , ,__ ( ) ( ) 9. BS&W__, ,__, () () () () () () () () Satis ~actory Type Inspection Yes No Item ( ) BOPE Tests i~'() 1~. i ~/"Casing set @_~_/_~ ( ) 1. Test fluid-( )wtr.''(~mud ()oil () () (~f () (~F ( ) (~Y~ ( ) (~() 10 Gr. Bbls. , (~ ( ) ( ) Final Abandonment (~ ( ) 11. P&A Marker (~}['. ( ) 12 Water well-( )capped( )plugged(~)~ ( ) 13. Clean-up 17. Master Hyd. Control Sys.- _psig 18. N? btls. , , , psig 19 R~mote C~ontrols 20. Drillin~l spoolz~"outlets 21 Kill Li~ie-(~Che'ck valve 22. Choke Flowline (~HCR valve 23. Choke Manifold No. valvs~'~ fles 24. Chokes-(~i~emote( )Pos. (~j. 25. Test Plug-( )Wellhd(~)c's~(~ne 26. Annular Preventer,~psie 27. B1 i nd Rams ,~_~ps i g 28.'~.Pipe Rams.:~ psig 29. Kelly & Ke-lly-cock.~oopsi.q 30. Lower Kelly valve~o~psig ( ) ( ) 14. Pad' leveled ( ) 31. Safety Floor valve-s-(~BV (~/q~art Total inspection observation time~ hrs/days Total number leaks and/or equip, failures ~ Remarks d~.~~~ ~~~ ~~ ~ ~~~ ~~-~ ~i./~ ~:.- ....... t r .... t- · ??-- cc: or w en oa e. , Parch 15, 1976 Re: Trading Bay Unit State G-24 (14-32) Union Oil Company of California State Permit -No. 76~-3~ Robert T. Anderson District Land ~nager Union Oil Co~q~any of California P. O. Box 6247 Anchorage, Alaska 99502 Dear Sir: Enclosed is the approved apP[~ication for permit to drill the above referenced well at a location in Section 31, Township 9N, Range 13t~, ~1t samples, core chips and a mud tog are not required. A directional survey ts required. Pollution of any ~aters of the State is prohibited by AS 46, Chapter 03, Article 7 and the regulations prolmulgated thereunder {Title 18, Alaska Administrative Code, Chapter 70} and by the Federal ~ater Pollution Control Act, as ar-~-nded, Prior to c~ncing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local 14!re Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this off!ce within 48 hours after the ~ll is spudded, t~e would also like to be notified so that a repres~tative of the Division may be present to witness testing of bl~t preventer equi~nt before surface casinq shoe is drilled. l~obert T..Anderson -2- March 15, 1976 In the event of suspension or. a~ndonnmnt please give this office adequate advan~ notification so that we may have a witness present. Very truly yours, i '-' /~" i-'" ' '; Chairman Alaska Oil and Gas Conservation Co~nittee Enclosure CC: ~par~nt of Fish a~ Ga~, Habitat Section w/o encl. ~par~t of £nvironmentat Conservation w/o encl. Department of Labor, Supervisor, Labor Law Compliance Division w/o encl. ~rm tO- ~0! REV. I--I--71 la. TI'P~ OF WORK SUBMIT IN T~RIPL (OLher lastructions reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE' PERMIT TO DRILL OR DEEPEN ·DRILL WEEL WKL'L DEEPEN OTHER ZON~ ZO.~E 2 NAME OF OP~lq_&TOR UNION OIL COMPANY OF CALIF. 3. ADDP. E-~S C~ OPF_~RA2X21R P, O. Box 6247, Anchorage, Alaska 99502 4 LOCATION OF WELL surf At ~e Conductor 5, Leg 3, Grayling Platform, 1810'N, 1408'W from SE corner. Section 29: T9N, R13W, S. M, ^t p,-o~sed pr*~. ~.o~ Hemlock Oil Pool @ approximately 9680'MD, 9].80'VD Di~stance~out 2.8.60'_ @ S240E 13. DISTANCE IN MILES AND DIRECTION F'~IO*! NEAREST ToWN OR POST OFFICE* Approximately 22 air miles north of Kenai, Alaska APl # 50-133-20286 ~. I_&CA. SI~. DIL~IGNATION A~N"D SI~:~I. AL NO. ADL-17594 I. IF INrDIAN. /~DOTTEE OR 'I?~BE NA~ 8. UNIT FARM OR LEASE Nt~.%IE Trading Bay Unit 9. WELL NO. State G-24 (14-32) 10. FIELAD AND POOL. OR WILDCAT McArthur River F/eld-Hemlock Il SEC.. T.. 1~., 51, ~ftoqr~FO.%ha I-IOLE OBJECTIVE, benches 1-6. Section 32: TgN, R13W, S, M 14. BOND INFOF_MATION: Statewide TYPE Surety and/or 15. DISTANCE FROM PROPOSED' LOCATION TO NEAREST PROPERTY OR LEASE LIN~. ]FT. ~Al~o to nearest drig, unit. if any) United Pacific Insurance Co. B-55372 ~0. ~o. o~ AC~ZS iN LE^SE 270' 5,120. [i~. PaOeOSm> DEP~ i 10,350~TMD 9,8001TVD I8. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING. COMPLETED. OR APPLIED FOR. FT. 1,450 $100,000 17. NO ACRES ASSIGNED TO THiS WELL 8O spacing except needed 20 ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS {Show whether DF, RT, CH, etc.~ 22. APPROX. DATE WORK WILL, START' 99' RT above MSL Apr. i].. 3, 1976 23, PROPOSED CASING AND CEMENTING PROGRA2¢I SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT ]_ GRADE SKT'rING DEPTH quantity of Cement 26" ; 26" ;'~/2" Wall T~.icknesJ' ' +359" P~edriven tO 359' below 0' elev, 24" ' 20" 94# _ H-40 . ,.~800' ,C,,mt to sur~face (+1250 cu ftj_) 17 1/2"" 13 3'/8h~ 61~ & 68# K-5-5 5200'MD ] Cn2~,,,t9 s. ur. face (+'5400 " · cu ft 2 g 12 1/4" 9 5/8" 47# N-80_,.P_4L10,3~0'MD Cmt. as determined from logs. ...... ' ,,, " ,i, - , ........... ..... ..'..' gs,) Plan of Procedure enclosed. !'.!.irc ~ 0 I976 I~ ABOV'E SPAC~ DI~SC'RIBE ]FI~OPOS~ PI~C~-R.adVI: If l:,ropo~l la to deepen give d~ta on present productive zone oa!d pro~o~ new pro'duct~ve zone..l~_j~_r_o.l>q~_l xa to. clrlll_ or ac. epen dwect_ionally, give pertinent data on au;bsurface 14>c~itJona and measured ~nd true vertical depths. Give blow~[ preventer prog~'am. 24. I hereby cen~f~i_~).hat ~oing ia True an~ Co,r~'ect ~-~~-~--~'f~-,--~'-//' --- M~rch 3, 1976 m~zo~ su~v~ F,m~ ~ ~.~.L ~c~ coax 1 50-133-20286 Dist. Land Mgr., P~ No 76-32 . . ~' 'z' ' , " ~ Chairman March 15 1976 TBLiS G-"24 (14-32) Pti2RMIit.' TO DRILL 2 March 3, 1976 Pl.,AN OF PROCEDURE: [. D~'ill 17 .1/2" hole vertically to 800+ & open hole to 23" OD. -- 2. Set 20" conductoP csg @ +800~ & cml to sur[ace. -- 3. Drill 17 1/2" hole to KOP @ +1000' 4. Drill 1.7 1/2" directional hole to +5200' (1.50' below e,stimate, d base of __ D-2 Sd. ) 5. Set 13 3/8~ csg, @ 5200~ and cml to surface. 6. Drill 12 ]/4'" directional hole to +10,350' TMD. -- 7. Log well as required. 8. Set 9 5/8" production string @ 10,350' and cml as required. 9. Complete well as single oil completi, on in Hemlock Zone. ESTIMATED COMPLETION TIME: Drilling Time FoPty (40) Days Sixteen (16) Days ......... .~:-~.-- - -/ .... ~ ............ ~ ............... TOTAL TiME Fi[tv-Six (56) Days CASING DESIGN 13 3/8" Csg. Intevval Footage Descri p.!ip.? ...... Wt. Acc. Wt. SFC SFT ~-i.--/~'~-6"'ii'~I5 .... 2~i)-~-: ..... ~T~-iUT~ Butt. '~-6-8'7~'~0 "'~'l}"~i 400 -]'T~-~" 0 ~54 0 ' TV D 2600 '- 5200 'TMD / 2600' 68# K-55 Butt. '176,800 1.76,800 .79 6.0 Note' Collapse on 13 3/8" 68# would be applicable only il7 fltt}~l lt~vc.l were re~n,~vcd to thc 3650'TVD level w/ 75~/cti ft mucl in cso annultts 8500 ' - 9800 ' T M D 1300 ~ 80 ':[ 9 '-- 9262 'T V I) 47# P-II0 Bi,ti. 61 , 1.00 86,950 I . I 3 17.2 9800 ')2(,2 47# U8S--95 t'l~tt. 25, gq0 25,850 '1.45 49.9 o. · . .. ~cAt. f:','.o:~' ~.~;,','~i!:~ T.~31. v,~f I..:-'.FI' I;~'.~: Ac. lq: 'r~!i:"13 ~ :'~":-'---:'-''/ , , ,' ' , - , r ,:~,'' '-' ~ I ~::::::: :: ', : ::::::::::::::::::::::::::::::: ............................................... ~ ~ ~r~ ~, ,,u.'., ,'.'I o ~.~', t.. ~.~'[~.,,~ I~ ......... _,~. ~_ ..... , ............ , .... ,~., ...... ~ . __.~ . '~: ~:~" S o,,'./ BC~'~"Ft~>I. " . · ~ .............. . . .o . ! I tI .' B lZ I~' B L E ' '?~ l'TK "' ' .. . ,,, ,~ DE6A$$ER .- .. 0£ II0,;:£ ,,,~,P,- t - . : · · · -_ 2 D-II ..._....lid 7 . ~ - / / / / ', . WELL LOCATION MAP TRADING BAY STATE UNIT----G-24 (14 -32) ~ DATE~ Feb. 23, 1976 -SC~L[~"~ ~000= .... F .... ~ .... CHECK LIST FOR NEW WELL PERMITS Company ~=f~l~ Yes No Remarks 1. Is the.permit fee attached ...................... ~ Lease & Well No. 2. Is well to be located in a defined pool ............... 3. Is a registered survey plat &ttached ............... 4. Is well located proper distance from property line .......... ~ 5. Is well located proper distance from other wells .......... ~j~ 6. Is sufficient undedicated acreage.available in this pool ....... x~J< ~ 7. Is well to be deviated ....................... ~ 8. Is operator the only affected party ................. ~Nc 9. Can permit be approved before ten-day wait · .. ........... W/~J~ 10 Does operator have a bond in force ................ ~m_, ll. Is a conservation order needed .................... ~K~a~ 12. Is administrative approval needed .................. 13. Is conductor string provided .................... 14. Is enough cement used to circulate on conductor and surface ..... 15. Will cement tie in surface and intermediate or production strings 16. Will cement cover all known productive horizons ........... 17. Will surface casing protect fresh water zones ..... . . . . 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating .......... Additional Requirements' Approval Recommended' Geol o,Qy Engi neeri ng' TRM ~q~ HWK ~W~JK, OKG ~,~ HHH JAL ~ ' ' ' LCS?~ ..... ~JCM ~/~qJ Revised !/!5/75 Well History File APPE'NDIX 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. oo6o 7777777777 ':' : ' ' ~ --. 1111 O0 O0 77 O0 O0 ~, ! 1, 1 O0 O0 77 O0 O0 11 O0 0000 77 O0 0000 11 O0 0000 77 O0 0000 11 O0 O0 O0 77 O0 O0 O0 i 1 O0 O0 O0 77 O0 O0 00 11 0000 O0 77 0000 O0 I 1 0000 O0 77 0000 O0 I1 O0 O0 77 O0 O0 11 O0 O0 77 O0 O0 111111 000000 7 7 000000 I 111 ! I 000000 77 000000 77 77 77 77 77 ¸7 ~7 ;7 71 77 77 7'7 066666 222222 7'777777777 333333 222222 666666 222222 7777777777 333333 222222 66 22 22 77 33 33 22 22 66 22 22 77 33 33 22 22 66 22 77 33 22 66 22 77 33 22 6bbb6666 22 '77 33 22 66bbbb6b 22 7'7 3,:3 22 66 66 22 77 3.3 22 66 bO 22 77 33 22 66 66 22 77 33 3,3 22 66 6:6 22 77 3~ 33 22 666666 2222222222 77 333333 2222222222 6bbb66 2222222222 77 333.333 2222222222 *START* USEF. PCAL, [10707,627321 d[)B SH. IP SEQ. 7003 DAI~. 07-/4PR-82 1.0:%5:05 (JNIT*'IR Sw$-WIjN DECIOEi 70102 *START* ONITtiF*START* swsUSERv~uNPCAbDEC 10E[1070716102 b27321, s,rAF, i,,dO~ 8BIP SEQ. 7003 OA'rk 07-/~PR,, B2 10:45:05 I I II II II II 1 i II II II I1 II II II II I I I I PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP *STAP,?'* USER PCAL [10707 627323 dOB S,HIP SE(-i. 7003 UNITf)R SWS-WUN I')ECI Og '7~102 *START* iLE: DS~,H:SHIP.'rO<157>[IO707,b2712] CRkATED: 0B-APR-B2 PRINTED: 07-APR'82 10:45:1q UEUE SWI'ICHES: /B'iLE:FOE~T /COPlB,S:l /5PACiNG:I /LIM1T:137 /FO}~iS:P-it.iRi',~AL [)ALE; 07-APR-82 13:42:31 10:45:05 SHIPFiNG INS%RUCTI~}N6 !SS~JED 5-A?.~-82 ! 3: ~42 HIP TO : ENT[iRA, ChLIF[)Rix~i,A 9;:t003 CCC I i i ;fL i I 3[: I ! I I I II 31i i I II II II I 1 IIII, II YY YY YY YY YY g Y YY YY YY 000000 000000 222222 000000 000000 222222 0 00 O0 00 22 22 0 O0 O0 O0 22 22 0 0000 O0 0000 22 0 0000 O0 0000 22 0 O0 O0 O0 O0 O0 22 0 O0 O0 O0 O0 O0 22 000 O0 0000 O0 22 000 00 0000 O0 22 0 O0 O0 O0 22 0 O0 O0 O0 22 000000 000000 2222222222 000000 000000 2222222222 *START* USER PCAL [10707.02732] dob ShIP (]NITi']R SWS-WUN DECiOE 70102 *START* ILE: PS[~:VE~iF~,O02<05!>[10707.627~2i CPEAT~D: PHI. NI'ED: 07-APR 82 10145128 UEUE SWITCHES: /~iLE:FOF. T /COPIES:i /SPACING:I /I,i~4lT:137 /B'OR~S:NORPiAL 7003 [>ATE 07-APR-82 07-APR-82 10:391~0 10:q5:05 LIS VI~;F'S.I{)i~ 15.H01 79103126 SCHI.,UHBERGE~ C[1MPUTING CENT£R .10707,62732 REEI~ HEADEP LENGTH: 132 BYTES REEL NA~E: P.C.A.b. SER¥iCE NAME: EDiT REEI~ CONTi.~UATION NU~qBERI PREVIOUS REEL NAHE: CftMMENTS: BlS FORMAT C(,,!STO~ER TAPE DATE: 82/ 4/ 5 TAPE HEADER I~ENGTB: 1152 B~TES TAPE NA~E: 62732 DATE: 82/ ~[/ 5 SERVICE NAME: EDIT TAPE CONTINUATION NUMBEI~: Ol PREVIOUS TAPE NAME: COMMENTS: UNIQUE WEbL IDENTIFICATIUN NOMBER IS NA TAPE COgM,ENTS THIS TAPE IN 1976, ~ II,E ~,EADER LENGTH: 62 B~/TE$ FILE NA~E: EDiT ,001 MAXIMUM PH~S1CAI~ RECORD LENGTH: PR~i V iIDUS FiLE COMPANY, : UNION UIL C(JMPAN¥ WEDL : .rBU $ G-24 F'IEI~I) : TRADING BA'~ F~A.NGE : NA TOWNSHIP : NA SECTION : NA COUNTY : F, ENAI S'rATE : AbASKA DENSITY : lb00. DATA Ft.~.,]~AT SPECIFICATION LENGTH; '730 BYTES ENTR'~ BLE1CKS: $I. ZE REP CODE ENTRY I 6 6 0 DATUM 6PECIIFICATiON ~L[3ChS; [,1NI~r AP1 AP1 APl APi FiLE SIZE SA~'~ REP Pi~UCESS ,INDICATtJRS DLPT SP DLL LLD DLL I,L$ DLL ILD DIL ILM DIL L L 8 (,I D I b GR C~L CALl CNL DRHfJ CNL NPBI C~L RHOB CNL FIRST CML NCNL CML FCNL C~L GR BBC CAb I BHC DT BHC I 68 1, 68 1. 68 !. 68 ! 68 ! 68 I 68 ] 68 i 68 I 68 1 68 1 68 1 68 I 68 SER DEF1NF, I) OUTPUT ARRAY UTPUT SP AT 2 UTPUT LLD AT 3 UTP!IT LLS AT 4 UTPUT ILD AT 5 UTPUT ILM AT 6 U r P Il T L b 8, I.] A T 7 UTPUT g~ AT 8 UTPtlT CALl AT 9 UTP(IT D~HO AT 10 UTPUT NPHI AT I 1 UTPUT RHOB AT 1,2 LtSPUT NBAT g'i' 1] UTPUT NCNb AT 1~ UTPt. iT FCNL AT 15 UTPUT GR AT 1 6 UTV'UT CALl AT 17 UTPUT DT AT 1 8 D E P k.. ' 10450.000 10400. O00 10300.000 10200.000 10100,000 1.0000.000 9qO0.O00 9800.000 97 O0. 000 SP NCNL DT SP NCNL DT SP ILM DRHO NCNL DT SP DRhO NCNL DT SP ILM DRHO N C N L DT SP N C N I, DT SP D R H O NCNL DT SF IhM DRHt.~ NC NL DT SP DRHU NCNI, DT VALUE -40,250 6.855 -999.000 -999.000 -999,000 -40.500 6,855 0.i00 763.090 77.700 -43,750 4.656 0.040 361.803 8,3,700 -41,000 12.589 0.0]5 :~08,584 72.850 -61,750 21,478 0.119 70. 000 -61.750 15,560 0.195 459.227 68.750 -66.000 15.996 0.066 386.266 72.600 -69.500 17,701 0.055 448.069 78,950 -48.750 8.318 0.020 383,262 77.250 MNE;MUN lC LLD LLSU NPHI FCNL LLD h L 8 O N P H I FCNL Li,~D L L 8 U NPHI FCNL Lt.,D NPHi FCNL LLD bi.,8 U NPHI ~.'CNL LLD LLSU NPHI FCNL LLP LL8 Il NPH] I~'CNL LLD LLSU NPHI F C N i., LI,D bLS U NPHI FCNI, V AL IJ -1.001 7.516 -999.000-999.000 14.485 7,516 20.080 256,652 7.206 5.346 26,860 127,897 18,O57 1.1.80:3 28,540 102.146 70. 968 25.823 9.280 309.442 34.348 !3.062 15.200 21~,026 34,985 16.29t 19.960 175.966 63.561 24.434 16.520 211.58.,8 12.1.65 5.248 23. @00 1~1 .202 LLS GR RHt]B L L S GR R ,ii 0 B GR LL6 GR R H O B GR LLS GR E H 0 B GR bLS G~ GR bLS GR G~ LLS GR LbS GR hHiJ~ L LS Gf~ VALU~ -I,001 -999.000 -999.000 -999.000 1,2.165 200.100 1.905 -23.900 5.521 87.600 2.371 52.200 1.4.889 134.000 2.594 88.200 43.215 57.800 2.518 27.000 22.928 53.800 2.509 29.200 21.304 67.000 2.470 42.500 32.806 54.200 2.401 33.50O 6,514 73.900 2.526 49.900 HN~MON lC ILD (]ALI NRAT C AL 1 I L D CALI NR, AT C AL ,I 1LO CALl N R A'I CAhI I LO C AL1 N R A T CALl ILO CALl NRAT CALl I LD C A h I N RAT CALl ibD CALl NRA1 C AL1 ILD CALl NRA'£ CALl iLO CAbI CALl VALU~ 12.942 -999,000 -999.000 -999,000 :12.706 9.100 0.084 10.800 5.970 12.250 2.790 1i.150 1i.169 12.700 3.000 12.500 55.976 11.850 1.642 1i.950 21.281 12.300 2.084 12.300 24.889 12.100 2.440 11.950 44.8'75 11./O0 2.120 1i.800 6.915 1.5. 100 2.770 13.~50 D E P t t:i 9600.000 9500.000 9400.000 9300.000 9200.000 9100.000 9000.000 8qO0.O00 880O.000 M N L ~¢1 LIN I C DRH[J N C N L DT SP DF~HO NCNL DT SP DRHO NCNb DT SP NCNL DT SP DRHO NCNL IBM DRHU NCNL DT SP ILM DPHO NCNL DT 6P I LM DRHO NCNL DT SP 1LM D~HO NCNL DT VALU 12. 0. 314. 82. 750 706 008 1,63 800 -71.500 34.356 0.094 244.206 98.500 -77 8 0 286 -83. 12. O. 466. 72. -55. 7. O. 359. 76. -93. 3. O. 460. 80. -89. 2. O. 405. 82. -57. O. 347. 87. -54. 9. 0. 271. 98. .250 .630 .034 .695 .700 500 062 95 ~ 250 750 727 020 657 600 250 192 011 515 550 50O 582 048 579 250 5O0 698 062 63q 400 250 462 O08 674 850 M N g M (..} N i C LLD LL8U NPHI ~CNL LLD LLSU NPHI FCNL LLD LLSU NPHI ~CNL LInD L L 8 U NPHI ~CNL LLD L L 8 U NPBI I~CNL LLD LLSU NPHI FCNL LI~D LLSU NPHI FCNL LLD LLSU NPHI LLD NI~BU NPH1 VALUE 25.600 11.912 32.840 96.567 14.618 4.325 30.660 98.283 15.027 9 462 102.146 42.429 13.932 15.260 233.176 15.165 7.516 28.280 11~.738 4 9qO 16.120 215.451 4.040 ~.281 22.000 161.80{ 6.337 3.565 27.240 121.459 17.566 12.q42 41.1~0 67.811 ' C M N L M t,)N 1 ,._ bLS LLS GR GR LLS GR GR LLS GR R ,H (3 B G~ LLS LLS GR RH()B GR LLS GR GR Li, S G~ GR LLS GR RflUb VALUg 21.109 117.300 2.565 105.100 5.~22 80.800 1.942 ]6.JO0 10.097 95.50O 2.494 79.800 19.794 66.600 2.451 42.100 9.406 130.500 2.588 111.000 4.077 50.000 2.422 25.000 3.585 bO.O00 2. 397 ,17. 000 3.823 67.]00 2.548 45.j00 12.620 101.600 2.453 83.000 M N t'.: M U N I C 1LD CALl NRA1' C ALI C AL1 N R A 1 CALl CALl NRAT CALl CALl NRAT CALl t LD C A L I N RAT CALl CALl NRAT CALl lbo CALl NRAT CALi ILO CALl NRAT CALl tLD CALl NRA'I CALl VALOE i6.144 !4.200 3.2~0 13.650 4.613 17.000 3.300 13.200 10.66~ 13.550 2.812 12.850 22.284 12.400 2.170 12.250 8.954 15.250 2.986 13.400 2.7~0 12.050 2.090 12.050 2.377 12.450 2.b32 12.250 4.1]0 15.250 2.978 1].250 9.03b 14.100 3.456 13.o00 8700. 000 8600,000 8500.000 8400.000 a300.O00 8200.000 81 O0. 000 BO00,OOO 7900.000 SP I lr"M DRHO NCNL D? SP DRHO NCNL D T 8P D R H [1 N C N L DT 8P IbM D R H [) NCNb SP DRHO NCNL DT i LM DRHO DT SP NCNL DT SP I h M DRHO N C N I., DT SP ILM DRHO NCNL DT V A L U E -ql.O00 4.966 0.053 441.631 84.750 -59.750 4.285 0,058 345.923 86.550 -74.000 8.017 0.052 236.910 I01,950 -85,750 7.870 0.006 280,258 80.600 -'7'7.750 6.855 0.072 332,189 92.800 -80,750 7.047 0,000 309,442 1.11,200 -77.250 !4.454 0,015 269.09g 94.650 -27.750 4,01~ O,O1B t88.841 89.650 -35.750 7.244 0.026 ]42.060 83.900 LLD [ I.~ll NPHI f C N I, LbO LLStJ NPH I FCNL bLD LLSU NPHI FCNL L L D b L 8 U N P,H i bLO bh8O NPHI FCNL h I., [) b L 8 U FCNL LLD NPHI FCNL LLD LLSU NPfll LL D L L 8 ti NPHI FC N L V AL UE 16.172 5,29'7 2t.900 1.84.I~20 7. :t40 4,169 26.740 1,21,, .030 13.335 6.026 57.180 49,785 14.485 8.017 31.460 87,983 ~5.878 6.427 33.040 101.71,7 12.390 5.970 29.880 100,429 43.215 15.704 J8.120 77.682 6.454 ~.802 22.080 149.1356 1~.962 6.546 29.260 100.~71 ,~ MNEM[)NIC G~. GR ItLS GR LbS GR LLS GR GR L L S GR R H 0 B h L S G~ G~, bLS (;R LbS (;la RH(iB GR L GR VALU~ 6,221, 65.800 2.371 43,700 4.511 77.300 2.386 47.300 1:1.726 99,000 1.761 70.500 9.580 124.500 2.556 85.700 8. 902 99.400 2.581 74. 400 ~.046 136.4O0 2.593 100. 700 24.227 109.700 2.288 78.800 t.191 61.900 2.346 31.700 8.502 109.300 2.513 79.200 CALl ~RAT CALl ILO CALl NRAT CALl ILO C AL 1 NRAT CALl ILD CALl NRAT CALl CALl NRAT CALl I LO CALl, NRAT CAb I CALl NRAT CALl. ILO CALl CALl CALl CALl VALU~ 7.810 !2,300 2.3~8 Il.bO0 5.546 12.200 2.7'i2 12.050 8.166 14.050 5.020 12.800 9.204 13.650 3.!70 :i3.100 7.311 14,650 3.192 13.050 7.379 15.000 3.1lb 13.,350 11.37~ 14.300 3.a~4 13.150 5.058 12.150 2.570 12.000 7.441 15.550 3.104 t3.uO0 DEP 7800.000 7700.000 7600.000 7500. 000 7400.000 7300.000 7200.000 7100o000 7000.000 M N E M 0 N l C SP D P, H (} I~CNL DT SP ILM D R H O NCNL DT SP ILbl DRHO NCNL DT 6P I D~HO U C N L DT SP ibm DRHO NCNL DT 8P I DR}tO NCNL DT SP DR.HO NCNL PT SP I[,g NCNL DT SP l D R H 0 NCNb DT VALUE; -35.O00 6.668 0.046 311.588 85.000 -51.500 3.076 0.033 410.300 87.850 -43.000 7.311 0.01,6 278.970 88.750 -3b.250 5.445 0.059 326.180 85.550 -28,750 5,058 0,098 :307. 296 91,100 -18.000 4.613 0.072 324.034 94.950 -.30. 500 4.875 0.052 415.451 88.70O -35.750 10.000 0.084 195.708 1~9.750 -31.250 4.207 0.042 387.983 9].250 MN EMON lC LLD LbSU' NP~I ~CNL LLD LLSU NPDI FC~L LI,D LLSU LI,,D LL8 U NPB I FCNL LLD I., L 8 U NPHI FCNL LL,.D LLSII NPHI ~'CNL LLD L1,80 NPtiI fCNL LLSU NPHI FCNL LLD LLSU V A h U 11 'I. 656 28.380 :104.292 3.894 ].133 20,720 170.815 1.1.941 6.730 37.240 7'7.253 8.502 5.297 32.b80 96.567 8.195 4.656 31.600 89.700 7.900 4.906 32.900 111.159 7.756 5.058 2O.280 179.828 15.8'!8 8. 630 59.710 39.485 5.130 3.499 25.4~0 144.206 M N E t;~ [1 f~) 1 C L L S LL$ G~ LLS GR LLS GR R H O B GR LLS GR GR LLS LLS GR [-<HUB GR LI.,S LLS GF GI~ 9.067 I. I0.00"~ 2.594 80.100 3.153 53.800 2.362 37.200 11.200 101.900 2.520 84.200 6.758 123.000 2.546 95.600 5.421 106.400 2.546 79.200 5.1'17 ~6.400 ~.401 35.500 5.6,'15 50.200 2.408 24. 400 1,1.513 75.200 1.809 70.900 3.9.30 56.500 2.33] 3q.lO0 MNEMONIC i LD ALI 4. NRAT CALl I LO CALl C ALI i, LO CAbi. NRAT C A I, I iL, D CALl NRAT CALl ILO CAL, i N RAT C AL i ILD CALl NRAT CALl ILO CALl NRAT CALl l. bO CALl N~A~ CAbI ILO CALk NRAI CAbi VALUE '1.798 13.900 2.954 13.300 3.311 12.300 2.456 1.1.950 9.036 14.100 3.648 12.950 b.252 15.600 3.336 13.300 6.792 15.700 3.186 14.400 7.178 13.500 3.240 12.200 6.910 12.250 2.460 12.200 10.3'15 15.800 4.500 13.o00 5.702 12.500 2.850 1i.900 DE ' i 6900. 000 6800. 000 6700,000 6600.000 6500.000 6400.000 6300,000 6200,000 6100.000 iqNE Mt. iN i C SP 0 R H 0 NCNb DT SP I LM NCNI, DT SP IbM DRHO NCNL DT SP D P H O NCNL DT SP 1 LM D k H O NCNL DT SP DRHU DT SP il,iq DHH[~ NCNL DT SP NCNL DT SP ILN D R H O NCNL DT VALUE - 3 J. 00 o 4.013 0.0]5 249. 356 96. 700 -34.500 5.012 0.036 321.030 9:1,150 -!8.000 4,446 0,039 391.4!6 90.700 -32.750 11.695 0,026 158,798 1,27.750 -21.500 4.656 -0.001 331.330 90.550 -23.500 6.1.38 -0.004 40:1.717 135.350 -36.250 46.132 0.006 175,9a6 130.200 -32.750 4.207 0.018 280.687 94.250 -34.000 10.000 0.010 223.176 110.800 M.,~ EM{.) N lC LLD D 17 H I [.CNL LLD L L 8 U NPHI FCNb I, LD L L 8 U NPHI F C N L I., I., 8 U NPHI FC N LLD b :[, 8 U NPti i FCNL LLD LLSU NPHI ~CNL LLD LbSU NPHI FCNL LLD LI, SU NPI~I [-'CNL LLD LL8 LI NPBI FCNi, VALttF.: 8.820 5,649 4,4.O00 65.236 6,758 4,656 34.8O0 92.704 :7.010 4.169 23.220 151.073 70.319 1,6.144 66.540 30.043 8.424 4.055 29.6'20 108.584 1.3,708 5,546 20.840 177.253 56,927 12,823 70,440 29.~14 6.395 3.436 3].640 81.120 J2.277 6.792 52.3~0 48.927 I,~ L 8 RB[]B GR h h 8 ~NOB G~ LbS GR GR G R BLS GR Rkt06 GI~ hhS GR bLS GR RHttB L L $ G~ HHtJ~ GR , .4 l~ [J k 5,6'75 i,'~ 50a 2. 427 85.700 5.083 1.22,000 2.518 107,900 4.308 54.100 2,~49 36.700 42,820 58.100 1.502 23.000 4,2:]0 78.900 2.27.t 4'7.500 7.756 58.000 2.3O8 33.400 31.0~7 5q.600 1.q57 24.400 4.470 1()9.'100 2.438 77.~00 11.407 lOb.lO0 2.126 76. 300 IDD C ALI. NRAT CALl ILD CALl NRAT CALl ILD CALl NRAT CAbI iLD C A L., t NRAT C A L, i 1LD C A L I NRAT CALl ILD CALk NRAT CALl CALl NRA'£ CAbI ILl) CALi NRAT CAb1 1 L t) CALl NRA'l: CALl VALUE 5.3&0 !5.300 3,900 1,:3.550 5.702 15.000 ~.392 it.350 6,546 12.250 2,594 12,050 18.8~0 16.450 5.440 13.500 7.047 12.350 2.938 !2.250 10.568 12.O50 2.170 12.250 21.085 17.000 5.828 14.000 15.950 3.250 13.950 10.864 15.400 4.332 1.3.400 6000. 000 5900,000 5800.000 5700,000 5600.000 5500.000 5400,000 5300.000 5200. o00 MNEMONIC NCNL DT SP DRHO N C N L DT 8P DRIqO NCNL DT SP I L M DRHO NCNL DT SP 1 LM DRHO NCNb DT DRHU NCNL D '_r' SP DRMO NCNb DT SP ibm D~HCJ NC NL DT lI,a DRHO NCNL OT VALUE; -16.250 2.938 0.166 327.897 !00.750 -28.750 4.966 0.056 272.103 101.100 -21.250 5.808 0.051 240.34:5 93.800 -18.750 4.285 0.037 286.695 99.400 ].945 0.079 189.270 115.550 -23.750 3,1q2 0.043 332,189 ! 05.000 -.tl.O00 4.875 0,097 2]56.481 107.800 -22.750 6.310 0.172 212.87~ 102.600 -22.250 3.102 o.oa3 248.927 107.050 LLD L L 8 U NPHI i'CNb LLD LLSU NPHI FCNL L, h O L L 8 O LLD L b 8 U NPHI F C N L LLD Lb8 U NPHI P'CNL hbD Lb8 L{ NPHI i'CNL bl., O LLSU NPHI FCNL LLD L 13 8 U NPH I ['CNL L I, D LLSU mi)ii I PCNL VALUE 5,781 3.048 26,300 111,588 6.~95 3.532 34.640 74.2,49 8.984 7.447 33.880 74.249 7.615 4.169 ]2.560 94.421 9.939 5.248 51. ;140 41 .RO~ 5. 322 3.135 30. 060 106.438 7.273 4.093 39.420 52.661 10.796 4.529 45.000 54.95b ~.b06 40.980 69.099 iq i~ E M U 1:~ I C L L S GR bLS G~ GR GR GR LbS RH[JB GR LLS GR GR bLS GR RHtJB GR b LS LbS GR GR la V A h U E, 3,~62 2.295 35.300 4,269 102.bO0 2,435 80.500 7,685 95,000 2.397 70.800 4.388 68.200 2.268 38.500 6.052 109.000 2.045 84.300 3.424 67.800 2,290 39.000 4.680 104.200 2.350 73,600 5.572 108.300 2.3bl 77.500 2.~12 80.400 2,310 60. 200 C A L ! NRAT C AL1 I bD CALl. NRAT CAbI I b D C A L 1 NRAT C A L 1 IbD CAbI NRAT C A L, I 1 LD CALl NRAT CALl. lbo CALl NRAT CALl iLD CALl N P,A'f C Ab i i LD CAbi CALl lbo CAb[ C ALI VAbUE 4.055 !3.900 2.880 13.000 5.861 10.500 3.360 12.950 7.311 1:3.950 3.28~ 13.050 0.310 12.700 3,242 12,150 b.~68 il.050 4.554 12,600 4.055 13.400 3.096 12.250 5.445 1t.050 3.740 13.350 7.58b 17.050 4.020 13.450 3.59/ 17.050 3.832 13.650 5 ! 00. ()00 5000.000 4900.000 4800.000 4700. 000 1600.000 4500.000 4400. 000 MN EMONIC D R a 0 NCNL DT ibm DkHO NCNL tiP DRHU NCNL DT SP DRHU NCNL DT SP ILM DRHO DT 8P D R H 0 N C N L DT IbM DRHO NCNL DT 8P I LM DRHO NCNL DT iI~M O R M[~ NC N L PT VALO I . 193. 56. -274. 452. '0, 202 . 59. -275, 95, 229, 141. -275, 95, 136. 100. -275 , 95, 156, 100. -275, 95, 215, 100. -275. 95. -0, 271. 100. -275. 95. 153. 100. -275. 95, 150. i00. 000 8].7 092 562 550 750 897 304 575 900 000 499 304 185 600 000 499 305 481 75O 000 499 3(} 4 652 750 000 499 304 451 750 000 499 3O 4 245 750 000 499 304 750 000 304 21.5 750 LLD LLSU NPHI LLD LLSU NPHI FCNL LLD N P h I ~CNL 6 L D L Ia 8 U NPH I FC N 6 LL,D L 6 8 U NPHi F C N L LLD LLSU NPHI FCNL LLD LLSU NPHI FCNL LLD 6LSU NPHI FCNL LL[) LLSU NPHI ~CNL VALUE 0.297 n 904 46.940 45.064 1,000 457,088 43,640 50.215 1,0O0 529.663 35,660 6.~,090 1.O00 579.663 76.800 24.O~4 1.000 529,663 48.1,60 36.9i0 1.000 529,663 38,860 58,798 1.000 529.663 !7.340 109,871 1.000 529.663 59.660 30.043 1,000 529,663 55,700 ~1,760 i M N L M O N 1 C LbS I~HOB GR LLS RHOB GR 6LS GR RHOB GE LbS G~ RHOB GR L L S GR RHOB GR GR LLS GR R h 0 B GR LbS bLS GR V A. L U L 0.236 70,800 2.372 45,00() 0,991, 63,200 2,524 -23,b00 0.991 35.600 2.511 175.500 0.991 26,300 1,695 175.600 0.991 35.900 2.172 i75.600 0.991 3U.300 175. bO0 0,991 35,400 2,416 175.600 0.991 44.100 2,095 175.600 0.991 48,q00 2.00,3 175,600 MNEi~IONIC VALU~ lbD 162754.780 C~"'! 12 550 NRAT 4.208 CALl 12,550 lbo 575.440 CALl :12.400 NRA't 3.822 CALl 12.500 iLD 1.01.859 CA6I 12.450 NRAT 3.152 CALl 12.500 I60 101.859 CALl 12.450 CALl 12.500 ILO 101.859 CALl 12.450 NRAT ~.184 CALl 12,500 i60 101.859 CALl 12.~50 NRAT 3,O14 CALl. 12.500 ILO 10i.859 CALl 12.450 NRA~£ 2.408 CALl 12.500 lbo 101.859 CALl 12,450 NRA1 4.908 CALi 12.500 1613 101.859 CALl 12.500 NRA'[ q.554 CALl 12.500 DEPT~ 4200,000 4!,00.000 lO00.O00 13900,000 3800,000 3700.000 3600.000 3500.000 3400.000 SP .bi brat] NCt~L DT SP I L M DRiiO NCNb SP NCNb DT SP DRHU NCNL DT DRFtO NCNb DT SP DEMO NCNb DT SP DRHO NCNL DT SP DRHO NCNL DT SP 1LM DRH(.~ NC NI: DI' VALUE -275.000 95.499 -0.304 149,785 100.750 -275.000 95.499 -O,304 220.172 100.750 -,275.000 95.,499 -0.304 224.89~ 100.750 -275.000 95.~99 -0,304 1,40.77t 100,750 -275.000 95.499 -0.30,4 185.40~ 100.750 -275.000 95.499 -0.305 136.051 100.750 -275.000 95.t99 -0.30.4 184.549 100.750 -275.00o 95.¢99 -0.304 197.854 100.750 -275.000 95.499 -0.304 182.83~ 100.750 MN EMI)N IC LLD LLSU LLD NPHI ECNL LbD LIJSO NPHI FCNL LLD LL8 U NFl-ti. FCNL LLD LLBU NPHI LLD L!:,SU NPflI FCNL LLD LL8U mPHI, ~CNL LbD LLBO NPHi FCNI, bi, D I., L 8 tJ mPHI VALUE 1.000 529.663 69.680 27.468 1.000 529.663 31.120 69.528 1.000 529.663 25'260 79.399 1.000 529.66:] 69.520 25.751 1.000 529.66,3 43.220 46.781 1,000 529 663 7o:a o 24.893 !.000 529.663 38.620 48.069 1.000 529.663 38,840 53.219 1.000 529.66t 44.640 48.069 MNEMONIC GP. GR LLS GR L, LS GR RHOS LI.,S GR GP bLS GR i-iHUB GR LbS GR GR LLS GR GR LbS L LS GR VALUE 0.991 41, 70n 2.125 1.75.600 0.991 45.200 2,361 175.600 0.991 39.200 2.295 175.600 0.991 25.400 1.841 175.600 0.991 59.50O 2.26.J 175.6O0 0.991 22.000 175.600 0.991 41.200 2.159 175.b00 0.991 42.000 2.268 175.~00 0.991 52.200 2.316 175.000 t, L, D C AL I NRA'I C C A L i ,NRAT C AL I I, LD C,ALi N R A i' CALl I bD CALl NRA'I' C ALI; I b if) CALl CA,bi CALl NRA'i CALl ibD CALl NRAT CAbi .[LD CA6i NRAT CAb1 CALl NRAT CALl VALuE 101.859 !2,350 5.424 12.500 10i.859 i2.450 3.090 12.500 101.859 12. 500 2. 12.500 101.859 12.450 5.700 1,2.500 '101.859 12.500 4.008 1.2.500 101.859 12.500 5.558 12.500 101.859 12.450 3.65~ 12,500 1.01.859 12.500 12.bO0 101.~59 12.450 3.88u 12.500 D E P i! 3300.000 0O0 ] 1 O0,00O tO00oO00 2900,000 2800.000 2700,o00 2600,000 2500.000 SP I l, t4 DRH() NCNL DT SF N C l~ L D'I' SP ILiq D R H (l NCi'iL DT 8F ILM NCNL DT SP 1L_NI DRHO NCNb DT SP iLM DRHO NCNL DT SP N C iq L DT SP ILM DRHO NCNL DT SP DR.HO NCNL DT VALUE; -275.000 95.499 -0.304 157.082 100.750 -275.000 95.499 -0.304 138.197 100.750 -275.000 95.499 -0.304 163.090 100.750 -275.000 95.499 -0.304 178.970 100.750 -275.000 95.499 -0.304 188.841 100.750 -275.000 95.499 -0.304 224.034 100.750 -275.000 95.499 -0.304 160.086 100.750 -275.000 95.499 -0.304 155.365 100.750 -275.000 95.499 °0.304 139.056 100.750 M N k~ M U N I C LLD Li, 8 U NPHI LLD LLSU NFHI FCNL LI,D LLSU NPHI FC N L LhD LhSt} NPhI ~CNL LLD L, LSU NPHI fCNL LLD LLSU NPHI FCNL LLD NPHI FCNL LLD LL8 U NFHi FCNL LI, D NPHI FCNL V A h Il k 1.000 529.663 0i.220 30.901 1.000 529.6u3 7{.380 2i.464 1,000 529.663 54.30o 35.622 1.O00 529.b63 48.920 .t9.485 1.000 529.663 43,580 48.069 1.000 529.663 32,~80 65.665 1.O00 529.663 54.340 34.335 1.000 529.6 b 3 52,260 34.335 1,000 529.663 64.260 24.893 L L $ GR Rhf'l~ LLS F, HuB GR L LS RHUD (JR bLS GP RH(JB LLS I~HOB GR LLS R H O 8 GR LLS GR RH(]B GR hLS GR RHOB GR LLS GR R. HO~ GR V A h lJ E 0.991 ~7.200 1.957 175.600 0.991 17.200 1.132 175.~00 0.991 42.000 2.209 175.b00 0.991 41.800 2.265 115.600 0.991. t6.400 2.371 1.15.600 0,991 35.000 2.q14 1,75.600 0.991 39.300 2.250 175.600 0,991 37,200 2,125 1.75.600 0.991 42.800 1.785 175,600 HN EM(..iN lC ILl) CALl NRAT CALl ILO CALl NRA't CAL.[ lbo CALl NRA'F CALl I I.,D CALk N RAT CALl. lhD CALl NRA1 CAbI IbD CALl NRAT CALl I, LD CAbl N R A T CALl CALl NRA:t CALl I L D C A L 1 N RAT CALl, VALUE 101.859 12.450 4.904 12.500 101.U59 12.450 5.552 12.500 101.~59 12.q50 4.725 12.500 1,01.859 12.400 3.9~0 12.500 1011.859 12.400 3.844 i2.500 101.859 12.350 3.220 12,500 101,859 12,400 4,156 1,2.500 101.859 12.550 4.54~ i2.500 101.859 12,600 5.358 12,500 DEPTH 2400,000 2300,000 2200,000 2100,000 2000.000 1930,000 SP i LM DT 8P I I~M DRHO NCNL DT SP i LM NCNL DT SP NCNL D T SP I LM DT 8P ILM D 1~ H ii NCNL DT VALUE -275.0O0 95.499 144.206 1,00.750 -275.000 95.499 -0.304 144.206 !00.750 -275.000 95.499 -0.304 1:44.206 i00.750 -275.000 95.499 -0.304 144.206 100.750 -275.000 95.499 -0.304 14'7.639 100.750 -275.000 95.~99 -0.250 1063.519 100.750 MNEMON lC Li.,D NPHi i~' CNL LLD L L 813 I~CNL LLD LLSU NPHI FCNL LLD LLSU NP}iI FCNL LLD NP}ii FCNL LLD LL8 U NPHI FCNL V AL I. IE; 1.000 529.663 57.340 29.6!4 1.000 529.683 59.820 25.75~ 1,000 529.66] 68.140 25.751. 1.000 529.6~3 60.240 30.472 1,000 529.663 b0.380 29.185 1.000 529.66] -5.000 1055.794 L L S G~ LLS t~ H 0 B GH LLS GR LLS GR GR LLS L L S GR GR V A L U E 0.991 35.!00 1.934 175.~00 0.991 35.900 1.906 175.000 0.991 32.~00 1.962 1,75.600 0,991 35,?00 1,988 175.~00 0.99! 35.500 2.042 1'15.600 0.991 0.000 0.000 175.~00 MN P./MO N lC CALl NRAT CALX iLD CALl NRAT CALl CALl NRA% CALl 1 LD C AL i NRAf CALl ILD CALl NRAT C AL 1 1LD CALl CALl VAbU~ 101.859 12.650 ~.786 12.500 10:1.859 12.~00 5.8ie 12.500 10'1.859 i2.550 5.326 12.500 1.01.859 12.550 12.500 10i.859 i2.~00 4.952 12.500 101.859 0.100 2.308 12.500 SUMMAi,~ ,i []F DATA RECORDS NUMBER [][~' RECORDS: 1218 LENGTH OF RE:CORDS: 1014 BYTES I~ENGTH OF LAST RLCOED: 222 BYT~S ~ILE TRAILER LENGTH: 62 BYTES FILE NAME: ~iDIT .00] MAXIMUM PHYSICAL RECORD L}!~NGTH: NEXT PiLE NAME: 1, 024 TAPE TRAILER LENGT~: 132 BITES TAPE NA~E: t52732 DAT}L: 82/ 4/ 5 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: O1 NEXT TAPE NAME: COMMENTS: UNIQUE WEbh IDENTIFICATION NUMBER IS NA
