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Home My WebLink About207-1701. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Set Tbg Patch in LS 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,494'N/A Casing Collapse Structural Conductor Surface 1,130 psi Intermediate 3,090 psi Production 8,530 psi Liner 7,500 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Eric Dickerman Contact Email:Eric.Dickerman@hilcorp.com Contact Phone:(907) 564-4061 Authorized Title:Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Perforation Depth TVD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 AOGCC USE ONLY 8,430 psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018742 207-170 6.4# & 4.6# / L-80 TVD Burst 11,292' LS & 10,364' SS 11,220 psi Tubing Grade:Tubing MD (ft): 5,750 psi 2,000' Length 50-733-20285-01-00 Hilcorp Alaska, LLC 2,000' MD PRESENT WELL CONDITION SUMMARY Size 609' 2,710' 4-1/2" See Attached Schematic 9,409'7" 20" 8,219' September 16, 2025 11,492'936' 2-7/8" x 2-3/8" dual 9,683' 7,353' 10,704' Perforation Depth MD (ft): 8,219' Granite Pt St 18742 24RDN/A Same 2,730 psi 609' 1,958' N/A~804psi 609' N/A N/A 9,683'11,449'9,672' Granite Pt 13-3/8" See Attached Schematic Middle Kenai Oil 9-5/8" m n P s 66 t S N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:47 pm, Sep 02, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.09.02 13:30:34 - 08'00' Dan Marlowe (1267) 325-539 A.Dewhurst 08SEP25 DSR-9/9/25MGR05SEP25 10-404 JLC 9/10/2025 Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.09.10 14:11:07 -08'00' 09/10/25 RBDMS JSB 091125 Tubing Patch Well: AN-24RD Well Name: AN-24RD API Number: 50-733-20285-01 Current Status: Offline Oil Well Leg: Leg #2 (E corner) Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 207170 First Call Engineer: Eric Dickerman 307-250-4013 Second Call Engineer: Casey Morse 907-777-8322 Maximum Expected BHP: 1,699 psi at 8950’ tvd Shut in BHP survey – (May 2025) Max. Potential Surface Pressure (MPSP): 804 psi Using 0.1 psi/ft gradient to surface Brief Well Summary AN-24RD is a dual string jet pump well that was drilled in 2008 to develop the Northwestern flank of the Anna platform after the parent well AN-24 watered out. The well is a hockey stick style well with repeat tops but originally only the C7, C6, & C5 in the toe were perforated below 10710’md. In May 2015, a RWO was performed to perforate the C5, 7, 8, 9 in the heel of the well. The jet pump started to struggle in March 2025. Troubleshooting and an LDL identified a hole in the long string at ~4,450’md. Objective: Set tubing patch in the long string to restore tubing integrity and return well to production. Notes on wellbore: - No Flow Test passed June 24, 2015. 5/22/25 Pull jet pump and standing valve. 5/23/25 Drift to tag at 11,217’ kb with 1.75” bailer. 5/25/25 Set Plug in R nipple at 10,358’ kb. Pressure test failed. 5/31/25 LDL indicated leak in long string at ~4,450’. Tubing Patch Well: AN-24RD Slickline Procedure: 1. MIRU on longstring. 2. Pressure test PCE to 250 psi low / 2,500 psi high. 3. Pull plug from R nipple at 10,367'. 4. Confirm leak depth with holefinder. Test tubing below and above leak. 5. Set standing valve in the jet pump cavity at 10,361’. 6. Set jet pump in jet pump cavity at 10,361’. 7. Set 2-7/8” tubing patch across tubing leak. a. Leak expected at ~4,450’ based on LDL. 8. MIT-T (Bundle test) to 1,500 psi. a. Bundle test pressures up the long string and short string against the standing valve. 9. RDMO. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Granite Point Field Well #: An-24RD Completed: 06/08/2015 Revised By: JLL 10/23/18 SCHEMATIC CASING AND TUBING DETAIL Size WT Grade CONN ID Top BTM 20”94#K-55 -19.124”Surface 609’ 13-3/8”54.5 & 68#K-55 Buttress 12.415”Surface 2,000’ 9-5/8”40 & 43.5#N-80 & S-95 Buttress 8.755”Surface 8,219’ 7” Liner 29#P-110 Hydril 563 6.184”7,994’10,704’ 4.5” Liner 12.6#L-80 Hydril 563 3.958”10,556’11,492’ Long String TUBING DETAIL 2-7/8"6.5#L-80 8rd EUE 2.441”Surface 7,717’ 2-7/8"6.4#L-80 Supermax 2.441”7,717’10,492’ 2-3/8”4.6#L-80 Supermax 1.995”10,492’11,292’ Short String 2-7/8"6.4#L-80 8rd EUE 2.441”Surface 7,815’ 2-3/8”4.6#L-80 Supermax SCC 1.995”7,815’10,364’ PBTD = 11,449’ MD / 9,669’ TVD TD = 11,494’ MD / 9,677’ TVD JEWELRY DETAIL NO.Depth ID OD Item 60’Tubing Hanger 1 10,361’2.441 5.875 2.5" Accelerated JP BHA MVSR 2 10,367’2.188 2.875 R Nipple 3 10,525’1.875 3.063 XA Evolution Sliding Sleeve (up opens / down closes) 4 10,492’1.995 2.375 2-7/8” by 2-3/8” Crossover 5 11,292’2.375 3.250 Ratcheting Mule Shoe Note: Discrepancy of 3’ between the LS & SS cavity depth PERFORATION DETAIL Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)Amt spf C5B 9,213'9,263'8,281'8,330'50'TCP C7X 9,475'9,480'8,538'8,543'5'TCP C7B 9,571'9,576'8,631'8,636'5'TCP C7B 9,588'9,594'8,647'8,653'6'TCP C7C 9,662'9,699'8,717'8,752'37'TCP C7D 9,716'9,742'8,768'8,791'26'TCP C7E 9,789'9,804'8,834'8,847'15'TCP C8B 9,888'9,902'8,920'8,932'14'TCP C8C 9,959'10,011'8,979'9,020'52'TCP C8C 10,020'10,038'9,027'9,041'18'TCP C9A 10,209'10,225'9,161'9,171'16'TCP C9A 10,250'10,263'9,186'9,193'13'TCP C9B 10,325'10,345'8,227'9,238'20'TCP C8C 10,462'10,528'9,296'9,327'66'TCP C8B 10,565'10,580'9,345'9,357'15'TCP C8B 10,591'10,596'9,357'9,359'5'TCP C-7E 10,711'10,731'9,412'9,421'20'6 C-7D 10,784'10,805'9,444'9,453'21'6 C-7C 10,817'10,859'9,458'9,476'42'6 C7B 10,882'10,894'9,485'9,490'12'TCP C-7B 10,903'10,934'9,494'9,506'31'6 C-7A 10,944'10,990'9,510'9,528'46'6 C-6D 11,030'11,038'9,543'9,546'8'6 C-6X 11,079'11,086'9,561'9,563'7'6 C7X 11,087'11,095'9,564'9,567'8'TCP C-5B 11,291'11,355'9,630'9,648'64'6 C-5A 11,380'11,423'9,655'9,666'43'6 Fish: 10/19/2018 11,449' 1. Cutter Bar #2 - (5') 2. Cutter Bar #1 - (5') 3. Wireline Fishing Tools - (30.83') 4. Bailer Tube - (5') Granite Point Field Well #: An-24RD Completed: 06/08/2015 Updated by DMA 09-02-25 PROPOSED SCHEMATIC CASING AND TUBING DETAIL Size WT Grade CONN ID Top BTM 20”94#K-55 -19.124”Surface 609’ 13-3/8”54.5 & 68#K-55 Buttress 12.415”Surface 2,000’ 9-5/8”40 & 43.5#N-80 & S-95 Buttress 8.755”Surface 8,219’ 7” Liner 29#P-110 Hydril 563 6.184”7,994’10,704’ 4.5” Liner 12.6#L-80 Hydril 563 3.958”10,556’11,492’ Long String TUBING DETAIL 2-7/8"6.5#L-80 8rd EUE 2.441”Surface 7,717’ 2-7/8"6.4#L-80 Supermax 2.441”7,717’10,492’ 2-3/8”4.6#L-80 Supermax 1.995”10,492’11,292’ Short String 2-7/8"6.4#L-80 8rd EUE 2.441”Surface 7,815’ 2-3/8”4.6#L-80 Supermax SCC 1.995”7,815’10,364’ PBTD = 11,449’ MD / 9,669’ TVD TD = 11,494’ MD / 9,677’ TVD JEWELRY DETAIL NO.Depth ID OD Item 60’Tubing Hanger 1 ± 4,450’2-7/8” tubing Patch 2 10,361’2.441 5.875 2.5" Accelerated JP BHA MVSR 3 10,367’2.188 2.875 R Nipple 4 10,525’1.875 3.063 XA Evolution Sliding Sleeve (up opens / down closes) 5 10,492’1.995 2.375 2-7/8” by 2-3/8” Crossover 6 11,292’2.375 3.250 Ratcheting Mule Shoe Note: Discrepancy of 3’ between the LS & SS cavity depth PERFORATION DETAIL Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)Amt spf C5B 9,213'9,263'8,281'8,330'50'TCP C7X 9,475'9,480'8,538'8,543'5'TCP C7B 9,571'9,576'8,631'8,636'5'TCP C7B 9,588'9,594'8,647'8,653'6'TCP C7C 9,662'9,699'8,717'8,752'37'TCP C7D 9,716'9,742'8,768'8,791'26'TCP C7E 9,789'9,804'8,834'8,847'15'TCP C8B 9,888'9,902'8,920'8,932'14'TCP C8C 9,959'10,011'8,979'9,020'52'TCP C8C 10,020'10,038'9,027'9,041'18'TCP C9A 10,209'10,225'9,161'9,171'16'TCP C9A 10,250'10,263'9,186'9,193'13'TCP C9B 10,325'10,345'8,227'9,238'20'TCP C8C 10,462'10,528'9,296'9,327'66'TCP C8B 10,565'10,580'9,345'9,357'15'TCP C8B 10,591'10,596'9,357'9,359'5'TCP C-7E 10,711'10,731'9,412'9,421'20'6 C-7D 10,784'10,805'9,444'9,453'21'6 C-7C 10,817'10,859'9,458'9,476'42'6 C7B 10,882'10,894'9,485'9,490'12'TCP C-7B 10,903'10,934'9,494'9,506'31'6 C-7A 10,944'10,990'9,510'9,528'46'6 C-6D 11,030'11,038'9,543'9,546'8'6 C-6X 11,079'11,086'9,561'9,563'7'6 C7X 11,087'11,095'9,564'9,567'8'TCP C-5B 11,291'11,355'9,630'9,648'64'6 C-5A 11,380'11,423'9,655'9,666'43'6 Fish: 10/19/2018 11,449' 1. Cutter Bar #2 - (5') 2. Cutter Bar #1 - (5') 3. Wireline Fishing Tools - (30.83') 4. Bailer Tube - (5') Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/18/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250618 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN 07RD2 50733200120200 195113 6/1/2025 AK E-LINE LDL AN 24RD 50733202850100 207170 6/1/2025 AK E-LINE LDL BRU 221-24 50283202020000 225027 5/29/2025 AK E-LINE CBL KALOTSA 10 50133207320000 224147 5/21/2025 AK E-LINE Perf KALOTSA 2 50133206590000 216155 5/25/2025 AK E-LINE Perf PAXTON 11 50133207040000 221114 5/27/2025 AK E-LINE Perf PAXTON 11 50133207040000 221114 5/26/2025 AK E-LINE Perf PBU 06-12C 50029204560300 225022 5/17/2025 HALLIBURTON RBT-COILFLAG PBU 15-32C 50029224620300 217104 5/27/2025 HALLIBURTON RBT PBU D-01B 50029200540200 224155 5/18/2025 BAKER MRPM PBU D-01B 50029200540200 224155 5/18/2025 HALLIBURTON RBT-COILFLAG PBU H-18A 50029208800100 224011 5/14/2025 BAKER MRPM PBU H-18A 50029208800100 224011 5/14/2025 HALLIBURTON RBT-COILFLAG PBU L-109 50029230460000 201201 5/24/2025 HALLIBURTON IPROF PBU L-115 50029230350000 201140 5/19/2025 HALLIBURTON IPROF PBU L-117 50029230390000 201167 5/30/2025 HALLIBURTON IPROF PBU N-07B 50029201370200 223122 6/7/2025 HALLIBURTON RBT PBU S-100A 50029229620100 224083 5/26/2025 HALLIBURTON PPROF-LDL PBU Z-34 50029234690000 212061 5/17/2025 HALLIBURTON IPROF-LDL Please include current contact information if different from above. T40566 T40567 T40568 T40569 T40570 T40571 T40571 T40572 T40573 T40574 T40574 T40575 T40575 T40576 T40577 T40578 T40579 T40580 T40581 AN 24RD 50733202850100 207170 6/1/2025 AK E-LINE LDL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.18 12:03:53 -08'00' • ti 711//7.614_, �w\� ST THE STATE Alaska Oil and Gas irk' �-sf-9A, ofA Conservation Commission LAsKAL ilex----:_:---4:,--f _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main. 907 279 1433 OFALAS�� Fax 907 276.7542 www aogcc.alaska.gov August 6, 2015 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification SCANNEDGranite Point State 18742 #24RD '= PTD 2071700 Dear Mr. Golis: On June 24, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Granite Point State 18742 Well #24RD located on the Anna Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 —was rigged up on Granite Point State 18742 Anna#24RD prior to the test. The well performance was monitored for 3 hours with resulting flow rates (oil and gas) below the regulatory limits, passing the no-flow test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Granite Point State 18742 Anna #24RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Anna Platform. Sincerely, James B. Regg) )e_1<- Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1li5I17 DATE: 7/17/15 P. I. Supervisor FROM: Jeff Jones SUBJECT: No Flow Test Petroleum Inspector Granite Pt State 18742 #24RD Hilcorp Alaska LLC - PTD 2071700 - June 24, 2015: I traveled to Hilcorp's Granite Point Field Anna platform and witnessed a No-Flow verification test on well Anna 24RD. The following table shows test details: Time Pressures1 Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 9:30 <180 ' < 1 10:00 <180 V < 1 - 10:30 <180 < 1 11:00 <180 - < 1 11:30 <180 < 1 12:00 <180 < 1 - 12:30 <180 < 1 1 Pressures are T/IA/OA Summary: Gas flow rate recorded during the 3-hour test never exceeded 180 standard cubic feet per hour. Total volume of fluid produced was less than one quart. Hilcorp's Granite Pt State 18742 Well 24RD meets the AOGCC requirements for a No-Flow designation. Attachments: None 2015-0624_No-Flow_GranitePt State_18742_24RDjj.docx Page 1 of 1 • STATE OF ALASKA AL A OIL AND GAS CONSERVATION COM, _SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing CI Operations shutdown ❑ Performed: Suspend ❑ Perforate ] Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ P 9 PP 9 Plug for Redrill 0 Perforate New Pool❑ Repair Well ❑ Re-enter Susp Well❑ Other: Run Jet Pump Completion ] 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development E Exploratory❑ 207-170 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service El 6.API Number: Anchorage,AK 99503 50-733-20285-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018742 Granite Pt St 18742 24RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Point Field/Middle Kenai Oil Pool 11.Present Well Condition Summary: ECEIVED Total Depth measured 11,494 feet Plugs measured N/A feet true vertical 9,683 feet Junk measured N/A feet J U L 0 7 2 015 Effective Depth measured 11,449 feet Packer measured N/A feet AOG CC true vertical 9,672 feet true vertical N/A feet �, Casing Length Size MD ND Burst Collapse Structural Conductor 609' 20" 609' 609' Surface 2,000' 13-3/8" 2,000' 1,958' 2,730 psi 1,130 psi Intermediate 8,219' 9-5/8" 8,219' 7,353' 5,750 psi 3,090 psi Production 2,710' 7" 10,704' 9,409' 11,220 psi 8,530 psi Liner 936' 4-1/2" 11,492' 9,683' 8,430 psi 7,500 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 11,292'(MD)LS 9,631'(ND)LS Tubing(size,grade,measured and true vertical depth) 2-7/8"&2-3/8"dual 6.5#/6.4#&4.6#L-80 10,364'(MD)SS 9,248'(ND)SS Packers and SSSV(type,measured and true vertical depth) N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A %AWE© I j 1 28 ;!,11L.,.,11 L, Treatment descriptions including volumes used and final pressure: G N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 21 28 1 68 80 Subsequent to operation: 41 5 16 78 92 14.Attachments(required Per 20 AAC 25 070,25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development] Service El Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ] Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ 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: 315-303 Contact Trudi Hallett Email thallett ac hilcorp.com Printed Name Trudi Hallett Title Operations Engineer Signature UIA. 4461Phone (907)777-8323 Date 7/6/2015 7/315-- RBDMSJR !"` - 8 2015 Form 10-404 Revised 5/2015Submit Original Only Granite Point Field SCHEMATIC Well #: An-24RD HBcorp Alaska,LLC Completed: 06/08/2015 API#50-733-20285-01 CASING AND TUBING DETAIL RKB to TBG Head=60' Size WT Grade CONN ID Top BTM 20j L 20" 94# K-55 - 19.124" Surface 609' 13-3/8" 54.5&68# K-55 Buttress 12.415" Surface 2,000' 9-5/8" 40&43.5# N-80&S-95 _ Buttress 8.755" Surface 8,219' 7"Liner 29# P-110 Hydril 563 6.184" 7,994' 10,704' 4.5"Liner 12.6# L-80 Hydril 563 3.958" 10,556' 11,492' 13-3/8", , Long String TUBING DETAIL 2-7/8" 6.5# L-80 8rd EUE 2.441" Surface 7,717' 2-7/8" 6.4# L-80 Supermax _ 2.441" 7,717' 10,492' 3 2-3/8" 4.6# L-80 Supermax 1.995" 10,492' 11,292' 0 0 Short String 9-5/8"/ k 2-7/8" 6.4# L-80 8rd EUE 2.441" Surface 7,815' 2-3/8" 4.6# L-80 Supermax SCC 1.995" 7,815' 10,364' i I Est.TOC 8,250'ia IN CBL ( I - JEWELRY DETAIL 6/1/15 L IliIN M NO. Depth ID OD Item 60' _ Tubing Hanger 1 10,361' 2.441 5.875 2.5"Accelerated JP BHA MVSR E2 10,367' 2.441 2.875 R Nipple 3 10,525' 1.875 3.063 2 3/8"Evolution Sliding Sleeve 4 10,492' 1.995 2.375 800' -2 3/8"Supermax Tbg Tail 5 11,292' 2.375 3.250 Ratcheting Mule Shoe 12 I R '�'., : Note: Discrepancy of 3'between the LS&SS cavity depth 7„ I 3 ID( l!.,1, sm PERFORATION DETAIL ir ni Zone Top(MD) Btm(MD) Top(ND) Btm(TVD) Amt spf C58 9,213' 9,263' 8,281' 8,330' 50' TCP C7X 9,475' _ 9,480' 8,538' 8,543' 5' TCP C7B 9,571' 9,576' 8,631' 8,636' 5' TCP C7B 9,588' 9,594' _ 8,647' 8,653' 6' TCP V. C7C 9,662' 9,699' 8,717' 8,752' 37' TCP C7D 9,716' 9,742' _ 8,768' 8,791' 26' TCP C7E 9,789' 9,804' 8,834' 8,847' 15' TCP C8B 9,888' 9,902' 8,920' 8,932' 14' TCP C8C 9,959' 10,011' 8,979' 9,020' 52' TCP fl , C8C 10,020' 10,038' 9,027' 9,041' 18' TCP C9A 10,209' 10,225' 9,161' 9,171' 16' TCP C9A 10,250' 10,263' 9,186' 9,193' 13' TCP C9B 10,325' 10,345' 8,227' 9,238' 20' TCP L•, C8C 10,462' 10,528' 9,296' 9,327' 66' TCP tC8B 10,565' 10,580' 9,345' 9,357' 15' TCP Le 4 C8B 10,591' 10,596' 9,357' 9,359' 5' TCP C-7E 10,711' 10,731' 9,412' 9,421' 20' 6 4 4710 C-7D 10,784' 10,805' 9,444' 9,453' 21' 6 C-7C 10,817 10,859' 9,458' 9,476' 42' 6 C7B 10,882' 10,894' 9,485' 9,490' 12' TCP $11, k C-7B 10,903' 10,934' 9,494' 9,506' 31' 6 !' C-7A 10,944' 10,990' 9,510' 9,528' 46' 6 fl -. I C-6D 11,030' 11,038' 9,543' 9,546' 8' 6 C-6X 11,079' 11,086' 9,561' 9,563' 7' 6 C7X 11,087' 11,095' 9,564' 9,567' 8' TCP g :„. t. C-SB 11,291' 11,355' 9,630' 9,648' 64' 6 C-5A 11,380' 11,423' 9,655' 9,666' 43' 6 5Log ; tIllq 4-1/2"Iu...,I.:ji L. PBTD=11,449' MD/9,669'TVD TD=11,494' MD/9,677'TVD Revised By:1LL 07/06/15 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 #24RD _ 50-733-20285-01 207-170 5/27/15 6/8/15 Daily Operations: 05/27/15-Wednesday Bleed down well. Removed rig floor panels, "H" beam &drip pan. Installed hand rails. Shot fluid levels. N/d flow lines. Installed BPV's. N/D tree. N/U riser, single gate, mud cross. Unloaded boat. N/U double gate, annular&flow nipple. Installed Koomey lines. Installed scaffolding in cellar. C/o block valve on accumulator. Checked N2 in bottles, all good. C/o upper rams. 05/28/15-Thursday Finish install flow line. R/u flow line sensor. Calibrate/test gas system. R/u Platform air t/accumulator& remote panel. M/u 2 7/8 TJ. Pull BPV f/ I/s, install TWC, RIH m/u TJ t/SS. Fill stack w/water, shell test 250/250019od. Test BOPE as per Hilcorp &AOGCC regulations. Test witnessed by AOGCC,Johnny Hill. Tested w/2 3/8, 2 7/8" & 3 1/2 Ti's.Test 250 low, 2500 high, all good. (had pressure under BPV when c/o t/test blinds, bled pressure & pulled). R/D Ti's. R/U e-line. Pull TWC's. M/u 2 7/8 landing jt t/SS back out I/d pins on SS hanger. Pull hanger free @ 70k. Cont. pull t/90k. P/U e-line tools. RIH w/tubing punch, punch holes w/top shot @10,344 10 shots, 6spf, POOH. M/U 1 1/2" RCT, RIH t/ 10,345' attempt cut w/no indication. POOH find short in jars, C/O. RIH w/ 1 1/2 RCT, t/ 10,345' make cut, had good indication fired. POOH. 05/29/15- Friday POOH w/e-line. C/o accumulator air pump. Service rig. Install secondary hook-load sensor. Pull hanger t/floor, up wt 84, dn wt 56. R/u BJ tongs. Break hanger& I/d. POOH I/d 242 Jt's 2 7/8" IBT 6.4# L-80 SCC, &80 JT's 2 3/8" IBT 4.6# L-80 SCC & 1-cut jt 29.44, 6- pup jt's, using vac & inside wipers t/clean diesel f/tubulars. Vac out tubulars on pipe rack. Install thread protectors. Transfer diesel f/ISO tanks t/ R4R storage tank. M/u landing Jt. M/U landing jt t/hanger on LS. BO 1/d pins. Pull hanger t/floor. Unseat hanger @ 70k p/u wt 82k t/floor. L/d hanger& landing jt. POOH, L/D 100 JTs 2 7/8" IBT 6.4# L-80 SCC L/S= 3,215'. 05/30/15-Saturday PTSM. POOH L/D 227 Jt's 2 7/8" IBT 6.4# L-80 SCC, & 28 JT's 2 3/8" IBT 4.6# L-80 SCC& 1-cut jt 2.84', 9- pup jt's. Pump cavity assembly, 8,201', using vac& inside wipers t/clean diesel f/tubulars. Cleaned & cleared rig floor. Installed wear bushing. Stocked rig floor w/tools. P/U BHA#1- 6" bit, 7" casing scraper, bit sub, xo= 10.52, 84 jts 3 1/2 PH-6 wk string = 2,579.41'. Double pin xo sub, 9 5/8 scraper, bit sub, xo= 11.69'/2,601.63 total. TIH p/u 150 jt's 3 1/2 PH-6 wk string t/4,686', up wt 78, dn wt 68. 05/31/15-Sunday Cont. TIH w/tandem scraper assy. P/u 31/2 PH-6 wk string, 340 jts total. Saw 7" liner top @ 7,996', up wt 118, dn wt 90. Tagged 4.5" liner top @ 10,563', up wt 156, dn 106. POOH l/d 2 jts t/10,524'. Rig maint. Repair Hyd valve bank on rig hyd. POOH stand back w/3 1/2 PH-6 work string. L/d tandem 9 5/8"/7" scraper assy's. R/U e-line. P/u 3.25 CBL, w/gamma/CCL. RIH w/3.25 CBL, w/gamma/CCL. 06/01/15 - Monday Cont. running CBL up t/7,890'est TOC @ 81250'. Rid e-line. P/U 7"test packer.TIH t/9,121', set packer. Fill hole 127 bbls, pressure up t/2700 psi, lost 150 psi in 50 min, bled down. Had a bad valve from bleed down, c/o valve. Refilled lines, shut in & pressured up t/2800. Ran chart f/55 min, flat lined for last 35 min @ 2700, bled down. Blow down lines& choke. POOH. L/D 7" packer. P/U 4.5" c/o assy- 3 3/4" bit, 4.5" scraper, bit sub, 32 jts 2 3/8" HT SL-H90 DP, xo 3 1/2 if x 2 3/8 HT SL-H90, xo 3 1/2if x 3 1/2" PH-6 = 1001.33'. TIH w/3 1/2 PH-6 t/3,300' up wt, 52, dn wt 46. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 #24RD 50-733-20285-01 207-170 5/27/15 6/8/15 Daily Operations: 06/02/15-Tuesday Cont. TIH t/tag @ 11,442', up wt 168, dn wt 118. R/u t/circulate t/ production. Reverse CBU x2 @ 3.2 BPM 630 PSI. Circulate t/pits till interface. Circulate 102 bbls t/ production. Shut down, monitor well. Was u-tubing up tubing. Pump tubing vol. Monitor well, static. POOH t/ 10,154', up wt 158, dn 109. Monitor well. Service rig. Blow down choke & surface lines. POOH f/10,154', L/D 4 1/2 c/o assy. Clean & clear floor. Pull wear bushing. Fill pill pit w/water. M/u 3 1/2 tj.Attempt set test plug, no go. Inspect, take t/weld shop T/dress. R/u &flush well head. 06/03/15 -Wednesday Dress test plug. M/u rih w/o seal ring, good. Try insert "o" ring no go. Replacement arrived. M/u rih, fill stack, shell test t/2500 good. Test BOPE as per Hilcorp&AOGCC regulations.Test witness waived by AOGCC,Jim Regg @ 9:50 on 6-1-15. Tested w/2 7/8" & 3 1/2 TJ's.Test 250 low, 2500 high, all good. Pull test plug, install wear bushing, l/d test jt, c/o handling eq. PJSM w/all involved. P/U 2 3/4" &4 5/8 TCP assy. TIH w/3 1/2 PH-6 wk string 0,977' t/6,956', up wt 116, dn wt 82. 06/04/15-Thursday Cont.TIH_w/TCP assy t/ 11,131', up wt 172, dn wt 103. P/u t/111 120'. R/u e-line. Run correlation pass#1, move up 10', run correlation pass#2, send t/engineers to approve.Verified on depth. R/d e-line. Fill hole, r/u &drop bar. Bar fell 3 min, 55 sec. Guns fired, had good indication on surface. Well went on vac, filled 20 bbls. POOH t/10,435', up wt 178, dn 103, fill hole loss rate @ 11 BPH. CBU @ 3bpm, 350 psi, at 60 bbls back turned oil/gas returns t/ production. Cir 208 bbls total t/production. Cont. circ t/pits. Shut down, monitor well, static loss rate dropped t/3BPH while circ. POOH stand back 34 stands 3 1/2 PH-6 wk string. POOH, l/d 216 jts 3 1/2 PH-6 wk string, using vac & inside pipe wiper t/clean. L/d xo sub, RA sub. Fill disk, 2 jts 2 7/8 tubing, firing head, load boat w/wk string t/transfer t/ Bruce. Move gun racks. L/d guns. POOH l/d 4 5/8 guns. Clean while POOH. 06/05/15 - Friday Cont. L/D 6 5/8 & 2 3/4 TCP assy. OOH, all guns fired. Clean & clear floor, pipe rack& drill deck. C/o upper rams t/2 3/8 x 31/2 dual flex rams. M/u 2 3/8, x 2 7/8 tj t/dual fixture & land test plug. Finish m/u t/j fill stack. Test 250 low 2500 high, had leak on high test. Finding no surface leaks pulled t/j had cut seal ring. C/o seal ring, re-test, good.Tested w/dual 2 3/8 x 2 7/8 tj's both ways.Tested w/2 3/8 single t/j. Pull test plug. Unload boat. Setup pipe rack. R/u dual handling eq, stabbing board. PJSM. P/U mule shoe & 2 3/8 6.4# L-80 supermax tubing w/SCC t/732'. 06/06/15-Saturday P/U-completion jewelry w/Accelerated MVSR-Parallel BHA "Hilcorp special" pump cavity as perplan. TIH w/4.6# L-80 2 3/8" sprmx, SC collars Short string/ 6.4# L-80 2 7/8 sprmx, SC collars long string, Dual completion t/3,566', xo t/2 7/8" 8RD EUE 6.5" L-80 dual completion. Cont.TIH t/9,014' L/S. Hilcorp Alaska, LLC _ Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 #24RD 50-733-20285-01 207-170 5/27/15 6/8/15 Daily Operations: 06/07/15-Sunday Cont. RIH w/Accelerated MVSR- Parallel BHA" Hilcorp special" pump cavity, w/2 7/8" 8RD EUE 6.5" L-80 dual completion. Cont.TIH f/9,014', t/11,242', up wt 158k, do 98k. Ran total of 330 fts. P/U landing jts& m/u DCB hanger's. RIH t/ 11,290'. R/U slick line testing lubricator to 1500 psi-Drop standing valve on long,string and let fall. Chase standing valve to pump cavity seat at 10,365' MD with 2" gauge ring and verify standing valve seated. Pooh w/slick line. R/u, bundle test tubing to 1500 psi for 30 minutes on chart ( good test ). Rig down test equipment. Rigging down slick line and lubricator. Land out DCB hanger with 98k down weight. Weight indicator reading (Rig Block wt 12k), and run in lock down pins. Set BPV. R/d Weatherford dual handling equipment and hoses. Remove Floor plates & H-Beam. Remove drip pan. R/d flow shoe & hang off flow line. Install hand rails on rig floor. N/d bell nipple and stripper head. R/u hose and drain stack. P/u lifting plate and make up same to BOP's. Nipple down BOP's & rig down scaffolding. P/u and hang off BOP's. Nipple down and lay out riser. Set tree in place and nipple up same. 06/08/15 - Monday Held Safety meeting,JSA. Service rig. Finish torqueing bolts on tree and test void to 5k. Pull BPV's. Install two way checks. Shell tested tree to 5k. Cleaned up well head room. Hook up flow lines to tree. Turn well over to production. II P TO 2 o 7 _ v Loepp, Victoria T (DOA) From: Trudi Hallett <thallett@hilcorp.com> Sent: Tuesday,June 02, 2015 9:28 AM To: Schwartz, Guy L(DOA); Loepp,Victoria T(DOA) Cc: Juanita Lovett;Ted Kramer Subject Granite Pt St 18742,An-24RD, Sundry No.315-303 (PTD 207-170) Follow Up Flag: Follow up Flag Status: Flagged Good Morning,Guy/Victoria- Per sundry no:315-303,a cement bond log was run on June is`,2015 to verify sufficient bond/isolation above the proposed top perforation in the An-24RD.The top of cement was verified @ 8,25o'MD after the log was evaluated. It was also confirmed that there is sufficient cement to isolate and contain the new perforations.The new proposed top shot is @ 9,213'MD—yielding us+/-1000'of isolation above. Also per above mentioned sundry,a casing test was required on the 7"liner to confirm integrity. It needed to be tested to 2,5oopsi and charted for 3o min.A test packer was run in and set @ 9,121'MD. Pressured up to 2,700 psi, tested and charted for 35 min.Test good. Please contact me with any questions or concerns. Thanks- Tru-ol v Trudi Hallett Operations Engineer Cool.Inlet 01 .1 ,et I cam I lilLorh.Ua,l.a. [ L(' Hilcorp SCANNED ,ILIPJ 15 2015 A Company Built on Energy thallett a hilcorp.com 0: 90-.---.N323 C: 90-.301.66;- 1 TJt (. ...,<;,OF ,,,��j:s\ THE STATE Alaska Oil and Gas ` �'� OfALAsKA. Conservation Commission :_t __-_,- __= 4114,-.:,-;-_, 333 West Seventh Avenue itts� GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907.279 1433 �1 ALAS Fax 907 276 7542 www.aogcc.alaska goy %AWED JUN 0 1 � : a7 — /7 6 Trudi Hallett Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Pt Field, Middle Kenai Oil Pool, Granite Pt St 18742 24RD Sundry Number: 315-303 Dear Ms. Hallett: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, g/4 CI Cathy 1 Foerster Chair DATED this day of May, 2015 Encl. c �-�' • fjC� 6\900 IVED • STATE OF ALASKA Y 15 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 2QAAC 25.280 1.Type of Request: Abandon❑ Plug Perforation*❑ Fracture Stimulate Cl Pull Tubing 0 Operations shutdown❑ Suspend❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program❑ Plug for Redril❑ Perforate New Pool❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Jet Pumo Completion 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory 0 Development 0 207-170 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20285-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 76,Rule 2(map attached) Will planned perforations require a spacing exception? Yes ❑ No 0 Granite Pt St 18742 24RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018742 Granite Pt/Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,494 9,683 11,449 9,672 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 609' 20" 609' 609' Surface 2,000' 13-3/8" 2,000' 1,958' 2,730 psi 1,130 psi Intermediate 8,219' 9-5/8" 8,219' 7,353' 5,750 psi 3,090 psi Production 2,710' 7" 10,704' 9,409' 11,220 psi 8,530 psi Liner 936' 4-1/2" 11,492' 9,683' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 2-7/8"x 2-3/8"dual 6.4#&4.6#/L-80 11,436'&10,347' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A N/A 12.Attachments: Description Summary of Proposa 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 6/15/2015 Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Trudi Hallett__ Email thallettCa�hilcorp.com Printed Name Trudi Hallett Title O erations En ineer i�� y -7.;;;77-74340 , Signature ''' '1‹../ " " �� " " Phone (907)777-8323 Date 5/15/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: S^ 1S _ �0.7"Plug Integrity CI BOP Test� Mechanical Integrity Test ID Location Clearance ❑ Other: 2500 PS /3 c) P ( `5 f- ( /j,is P ._ / o .sU p S- k /Vc - F701--i 're.;f- re k -1- A Spacing Exception Required? Yes ❑ No 0 Subsequent Form Required: 1 b -- oif APPROVED BY iaApproved by: COMMISSIONER THE COMMISSION24_ Date: S- —15 4\ �Q L ALor / i 5 �� Submit Fon i ane Form 10-403 Revised 5/2015 pp o e a 11 a to 12 montl�Y(s frpftj a date of royal. Attachments in Duplicate RBDMS MAY 2 9 2015 Well Prognosis Well: An-24RD Hilcorp Alaska,LL Date:05/15/2015 Well Name: GRANITE PT ST 18742#24RD API Number: 50-733-20285-01 Current Status: Oil Producer Leg: . 2 Estimated Start Date: June 15, 2015 Rig: Moncla 301 Reg.Approval Reqd? N/A Date Reg.Approval Rec: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 207-170 First Call Engineer: Trudi Hallett (907) 777-8323 (0) (907)301-6657 (M) Second Call Engineer: Dan Taylor (907) 777-8319 (0) (907)947-8051 (M) AFE Number: Current Bottom Hole Pressure: —2,000 psi at 9,556 ft TVD (11,066' MD) Based Pressure Build Up test 6/28/2008 Maximum Expected BHP: —2,000 psi at 9,556 ft TVD(11,066' MD) Based Pressure Build Up test 6/28/2008 Max. Anticipated Surface Pressure: — 1,050 psi Based on 0.1 psi/ft gradient to 9,556 ft TVD. Brief Well Summary AN-24RD was sidetracked and completed in 2008 after the original well AN-24 watered out in 2003. The well was drilled as a "hockey stick" style to target the crest and west flank portions of the Tyonek reservoir. It was completed with a dual string packerless power oil completion in the Tyonek. AN-24RD is currently shut-in due to mechanical reasons. The RWO's objective is to clean out the well, and to add new perforations in intervals C5B - C9B. There is a decision point that will need to be decided after step# 12. Well research has not been able to determine the top of cement in the 7" casing string. Step# 12 is to run a CBL to determine that there is sufficient cement to isolate and contain the new perforations or if a block squeeze is necessary. The spacing exception has been reviewed and a map detailing that work is attached. Once perforated, AN-24RD will be placed back on line with a dual string jet pump completion. Procedure 1. Reverse out Jet Pump 2. Bleed well off(casing/tubing). 3. Shoot fluid levels on back side. 4. Circulate FIW down long string taking returns up short string until clean. 5. Ensure well is dead. 6. Set BPV. 7. ND tree/NU BOPE. Function test BOPE (notify AOGCC of test 48hrs prior to expected test). 8. Test all BOP equipment per AOGCC guidelines and Hilcorp BOPE testing procedures to 250psi LOW and 2,50.0 psi HIGH. 9. Remove BPVs. 10. POOH w/Dual string completion. LD same. 11. PU and RIH w/clean out assembly cleaning out to PBTD @ 11,449' MD. Circulate clean. 12. RU E-line. RIH w/Cement Bond Log tool to confirm TOC or quality of cement integrity in 7"liner. RD E-Line. 13. PU 7"test packer and RIH to 9,000' MD. Set pkr,test backside to 2,500 psi to confirm casing integrity. Hold for 30 min and chart. Release test pkr, POOH. 14. PU and RIH w/tubing conveyed perforating guns. 15. PU and RIH w/ratcheting mule shoe,XN nipple,jet pump BHA, and dual strings setting BHA at+/-10,500 ft MD. 16. Land hanger. 17. Set BPVs and test. 18. ND BOP, NU tree and test. Well Prognosis Well: An-24RD • llilcorp Alaska.LI: Date:05/15/2015 19. Turn well over to production. 20. Complete'No Flow'test in accordance with AOGCC regulations(20 AAC 25.265.Well safety valve systems, section.h). Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. Current/Proposed Wellhead Diagram (same) 4. BOP Stack 5. Spacing Exception Map ADL017586 T10N,R12W,Section 1 BR-42-42 Spacing Exception Analysis Granite Pt St 18742 24RD Well • (AN-24RD) AN-24RD IAN 24RD BPH There are only 2 wells producing from the Middle Kenai Oil Pool in the North East quarter of Section 1. TPH The BR 42-42 well and the AN 28RD2 • are the closest wells producing from the Middle Kenai Oil Pool. They are both • more than 1,000 ft.from the AN 24RD. ADL0187(1 ADL018742 AN The radiius of the circles are 1,000 ft from the Top of the Producing Horizon(TPH) and the Bottom of the Producing Horizon(BPH). The nearest distance between the perforations in the BR 42-42 and the perforations in the AN 24RD is 1,039 feet. The well bore is greater than 500 ft from the lease or property line. Anna • Bettis, Patricia K (DOA) From: Judy Stanek <jstanek@hilcorp.com> Sent: Friday, May 15, 2015 4:45 PM To: Bettis, Patricia K (DOA) Cc: Juanita Lovett Subject: RE: Granite Pt St. 18742 24RD Attachments: GP AN-24RD Spacing_ExcepitonReview.pdf Hi Patricia, The Sundry was delivered to AOGCC today at 3:56pm. Per your request this map includes all the wells(6)wells capable of producing in the Middle Kenai Oil Pool in Section 1. Please add this to the Sundry application. In addition, here's a snip showing wells in surrounding sections also capable of producing in the Middle Kenai Oil Pool. BR�6- • GRAZ42 \` , 1 AN O2 ` J hl#611RD` Aft- AN-37 %woos two Piot �cwow toarepio Air AM-last? A01-44 � aa • • r M+..11$3 Hope this is helpful. Judy Judy Stanek,CPL Landman 1 • .Hilcorp Alaska LLC Ph: 907.777.8341 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, May 15, 2015 4:03 PM To: Judy Stanek Subject: RE: Granite Pt St. 18742 24RD Good afternoon Judy, Please submit a spider map that shows the proposed Middle Kenai Oil Pool perforation intervals for Granite Pt St 18742- 24RD along with perforated intervals in surrounding wells that are open to the Middle Kenai Oil Pool, regardless of whether those wells are currently on production or suspended. See CO 76, Rule 2. If the well is P&A'd,or if the perforations within the Middle Kenai Oil Pool have been squeezed and said well is recompleted in a different pool,such as undefined gas, this needs to be noted. Thank you, Patricia From:Judy Stanek [mailto:jstanek@hilcorp.com] Sent: Friday, May 15, 2015 10:26 AM To: Bettis, Patricia K (DOA) Subject:Granite Pt St. 18742 24RD Hi Patricia, On a recently submitted Sundry for this well,AOGCC stated that there was insufficient information to determine if a spacing exception is needed. There was no indication as to what kind of information you needed. Attached is a map showing that there are only 2 wells producing from the Middle Kenai Oil Pool within the NE quarter of Section 1. No wells producing in this pool are closer than 1,000 ft. and they are not nearer than 500 Ft.from the lease property line. Is this the kind of information you are looking for? Thanks for your advice. Judy Judy Stanek,CPL Landman Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Ph: 907.777.8341 jstanek@hilcorp.com 2 Granite Point Field SCHEMATIC Well #: An-24RD HilcorpAlaska,LLC Completed 7/10/2008 CASING AND TUBING DETAIL API#50-733-20285-01 Size WT Grade CONN ID Top BTM RKB to TBG Head=60' 20" 94# K-55 - 19.124" Surface 609' 1 AL 13-3/8" 54.5&68# K-55 Buttress 12.415" Surface 2,000' zo' 9-5/8" 40&43.54f N-80&5-95 Buttress 8.755" Surface 8,219' 7"Liner 29# P-110 Hydril 563 6.184" 7,994' 10,704' 4.5"Liner 12.6# L-80 Hydril 563 3.958" 10,556' 11,492' Long String TUBING DETAIL 13-3/8' t .\ 2-7/8" 6.4# L-80 IBT(SCC) 2.441" Surface 10,505' 2-3/8" 4.6# L-80 IBT(SCC) 1.995" 10,505' 11,436' Short String 2-7/8" 6.41# L-80 IBT(SCC) _ 2.441" Surface 7,757' 2-3/8" 4.6# L-80 IBT(SCC) 1.995" 7,757' 10,347' z 9-5/8"Z . 2 B JEWELRY DETAIL NO. Depth ID OD Item C , 60' Tubing Hanger,Cameron,3-1/2"X 3 1/2 11"DCB 1 54' 2.44 2.88 X-over 3-1/2"EUE x 2-7/8"IBT PxP • D 2 54' 2.44 - 2-7/8 Tubing 6.4#L-80 - .' Oilwell Hydraulics Type"A"Single Parallel Cavity w/Stainless Steel • 3 — -, 3 10,350' 2.25 5.8 Bands 4 10,351' 2.44 2.88 XO 27/8"IBT x EUE — N. ' 5 10,361' 2.44 2.88 1 joints 2 7/8"Buttress Tubing+8'Pup Jt 4 6 10,401' 2.19 2.88 2 7/8"R nipple 5 7 10,410' 2.44 2.88 8'Pup it+3 joints 2-7/8"Buttress Tubing R 6 8 10,505' 2 2.88 X-over 2 3/8 EUE x 2 7/8 Buttress z9 10,506' 2 2.38 1 joint 2 3/8"EUE Tubing \XO/ 8 10 10,541' 1.88 3.25 2 3/8"CMU Sliding Sleeve 11 10578 2 2.38 +/-26 joints 2 3/8"Buttress Tubing(EOT at 11436') 9 0 fl n 10 12 11436' Mule Shoe EDT Short String A 54' X-over 3-1/2"EUE x 2-7/8"IBT PxP 11 B 7,757' 2 2.88 X-over,2-7/8"IBT Box x 2-3/8"IBT Pin C 10,347' 1.63 2.6 X-over,2 3/8"SCC.Box x"1'A"If Pin D 10,386' 1.625 1.900 Integral pup joint 1 A"IJ " PERFORATION DETAIL I. Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf s C-7E 10,711' 10,731' 9,412' 9,421' 20' 6 C-7D 10,784' 10,805' 9,444' 9,453' 21' 6 C-7C 10,817' 10,859' 9,458' 9,476' 42' 6 d 7 C-7B 10,903' 10,934' 9,494' 9,506' 31' 6 C-7A 10,944' 10,990' 9,510' 9,528' 46' 6 r: C-6D 11,030' 11,038' 9,543' 9,546' 8' 6 Ir C-6X 11,079' 11,086' 9,561' 9,563' 7' 6 r. i � � C-SB 11,291' 11,355' 9,630' 9,648' 64' 6 C-5A 11,380' 11,423' 9,655' 9,666' 43' 6 44— All Zones Re-perforated w/2-3/4"72"TCP guns it i . , 12 ' ' : , PBTD=11,449' MD/9,669'TVD 4-1/2'/. , TD= 11,494' MD/9,677'TVD Revised By:TDF 1-15-2013 Granite Point Field PROPOSED Well #: An-24RD Hilcorp Alaska.LLC Completed: Future CASING AND TUBING DETAIL API#50-733-20285-01 Size WT Grade CONN ID Top BTM RKB to TBG Head =60' 20" 94# K-55 - 19.124" Surface 609' L13-3/8" 54.5&68# K-55 Buttress 12.415" Surface 2,000' 20" 9-5/8" 40&43.5# N-80&5-95 Buttress 8.755" Surface 8,219' 7"Liner 29# P-110 Hydril 563 6.184" 7,994' 10,704' 4.5"Liner 12.6# L-80 Hydril 563 3.958" 10,556' 11,492' Long String TUBING DETAIL 13-3/8" , 2-7/8" 6.58 L-80 8rd EUE 2.441" rface ±10,505' 2-3/8" 4.6# L-80 Supermax ' 095" -05' ±11,436' Short String 2-7/8" 6.58 L-80 8rd EUE 2.441" Surface ±7,757' X2-3/8" 4.6# L-80 Supermax 995" ±7,757' ±10,347' ; .t.9-5/8'Z ., a JEWELRY DETAIL r,. ', NO. Depth ID OD Item , ;r 60' Tubing Hanger -o. 1 ±10,350' 2.25 5.8 Single Parallel Cavity ' = 2 ±10,401' 2.19 2.88 R Nipple - •' 3 ±10,541' 1.88 3.25 2 3/8"CMU Sliding Sleeve t4 ±10578 1.995 2.38 +/-850' -2 3/8"Tbg Tail miEl 5 - - ±11436' Mule Shoe 1. -l- PERFORATION DETAIL 2 RZone Top(MD) Btm(MD) Top(ND) Btm(ND) Amt spf Z C5B ±9,213' ±9,263' ±8,281' ±8,330' ±50' C7X ±9,475' ±9,480' ±8,538' ±8,543' ±5' O C7B ±9,571' ±9,576' ±8,631' ±8,636' ±5' ' r C7B ±9,588' ±9,594' ±8,647' ±8,653' ±6' 7" �'• 3 HI C7C ±9,662' ±9,699' ±8,717' ±8,752' ±37' C7D ±9,716' ±9,742' ±8,768' ±8,791' ±26' • I C7E ±9,789' ±9,804' ±8,834' ±8,847' ±15' ' C8B ±9,888' ±9,902' ±8,920' ±8,932' , ±14' C8C ±9,959' ±10,011' ±8,979' ±9,020' ±52' C8C ±10,020' ±10,038' ±9,027' ±9,041' ±18' C9A ±10,209' ±10,225' ±9,161' ±9,171' ±16' 1 C9A ±10,250' ±10,263' ±9,186' ±9,193' ±13' C9B ±10,325' ±10,345' ±8,227' ±9,238' ±20' • C8C ±10,462' ±10,528' ±9,296' ±9,327' ±66' C8B ±10,565' ±10,580' ±9,345' ±9,357' ±15' C8B ±10591' ±10,596' ±9,357' ±9,359' ±5' C-7E 10,711' 10,731' 9,412' 9,421' 20' 6 C-7D 10,784' 10,805' 9,444' 9,453' 21' 6 C-7C 10,817' 10,859' 9,458' 9,476' 42' 6 II C7B ±10,882' ±10,894' ±9,485' ±9,490' ±12' , C-7B 10,903' 10,934' 9,494' 9,506' 31' 6 C-7A 10,944' 10,990' 9,510' 9,528' _ 46' 6 ' 4 C-6D 11,030' 11,038' 9,543' 9,546' 8' 6 C-6X 11,079' 11,086' 9,561' 9,563' 7' 6 9 C7X ±11,095' ±9,564' ±9,567' ±8' C-58 11,291' 11,355' 9,630' 9,648' 64' 6 C-5A 11,380' 11,423' 9,655' 9,666' 43' 6 • • I i . ...„.._._ 5 DI 4-1/2/, :" i •`,; -1. ✓� PBTD= 11,449' MD/9,669'TVD TD= 11,494' MD/9,677'TVD Revised By:.ILL 05/07/15 Anna Platform An-24RD Current 03/22/2013 Ifilrnrp %Lasko.1.1.! An-24RD Tubing hanger,Dual,CIW- 20 X 13 3/8 X 9 5/8 X DCB,11 X 3 1/2 EUE lift X 2 7/8 X 2 7/8 Valve,Master,CIW F, 3 1/2,w/3"type H BPV 3 1/8 5M 5 bolt,FE,HWO profile,5 3/64 centers Qty 2 l �; If /STA vOF � 4, Ai�%tea Tubinghead,CIW-DCB, D® ��: Ad1/8apter5M,CIW d 5 boltuatopl,,prepped f/ 11 5M FE X 13 5/8 3M X 11 5M,w/2- ;00 3 2 1/16 5M EFO,X-bottom 3"nom CIW hanger necks prep III III 53/64 centers '• Void test good 250/5000 =.al •I il I 'lig: 6/10/2010 III 1 — III Valve,WKM-M,2 1/16 5M C. _ S O 1,0iii i � p - FE,HWO - -` - I 1 O y; . Ti t 6'ii' :ro, I♦I-1•=i Qty2 111 I IU Casing spool,CIW-WF,21%2M ill Ile Void test good 250/2500 X 13 5/8 3M,w/2-2 1/16 5M 6/10/2010 EFO,X bottom prep OL ill- ! 111 Valve,CIW F,2 1/16 5M FE, - ®imii4iIi ■I - 111 , iii T" Void test good 250/800 alMr— Casing head,CIW-WF,21 Y.2M X al J. 6/10/2010 SOW,w/2-2 1/16 2M EFO III iuI'i :1'I 1 7 .Valve,CIW-F,2 1/16 2M FE, HWO ill s Anna Platform II AN-24RD 03/22/2013 Hika.q Maokn.1.1.1. 1 iI It-1 Iti Itlltl hail/ - 'l ill Iii il 3]4Shaffer ae5M ail l i I Mill It 2 7/85 Variable. Shaffer LXT © M= 2'50 1 135/85M Choke and Kill valves .°'%1 Ili I i I 7"N.,.1 3 1/8 5M 1.78 1i1v 1: i it 1 - ... ,��0� II 1 I I ./ Dual Flex Rams 2.83' _ i11 ili'Ii ii i11 1 I 1 14.20 Riser 13 5/8 5M FE X 13 5/8 5M FE 1, 1, 1 1 ,i1 11: I.11 ,. ill 1.00 Spacer spool 135/85M FE X 11 5M 1 1 1 11 I .C"1-.1 1 i far;Al A L.(IP_Ail i 111.1:4i. ,.: 1- ul , !imitlillittlj1111 I -l. MI 1 ,.Ism. ro 111 ) doll Ii 1 II. :r! STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOTICE OF APPLICATION DEFICIENCY r �� 15 ao7- The attached application is being returned due to the deficiency or deficiencies listed below. Please submit a new application and all required supporting information. _insufficient information to confirm that the casing and cementing program will protect freshwater aquifers insufficient information to demonstrate that the proposed perforations will be in compliance with applicable spacing provisions _insufficient information to demonstrate that adequate barriers to flow will be maintained failure to calculate (or to calculate accurately)anticipated pressures _insufficient information to confirm quality of cement and TOC, relative to proposed perforations _insufficient or contradictory well location information or coordinates _insufficient or contradictory geologic prognosis information 6_,,,, ,.1.) ( '?V other tie-/k1;4J tie-/k1; � j'� Cit1 to _other _other _other same MA', 2 12015 D jll`I,1 / r ,t, k r - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AO C C APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown❑ Suspend❑ Perforate El Other Stimulate ❑ Atter Casing ❑ Change Approved Program❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. Jet Pump Completion 0 2.Operator Name: 4.Current Wel Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory 0 Development 0 207-170 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20285-01 7.If perforating: 8. Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 76,Rule 2 Will planned perforations require a spacing exception? Yes ❑ No 0 Granite Pt St 18742 24RD 9.Property Designation(Lease Number): 10.Field/Pool(s): y ADL0018742 Granite Pt/Middle Kenai Oil Poo 11. PRESENT WELL CONDITION SUMMAR Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Dept D(ft): Plugs(measured): Junk(measured): 11,494 9,683 11,449 -=7/r 9,672 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 609' 20" 60 ......7 609' Surface 2,000' 13-3/8" 2,1,i1,958' 2,730 psi 1,130 psi 11.,P_ Intermediate 8,219' 9-5/8" 8, ' 7,353' 5,750 psi 3,090 psi Production 2,710' 7" %, 44' 9, 11,220 psi 8,530 psi Liner 936' 4-1/2" 1 ,492' ,683' 8,430 psi 7,500 psi / Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubin . Tubink de: Tubing MD(ft): See Schematic See Schematic 2-7/8' 3/8"3/8"dual 4//8 4.6*/L-80 11,436'&10,347' Packers and SSSV Type: 9.1 P ckers d S VD/R. (ft)and TVD(ft): I N/A N/A,N 12.Attachments: Description Summary of Proposal W 13 ,III Crafter proposed work: Detailed Operations Program ❑ BOP Sketch .1 Explc ratory ❑ Stratigraphic❑ Development 0 Service ❑ 14.Estimated Date for 5.Well Status after proposed work: 6/15/2015' Commencing Operations: 1 L 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: / ( \ , t AS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correc o the best .f m nowledge. Contact Trudi Hallett Email thalletta.hilcorp.com Printed Name —' Trudi Hallett Title Operations Engineer Signature 1t4- Ifirijrri'Phone (907)777-8323 Date 5/8/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission s• that a representative may witness Sundry Number: r 3t5211 Plug Integrity ❑ BOP Test • Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes Cl No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: O I i N A Submit Form and Form 10-403 Revised 5/2015 rt i alid for 12 months from the date of approval. Attachments in Duplicate RBDMSAk MAY 1 2 2015 Well Prognosis Well: An-24RD Hilcorp Alaska,LL, Date:05/11/2015, Well Name: GRANITE PT ST 18742#24RD API Number: 50-733-20285- Current Status: Oil Producer Leg: 2 Estimated Start Date: June 15,2015 Rig: Moncla 3 Reg.Approval Reqd? N/A Date Reg.Approval Rec: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 207- 0 First Call Engineer: Trudi Hallett (907)777-8323(0) (9 )301-6657 (M) Second Call Engineer: Dan Taylor (907)777-8319(0) 07)947-8051 (M) AFE Number: Current Bottom Hole Pressure: —2,000 psi at 9,556 ft TVD(11,066' MD) Baa'ed Pressure Build Up test 6/28/2008 Maximum Expected BHP: —2,000 psi at 9,556 ft ND(11,066' MC)4 Based Pressure Build Up test 6/28/2008 Max.Anticipated Surface Pressure: — 1,050 psi s Based on 0.1 psi/ft gradient to 9,556 ft ND. Brief Well Summary // AN-24RD was sidetracked and completed in 2008 after the riginal well AN-24 watered out in 2003. The well was drilled as a "hockey stick" style to target the crest an west flank portions of the Tyonek reservoir. It was completed with a dual string packerless power oil comple on in the Tyonek. AN-24RD is currently shut-in due to mechanical reasons. New perforations will be placed in intervals C5B - C B. AN-24RD will be placed back on line with a dual string jet pump completion. Procedure 1. Reverse out Jet Pump 2. Bleed well off(casing/tubing). 3. Shoot fluid levels on back side. 4. Circulate FIW down long string takin eturns up short string until clean. 5. Ensure well is dead. 6. Set BPV. 7. ND tree/NU BOPE. Function to BOPE(notify AOGCC of test 48hrs prior to expected test). 8. Test all BOP equipment per AO.CC guidelines and Hilcorp BOPE testing procedures to 250psi LOW and 2,500 psi HIGH. 9. Remove BPVs. 10. POOH w/Dual string compl rion. LD same. 11. PU and RIH w/clean out a.'sembly cleaning out to PBTD @ 11,449' MD. Circulate clean. 12. RU E-line. RIH w/Ceme , Bond Log tool to confirm TOC or quality of cement integrity in 7"liner. RD E-Line. 13. PU 7"test packer and R to 9,000'MD. Set pkr,test backside to 2,500 psi to confirm casing integrity. Hold for 30 min and chart. Releas- est pkr, POOH. 14. PU and RIH w/tubing nveyed perforating guns. 15. PU and RIH w/ratch ting mule shoe,XN nipple,jet pump BHA, and dual strings setting BHA at+/-10,500 ft MD. 16. Land hanger. 17. Set BPVs and tes 18. ND BOP, NU tre: and test. 19. Turn well over t' production. 20. Complete'No -ow'test in accordance with AOGCC regulations(20 AAC 25.265.Well safety valve systems, section.h). Attachments: 1. As-built ell Schematic fl Well Prognosis Well: An-24RD Hilcorp Alaska,LL, Date:05/11/2015 2. Proposed Well Schematic 3. Current/Proposed Wellhead Diagram(same) 4. BOP Stack /' • • • Granite Point Field SCHEMATIC Well #: An-24RD Hilcorp Alaska,LLC Completed 7/10/2008 CASING AND TUBING DETAIL API#50-733-20285-01 Size WT Grade CONN ID Top BTM RKB to TBG Head =60' 20" 94# K-55 - 19.124" Surface 609' A 13-3/8" 54.5&68# K-55 Buttress 12.415" Surface 2,000' 20'A 9-5/8" 40&43.5# N-80&S-95 Buttress 8.755" Surface 8,219' I )', 7"Liner 29# P-110 Hydril 563 6.184" 7,994' 10,704' 4.5"Liner 12.68 L-80 Hydril 563 3.958" 10,556' 11,492' Long String TUBING DETAIL �' 13-3/8" .\ 2-7/8" 6.4# L-80 IBT(SCC) 2.441" Syrface 10,505' 2-3/8" 4.6# L-80 IBT(SCC) 1.995" 10,505' 11,436' Short String 2-7/8" 6.4# L-80 IBT(SCC) 2.441" _ Surface 7,757' 2-3/8" 4.6# L-80 IBT(SCC) 1.995" 7,757' 10,347' 1 9-5/8"L( 2 B JEWELRY D AIL NO. Depth ID OD Item , i, J C 60' Tubing Hanger,Cameron,3-1/2"X 3 1/2 11"DCB 1 54' 2.44 2.88 X-over 3-1/2"EUE x 2-7/8"IBT PxP D 2 54' 2.44 - 2-7/8 Tubing 6.4#L-80 - • Oilwell Hydraulics Type"A"Single Parallel Cavity w/Stainless Steel 3 — „ 3 10,350' 2.25 5.8 Bands 4 10,351' 2.44 2.88 XO 2 7/8"IBT x EUE m • ' 5 10,361' 2.44 2.88 1 joints 2 7/8"Buttress Tubing+8'Pup Jt 4 6 10,401' 2.19 2.88 2 7/8"R nipple 5 7 10,410' 2.44 A.88 8'Pup it+3 joints 2-7/8"Buttress Tubing R 6 8 10,505' 2 j 2.88 X-over 2 3/8 EUE x 2 7/8 Buttress 9 10,506' 2 f— 2.38 1 joint 2 3/8"EUE Tubing 7 \XO/ 8 10 10,541' 1.88 3.25 2 3/8"CMU Sliding Sleeve L. 11 10578 2 2.38 +/-26 joints 2 3/8"Buttress Tubing(EOT at 11436') 9 1 O 12 11436' Mule Shoe EOT 0 inShort String A 54' X-over 3-1/2"EUE x 2-7/8"IBT PxP 11 B 7,757' 2 2.88 X-over,2-7/8"IBT Box x 2-3/8"IBT Pin C _ 10,347' 1.63 2.6 X-over,2 3/8"SCC.Box x"1''A"IJ Pin s _ D 10,386' 1.625 1.900 Integral pup joint 1'A"IJ '.l I. . IT— PERFORATION DETAIL 'III Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf JO C-7E 10,711' 10,731' 9,412' 9,421' 20' 6 ` C-7D 10,784' 10,805' 9,444' 9,453' 21' 6 =,■ _a--. C-7C 10,817' 10,859' 9,458' 9,476' 42' 6 ' f21— C-7B 10,903' 10,934' 9,494' 9,506' 31' 6 _i C-7A 10,944' 10,990' 9,510' 9,528' 46' 6 — C-6D 11,030' 11,038' 9,543' 9,546' 8' 6 ''i" it C-6X 11,079' 11,086' 9,561' 9,563' 7' 6 -- C-5B 11,291' 11,355' 9,630' 9,648' 64' 6 C-5A 11,380' 11,423' 9,655' 9,666' 43' 6 1 aiE All Zones Re-perforated w/2-3/4"72"TCP guns / :e..e 1 f / -.1y ,;: 12 .i `•' "`%" ` $ PBTD=11,449' MD/9,669'TVD � : : 4-1/r� ` ✓ N.. TD= 11,494' MD/9,677'TVD Revised By:TDF 1-15-2013 • . Granite Point Field PROPOSED Well #: An-24RD HilcoraAlaska,LLC Completed: Future CASING AND TUBING DETAIL API#50-733-20285-01 Size WT Grade CONN ID Top BTM RKB to TBG Head=60' - 20" 948 K-55 - 19.124" Surface /609' 13-3/8" 54.5&68# K-55 Buttress 12.415" Surface / 2,000' 20'Z IS, 9-5/8" 40&43.5# N-80&S-95 Buttress 8.755" Surface/ 8,219' 7"Liner 29# P-110 Hydril 563 6.184" 7,99/ 10,704' 4.5"Liner 12.6# L-80 Hydril 563 3.958" 1' 56' 11,492' Long String TUBING DETAIL 13-3/8" , 2-7/8" 6.58 L-80 8rd EUE 2.441" Surface ±10,505' 2-3/8" 4.6# L-80 Supermax 1.99, ±10,505' ±11,436' Short String 2-7/8" 6.5# L-80 8rd EUE .441" Surface ±7,757' • 2-3/8" 4.68 L-80 Supermax 1.995" ±7,757' ±10,347' .1 9-5/8"L MI JEWELR,: 'ETAIL ii NO. Depth ID OD Ite III !! 60' bing Hanger 1 ±10,350' 2.25 5.8 Single Parallel Cavity " 2 ±10,401' 2.19 2.88 R Nipple ' 1_ . '!'>!. 3 ±10,541' 1.88 3. _ 2 3/8"CMU Sliding Sleeve 4 ±10578 1.995 .38 +/-850' -2 3/8"Tbg Tail ha5 ±11436' - - Mule Shoe 0 PERFORATION DETAIL t: 2 1111 ' 4 Top(MD) Btm(MD) Top(TVD) Btm(ND) Amt spf CSB ±9,213' ±9,263' ±8,281' ±8,330' ±50' : a l , C7X ±9,47. ±9,480' ±8,538' ±8,543' ±5' 1%i ? . C7B - 1' ±9,576' ±8,631' ±8,636' ±5' ?" ! y C7B :,588' ±9,594' ±8,647' ±8,653' ±6' 7 .4, 3 ( * C7C ±9,662' ±9,699' ±8,717' ±8,752' ±37' I�Ii1kI g mi C7D ±9,716' ±9,742' ±8,768' ±8,791' ±26' '" C7E , ±9,789' ±9,804' ±8,834' ±8,847' ±15' "4C8B ±9,888' ±9,902' ±8,920' ±8,932' ±14' CSC ±9,959' ±10,011' ±8,979' ±9,020' ±52' wr C8 ±10,020' ±10,038' ±9,027' ±9,041' ±18' 11) CM ±10,209' ±10,225' ±9,161' ±9,171' ±16' ±10,250' ±10,263' ±9,186' ±9,193' ±13' ZI" Al ±10,325' ±10,345' ±8,227' ±9,238' ±20' µ ±10,462' ±10,528' _ ±9,296' ±9,327' ±66' 14' `4 C8B ±10,565' ±10,580' _ ±9,345' ±9,357' ±15' C8B ±10,591' ±10,596' ±9,357' ±9,359' ±5' C-7E 10,711' 10,731' 9,412' 9,421' 20' 6 C-7D 10,784' 10,805' 9,444' 9,453' 21' 6 C-7C 10,817' 10,859' 9,458' 9,476' 42' 6 -e4 C7B ±10,882' ±10,894' ±9,485' ±9,490' ±12' C-7B 10,903' 10,934' 9,494' 9,506' 31' 6 y � C-7A 10,944' 10,990' 9,510' 9,528' 46' 6 4 C-6D 11,030' 11,038' 9,543' 9,546' 8' 6 'C C-6X 11,079' 11,086' 9,561' 9,563' 7' 6 is p C7X ±11,087' ±11,095' ±9,564' ±9,567' ±8' C-5B 11,291' 11,355' 9,630' 9,648' 64' 6 4. i C-5A 11,380' 11,423' 9,655' 9,666' 43' 6 a L4 .. i -. i' 5 >t- -rt !r Utz. 4-1/2"/ . ., '" PBTD= 11,449' MD/9,669'ND TD=11,494' MD/9,677'ND Revised By:JLL 05/07/15 . . . 11 Anna Platform An-24RD Current 03/22/2013 Hilrarp Alnrka.ILIA. An-24RD Tubing hanger,Dual,CIW- 20X133/8 X95/8X DCB,11 X 3 1/2 EUE lift 2 7/8 X 2 7/8 Valve,Master,CIW-F, 3 1/2,w/3"type H B' 3 1/8 5M 5 bolt,FE,HWO profile,5 3/64 ce -rs Qty 2 r %i0'° - Adapter,CIW-. , Tubinghead,CIW-DCB, 0 J o- 3 1/8 5M 5 boltualtop11,prepped5MFE Xf/ 13 5/8 3M X 11 5M,w/2- al;a 0 3"nom CIW hanger necks 2 1/16 5M EFO,X-bottom = prep III�� III 111 5 3/64 centers 11,!„,.: Void test good 250/5000 24i1 ,I 'I ,,;l_ 6/10/2010 iil III Valve,WKM-M,2 1/16 5M 1 .1]i 1 ''•� 01011 � t■1 11116(?>, ■I 1.:, y 1111 I III Casing spool,CIW-WF,21%2M 111 1WAT:: Void test good 250/2500 X 13 5/8 3M,w/2-2 1/16 5M ►I. 6/10/2010 EFO,X bottom prepin I-- -"--- 111 �� Valve,CIW F,2 1/16 5M FE, E. '� OD) HWO II liz linr-li - 1.1111(111111111111-L III t Inq_'= Void test good 250/800 Casing head,CIW-WF,21'/< X I 6/10/2010 / SOW,w/2-21/162M 0 iii — 1I: t c �' :i 1:Valve,CIW-F,2 1/16 2M FE, � HWO • .. . 11 Anna Platform AN-24RD 03/22/2013 NBrnrj. %Islekn_II( UT III III It Ill Ili 111 •,_. ill i(I� ■ �iililliIl(Il iilli 3.74' III 111 III III It - 2 7/&5 varied. _I Sheffer UR - 0 / ind 2.50 -� 5M/ WAIMi" - Choke and Kill valves �� 1 .rl lir ixl Ire lel r, 31/85M 1.76 I 11 ♦;t•� 01 -�1 -l.:l.iri Iles. � Duel Flex Rams — 2.83' air1i 1'.'I. Ili Irr IL it ri 14.2 r Riser 13 5/8 5M FE X 13 5/8 5M FE iri is I;ii',iii tl1i1 1. Ali tar Spacer spool 13 5/8 5M FE X 11 5M c .f- ill fa. I I--MI'1 U I••i M , .-I. ilk 1r_`` Hi I1_ It !)II11 -I. PI L IIIII !�(�I. • €I-amu li-r. I� I\ • STATE OF ALASKA -1'r6 o2t).7--/ ALASKA OIL AND GAS CONSERVATION COMMISSION NOTICE OF APPLICATION DEFICIENCYt5 5( '4 9t1) The attached application is being returned due to the deficiency or deficiencies listed below. Please submit a new application and all required supporting information. insufficient information to confirm that the casing and cementing program will protect freshwater — aquiferse�,�1�,en NIA, ` 2.(31S, insufficient information to demonstrate that the proposed perforations will be in compliance with applicable spacing provisions insufficient information to demonstrate that adequate barriers to flow will be maintained failure to calculate (or to calculate accurately) anticipated pressures insufficient information to confirm quality of cement and TOC, relative to proposed perforations _insufficient or contradictory well location information or coordinates _insufficient or contradictory geologic prognosis information Y other ea5t �Lh e� 1/:s Po'r .5'p /e_• It S F /O r ea.....r c- 7,e_S 'e -, _other _other _other RECEIVED STATE OF ALASKA MAY 0 8 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 2QAAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown Cl Suspend El Perforate 0 Other Stimulate El Alter Casing ❑ Change Approved Program 0 Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. Jet Pump Completion 0 2.Operator Name: 4.Current Well Class: 5.Permit to DriN Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 207-170 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ API Number. Anchorage,AK 9950350-733-2028' r 1 7.If perforating: 8. • :to e and Number. / What Regulation or Conservation Order governs well spacing in this pool? CO 76 ' Will planned perforations require a spacing exception? Yes ❑ No 0 I��; ipt St 187 2 *�I 7` 9.Property Designation(Lease Number): 10.Field/Pool(s): , P' \VI •� �\ ADL0018742 Granite Pt/Middle Kenai G Oil Pool VJ 11. PRESENT WELL CONDITION SUMMARY ` \ Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Dept 1'!�ft): V Plugs m red): Junk(measured): 11,494 9,683 11,449 9,672 N/A N/A Casing Length Size MD TVD Burst Collapse Structural NY t1_ Conductor 609' 20" 609't� 609' Surface 2,000' 13-3/8" 2,00(ta'k tr 1,958' 2,730 psi 1,130 psi Intermediate 8,219' 9-5/8" a •1• 7,353' 5,750 psi 3,090 psi Production 2,710' 7" 0 04' O 9,409' 11,220 psi 8,530 psi Liner 936' 4-1/2" t , 1, 9,683' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tub' g'j e: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 7 -3/8"dual 6.4#&4.6#/L-80 11,436'&10,347' Packers and SSSV Type: A Packers and SSSV MD(ft)and ND(ft): N/A ) N/A 12.Attachments: Description Summary of Propos: rp f 13.Well Class after proposed work: Detailed Operations Program Cl BOP Sket ' l'2 . Exploratory CIStratigraphic❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 6/15/2 r' 5�1 Commencing Operations: OIL 0 WINJ CIWDSPL ❑ Suspended El16.Verbal Approval: Date: 'GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and ,rrect to the best of my knowledge. Contact Trudi Hallett Email thallett@hilcorp.com Printed Name /Trruudii Hallett r Title Operations Engineer Signature ��v"`V"r I / F Phone (907)777-8323 Date 5/7/2015 COMMISSION USE ONLY Conditions of approval: Notify Commi sion so that a representative may witness Sundry Number: 316 — n Plug Integrity 0 B r•P Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception R-•uired? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: RBDMS. MAY 1 1 2015 O �� P� e I� pp Submit Form and Form 10-403 Revised 5/2015 A e li a for 12 months from the date of a royal. Attachments in Duplicate Well Prognosis Well: An-24RD Hilcorp Alaska,LL Date:05/07/2015 Well Name: GRANITE PT ST 18742#24RD API Number: 50-733-20285-01 Current Status: Oil Producer Leg: 2 Estimated Start Date: June 15,2015 Rig: Moncla 301 Reg.Approval Reqd? N/A Date Reg.Approval Rec: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 20 170 First Call Engineer: Trudi Hallett (907)777-8323(0) s$7)301-6657 (M) Second Call Engineer: Dan Taylor (907)777-8319(0) '(907)947-8051 (M) AFE Number: Current Bottom Hole Pressure: —2,000 psi at 9,556 ft TVD(11,066'MD) :-sed Pressure Build Up test 6/28/2008 i Maximum Expected BHP: --2,000 psi at 9,556 ft TVD(11,066' II) Based Pressure Build Up test 6/28/2008 Max.Anticipated Surface Pressure: —1,050 psi Based on 0.1 psi/ft gradient to 9,556 ft TVD. Brief Well Summary AN-24RD was sidetracked and completed in 2008 after th:'original well AN-24 watered out in 2003. The well was drilled as a "hockey stick" style to target the crest a • west flank portions of the Tyonek reservoir. It was completed with a dual string packerless power oil compl: ion in the Tyonek. AN-24RD is currently shut-in due to mechanical reasons. New perforations will be placed in intervals C5B - , •B. AN-24RD will be placed back on line with a dual string jet pump completion. Procedure 1. Reverse out Jet Pump 2. Bleed well off(casing/tubing). 3. Shoot fluid levels on back side. 4. Circulate FIW down long string taking,'eturns up short string until clean. 5. Ensure well is dead. 6. Set BPV. 7. ND tree/NU BOPE. Function tes :OPE(notify AOGCC of test 48hrs prior to expected test). 8. Test all BOP equipment per AO C guidelines and Hilcorp BOPE testing procedures to 250psi LOW and 2,500 psi HIGH. 9. Remove BPVs. 10. POOH w/Dual string comple''.n. LD same. 11. PU and RIH w/clean out as•embly cleaning out to PBTD @ 11,449' MD. 12. PU and RIH w/tubing cony=yed perforating guns. 13. PU and RIH w/ratcheting ule shoe,XN nipple,jet pump BHA, and dual strings setting BHA at+/-10,500 ft MD. 14. Land hanger. 15. Set BPVs and test. 16. ND BOP, NU tree and est. 17. Turn well over to pr•• ction. 18. Complete'No Flow' -st in accordance with AOGCC regulations(20 AAC 25.265.Well safety valve systems, section.h). Attachments: • 1. As-built Well hematic 2. Proposed W- I Schematic 3. Current/P •posed Wellhead Diagram(same) 4. BOP Sta► Granite Point Field . 13 SCHEMATIC Well #: An-24RD tti7eorp Alaska,LL(: Completed 7/10/2008 CASING AND TUBING DETAIL API #50-73 320285 01 Size WT Grade CONN ID Top BTM RKB to TBG Head =60' 20" 94# K-55 - 19.124" Surface 669' 1 A L13-3/8" 54.5&68# K-55 Buttress 12.415" Surface 2,000' 20'A 9-5/8" _ 40&43.5# N-80&5-95 Buttress 8.755" Surface/ 8,219' 4, 7"Liner 29# P-110 Hydril 563 6.184" 7,994' 10,704' {4" 4.5"Liner i 12.6# L-80 Hydril 563 3.958" 10, 56' 11,492' Jri Long String TUBING DETAIL 13-3/8" , 2-7/8" 6.4# L-80 IBT(SCC) 2.441" Surface 10,505' 2-3/8" 4.6# L-80 IBT(SCC) 1.995" 10,505' 11,436' Short String 1' 2-7/8" 6.4# L-80 IBT(SCC) 2.441" Surface 7,757' z 2-3/8" 4.6# L-80 IBT(SCC) 1.995" 7,757' 10,347' B , 9-5/8Z 2 JEWELRY DETAIL NO. Depth ID OD Item k l C 60' Tubing Haager,Cameron,3-1/2"X 3 1/2 11"DCB 1 54' 2.44 2.88 X-over 3-1/2"EUE x 2-7/8"IBT PxP D 2 54' 2.44 2-7/8 Tubing 6.4#L-80 r • Oilwell Hydraulics Type"A"Single Parallel Cavity w/Stainless Steel 3 — „ 3 10,350' 2.25 5.8 Bands 4 10,351' 2.44 2.88 XO 2 7/8"IBT x EUE m • ' 5 10,361' 2.44 2.88 , 1 joints 2 7/8"Buttress Tubing+8'Pup Jt 4 6 10,401' 2.19 2.88 . 2 7/8"R nipple 5 7 10,410' 2.44 2.88 8'Pup Jt+3 joints 2-7/8"Buttress Tubing R 6 8 10,505' 2 88 X-over 2 3/8 EUE x 2 7/8 Buttress Z _ >‹ 9 10,506' 2 /.38 1 joint 2 3/8"EUE Tubing \XO/ 8 l� 10 10,541' 1.88 3.25 2 3/8"CMU Sliding Sleeve 11 10578 2 2.38 +/-26 joints 2 3/8"Buttress Tubing(EOT at 11436') „z OH9 12 11436' Mule Shoe EOT � 10 Short String , , /11 A - 54' X-over 3-1/2"EUE x 2-7/8"IBT PxP B 7,757' 2 2.88 X-over,2-7/8"IBT Box x 2-3/8"IBT Pin C 10,347' 1.63 2.6 X-over,2 3/8"SCC.Box x"1%"IJ Pin —s-= l i D 10,386' 1.625 1.900 Integral pup joint 1%"IJ 1 —444 I I rt—1,,, PERFORATION DETAIL t I I _ Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf '1-:-: C-7E 10,711' 10,731' 9,412' 9,421' 20' 6 1-= C-7D 10,784' 10,805' 9,444' 9,453' 21' 6 �5l f � C-7C 10,817' 10,859' 9,458' 9,476' 42' 6 i = - I 'l_ C-7B 10,903' 10,934' 9,494' 9,506' 31' 6 C-7A 10,944' 10,990' 9,510' 9,528' - 46' 6 C-6D 11,030' 11,038' 9,543' 9,546' 8' 6 C-6X 11,079' 11,086' 9,561' 9,563' 7' 6 11.111, C-5B 11,291' 11,355' 9,630' 9,648' 64' 6 M� C-5A 11,380' 11,423' 9,655' 9,666' 43' 6 All Zones Re-perforated w/2-3/4"72°TCP guns � � . we 12 i 4-1/z"/� , PBTD= 11,449' MD/9,669'TVD TD= 11,494' MD/9,677'TVD Revised By:TDF 1-15-2013 Granite Point Field PROPOSED Well #: An-24RD llikorp Alaska,LLC Completed: Future CASING AND TUBING DETAIL API#50-733-20285-01 Size WT Grade CONN ID Top BTM RKB to TBG Head =60' 20" 94# K-55 - 19.124" Surface 609' Il 13-3/8" 54.5&68# K-55 Buttress 12.415" Surface 2,000' 20"' p 9-5/8" 40&43.5# N-80&S-95 Buttress 8.755" Surface 8,219' 7"Liner 29# P-110 Hydril 563 6.184" 7,994' 10,704' 4.5"Liner 12.68 L-80 Hydril 563 3.958" 10,556' 11,492' Long String TUBING DETAIL 13-3/8 2-7/8" 6.5# L-80 8rd EUE 2.'41" Surface ±10,505' 2-3/8" 4.6# L-80 Supermax .995" ±10,505' ±11,436' Short String 2-7/8" 6.58 L-80 8rd EUE 2.441" Surface ±7,757' 2-3/8" 4.6# L-80 Super ax 1.995" ±7,757' ±10,347' 9-5/8"Z 1 JEW, RYDETAIL NO. Depth ID OD tem 4 ' 60' y Tubing Hanger 1 ±10,350' 2.25 5. Single Parallel Cavity 2 ±10,401' 2.19 .88 R Nipple Joe - • 6.1 3 ±10,541' 1.88 3.25 2 3/8"CMU Sliding Sleeve 1 limn m ■ as. � ■ 4 ±10578 1.995 2.38 +/-850' -2 3/8"Tbg Tail air' - ■ tor 5 ±11436' Mule Shoe r `/ PERFORATION DETAIL 2 R Zone Top(MD Btm(MD) Top(ND) Btm(ND) Amt spf C5B ±9,21. ±9,263' ±8,281' ±8,330' ±50' C7X ±9, 5' ±9,480' ±8,538' ±8,543' ±5' C7B ±•,571' ±9,576' ±8,631' ±8,636' ±5' OD rt C7B _9,588' ±9,594' ±8,647' ±8,653' ±6' 7-" 3 0, = C7C ±9,662' ±9,699' ±8,717 ±8,752' ±37' C7D ±9,716' ±9,742' ±8,768' ±8,791' ±26' _ C7E ±9,789' ±9,804' ±8,834' ±8,847' ±15' �-4, -- C8B ±9,888' ±9,902' ±8,920' ±8,932' ±14' ----- C8C ±9,959' ±10,011' ±8,979' ±9,020' ±52' C8' ±10,020' ±10,038' ±9,027' ±9,041' ±18' :A ±10,209' ±10,225' ±9,161' ±9,171' ±16' 9A ±10,250' ±10,263' ±9,186' ±9,193' ±13' C96 ±10,325' ±10,345' ±8,227' ±9,238' ±20' C8C ±10,462' ±10,528' ±9,296' ±9,327' ±66' C88 ±10,565' ±10,580' ±9,345' ±9,357' ±15' C8B ±10,591' ±10,596' ±9,357' ±9,359' ±5' .- C-7E 10,711' 10,731' 9,412' 9,421' 20' 6 1.-: C-7D 10,784' 10,805' 9,444' 9,453' 21' 6 = C-7C 10,817' 10,859' 9,458' 9,476' 42' 6 - Q C7B ±10,882' ±10,894' ±9,485' ±9,490' ±12' C-7B 10,903' 10,934' 9,494' 9,506' 31' 6 C-7A 10,944' 10,990' 9,510' 9,528' 46' 6 4 C-6D 11,030' 11,038' 9,543' 9,546' 8' 6 C-6X 11,079' 11,086' 9,561' 9,563' 7' 6 O C7X ±11,087' t 11,095' ±9,564' ±9,567' C-SB 11,291' 11,355' 9,630' 9,648' 64' 6 C-5A 11,380' 11,423' 9,655' 9,666' 43' 6 M ct. i/ 5 •" / �,. PBTD=11,449' MD/9,669'TVD TD=11,494' MD/9,677'TVD Revised By:1LL05/07/15 il Anna Platform An-24RD Current Har.1rp:%loan.ILIA. 03/22/2013 An-24RD Tubing hanger,Dual,CIW- 20X 133/8X95/8X DCB,11 X 3 1/2 EUE li 2 7/8 X 2 7/8 Valve,Master,CIW-F, 3 1/2,w/3"type :PV 3 1/8 5M 5 bolt,FE,HWO profile,5 3/64 c- ters Qty 2 1] 0 1� 0 A.:1 , Adapter,CIW-dual,11 5M FE X Tubing head,CIW DCB, I3© 4 orj 3 1/8 5M 5 bolt top,prepped f/ �� 13 5/8 3M X 11 5M,w/2- ° o 2 1/16 5M EFO,X-bottom ,for 3"nom CIW hanger necks prep 111 111 5 3/64 centers Ili — t= " / Void test good 250/5000 =w1 1' 'I liErz 6/10/2010 111 — _ 111 Valve,WKM-M,2 1/16 5M ., I ,. FEQt HWO2 Hi-1.1 111), ')011 I MI IIo 11 °J;' i .I I } Y 111 il 111 - Casing spool,CIW WF,21%2M11111 :, ;.. Void test good 250/2500 X 13 5/8 3M,w/2-2 1/16 5M EFO,X bottom prep NI :T' 6/10/2010 1 1I I Valve,CIW-F,2 1/16 5M FE, :ii1 - - e dirO 4, l- C'i HWO 1111111119 071 AIR* 111 ' Ill Ey '= - Void test good 250/800 Casing head,CIW-WF,21 1/4 2M X :I 6/10/2010 SOW,w/2-2 1/16 2M EFO :el; % _1S" 6 Illi 11.110A111111-1*:, o =Valve,CIW-F,2 1/16 2M FE, HWO P. Orr 1 •Il Anna Platform Moncla BOP 03/16/2015 Hil/rlrp Alaska.1.11. 1111111.1 , I I I 1 i 4 C 1:ydr,l e owl,1/1 i1111, CI U .e a.ez' it ...613 5/&5000 _ a. 1116 ,11.1'�1111111i.i.l mils -� � Choke and Nilvalves arCir 4E 31/85M � , I11 111 111111 111 z.zE I ,,'a ,1•idoII r lk� I©II1`:01i 5 III III 111 III III 1 "1 Ali©' 4 1111 111 111 111 1.83' - IIS I i11 ili III I 1. I III IU I 111 135/8SM FE ll 135/85M FE 11.017 I 1 II I II 1111 III _ � E_ 111 II', 11.!1! ilI I_/I 2.00. Spacer spool 135/85M X 135/8 SM III III III III III ilP I11 111 III 111-111 3.]5' 8S51 135/85MM 8 811 Y 115M I I Ill Ill III III • II Moncla 301 BOP Test Procedure Hilrorp Alaeka,LLC Attachment#1 Attachment#1 / Hilcorp Alaska LLC. BOP Test Procedure: Moncla 301, Grayling Platform WO Program — Oil Producers, Water jectors • Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare t tmosphere 2) Load well with FIW to kill well. (" • Note: Fluid level will fall to a depth that balances with resetioir pressure. 3) Shoot fluid level at least 24 hours before moving on well. // 4) Shoot fluid level again, right before ND/NU. Confirm that wel is static. ,r' r Initial Test(i.e.Tubing Hanger is in the Wellhead) fir" If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in haer. 3) Space out test joint so end of tubing(EOT) is jus bove the blind rams. 4) Set slips, mark same. Test BOPE per standard est procedure. 0 If the tubing hanger won't pressure test due ted either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set wit tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile nd landing threads are bad. 1) Attempt to set BPV through tree. I unsuccessful, shoot fluid level. 2) If fluid level is static from previo . fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be re •ved with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BP profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressur . If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a ire brush or wheel. c) Set 2-way check Ilve by hand, or MU landing(test)joint to lift-threads d) For ESP wells- . sure that cap is on cable penetrator e) NU BOP. Tes :OPE per standard procedure. 2) If both set of threa•: appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations ' ngineer(Hilcorp), Mr. Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the w-Ilhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to w''ness.As outlined and approved in the sundry, proceed as follows: a) Nipp e Up BOPE b) Wi stack out of the test path,test choke manifold per standard procedure Moncla 301 BOP Test Procedure Hilrorp Alaska,LLCAttachment#1 c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the sys m following the normal test procedure(floor valves,gas detection,etc.) f) Record and report this test with notes in the remarks column that the tubin anger/BPV profile/penetrator wouldn't hold pressure and rolling test was performe on BOP Equipment and list items, pressures and rates. 3) Pull hanger to surface. (Requires tubing cuts as necessary to free tubin . CBU to displace annulus and tubing with kill weight fluid. 4) If a rolling test was conducted, remove the old hanger, MU new hap(ger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head//Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) r 1) Remove Wear bushing. s a) Use inverted test plug to pull wear busing. MU to 1 t.of tubing. b) Thread into wear bushing a't c) Back out hold down pins I d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH o 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to sp a the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after ay check or test plug is set) 1) Fill stack with rig pump and install hart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure u with pump to desired pressure, close valve on pump manifold to trap pressure and read same ith chart recorder. 3) Test all Rams and Valves 1) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 2) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all ,.ms and valves,for correct operating position 3) Fill out the AO C BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document b• h the rolling test and the follow up tests. • • \ s THE STATE i OF r� ®fl l s� Conservation Commission rh„ GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Dan Taylor Operations Engineer scot* ti�iQv Hilcorp Alaska, LLC $c ab-7- 170 3800 Centerpoint Drive, Suite 100 // Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 18742 24RD Sundry Number: 313-330 Dear Mr. Taylor: 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, ia?)'e4/iks- Cathy P. oerster Chair DATED this /5 day of August, 2013. Encl. 1 e e 1, VA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION D t,S V)f ¶,13 APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Chang Approved Program El Suspend❑ Plug Perforations❑ Perforate CI o Pull Tubing U . .l Time Extension❑ Operations Shutdown El Re-enter Susp.Well El Stimulate El Alter Casing❑ I . Other:, , _ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory El Development El. 207-170 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20285-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 76,Rule 2 t 4/i/,, ?)ci-JOA " Will planned perforations require a spacing exception? Yes ❑ No 8 Granite Pt St 18742 24RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018742 - Granite Pt/Middle Kenai G Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): l Effective Depth MD(ft): Effective Depth ND i(ftft): Plugs(measured): Junk(measured): L 11,494 �(,'fl 8;683' �41Js'll� . 11,449 5669 8 • •2 4lk5I13 • N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 609' 20" 609' 609' Surface 2,000' 13-3/8" 2,000' 1,958' 2,730 psi 1,130 psi Intermediate 8,219' 9-5/8" 8,219' 7,353' 5,750 psi 3,090 psi Production 2,710' 7" 10,704' 9,409' 11,220 psi 8,530 psi Liner 936' 4-1/2" 11,492' 9,683' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 2-7/8"x 2-3/8"dual 6.4#&4.6#/L-80 11,436'&10,347' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A N/A 12.Attachments: Description Summary of Proposal p• 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch G • Exploratory ❑ Stratigraphic❑ Development El• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 7/15/2013 Oil GI • Gas ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: WINJ ❑ GINJ El WAG ❑ Abandoned El Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtavlorCa hilcorp.com Printed Name Dan Ta I. Title Operations Engineer Signature "` ...10 . Phone (907)777-8319 Date 6/21/2013 44 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .� l Plug Integrity I=1 BOP Test Mechanical Integrity Test CI Location Clearance ❑ RBDMS AUG .1/4,3 Other: $ 3COO p St; 66P 7'�5. )F Se, S,,z1ry dei_ A7 i. fi^...c e- -3 c.A:✓ • . Spacing Exception Required? Yes ❑ No / Subsequent Form Required: `6 — U O APPROVED BY Approved by: "-ki 1 2 (4. COMMISSIONER THE COMMISSION Date: 8 r! —i3 '` V i N Alzonths Submit Form and ��-Form taao3(Revised to/20t2) Appro e i i from the da of approval. Atta is in Duplicate V�� ■9� 7123�i3 " `z. Well Prognosis Well: AN-24RD Hilcorp Alaska,LL Date:6/21/2013 Well Name: AN-24RD API Number: 50-733-20285-01 Current Status: SI Producer _ Leg: 2 Estimated Start Date: July 15, 2013 Rig: Anna Platform Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 _ Permit to Drill Number: 207-170 First Call Engineer: Dan Taylor (907) 777-8319 (0) (907) 947-8051 (M) Second Call Engineer: Reid Edwards (907) 777-8421 (0) AFE Number: Current Bottom Hole Pressure: 2,000 psi 9556' TVD/ 11066' MD 0.21 psi/ft, 4.02 at mid-perf > P P @ p ( Ppg) from PBT 6/28/2008 Maximum Expected BHP: 2,000 psi @ 9556'TVD/ 11066' MD 0.21 psi/ft, (4.02 ppg) at mid-pert Max. Allowable Surface 0 psi using 0.364psi/ft, Diesel gradient Pressure: to surface Brief Well Summary AN-24RD was sidetracked and completed in 2008 after the original well AN-24 watered out in 2003. The well was drilled as a "hockey stick" style to target the crest and west flank portions of the Tyonek reservoir. It was completed with a dual string packerless power oil completion in the Tyonek. AN-24RD is currently online producing 15 BOPD and 10 BWPD and has produced a cumulative 19 MBO. A StimGun procedure will be worked on lower intervals C-5B and C-5A while standard TCP perforations will be placed in intervals C- 7C and 7D. The upper C-7C and 7D perforations will be hydraulically fractured. AN-24RD will be placed back on line with a dual string jet pump completion. Pre Rio Work 1. Skid Rig over An-24RD. 2. Retrieve Jet Pump. 3. Rig up slickline. 4. Pressure test lubricator to 250 psi Low/ 1,500 psi High. 5. Pick up equalizing prong, run in hole, and equalize well. 6. Pull out of hole with equalizing prong and lay down the same. 7. Pick up, run in hole, and retrieve standing valve. 8. Pull out of hole and lay down standing valve and pulling tool. 9. Pick up and run in hole down long string with GR. a. Previous tag 10,168 ft. on 1/28/13. 10. Pull out of hole and lay down GR. 11. Rig down slickline. Brief Procedure: 1. Circulate until clean returns up casing. 2. Monitor losses. 3. Install back pressure valves in long and short strings. 4. Nipple down tree. 5. Pick up and nipple up riser. 6. Pick up and nipple up BOPE. 7. Remove back pressure valve. • • • gnos Well:Well Pro AN-24Ris D Hiicori,Alaska,LL Date:6/21/2013 8. Pressure test BOPE 250 psi Low/3,000 psi High (Notify AOGCC 24 hours before pending BOPE Test). 9. Double check all rams and valves for correct operating position. 10. Rig up to pull dual string tubing. Pick up dual string elevators. 11. Release tubing hanger and lay down the same. 12. Pull out of hole with jet pump dual string cavity and lay down the same. 13. Pull out of hole with single string tubing and lay down the same. 14. Pick up and run in hole with clean out assembly. 15. Circulate hole clean and pull out of hole with clean out assembly. 16. Pick up/make up RTTS assembly and trip in hole to+/- 10,500 ft. a. Set RTTS tool b. Test casing to 1,000 psi and hold 30 min and chart(no loss more than 10%). 17. Rig up e-line. 18. Pick up and run in hole with GR/CCL from PBTD to surface. a. PBTD deviation = -71° 19. Rig down e-line. 20. Pick up and run in hole with 3 1/8" StimGun's and 4 5/8"TCP perforating guns spacing out with correlation log over the following intervals: Zone Type Top (MD,ft) Btm (MD,ft) Total (ft) C-7C Sand TCP 4 5/8", 5 SPF 9,662 9,699 37 C-7D Sand TCP 4 5/8", 5 SPF 9,716 9,738 22 C-5B Sand StimGun 3 1/8", 5 SPF 11,290 11,354 64 C-5A Sand StimGun 3 1/8", 5 SPF 11,379 11,422 43 21. Pick up guns above Perfs and monitor well for 1 hr. shooting fluid levels with fluid level gun to establish liquid level in wellbore. 22. Once well is static, POOH laying down Perf guns. 23. Rig up e-line. 24. Pick up and run in hole with ported mule shoe, bottom packer, plug, setting tool, and CCL. a. Set bottom packer at+/-10,500 ft. b. Deviation at packer=61° 25. Pull out of hole with setting tool and lay down the same. 4;4, 26. Rig down e-line. 27. Pick up and run in hole with latching type packer plug. /11l/'' 28. Pull out of hole with packer plug setting assembly and lay down the same. 29. Pick up, run in hole, and set 10K psi retrievable squeeze packer to+/-9,600 ft. 30. Pressure test packer to 1,500psi and chart 30min. ef-wlr . 31. Install 10K •si TIW safet valve in work strin•. 32. Prepare rig and platform for fracture treatment. a. See attached MSDS sheets Shut in BOP c. Rig up fracture treatment equipment. s-KNPe Anticipated Fracture Treatment Summary Surface Treating Pressure (max) +/-6,111 psi t,e--7.,.4% Total Rate (max) +/- 18.0 bpm Estimated Pump Time +/-44 min Flush +/-7,060 gals (Platform Oil) Fracture Fluid +/-22,125 gals (Super Rheo Gel) $r Proppant +/-68,500 lbs (Carbolite, 20/40) +/-32,000 lbs (Carbobond, 20/40) 1 . • • Well Prognosis Well: AN-24RD Ililcarp Alaska,Lb Date: 6/21/2013 Casing Summary Size WE Grade Collapse Internal Body Wall Con, ID Drift bbl/ft Total Top BTM (in) (lbs/ft) (psi) Min Yield Thickness (in) (in) (bbls) (MD,ft) (MD,ft) Yield (1000lbs) (in) (Psi) 2, 94 K-55 520 2110 1490 1.438 - 19.124 18.936 x.3553 - Surface 609 13.375 54.5 K-55 1,130 2,730 853 0.380 BUTT 12.615 12.459 0.1546 - Surface 2,000 68 1,950 3,450 1,069 0.480 12.415 12.259 0.1497 9.625 40 N-80 3,090 5,750 916 0.395 BUTT 8.835 8.679 0.0758 331.93 Surface 4,379 40 5-95 4,230 6,820 1,080 0.395 8.835 8.679 0.0758 187.38 4,379 6,851 43.5 S-95 5,600 7,510 1,193 0.435 8.755 8.599 0.0745 85.154 6,851 8,219 7 29 P-110 8510 11,220 929 0.408 F1 driI 6.184 6.059 0.0371 95.050 7.994 10,704 563 Thrd 4.5 12.6 L-80 7,50 9,431 299 0.271 Nydril 3.958 3.833 0.0152 14.227 10,556 11,492 iLirer■ 563 `hrd 33. Perform fracture treatment in accordance with proposed model. 34. Flow back well to production until static. 35. Pull out of hole with retrievable squeeze packer and lay down the same. 36. Pick up and run in hole with overshot assembly to retrieve latching type packer plug. 37. Pull out of hole with latching type packer plug and lay down the same. 38. Pick up and run in hole spacing out with snap latch seal assembly, ported sub, tubing, and jet pump. 39. Change out upper single variable rams to dual rams. 40. Test BOPE rams 250 psi Low/3,000 psi High. 41. Run in hole with dual strings. 42. Land new hangar. 43. Set back pressure valves. 44. Nipple down BOPE and install tree. 45. Remove back pressure valves. 46. Turn well over to production. �- ) ,tio ir7o41 Attachments: .4./.3 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Well Head Drawing • • Granite Point Field . ini SCHEMATIC Well #: An-24RD Hilcoru Alaska,LLC Completed 7/10/2008 CASING AND TUBING DETAIL API#50-733-20285-01 Size WT Grade CONN ID Top BTM RKB to TBG Head=60' 1 20" 94# K-55 - 19.124" Surface 609' 1 7 A 13-3/8" 54.5&68# K-55 Buttress 12.415" Surface 2,000' 20' I L 9-5/8" 40&43.5# N-80&S-95 Buttress 8.755" Surface 8,219' 7"Liner 29# P-110 Hydril 563 6.184" 7,994' 10,704' 4.5"Liner 12.6# L-80 Hydril 563 3.958" 10,556' 11,492' Long String TUBING DETAIL 13-3/8, , 2-7/8" 6.4# L-80 IBT(SCC) 2.441" Surface 10,505' 2-3/8" 4.6# L-80 IBT(SCC) 1.995" 10,505' 11,436' Short String 2-7/8" 6.4# L-80 IBT(SCC) 2.441" Surface 7,757' 2-3/8" 4.6# L-80 IBT(SCC) 1.995" 7,757' 10,347' 9-5/8' 2 B JEWELRY DETAIL ,„ x1 NO Depth ID OD Item A C "" 60' Tubing Hanger,Cameron,3-1/2"X 3 1/2 11"DCB e,.11, I Q. 1 54' 2.44 2.88 X-over 3-1/2"EUE x 2-7/8"IBT PxP `°: D *. 2 54' 2.44 - 2-7/8 Tubing 6.4#L-80 m 1.i 4 Oilwell Hydraulics Type"A"Single Parallel Cavity w/Stainless Steel 3.' 3 m,., 3 10,350' 2.25 5.8 Bands mew, 41 ',41 .i; 4 10,351' 2.44 2.88 XO 2 7/8"IBT x EUE . 5 10,361' 2.44 2.88 1 joints 2 7/8"Buttress Tubing+8'Pup Jt a � 4 6 10,401' 2.19 2.88 2 7/8"R nipple 5 7 10,410' 2.44 2.88 8'Pup Jt+3 joints 2-7/8"Buttress Tubing T. ' R I 6 8 10,505' 2 2.88 X-over 2 3/8 EUE x 2 7/8 Buttress � '*,, 9 10,506' 2 2.38 1 joint 2 3/8"EUE Tubing 10 10,541' 1.88 3.25 2 3/8"CMU Sliding Sleeve ' 8 11 10578 2 2.38 +/-26 joints 2 3/8"Buttress Tubing(EOT at 11436') i� '' 12 11436' Mule Shoe EOT r • 9 l a a 10 4 Short String y A 54' X-over 3-1/2"EUE x 2-7/8"IBT PxP 11 B 7 757 2 2.88 X-over,2-7/8"IBT Box x 2-3/8"IBT Pin C 10,347' 1.63 2.6 X-over,2 3/8"SCC.Box x"1''A"IJ Pin D 10,386' 1.625 1.900 Integral pup joint 1'A"IJ in. In ill LI PERFORATION DETAIL is N Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf _ C-7E 10,711' 10,731' 9,412' 9,421' 20' 6 ii IP C-7D 10,784' 10,805' 9,444' 9,453' 21' 6 C-7C 10,817' 10,859' 9,458' 9,476' 42' 6 41 C-7B 10,903' 10,934' 9,494' 9,506' 31' 6 1a C-7A 10,944' 10,990' 9,510' 9,528' 46' 6 _ C-6D 11,030' 11,038' 9,543' 9,546' 8' 6 i i C-6X 11,079' 11,086' 9,561' 9,563' 7' 6 C-5B 11,291' 11,355' 9,630' 9,648' 64' 6 W C-5A 11,380' 11,423' 9,655' 9,666' 43' 6 All Zones Re-perforated w/2-3/4"72°TCP guns } it Pal 1-10 f1: 12 I r ,',.a >s '„.� � � PBTD=11,449' MD/9,669'TVD 4-112" », .. - - �`1 "fi+- TD=11,494' MD/9,677'TVD• Revised By:TDF 1-15-2013 • • Granite Point Field .. H PROPOSED well #: An-24RD Hileorp Alaska,LLC Completed 7/10/2008 CASING AND TUBING DETAIL API#50-733-20285-01 Size WT Grade CONN ID Top BTM RKB to TBG Head=60' 20" 94# K-55 - 19.124" Surface 609' 1 . A 13-3/8" 54.5&68# K-55 Buttress 12.415" Surface 2,000' 20" L 9-5/8" 40&43.5# N-80&S-95 Buttress 8.755" Surface 8,219' 7"Liner 29# P-110 Hydril 563 6.184" 7,994' 10,704' 4.5"Liner 12.6# L-80 Hydril 563 3.958" 10,556' 11,492' Long String TUBING DETAIL 2 I I B 2-7/8" 6.4# N-80 Buttress 2.441" Surface ±7,900 13-3/8" 2-7/8" 6.4# L-80 IBT(SCC) 2.441" ±7,900 ±9,629 L , Short String 3 r` 2-7/8" 6.4# N-80 Buttress 2.441" Surface ±7,915' C 2-3/8" 4.6# L-80 IBT(SCC) 1.995" ±7915' ±9,598' Ezt r LONG STRING 9-5/8"A ' NO. Depth ID OD Item 4 60' Tubing Hanger,Cameron,3-1/2"X 3 1/2 11"DCB D 1 ±54' 2.441 3.5 X-over 3-1/2"EUE Box x 2-7/8"EUE Pin 2 ±55' 2.441 3.5 2-7/8"6.4#N-80 EUE Tubing 3 ±7,899' 2.441 3.5 X-over 2-7/8"EUE Box x 2-7/8"IBT Pin E >_ 4 ±7,900' 2.441 3.220 2-7/8"6.44 L-80 IBT Special Clearance Tubing ' 5 ±9,629 2.441 3.5 X-over 2-7/8"IBT Box x 2-7/8"EUE Pin F 6 ±9,630' 2.2502 5.8 Oilwell Hydraulics Type Single Parallel Cavity 7 ±9,636' 2.441 3.688 XO 2-7/8"EUE Box x 2-7/8"BTS-8 Pin 5 8 ±9,637' 2.313 2.188 2-7/8"BTS-8 Non-Elastomeric Sliding Sleeve ■ / 9 ±9,642' 2.441 3.5 X/O 2-7/8"BTS-8 Box x 2-7/8"6.4#EUE Pin i f��. 10 ±9,643' 2.441 3.5 2-7/8"6.44 N-80 EUE Tubing -,., r 6 = mi sI" 11 ±9,992' 2.441 3.5 X-over 2-7/8"6.44 L-80 IBT Box x 2-7/8"EUE Pin - . / 12 ±9,993' 2.441 3.688 2-7/8"6.54 L-80 EUE Tubing Pup Joint F:1 !�i 13 ±9,999' 2.313 5.75 3.250"Snap Latch Seal Assembly w/5'Seals �7 C.... 14 ±10,000' 3.25 5.813 7"26-32#Model D Permanent Packer 7 ,�' 15 ±10,002' 3.25 5.813 3.250"Concentric Packer Adapter sex.c 1 p T i■ 8 C-7 D 16 ±10,003' 3.25 4.75 5'Seal Bore Extension I4 9 r Cr`G Z rt .fl 17 ±10,008' 2.441 5.813 Tubing Adapter w/2-7/8"EUE Pin imil 10 18 ±10,009' 2.441 3.688 2-7/8"6.5#L-80 EUE Tubing Pup Joint 11 m; 19 ±10,017' 2.313 3.688 2-7/8"EUE"R"Landing Nipple(Otis Type R) 12 20 ±10,018' 2.441 3.688 2-7/8"6.54 L-80 EUE Tubing Pup Joint 13 14 21 ±10,026' 2.441 3.688 2-7/8"EUE WLEG 15 SHORT STRING A ±54' 2.441 3.5 X-over 3-1/2"EUE Box x 2-7/8"IBT Pin MI 18 �' 19 B ±55' 2.441 3.500 2-7/8"6.4#N-80 EUE Tubing 19 c ±7,91S' 1.995 3.500 X-over,2-7/8" 6.44 N-80 EUE Box x 2-3/8"IBT Pin MI 2p0 ±7,916' 1.995 2.700 2-3/8"4.64 L-80 IBT Special Clearance Tubing ■ Q' E ±9,598' 1.625 2.875 X-over 2-3/8"4.641-80 IBT Box x 1-1/2"IJ Pin F ±9,599' 1.625 1.9 Integral Joint 1-1/2"U 7" ► !070-1 PERFORATION DETAIL WI ly / Zone Top(MD) Btm(MD) Top(ND) Btm(ND) Amt spf ® C-7C 9,662' 9,699' 8,717' 8,752' 37' 5 C-70 9,716' 9,738' 8,768' 8,788' 22' S C-7E 10,711' 10,731' 9,412' 9,421' 20' 6 C-7D 10,784' 10,805' 9,444' 9,453' 21' 6 1 %, C-7C 10,817 10,859' 9,458' 9,476' 42' 6 C-7B 10,903' 10,934' 9,494' 9,506' 31' 6 C-7A 10,944' 10,990' 9,510' 9,528' 46' 6 111 4 C-60 11,030' 11,038' 9,543' 9,546' 8' 6 C-6X 11,079' 11,086' 9,561' 9,563' 7' 6 C-56 11,290' 11,354' 9,630' 9,648' 64' 5 RI i C-5B 11,291' 11,355' 9,630' 9,648' 64' 6 C-5A 11,379' 11,422' 9,654' _ 9,666' 43' 5 C-SA 11,380' 11,423' 9,655' 9,666' 43' 6 t' - r; PBTD=11,449' MD/9,669'ND 4-1/2"/ k, _, '1. . ■ TD=11,494' MD/9,677'ND Revised By:1LL 06/20/13 e • • Anna Platform AN-24RD & AN-39RD 03/22/2013 H 1rtirr.ilaska.Lit 47 1 H H i 0� v rift I I I iii iii 1.1 iii H 3.74• Shaffer iiIMIEF I11 III 1Ii I11 III 2 7/83 Variables 1ind ' Sheffer .. 2.50 _ = Choke and Kill valves I�� 31/85M 1.76 ��∎��. i 1, 1, 1. I "hie" ' 11. 1 1 '1' I I' Dual Flex Rams 2.83' III:11.1111 ill 14.20" DOCD 1611 14.20' Riser 13 5/8 5M FE X 135/85M FE I0 111 I ' . 11■,II 111 1.00 Spacer spool 13 5/8 5M FE 11 5M it 1i, i• ,ti E • 1II Pit 1.1 •1-.uIIrt ,�I'' ' tI liji NI-I• 4 11 t r 11a 11 ri I.w 1111 1 M.fir 4,,11 1 i• O ! • • Anna Platform An-24RD Current 03/22/2013 Ililrnrp Alaska.131. An-24RD Tubing hanger,Dual,CIW- 20 X 13 3/8 X 9 5/8 X DCB,11 X 3 1/2 EUE lift X 2 7/8 X 2 7/8 Valve,Master,CIW-F, 3 1/2,w/3"type H BPV 3 1/8 5M 5 bolt,FE,HWO profile,5 3/64 centers Qty 2 MNIIIMMIN (:111, �C 4 ,'� / Adapter,CIW-dual,11 5M FE X Tubing head,CIW-DCB, 8'= 1 8 5M 5 bolt top,prepped f 3 / p,p pp f/ 13 5/8 3M X 11 5M,w/2- ��;_0, 3"nom CIW hanger necks 2 1/16 5M EFO,X-bottom III�M 111 5 3/64 centers prep 1171711.--M- - Void test good 250/5000 =o«I I' 'II 1«'_ 6/10/2010 III I ° Ill Valve,WKM-M,2 1/16 5M 0 _ FE,HWO © _ ® - 1 © ! it 0 Qty 2 lil I 161 Casing spool,CIW-WF,21%2M X 13 5/8 3M,w/2 2 1/16 5M Void test good 250/2500 11=111=W' , 6/10/2010 EFO,X bottom prep `1/I — I II Valve,CIW-F,2 1/16 5M FE, HWO III1St II I I-!. III I III 5v'= Void test good 250/800 Casing head,CIW-WF,21'/2M X I. 6/10/2010 ei!SOW,w/2-2 1/16 2M EFO tel 1 Ill li I - lail ill .41111 111-1": -Valve,CIW F,2 1/16 2M FE, HWO tr 7 1:3F1-80-U3 N TYST8 985 0 - . <0 04-02 Section 36 'sTr `fl :R-::-08 1 T1 ON R12W :R-•2-403RD,,, 6 BR-42-1 CP i9 B'42-4' '4;4).yes '38? ��s, HILCORP ALASKA, LLC ADL 18742 II AN-2. -D AN-24 GRANITE POINT y AN-11 - MIDDLE KENAI GROUP Section 1 8,14) AN 24RD PERF ADD AN- x 199 N POSTED WELL DATA 4, 1' Well Label • FM TOPS-C-5_MKR[JFD](SS) AN-28 •N- 4-D qM AN-28RD2 i l�4TYST 2- 11 WELL SYMBOLS • Oil Well � 3 •��05 Plugged and Abandoned lik Abandoned Injector 1\ AN-07 Plugged&Abandoned Oil Well t' r 7RD + Shut-in Well / C �J REMARKS AN-26 d 6pr AN-24RD&BR-42-42 are the only active producers in the quarter section;AN-24&AN-11 are P&A producers; ^3 0) 9'bh BR-42-40 never produced and is P&A;AN-28RD& '. ,�� '1. BR-42-16 are abandoned water injectors • injectors AN-11 RD co 0 ...coil i AN-39 0 1 000 2 000 3 000 FEET r March 20,2013 PETRA 3/202013 9:15:26 AM • • • '" • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,.s, ( ',¢ 11 20 MC 25.280 1. Type of Request: Abandon El Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend El Plug Perforations ❑ Perforate El Pull Tubing El me Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current WeN Class: 5. Permit to NH umber. Hilcorp Alaska, LLC Exploratory ❑ Development El • 207 -170 • 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic El S ervice ❑ 6. API Nu � •er. Anchorage, AK 99503 50-7 . 20285-01' 7. If perforating: 8. Well Name and ' umber. What Regulation or Conservation Order governs well spacing in this pool? CO 76, Rule 2 A.,... pt 4- .Cor••.. Will planned perforations require a spacing exception? Yes ❑ No El Gran tet,8742 24RD - 9. Property Designation (Lease Number): 10. Field /Pool(s): ) ADL0018742 • Granite Pt / Middle Kenai G Oil Pool • 11. gg PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): TI Effective Depth MD (ft): Effective Depth TVD ft):0,„ lugs (measured): Junk (measured): • 11,494 9683 9( }7' 11,449 9;872' q 6 t t N/A N/A Casing Length Size MD TVD Burst Collapse Structural , Conductor 609' 20" 609' 60 ' Surface 2,000' 13 -3/8" 2,000' .1r , 58' 2,730 psi 1,130 psi Intermediate 8,219' 9 -5/8" 8,219' ' ' 7,353' 5,750 psi 3,090 psi Production 2,710' 7" 10,7 9,409' 11,220 psi 8,530 psi Liner 936' 4 -1/2" 11 ` 9,683' 8,430 psi 7,500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 4' Tubing Grade: Tubing MD (ft): See Schematic • See Schematic 2 -7/8" x 2- " ual 6.4# & 4.6# / L -80 11,436' & 10,347' Packers and SSSV Type: Pack - ` . nd SSSV MD (ft) and TVD (ft): N/A t N/A 12. Attachments: Description Summary of Propos. ` , . , 1 1 . II Class after proposed work: Detailed Operations Program ❑ BOP Sketch . \ plora ory ❑ Stratigrap .c CI Development G • Service El 14. Estimated Date for ; 5. Well Status after proposed wor 6/2/201 Commencing Operations: Oil ❑ • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct • the best of my knowledge. Conta. Dan Taylor Em .il dtavlorOhilcoro.com Printed Name Dan Ta for Title Operations En. ineer i Signature ...0"--- Phone (907) 777 -8319 Date 4/9/2013 COMMISSION USE ONL Conditions of approval: Notify Commission - . that a representative may witness Sundry Number: 313-(77 Plug Integrity ❑ BOP Test Wr Mechanical Integrity Test ❑ •cation Clearance ❑ Other: .*- 3 UOO PS.- i3 p P 77 (-- ,� n $ Ms r70 .J (es f" (•� w ir e -- . SCANNED JUN 0 7 2013 Spacing Exception Required? Yes ❑ No i Subsequent Form Required: /0 L i APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 0 � A � JUN -6 20 Submit Form and re- •� is /�0 L Approved application is valid for 12 months from the date of approval. Attachments in Dupii e 4 6K - *O-U3 N TYST8 '0 cO So-02 - B- - - f : Section 36 -, : R- I -08 T10N R12W : R .2-4�R - 6 ,:t. BR -42 -1 CP B ' - 42-4 9 ' � II � S HILCORP ALASKA, LLC ADL 18742 ^`� AN -24RD AN -24 GRANITE POINT • AN -11 MIDDLE KENAI GROUP Section 8 ,14 AN 24RD PERF ADD AN— ; ' • 7, 976 1 POSTED WELL DATA 4 1 9 Well Label • FM TOPS - C- 5_MKR[JFD] (SS) AN -28 -D a jA■ el AN -28RD2 • ICSTYST 2g1 WELL SYMBOLS 1 • Oil Weil o3 gto5 Plugged and Abandoned Abandoned Injector AN -07 0 Plugged & Abandoned Oil Well r l 7RD + Shut -in Well � REMARKS • AN - 6p AN -24RD & BR -42 -42 are the only active producers in to oJ � the quarter section; AN -24 & AN -11 are P&A producers; „J 0! ^' BR -42 -40 never produced and is P&A; AN - 28RD & • , � � A.. BR -42 -16 are abandoned water injectors i njectors AN -11 RD co — s o A AN -39 0 1 000 2 000 3 000 , = FEET 1 _ March 20, 2013 PETRA 32020139: 1526 AM • • Well Prognosis Well: AN -24RD Hileorp Alaska, LL Date: 04/09/2013 Well Name: AN -24RD API Number: 50- 733 - 20285 -91 Current Status: SI Producer Leg: 2 '(Zf' f Estimated Start Date: June 2, 2013 Rig: Anna Platform ✓ Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 207 -170 First Call Engineer: Dan Taylor (907) 777 -8319 (0) (907) 947 -8051 (M) Second Call Engineer: Reid Edwards (907) 777 -8421 (0) AFE Number: Current Bottom Hole Pressure: -2,000 psi @ 9556' TVD / 11066' MD .21 psi /ft., (4.02 ppg) at mid -pert from PBT 6/28/2008 Maximum Expected BHP: -2,000 psi @ 9556' TVD / 11066' MD .21 psi /ft., (4.02 ppg) at mid -pert Max. Allowable Surface Pressure: -Opsi using 0.435psi /ft. SW gradient to surface Brief Well Summary AN -24RD was sidetracked and completed in 2008 after the original well AN -24 watered out in 2003. The well was drilled as a "hockey stick" style to target the crest and west flank portions of the Tyonek reservoir. It was completed with a dual string packerless power oil completion in the Tyonek. AN -24RD is currently online producing 15 BOPD and 10 BWPD and has produced a cumulative 19 MBO. A StimGun procedure will be worked on lower intervals C -5B and C -5A while standard TCP perforations will be placed in intervals C -7B, 7C, 7D, 7E, 8B, 8C, 9A, 9B, 9C. AN -24RD will be placed back on line with the same as initial completion. ? P Brief Procedure: 1. ND Wellhead, NU BOP 6c1 test to 250 psi low /2,500 psi high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). cc;rc, (zW F 2. RU WL on long string and RIH with 2.5" JDC; latch and remove standing valve. 3. POOH with 2 -7/8" X 2 -3/8" dual tubing string and lay down the same. 4. PU and RIH with 3 -7/8" GR to 11,430 ft. - 7 Dr- 5. Circulate and POOH laying down GR. 6. PU StimGuns and standard Perforating Guns and RIH spacing out with correlation log. Perforate the following intervals: Zone Top (MD) Btm (MD) Amt (ft) C -7B Sand 9571 9576 5 C -7C Sand 9662 9699 37 C -7D Sand 9716 9738 22 C -7E Sand 9787 9800 13 C -8B Sand 9888 9898 10 C -8C Sand 9955 10011 56 C -9A Sand 10173 10180 7 C -9B Sand 10209 10226 17 C -9C Sand 10248 10264 16 C - 5B Sand 11290 11354 64 C - 5A Sand 11379 11422 43 • • Well Prognosis Well: AN -24RD Hilcorp Alaska, LL Date: 04/09/2013 7. PU string above perforations and monitor well for 1 hr. Shooting fluid levels with fluid level gun to establish liquid level in wellbore. 8. Once well is static, POOH laying down perforation guns. 9. PU and RIH with retrievable packer and dual tubing assembly. Set packer at 10,296 ft (see proposed well schematic). 10. ND BOP, NU well head and test. 11. Turn well over to production. Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Well Head Drawing H. Granite Point Field SCHEMATIC Well #: An -24RD ffilcorp Alaska, LLC r„:$4,--a____ Completed 7/10/2008 CASING AND TUBING DETAIL API # 50 Size WT Grade CONN ID Top BTM RKB to TBG Head = 60' 20" 94# K -55 - 19.124" Surface 609' 1 A 13 - 3/8" 54.5 & 68# K -55 Buttress 12.415" Surface 2,000' 20" L. 9 -5/8" 40 & 43.5# N -80 & S -95 Buttress 8.755" Surface 8,219' 7" Liner 29# P -110 Hydril 563 6.184" 7,994' 10,704' 4.5" Liner 12.6# L -80 Hydril 563 3.958" 10,556' 11,492' Long String TUBING DETAIL 13 - 3/8 N. 2 -7/8" 6.4# L -80 IBT(SCC) 2.441" Surface 10,505' 2 -3/8" 4.6# L -80 IBT (SCC) 1.995" 10,505' 11,436' Short String 2 -7/8" 6.4# L -80 IBT (SCC) 2.441" Surface 7,757' 2 -3/8" 4.6# L -80 IBT (SCC) 1.995" 7,757' 10,347' 2 1.1 B 9-5/8" ', 1:a ■ JEWELRY DETAIL 1 °l .t NO. Depth ID OD Item y C 60' Tubing Hanger, Cameron, 3 -1/2" X 3 1/2 11" DCB p 1 1 54' 2.44 2.88 X -over 3 -1/2" EUE x 2 -7/8" IBT PxP .l. D 'R 2 54' 2.44 - 2 -7/8 Tubing 6.4# L -80 - • ` sw Oilwell Hydraulics Type "A" Single Parallel Cavity w/ Stainless Steel t;' 3 .. . . 3 10,350' 2.25 5.8 Bands 'i Ns _ ..1 4 10,351' 2.44 2.88 X0 2 7/8" IBT x EUE 5 10,361' 2.44 2.88 1 joints 2 7/8" Buttress Tubing + 8' Pup Jt , T 4 `." 6 10,401' 2.19 2.88 2 7/8" R nipple '" 5 um 7 10,410' 2.44 2.88 8' Pup Jt + 3 joints 2 -7/8" Buttress Tubing b +. 6 h 8 10,505' 2 2.88 X -over 2 3/8 EUE x 2 7/8 Buttress g # I R 1 , ' 9 10,506' 2 2.38 1 joint 2 3/8" EUE Tubing 4 , ; 7 8 '• 10 10,541' 1.88 3.25 2 3/8" CMU Sliding Sleeve * v • 11 10578 2 2.38 +/- 26 joints 2 3/8" Buttress Tubing (EOT at 11436') 7 „ 9 f 10 � ' 12 11436' Mule Shoe EOT IN 11 1 i Short String A 54' X -over 3 1/2" EUE x 2 -7/8" IBT PxP B 7,757' 2 2.88 X -over, 2 -7/8" IBT Box x 2 -3/8" IBT Pin l - G1c C 10,347' 1.63 2.6 X -over, 2 3/8" SCC.Box x" 1 'A" 1.1 Pin D 10,386' 1.625 1.900 Integral pup joint 1'''A" IJ !Ni NS A. + 5I PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf C -7E 10,711' 10,731' 9,412' 9,421' 20' 6 C -7D 10,784' 10,805' 9,444' 9,453' 21' 6 ii i ii C -7C 10,817' 10,859' 9,458' 9,476' 42' 6 C -7B 10,903' 10,934' 9,494' 9,506' 31' 6 ' 0: 1 . C -7A 10,944' 10,990' 9,510' 9,528' 46' 6 C -6D 11,030' 11,038' 9,543' 9,546' 8' 6 i, C -6X 11,079' 11,086' 9,561' 9,563' 7' 6 C -5B 11,291' 11,355' 9,630' 9,648' 64' 6 !w w C -5A 11,380' 11,423' 9,655' 9,666' 43' 6 All Zones Re- perforated w/ 2 -3/4" 72° TCP guns t 12 1c5A we ts R. Ili a- 1/2"A.� ; PBTD = 11,449' MD / 9,669' TVD TD = 11,494' MD / 9,677' TVD Revised By: TDF 1 -15 -2013 ll , • • Granite Point Field PROPOSED Well #: An -24RD tlikora Alaska, LLC Completed 7/10/2008 CASING AND TUBING DETAIL API # 50-733-20285-01 Size WT Grade CONN ID Top BTM RKB t0 TBG Head = 60' 20" 94# K -55 - 19.124" Surface 609' A 13 -3/8" 54.5 & 688 K -55 Buttress 12.415" Surface 2,000' 220J 1 in L I , 9 -5/8" 40 & 43.58 N -80 & 5 -95 Buttress 8.755" Surface 8,219' 7" Liner 29# P -110 Hydril 563 6.184" 7,994' 10,704' 4.5" Liner 12.68 L -80 Hydril 563 3.958" 10,556' 11,492' Long String TUBING DETAIL 2 -7/8" 1 6.48 1 L -80 1 IBT (SCC) 1 2.441" 1 Surface 1 10,320' 13 -3/8" Short String L 2 N. 2 -7/8" 6.4# L -80 IBT (SCC) 2.441" Surface 7,757' 2 -3/8" 4.6# L -80 IBT (SCC) 1.995" 7,757' 10,212' �l CI LONG STRING 9- 5 /8 "Al 1 ■ NO. Depth ID OD Item Tubing Hanger, Cameron, 3 -1/2" X 3 1/2 11" DCB 1 1,889' 2.441 3.500 X -over 3 -1/2" EUE Box x 2 -7/8" IBT Pin 2 1,890' 2.441 3.500 2 -7'8" 6.4# L -80 IBT Tubing 3 10,212' 2.441 3.500 X -over 2 -7/8" IBT Box x 2 -7/8" EUE Pin 4 10,213' 2.2502 5.800 Oilwell Hydraulics Type Single Parallel Cavity B 5 10,219' 2.441 3.688 XO 2 -7/8" EUE Box x 2 -7/8" IBT Pin ,r / 6 10,220' 2.441 3.500 2 -7/8" 6.4# L -80 IBT Tubing Joint +� . C C .. 1 - 7 10,250' 2.441 3.500 X/O 2 -7/8" IBT Box x 2 -7/8" BTS -8 pin IN 3 S J D 6 8 10,251' 2.313 2.188 2 -7/8" BTS -8 Non - Elastomeric Sliding Sleeve M l I • 3 9 10,256' 2.441 3.500 X/O 2 -7/8" BTS -8 Box x 2 -7/8" IBT Pin i F7 �4 r. • - - .... 10 10,257' 2.441 3.500 2 -7/8" 6.4# L -80 187 Tubing Joint i�r 11 10,287' 2.441 3.500 X -over 2 -7/8" 6.4# L -80 IBT Box x 2 -7/8" EUE Pin 12 10,288' 2.441 3.688 2 -7/8" 6.58 L -80 EUE Tubing Pup Joint ',, 13 10,294' 2.313 5.750 3.250" Snap Latch Seal Assembly w/ 5' Seals killi 4, f 14 10,296' 2.375 5.875 7" 26 -32# AS1 -X Retrievable Packer - Carbide Slips 6 # 15 10,303' 2.441 3.688 2 -7/8" 6.58 L -80 EUE Tubing Pup Joint ' 7 U Q .M 16 10,311' 2.313 3.688 2 -7/8" EUE "R" Landing Nipple (Otis Type R) gEt 61 17 10,312' 2.441 3.688 2 -7/8" 6.5# L -80 EUE Tubing Pup Joint 1 8 18 10,320' 2.441 3.688 2 -7/8" EUE WLEG ele IC ....` 10 " ' 6 1 c. SHORT STRING IIM i+.. ±: 11 A 2 -7/8" 6.4# L -80 IBT Tubing 12 B 7,757' 1.995 3.500 X -over, 2 -7/8" 6.4# L -80 IBT Box x 2 -3/8" IBT Pin 13 14 C 7,758' 1.995 2.875 2 -3/8" 4.6# L -80 IBT Tubing MIR D 10,212' 1.625 2.875 X -over 2 -3/8" 4.6# L -80 IBT Box x 1 -1/2" IJ Pin 15 , 1 16 NOM 17 0. ,-1 i 18 ► PERFORATION DETAIL 7 " A F, • Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf C-78 9,571' 9,576' 8,631' 8,636' 5' C/� C -7C 9,662' 9,699' 8,717' 8,752' 37' C -70 9,716' 9,738' 8,768' 8,788' 22' C -7E 9,787' 9,800' 8,832' 8,844' 13' C -8B 9,888' 9,898' 8,920' 8,929' 10' C -8C 9,955' 10,011' 8,976' 9,021' 56' C -9A 10,173' 10,180' 9,138' 9,143' 7' 1.i. i. C -9B 10,209' 10,226' 9,161' 9,172' 17' C -9C 10,248' 10,264' 9,185' 9,194' 16' C -7E 10,711' 10,731' 9,412' 9,421' 20' 6 C -7D 10,784' 10,805' 9,444' 9,453' 21' 6 S S C -7C 10,817' 10,859' 9,458' 9,476' 42' 6 C -7B 10,903' 10,934' 9,494' 9,506' 31' 6 t C -7A 10,944' 10,990' 9,510' 9,528' 46' 6 ii C -6D 11,030' 11,038' 9,543' 9,546' 8' 6 C -6X 11,079' 11,086' 9,561' 9,563' 7' 6 C -58 11,290' 11,354' 9,630' 9,648' 64' � C -5B 11,291' 11,355' 9,630' 9,648' 64' 6 / - IN or C -5A 11,379' 11,422' 9,654' 9,666' 43' IS 6V ,1. C -5A 11,380' 11,423' 9,655' 9,666' 43' 6 • 1f.(�',X`... A ... ,PZ . PBTD = 11,449' MD / 9,669' TVD 4 - 1 /2 ,,, r�F ` ,14 . .. TD = 11,494' MD / 9,677' TVD Revised By:1LL 04 /04/13 ll , • Anna Platform AN -24RD & AN -39RD 03/22/2013 Hilt-119v AisiLa. IIA 1.1 II Ill I11 al liitil • liliil al al iii al iiliil 3.74' 1t1111 Lis 1t1 it 2 7/8 -5 Variables Shaffer LXT - ® 11_ _ 2.50' =Find 13 5/8 5M Choke and Kill valves 1 6 _ 111 1.1 I .1 1.1 111 3 1/8 5M .7 I , r 4 t ©�Lvi ' 111 111111111111 ,� vu.- maw' iv lil Dual Flex Rams 2.83' -- = li 1 _ 1 1 1 1 1 1 1 1 1 1 1 1 1 i 1 III 111111 111 1.1 1420' Riser 135/85M FE X 135/85M FE 111 111 11/ 111 lil 111 111 111 /11 111 1 00' Spacer spool 135/85M FEX115M 'Si 111 111 lid Iii 1 .1 riI)luIti . . on L O��, 1• 11111 al r ..... ...- .., • • Anna Platform An -24RD Current 03/22/2013 HIIrnrp .itlaoka. 1.11. An -24RD Tubing hanger, Dual, CIW - 20X133/8X95/8X DCB,11X31 /2EUE lift X 2 7/8 X 2 7/8 Valve, Master, CIW -F, 3 1/2, w/ 3" type H BPV 3 1/8 5M 5 bolt, FE, HWO profile, 5 3/64 centers Qty 2 O Q r r f -• p` . ,- , Adapter, CIW -dual, 11 5M FE X Tubing head, CIW-DCB, � �� ' 3 1/8 5M 5 bolt top, prepped f/ 13 5/8 3M X 11 5M, w/ 2- =a 0 2 1/16 5M EFO, X-bottom i�6 3'' nom CIW hanger necks prep III 111 5 3/64 centers El ---7 I = '- f Void test good 250/5000 . ari l I' 1111 III'= 6/10/2010 111 — III Valve, WKM -M, 2 1/16 5M n .. _ I _ O F E, HWO Ai 010 1■ . v ° _j, Qty 2 I1 I III Casing spool, CIW WF, 21 % 2M i . _ Void test good 250/2500 X 13 5/8 3M, w/ 2- 2 1/16 5M 14 4 6/10/2010 EFO, X bottom prep 111 � 1 I Valve, CIW -F, 2 1/16 5M FE, ' tell i 1 u I ! $ : i I) I _ ! 1111 :: �� - 4 Void test good 250/800 Casing head, CIW -WF, 21 % 2M X .i� 6/10/2010 SOW, w/ 2- 2 1/16 2M EFO 1. i l A I •, l i A 1 j V . e l ` e I CIW F 21 16 2M FE, , / HWO lor • • Schwartz, Guy L (DOA) From: Daniel Taylor <dtaylor @hilcorp.com> Sent: Thursday, June 06, 2013 7:06 AM To: Schwartz, Guy L (DOA) Subject: RE: Anna Platform - GP state 18742 24RD sundry (PTD 207 -170) Guy, Please withdraw Sundry 313 -177 for Anna 24RD. I will be resubmitting this request with a modified procedure. Regards, Dan Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907 - 947 -8051 From: Schwartz, Guy L (DOA) [maiito: u .schwartt `ac is k:3.;:;ov_ Sent: Wednesday, June 05, 2013 1:46 PM To: Daniel Taylor Subject: Anna Platform - GP state 18742 24RD sundry (PTD 207 -170) Dan, Please request in writing to withdraw sundry 313 -177 for Anna 24RD. As we discussed you are going to resubmit this sundry for the wellwork with a modified procedure. A response to this email is sufficient. Guy Schwartz Senior Petroleum Engineer AOGCC 907 - 444 -3433 cell 907 - 793 -1226 office DATA SUBMITTAL COMPLIANCE REPORT 3/2/2011 Permit to Drill 2071700 Well Name /No. GRANITE PT ST 18742 24RD Operator UNION OIL CO OF CALIFORNIA API No. 50- 733 - 20285 -01 -00 MD 11494 TVD 9677 Completion Date 3/20/2008 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION / .. Mud Log No Samples No Directional Survey Yes DATA INFORMATION • Types Electric or Other Logs Run: NEU / RES / GR / PRESS / DEN / NMR (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Tye Med /Frmt Number Name Scale Media No Start Stop CH Received Comments f og 5 Col 10100 11400 Open 6/23/200 Ontrak GR w /Litho Density Images. og Density 2 Col 8249 11494 Open 6/23/2008 MD RHOB, Nuetron Porosity, GR Log Induction /Resistivity 2 Col 8249 11494 Open 6/23/2008 MPR, CNP, CBD, RHOB, L GR ED C 16498 04ee Notes 0 0 Open 6/23/2008 Digital Dip, Plot and GR track in CGM, Meta, ASCII and multiple LAS files in Zip format. .g See Notes 5 Blu 10000 10480 Case 6/27/2008 TCP Correlation, GR, CCL 26- May -2008 (Cog See Notes 5 Blu 10000 10350 Case 6/27/2008 TCP Correlation, GR, CCL III 29- May -2008 g Sonic 5 Col 1959 4596 Case 6/27/2008 DIST, P &Sm Upper Dipole Log 9- Mar -2008 og Cement Evaluation 5 Col 300 8680 Case 6/27/2008 USIT and Casing Eval 9- Mar -2008 ED C 16510 wee Notes 0 0 Case 6/27/2008 Plug Back's 1 and 2 in PDS with USIT and Cement Eval in PDS ED C Las 16511 Gamma Ray 9895 10480 Case 6/27/2008 GR, CCL D C Las 16512 'ee Notes 9632 10350 Case 6/27/2008 TENS, GR, CCL I DATA SUBMITTAL COMPLIANCE REPORT 3/2/2011 Permit to Drill 2071700 Well Name /No. GRANITE PT ST 18742 24RD Operator UNION OIL CO OF CALIFORNIA API No. 50- 733 - 20285 -01 -00 MD 11494 TVD 9677 Completion Date 3/20/2008 Completion Status 1 -OIL Current Status 1 -OIL UIC N Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments • ADDITIONAL INFORMATION Well Cored? Y Daily History Received? 0/ N Chips Received? Thcr Formation Tops / N Analysis Received? Comments: Comments: rt Compliance Reviewed By: _ _ __ Date: • RE: AN -24Rd coordinates 0 20 7 Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Flynn, Tim [ASRC] [Tim.Flynn @chevron.com] Sent: Tuesday, January 06, 2009 11:39 AM To: Saltmarsh, Arthur C (DOA) Subject: RE: AN -24Rd coordinates Art Good to hear from you. The following are the updated coordinates for GP State 18742 AN -24RD2 Top of productive interval X: 264588 Y: 2555346 2122' FNL, 2338' FWL, Sec 1, T1ON, R12W, S TD X: 264695 Y: 2555420 2046' FNL, 2443' FWL, Sec 1, T1ON, R12W, S We apologize for the inconvenience. Let me know if there any further corrections. Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 -3322 907 -263 -7824 phone 907- 317 -5504 cell 1/6/2009 STATE OF ALASKA e- RECEIVED ALA OIL AND GAS CONSERVATION COMMI SION AUG 2 0 2008 ELL OR RECOMPLETION REPO/ AN LOG la. Well Status: ❑ ❑ Abandoned ❑ ❑ 1b: e a q. 83 vna. Curnml5 >ion 20AAC 25.105 20AAC 25.110 Development 0 AnchO � a(iirator y ❑ GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other❑ No. of Completions: Service ❑ Stratigraphic Test❑ 2. Operator Name: 5. Date Comp., 4 , o 12. Permit to Drill Number: Union Oil Company of California Aband.: ; 2008 207 -170 3. Address: 6. Date Spudded: 13. API ipber: Ku P.O. Box 196247, Anchorage, AK 99519 3/20/2008 , 50- 3- 20285 -01 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 790' FNL, 600' FEL, Sec 12, T1ON, R12W, SM - 5/16/2008 - GP ST 18742 24RD (AN -24RD) Top of Productive Horizon: ltd 4pLi /'° " 8. KB (ft above MSL): 105' 15. Field /Pool(s): 3 9' -94-2' FA, SecA, T1ON R12W SM q Ground (ft MSL): 65' Granite PT Field Total Depth: 2/0-, 3 , /. - t , 9. Plug Back Depth(MD +TVD): °� FNL, =,' � FxL, Sec 1 T1ON, R12W, SM 11,487' MD (9,675' TVD) Tyonek Sands 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 266857 y- 2551352 Zone- 4 . 11,494' MD (9,677' TVD) ADL0018742 TPI: x- 264588 y- 2555346 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 264695 y- 2555420 Zone- 4 N/A N/A 18. Directional Survey: Yes 0 No Lf 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) 85' (ft MSL) N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): fr 2fY A a 2 /Y # Neutron Porosity/Propagation Resistivity/Gamma Ray/ Formation Pressures /Azmuthac Density /NMR (5- 18 -08) P.3 ff'rr2) 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 94 K -55 0 609' 0 608' 13 3/8" 68,54.4 K -55 0 2,000' 0 2,000' 17 1/4" 900 sx G w/ 2% gel /CaCI 9 5/8" 40,43.5 S -95 0 9,105' 0 8,099' 12 1/4" 600sx G w /1 %CFR2,1 %HR7 7" 29# P -110 8793 10,400' 7,840' 9,220' 8 1/2" 525 sxs 4 -1/2" 12.6# L -80 10,558' 11,494' 9,337' 9,677' 6" 116 sxs G 23. Open to production or injection? Yes ❑ No El If Yes, list each 24. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) Perforated Intervals: 2- 7/8 "x2 -3/8" 4.6# L -80 10,347' (SS) N/A Comingled Coriipletions 2- 7/8 "x2 -3/8" 4.6# L -80 11,436' LS) N/A Initially perfed at 6spf over the following intervals: 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. C 7E 10,711'- 10,731' (20') C 7D 10,784'- 10,805' (21') DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED C -7C 10,817'- 10,859' (42') C -7B 10,903'- 10,934' (31') C -7A 10,944'- 10,990' (46') C -6D 11,030'- 11,038' (8') C -6X 11,079'- 11,086' (7') C -5B 11,291'- 11,355' (64') C -5A 11,380'- 11,423' (43') Same intervals reperfed on 7/9/08 at 6spf 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 7/22/2008 Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 8/13/2008 24 hrs Test Period . 6 6 16 N/A N/A Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 360 psi 24 -Hour Rate ii. 6 6 16 N/A 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. �..�7tA i'LC. i i� O 1 ^ ^r= ■ Form 10-407 Revised 2/20 em CONTINUED ON REVERSE R4v, --kr J }r 1(1 J �'` 'y ' — s t d • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ✓ U No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Lower Tyonek MGS Sand Member C -3 8,862' 7,938' (- 7,815') C -4 8,964' 8,036' (- 7,912') C -5A 9,085' 8,154' (- 8,030') C -5B 9,186' 8,252' (- 8,128') C -6D 9,464' 8,524' (- 8,400') C -7A 9,526' 8,585' (- 8,461') C -7C 9,660' 8,717' (- 8,593') C -7D 9,713' 8,769' (- 8,645') C -7E 9,789' 8,831' (- 8,707') C -8B 9,886' 8,916' (- 8,792') C -8C 9,957' 8,974' (- 8,850') C -7E Base Repeat 10,708' 9,408' (- 9,284') C -5A Top Repeat 11,473' 9,675' (- 9,551') 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Flynn 907 - 263 -7824 Printed Name: Timothy Brandenburg Title: Drilling Manager Signature: Phone: 907 - 276 -7600 Date: 8/19/2008 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 la: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for I njection, 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 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: 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 29: 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 2/2007 'Chevron • nna Platform 1 NNW An -24RD 1 ft.. Final WBD API #50- 73320285 -01 CASING AND TUBING DETAIL RKB to TBG Head = 60' SIZE WT GRADE CONN ID TOP BTM. 20" 94# K -55 - 19.124" Surface 609' 1 , j A 13 -3/8" 54.5 & 68# K -55 Buttress 12.415" Surface 2,000' 9 -5/8" 40 & 43.5# N -80 & S -95 Buttress 8.755" Surface 8,219' 7" Liner 29# P -110 Hydril 563 6.184" 7,994' 10,704' 4.5" Liner 12.6# L -80 Hydril 563 3.958" 10,556' 11,492' Tubing Long String L 2 -7/8 6.4# L -80 IBT (SCC) 2.441" Surface 10,505' 2 -3/8" 4.6# L -80 IBT (SCC) 1.995" 10,505' 11,436' Short String 1 P ' 11 2 -7/8 6.4# L -80 IBT (SCC) 2.441" Surface 7,757' �� 2 B 2 -3/8" 4.6# L -80 IBT (SCC) 1.995" 7,757' 10,347' I D JEWELRY DETAIL 4 , NO Depth ID OD Item s ±' I • • . � 60' Tubing Hanger, Cameron, 3 -1/2" X 3 1/2 11" DCB v 3 —• — . ,,.1 1 54' 2.441 2.875 X -over 3 -1/2" EUE x 2 -7/8" IBT PxP = ■ ; 2 ?�� 4 3 10,350' 2.250 5.800 Oilwell Hydraulics Type "A" Single Parallel Cavity w/ 5 = Stainless Steel Bands ' ' R 6 r 4 10,351' 2.441 2.875 XO 2 7/8" IBT x EUE �� , 5 10,361' 2.441 2.875 1 joints 2 7/8" Buttress Tubing + 8' Pup it i 8 ; 6 10,401' 2.188 2.875 2 7/8" R nipple • 9 i Q I 10 ■ } 7 ,' 28' P Jt j" ttbing 8 10 ,505' 1.995 2.875 2.75 X - up 2 3/8 3 EU E x 2 7/8 Buttress Tu al t 11 9 10,506 1.995 .441 2.375 1 joint 2 3/8 " EU E oi nts Tubing 10 10,541' 1.875 3.25 2 3/8" CMU Sli ding Sleeve 1 11 10578 1.995 2.375 +/- 26 joints 2 3/8" Buttress Tubing (EOT at 11436') t Mom Ffita 44'a 12 11436' Mule Shoe EOT Pk f Short String n A 54' X -over 3 -1/2" EUE x 2 -7/8" IBT PxP B 7,757' 1.995 2.875 X -over, 2 -7/8" IBT Box x 2 -3/8" IBT Pin f it C 10,347' 1.625 2.600 X -over, 2 3/8" SCC.Box x " 1 Y2" IJ Pin Zr. PERFORATION HISTORY ..- Interval Axun • �' L. Zone Top Btm Pat spf Comments Kr rya C-7E 10,711' 10,731' 20 6 Re-perforate W 2 314" 72' TCP guns G7D 10,784 10,805 21' 6 Re- perfaabe IN 2 314' 72° TCP guts F C-7C 10,817 10,859' 42 6 Re- perforate W 23/4" 72° TCP guns ' C-7B 10,903' 10,934' 31' 6 Re- perforate W 2 314" 72° TCP guns r ! # r C-7A 10,944' 10,990' 45 6 Re-perforate W 2 3/4" 72° TCP guns zt —_:.. i GED 11,030 11,035 8 6 Re- perforate W 2 314' 72° TCP grass 12 c- ex 11,075 11,095 T 6 Re perfaaee W 2314'72° TCP guns G56 11,291' 11,355 64' 6 Re- perfaate W s 2 314" 72° TCP gu C-5A. 11,380 11,423 43' 6 Re- perforate W 2 3/4" 72° TCP gus All 41' 1, e � -4 'k o . ■ PBTD = 11,436' MD / 9,679' TVD "` ` TD = 11,436' MD / 9,679' TVD AN -24RD WBD finaltsf.doc DRAWN BY: TSF 8/19/08 • • Osman Chevron - Alaska Time Log Summary Sort Well Name Tield Name APINWI 1' lease /Serial Ong KB Elev (ftKB) Water Depth (ft) AN -24 Granite Point Field 507332028500 1 ADL0018742 105.0 Primary Job Type Primary Wellbore Affected License No /Property Code Abandon Well Main Hole 1760220 T —_ — . - -- ' BiKCeg i IUnsa Start Date ; Dur Ors)! .End Date 1 Activity 1 sz c I Unached MI Type 3/1/2008 00:00 8.00 3/1/2008 08:00 BOP Nipple Remove bell nipple assembly - Change rams from 5" to 3-1/2" X Down 2 -7/8" - N/D BOP and secure to BOP stump - N/D drilling riser & spacer spool. 3/1/2008 08 :00 1.5013/1/2008 09:30 'Wellhead - Nipple 1 IN/U & test dry tole tree T/ 5000 psi /30 min Pull BPV set '/WC and 1 1 Up I 'test T/ 5000 PSI F/ 30 minutes all good Pull TWC and secyre welt. 3/1/2008 09:30 2.5013/1/2008 12:00 Preparations"' Prepare rig for skidding operations - Remove required access stairs, handrails & equipment for rig relocation to AN24. 3/1/2008 12:00 8.00 3/1/2008 20:00 Preparations"' Have JSA, R/U & tum top section jack frogs - Putt stairs for loamy & MCC raise substructure stairs, secure flowline, raise catwalk - Skid top section of rig 2' 6" North, Skid bottom section 5' 6" East - Un -bolt flowline & scope in, welder fabricating flowline extension - Complete 1 skid East to center of wen AN24 - Secure rig. 3/1/2008 20:00 0.50:3/1/2008 2030 'Preparations** Pull KOBE pump and lay out on deck. AN -24 3/1/2008 20:30 3.50 3/2/2008 00:00 Slickline - Fishing I Held PJSM - Spot & R/U slicktine equipment - RIH W/ KOBE lequalizing prong 17 8841 (428 RKB} StM, jar down to equalize std 'valve, POOH. AN -24 3/2/2008 00:00 0.00 3/2/2008 00:00 Monitor Casing Pressures: AN -32 - 20" = 15psi, 13 -3/8" = 305psi AN -24 - 20" , 4psi, 13 -3/8" = 320psi, 9 -5/8" = 75psi All IFO operations last 24 hours, Total IFO days = 10 Note- This is the last report for AN32 until side track operations. All costs will be transferred to AN24 starting 3/2/08 3/2/2008 00:00 6.50 3/2/2008 06:30 Sliddine - Run or Attempt to pull standing valve, sheared off 3 pulling toots. Ran out I Pull Plug or Stop had to have more sent over from Bruce platform Put Pollard to Bed. Prep bolts on ttanges F/ easier removal, gather tools and equipment F/ circulating welt. 3/2/2008 06:30 5.50 3/2/2008 12:00 Rig - Repair Remove trip tank flowline and replace air boot. Prep deck to LD 202 T tubing. Remove remainder of flowline to add extension. 3/2/200812 :00 3:50 321200815:30 'Rig- Repair HACL and JSA, add extension to flowline and install same. work on 202 T wirelirre lubricator, RU to circulate down annulus. 1 3/2/200815:30 3.00,3/2/2008 18:30 :Circulate & Pressure test lubricator to 1500 PSI. Initial pressures on annulus 340 1 Condition .PSI, bled off to 250 PSI, LS had a strong vac. Pumped 210 BBL down annulus, ending pump rpressure 100 PSI LS still on slight vac, 1 after 20 minutes pressure at 400 PSI. Bled pressure off to 300 PSI pumped an additional 100 BBL and shut down. Pump pressure at 150 PSI, LS had 20 PSI, after 20 minutes annulus had 500 PSI. Bled down to 400 PSI. , 3/21200818:30 1.00 312/200819 :30 Sncicline - Run or I RIH VvN new KOBE SV pulling tool, latched SY ® 8841' WLM, latch it j (Pull Plug or Stop 1 SV pulled 200 over string weight and SV came free POOH 1 3/2/2008 19:30 , 1.50 3/2/2008 21:00 Slickline - Rig Up / Rig down PWL, inspect SV, found 1 equalizing shear disc sheared, I Test BOPs / Rig :second one intact, one that was sheared had piece of teflon from Down Test pump seal cup plugging it off. The equalizing prong appears to have 'been redressed one time to many, it has been taken out of service. 3/2/200821:00 21:00 I 1.50 3/2/2008 22:30 Wellhead - Nipple Hetd PJSM with producton - Nipple down Kobe pump lines from { Down upper tree assembly & instal circulating flanges - Ready RPM tank for l , 'contingency displacement option - Fill mud puts with Inlet water. 3/2/2008 22:30 1.50:3 /3/2008 00:00 Kill Well Held displacement meeting - Pressure tested lines t o 1500 psi - Made 1 call to not begin displacement until crew change - Continue work 1 1 getting RPM tank ready for use, clean up tools & equipment in sub, re install winterization that had blown out of place. 3/3/2008 00:00 ' 1.5013/3/2008 01:30 `Preparations" 1 'Secure lines and prep to circulate well , 3/3/2008 01:30 2.00.3/3/2008 03:30 ;Circulate & .Pump Dn SS & take retums to production, initial tubing pressure 200 1 Condition ;PSI, pump 171 BBLS to get returns pumped a total of 271 bbls to get 1 I I clean fluid. Rate 3 BPM, final pressure 450 PSI well on vac after I pumping. 3/3/2008 03:30 3.5013/3/2008 07:00 Circulate & I R' 1 e uP on LS and Pump P told n9 retums to production, Initial pump Condition pressure 600 PSI, pump 600 BBL i 3 BPM, intermittent oil returns, 3/3/2008 07:00 ! 1.5013/3/2008 08:30 1 Monitor Well Monitor well while rigging up to circulate Dn LS taaking returns from 1 SS back to production 3/3/2008 08:30 1.00 3/3/2008 09 :30 Circulate & I Pump surface to surface Dn LS, UP SS to production to sweep Condition 'tubing, 150 BBL 0 3 BPM 680 PSI 3/3/2008 09:30 1 0.50 i 3/3/2008 10:00 1Monitor Well Monitor well LS, SS, and 9 5/8" x tubing annulus on vacuum. 313200810;00 j 0:5013737200810:30 Preparations** Production shot fluid level on casing, fluid level 0 783' - ND additional power oil flowtine section and valve, install blind on same. 3/3/2008 1030 1 0.5013/3/2008 11:00 1 Rig Up / Rig IND all hoses and steel line connections from tree and production. ,Down" 3/3/200811:00 1.0013/3/2008 12:00 Wellhead Set l Set 3" CIW type "H" BPV in long and short strings. BPV " r° 3/3/2008 12:00 0.50 3/3/2008 12:30 ,Preparations** Removed production hatch cover and install modified hatch cover for riser. 3/3/200812:30 4.5013/3/2008 17:00 Wellhead - Nipple PJSM W/ crew and production. NO tree and remove same - Tubing Down head adapter flange was studded not ntrougn 00t1 stuns had nisted to the bolt holes of the tubing spoof flange. Took some work to get off, had to assist removal W/ 3prota- powers, 3/3/2008 17:00 7.00 3/4/2008 00:00 'BOP - Nipple Up PJSM W/ crew, set riser & spacer spool - Orient BOP stack for 3 -1/2" I X 2 -7/8" dual rams - Install choke & kill lines, upper spacer spool on annular preventer & begin installing bell nipple. 3/4/2008 00:00 1 , 5.00 3/4/2008 05:00 I BOP - Nipple 1 NU bell nipple, install strip-o -matic rails and pull SOM over hole. Down Double check flange bolts. 3/4/2008 05:00 2.00 3/4/2008 07:00 BOP Test MU and set 2 7/8" x 3 1/2" dual test joints __ —_ • • Chevron Chevron - Alaska Time Log Summary Sort 0) Well Name 'Field Name APUUYJI Lease/Serial Ong KB Elev (ftKB) '', Water Depth (ft) AN -24 Granite Point Field 507332028500 ADL0018742 105.0 I i etucag 1 — — Una, Start Date iDur (firs) End Date 1 Activity --t- Sz I Comment Unsohed DU TYpe i 3/4/2008 07:00 5.00 3/4/2008 12.00 BOP Test Test BOP's 250 PSI low and 3000 PSI high, for 5 minutes each. Test all choke manifold valves, kill HCR and manual valve, (2) 3 1/2" TIW, (1) 3 1 /2" IBOP, 2 7/8 "Choke NCR and manual valve, along with 2 7/8" x 3 1/2" dual rams. Note had to lube choke HCR to get to hold. 3/4/2008 12:00 2.50314/2008 14:30 BOP Test i Pull 2 7/8" test joint, remove BPV and install TWC, test VBR and 'annular on 3' 1!2 "pipe. 250-3000 PSI 3/4/2008 14:30 2.5013/4/2008 17:00 BOP Test Install 2 7/8" test joint, remove 3 1/2" test joint pull BPV and install TWC. Test VBR and annular on 3 1/2" pipe 250- 3000PSI for 5 minutes each. Pull 2 7/8" test joint and test blinds to 250 -3000 PSI for 5 minuts each. 3/4/2008 17:00 f 1.50 BOP Test [Pull TWC F/ L&S sides, install 31/2" test joint, Koomey test, full recovery time 2 minutes 9 seconds 3/4/2008 18:30 4.50 3/4/2008 23:00 Tubing - Running Had pre job safety meeting, with all hands, RD equipment off floor, changed out bails, and rig up WOTCO dual equipment. 3/4/200823:00 1.0013/5/2008 00:00 Trip Out of Hole IMIJ landing joints and install same 3/5/2008 00:00 1.0013/5/2008 01:00 'Trip Out of Hole Pull 2 -7/8" X 3-1/2" hanger free & continue to pull same to rig floor - No additional overpull required to pull free - P/U weight = 195M. 3/5/200801:00 0.5013/5/2008 01 :30 (Monitor Well I Monitor wen for loss - v'ell loss rate observed = 13 bph. 3/5/2008 01:30 0.50 3/5/2008 02:00 Trip Out of Hole UD landing joints. 3/5/2008 02:00 3.50 3/5/2008 05:30 I Circulate & (Welt 0-tubing from SS side, attempted to tJD Ranger halves - Condition WOTCO tongs inoperable, troubleshoot same - Ciro & Cond (3.5 bpm I - 550 psi) while WOTCO repaired tongs. ' 3/5/2008 05:30 18.50'3/6/2008 00:00 ;Trip Out of Hole ;WOTCO completed repairs - S/D pump (well static) - Break out & UD I hanger halves - PJSM on UD tbg - Continue to POOH W/ 3 -1/2" X 2 -7/8" dual string - Strap & tally tbg on TOOH - Avg Fluid loss at midnight was 6.3 bph, UD total of 150 jts (75 3 -1/2" & 75 2 -7/8 ") P/LI 1 weight @ midnight = 125M 3/6/2008 00:00 0.00 3/6/2008 00:00 Monitor Well Casing pressures as follows: AN32 - 9-5/8" = 0 - 133/8" = 390 - 20" = 10 AN24 -9-5/8" N/A- 13-318" =270 - 20" = 7 . 1100% IFO last 24 hours, Last incident = 220/2008 - Days since last incident = 15 Held BOP drill WI dual string. Environmental & BOP check list completed. I '3/6/2008 00:00 6.50 3/6/2008 06:30 (Trip Out of Hole Continue POOH W/ 3 -1/2" X 2 -7/8" dual tbg string 3/6/2008 06:30 0.50 3/6/2008 07:00 Rig - Service { Monitor well on trip tank & Service rig while WOTCO changing tong /dies & repair of a hydraulic line 3/6/2008 07:00 l 5.0013/6/2008 12:00 ;Trip Out of Hole Continue POOH W/ 3-1/2" X 2 -7/8 "dual string - After 300 jts out of the hole P/U = 110M, S/0 = 105M -12 hour fluid loss = 72 bbls (6 bph , ',avg) - Total jts POOH for last 12 hours = 130 (10.8 Its / hr avg) 3/6/2008 0:5013/6/200812:30 Monitor Well Monitor well on trip tank during crew change - PTSM & JSA on rig flow. 3/7/2008 00:00 0.0013/7/2008 00:00 I Safety 100% IFO last 24 hours, Last incident = 2/20/2008 - Days since last Drills /Meetings incident = 17 ,Proactive Safety Efforts Last 24 Hours = 12 1 Environmental & BOP check list completed. Casing pressures as follows: .AN32 - 9 -5 /8" = 0 - 13-3/8" = 390 - 20" = 8 ;AN24 - 9 -5/8" N/A - 13-3/8" = 270 - 20" = 10 :3/6/2008 12:30 11.50 3/7/2008 00 :00 [Trip Out of Hole Continue to POOH W/ dual siring - P/U weight © EOT = 75M S/0 = I 73M - Total jts POOH during tour =130 (10.8 jts / hr avg) Encountering some very tight connections space out issues - Fluid loss last 12 hours = 74 bbts (6.16 bph) 1 . Note: NORM levels over last 24 hours = <1 Rem/hr 0 background - No tubing integrity issues noted so far. 3/7/2008 00:00 0.003/7/2008 00:00 [Monitor Well ;Casing pressures as follows: AN32 - 9 -5/8" = 0 - 13 -3/8" = 400 - 20" = 10 AN24 - 9 -5/8" N/A - 13-3/8" = 275 - 20" = 10 100% IFO last 24 hours, Last incident = 2/20/2008 - Days since last incident = 16 Environmental & BOP check list completed. 3/7/2008 00:00 11.00 3/7/2008 11:00 Trip Out of Hole POOH LD dual string 312" x 2 7/8" 10 KOBE type 10" Cavity (OD 5 5/8 ") LD total of 262 JTS 3 12", 5 JTS 2 3/8", and 267 JTS 2 7/8" tubing. 3/7/2008 11:00 2.50'.3/7/2008 13:30 ;Trip Out of Hole RD Dual elevators and slips change out bails, and hand 2 7/8" elevators '.. 3/7/2008 13:30 1.00 3/7/2008 14:30 !Trip Out of Hole 1 BO and LD KOBE Cavity, all looked good no missing parts or holes i observed, check for NORM OK Zero reading. KOBE Cavity OD = 5-5/8" L L I —_ L . • Menem m Chevron - Alaska Time Log Summary Sort Well Weil Name Field Name APINWI Lease /Serial ',Org KB Etter (RKB) '�. Water Depth (R) AN - 24 Granite Point Field 507332028500 ADL0018742 105.0 Unsc_. Start Date ! Der (firs) End Date A ctivity J Sc 1 Comment : Unsched MI Type 3/7/2008 14:30 2.50 3/7/2008 17:00 ' Trip Out of Hole POOH and LD remainder of LS tailpipe 39 JTS of 2 7 /8' had a good bit of scale inside and some on the outside as well. NORM reading was OK. 3/7/200817 :00 1.0013/7/200818:00 I Tubing - Running I 1Monitor well F/ static losses 7 BPM rig down WOTCO 3/7/2008 18:00 1.00 3/7/2008 19:00 Preparations" Clean floor organize tools 3/7/200819:00 4.00 3/7/2008 23:00 Rig Up / Rig RAJ to drain BOP stack & drain same down to blind rams - Change 1 Down" rames in upper double gate cavity from 3-1/2" X 2 -7/8" to 5" RAJ 5" handling equipment (rig tongs, elevators, slips etc) - Install I ironroughneck track. I 3/8/2008 00:00 0.00 3/8/2008 00:00 Safety 1 incident fast 24 hours, Last incident = 3/08/2008 - Days since last Drills /Meetings incident = 0 Proactive Safety Efforts Last 24 Hours = 10 .Environmental & BOP check list completed. Casing pressures as follows: AN32 - 9 -5/8" = 0 - 13-3/6" = 390 - 20" = 10 AN24 - 9 -5/8" N/A - 13-3/8" = 270 - 20" = 10 3/7/2008 23:00 1.00 3/8/2008 00:00 Rig Up / Rig P/U & M/U test plug & ported sub W/ 5: DP assembly in preparation Down" to test BOPE on 5" DP. 3/8/2008 00:00 2.00:3/8/2008 02:00 BOP Test Finish MU test joint, set test plug, MU TIW & IBOP valve and fill stack '- Observed IBOP would not seat, removed & replaced with back -up. 3/8/2008 02:00 2.50 :30 `BOP Test Test all aplicable BOPE on 5" DP, after ram change to 250 -3000 PSI chart same for 5 minutes each test. 3/8/2008 04:30 2.00'3/8/2008 06:30 Preparations" Pull test plug and run wear ring, LD test joints 3/8/2008 06 :30 05013/8/2008 07:00 I Rig -Service Service rig, record wet static loss rate of 7 BPH 3/8/2008 0700 3.00 3/8/2008 10:00 BHA - PU /MU" PU and MU 7" X 9 -5/8" tandem cleanout assy 3/8/200810:00 2.00 3/8/200812:00 Tripping to RIH F/ 520' - T/3350' - Fill pipe & blow down top drive - Inspect hyd leak on iron roughneck & attempt to repair same. 3/8/200812:00 0.50',3 /8/200812:30 Tripping In TIH F/ 3350' T/ 4578' - S/D & monitor well while working on dwks & iron roughneck. 3/8/200812:30 200(3/8/200814:30 'Tripping In { TIHF /d578T15500' -Mkt top drive & fill pipe. I 3/8/2008 14:30 0.5013/8/2008 15 Rig - Repair Resecure TD service loop hyd lines - Lubricate kelly hose to prevent 1 . sticking between DP & derrick. 3/8/200815 :00 2.00 3/8/200817:00 Tripping In TtH F/ 5500' 71 7800' - M/U top drive & fill pipe - Break circulation (g 52 spin -190 psi: 3/8/200817:00 0.50'' 3/8/2008 17:30 Tripping In TIH F/ 7800' T/ 8857' - P/U = 250M, S/0 = 190M - M/U TD & break circulation, stage pump to 30 SPM, 65psi - slowly slack off watching for indication of stack out on stop sub - Pick up, break out TD & P/U a , single - M/U TD stage pump to 30 SPM, 65 psi - Slack off & tart stop sub on TOL W/ 10M (rD, 8918' bit depth DPM (18' RKB difference from :prior rig) 7" l OL corrected depth = 8/21' UM. 3/8/2008 :30 3.00 3/8/2008 20:30 (Circulate & Stage pump up to 10.5 BPM - 825 psi - Pupm hi vis sweep around, 1 Condition observed no solids or fill at return of sweep. 3/9/2008 00:00 0.00:3/9/2008 00:00 '0 incident last 24 hours, Last incident = 3/08/2008 - Days since last 1 incident = 1 Proactive Safety Efforts Last 24 Hours = 13 Environmental & BOP check list completed. Casing pressures as follows: AN32 - 9 -5/8" = 0 - 13-3/8" = 400 - 20" = 10 AN24 - 9 -5/8" N/A - 13 -3/8" = 280 - 20" = 6 3/8/2008 20:30 3.50 3/9/2008 00:00 'Tripping In Held PJSM - Filled trip tank - Break out TD & blow down saute - 1 I POOH F /8996' 712502' -NU l 2500' = 95M 3/9/2008 00:00 2.00 3/9/2008 02:00 :Trip Out of Hole POOH F/ 2506'- 520' monitor well OK 3/9/2008 02:00 I 3.00 3/9/2008 05:00 (BHA - Handle" STD 5" HWDP and all 3 1/2" DP back, LO BHA, service boot basket found d minor chunks of scale in same. (Spring Ahead 1 Hour) 3/9/2008 05:00 1 50', 3/9/2008 06:30 ( Preparations" MU 5" DP lubricator RU SLB a -line line. 3/9/2008 06 :30 1.00(3/9/2008 07:30 (Safety JSA, Complete CVX, perforation and explosives checklist, MU Baker Drills/Meetings 7" CIBP on E -line. 3/9/2008 07:30 3.00:3/9/200810:30 'Slickline - Run or RIH W/ Baker CIBP F/ 7" casing, 1.56' long 5 5/8" OD, running tool Pull Plug or Stop max OD 3 3/8 ", Set CIBP (rD 8880' corelated off SLB Gamma on , 'Compensated Density log 4-21-76, note collar at 8886', CIBP set i 09:30, POOH 3/9 /200810:30 0.50 3/9/2008 11:00 Casing - Pressure Pressure test casing to 500 PSI f/ 15 minutes and chart same 0 PSI Testing ' ss.. r... 3/9/2008 11:00 1.00 3/9/2008 12:00 Electricline - Rig RD E -line head LD 5" DP lubricator and prep f/ USIT/ Neutron Sonic Up / Rig Down logs 3/9/200812:00 1.0013/9/2008 13:00 I Electricline - Rig I PJSM w/ SLB prior to rigging up USIT logging tool, start rigging up Up / Rig Down (equipment found, SL8 Missing bowspnng centralizer 3/9/2008 13:00 2.00 13/9/2008 15 Rig - Repair SLB Shut down waiting on tools, continued w/ housekeeping and :503 T !work in RPM 3/9/2008 15:00 1 1.0013/9/200816:00 i Electricline - Rig I Continue to M/U USIT tools testing same found electrical failure in Up / Rig Down I (tools. SD • • Chevron - Alaska 1 , 11 00 0 Time Log Summary Sort Well Name Field Name - -- AP W WI - Lease /Serial - -- - - - Ong KB Flay (gKB) : Water Depth (ft) AN -24 Granite Point Field 507332028500 ADL0018742 105.0 a Una. I Start Date 1 Der (firs) I End Date I Activity Activity s9 Comment Unsoiled DO Ty e 3/9/2008 16:00 2.0013/9/2008 18:00 Rig - Repair Trouble shoot equipment found head leaking current rehead checked 503 T again found current leakage at electrical disconnect, replaced with conventional weak link set at 5000#. Rewired cable at unit spear. 3/91200818:00 2.5013/9/2008 20:30 1 Log - Caliper RIH w/ USIT log to TOL / 8700' Loq up A 4000 FPH to 3450', SLB 1 I Power pack developed a fuel fine leak, all contained in enclosure. I 'UPS stored data on computer and shut down. 3/9/2008 20:30 1.50 3/9/2008 22:00 Rig - Repair Repair leak in primer pump of fuel system, RIH to 4650' and restart 503 T computer system to tie back in for splice logs. 3/9/2008 22:00 1 2.00 3/10/2008 00:00 Log - Caliper Log with USfT /Neutron Sonic (PSI) f/ 4650' - t/ 4150' logging data ■ 'frequency needed to be changed to a lower level. RIHTT4•50` change parameters of tools and re-log 1/ 4500' same results. POOH t/ 42017 continue logging 1/ 3800' WLM @ 500 FPH. I 3/10/2008 00:00 3.00'3/10/2008 03:00 Log - Caliper Continue w/ SLB E -line USIT/ Neutron Sonic (DSI) logging tools f/ 3800' - t/ 2300' WLM, @ 0300 hrs. computer system shut down. 3/10/2008 03:00 j 1.00 3/10/2008 04:00 i Log - Caliper I Attempt to reboot system primary computer with no luck and went to ■ I I back -up system to continue logs. RIH with tool string to 2100' to splice I i in logs. 3/10/2008 04:00 1.50 3/10/2008 05:30 Log - Caliper Continue logging f/ 2450' - U I) 1990' with USIT and Neutron Sonic (DS logs © 500 FPH. Stop Neutron Sonic (DSI). RIH t/ 2150' and continue USIT f/ 2150' - surface @ 4000 FPH. Retrieve data off hard of primary computer. 3/10/2008 05:30 1.0013/10/2008 06:30 Log - Rig Up / Rig R/D Schlumberger E-line tools and equipment. Retrieve data off hard Down of primary computer. 3/10/2008 06:30 2.50'3/10/2008 09:00 1 P/11 Tubing - Running 2 7/8" tbg. cement stinger w/ mule shoe. 414.8', Rabbit with 2.35" drift. I 3/10/2008 09:00 5.00 3/10/200814:00 iTripping In , I RIH w/ 2 7/8" tb2 stinper on 5" drill Pipe and tap CIBP (& 8902' DPM, I set down 5K to firm, Up wt 235K / Dn wt. 180K. Space out to circulate and pump cement. 2 718" tail CO 8.893'. 3/10/200814:00 2.50 3/10/2008 16:30 Circulate & Circulate hole @ 9 bpm w/ 550 psi. PJSM w/ Schlumberger on Condition cement job. 4 ._t___ 3/10/200816:30 1.50 3/10200818 :00 (Cement - Rig Up / Change over to Schlumberger and break circulation -test lines to Rig Down 3000 psi.- Pump 10 bbls. Drill H2O spacer, 20 bbls class G cement - Equipment scaled @ 15.6 ppg -10 bbls. Drill H2O spacer and displace with 135 bbfs. Cement in place @ 1755 hrs. Estimated top 8,537' 3/10/2008 18:00 0.5013/10/200818:30 'Trip Out of Hole POOH slow to 8 313' 3/10200818:30 1.00 3/10200819 :30 Circulate & ( R/U and Reverse out @ 9.2 bpm w/ 620 psi, got back 12.5 bbls. Condition colored water - no cement. pumped 2 tubular volumes. 3/10/2008 19:30 4.50 3/11/2008 00:00 ,Trip Out of Hole POOH w/ 5" drill pipe to 2 7/8" tbg. Pumping 3/11/2008 00 :00 2.00 3/11/2008 02 :00 Tubing - Running L/D 2 7/8" tbg stinger 3/11/2008 02:00 1.00:3/11/2008 03:00 'Casing - Pressure ;Testing 9 5/8" csq. and cement plug to 2000 psi for 30 minutes with Testing 8.5 DDQ FIW, witness by Lou Giimaldi of AOGCC, charted test, good. Schlumberger prep to set CIBP. 3/11/2008 03:00 1.00 3/11/2008 04:00 Electricline - Rig I R/U SL8 E4ine to run CIBP, PJSM w/ perforating/explosive safety IUp / Rig Down 'check fist. 1 3/11/2008 0400 2.50 3/112008 06:30 'Cement - Set RIH with Baker CIBP @ rate of 3600' FPH t/ 8370' and tie in to USIT Retainer I log 3/9/08. Set CIBP @ 0632 hrs.- top Cd 8,223.5' WLM and tao 'same. Put feed pump for centrifuge in utility module. 3/11 /2008 06:30 1.00 3/11/2008 07 :30 Cement - Set Attempt to log out but computer data linking problems, started out with 503 T Retainer E-line t/ 6920' and unit ran out of fuel, reminded the problems. 3/11/2008 07:30 1.50 3/11/2008 09:00 'Cement - Set Continue to POOH with E -line, all tools in tack, R/D SLB tools and Retainer ,unit. 3/112008 09:00 300 3/11/200812:00 Preparations" Work on getting electrical power to mud shack (Plug type), Fill #1 reserve tank in RPM for fluid test, no teak. Remove 2 7/8" & 3 1/2" tbg. equipment and XO from rig prep for boat. Maintenance iron rough neck. Organize and housekeeping. 3/11 /200812:00 2.0013/11/2008 14:00 Preparations** PJSM LID 3 1/2" drill pipe and move 5" drill pipe in derrick. Transfer fluid to #3 reserve tank in RPM for fluid test. 3/11200814:00 2.00 3/11200816:00 Preparations"` Service top drive/dray/works and change oil in tuggers. Organize and housekeeping. 3/11/200816:00 2.50 3/11/2008 18:30 Preparations" I House keeping in cellar, around suit case and pits. mount fire extinguisher in Swaco unit. Finished transfer of fluid to #3 reserve tank of RPM no leaks, R/U to transfer to active pits 3/11/2008 18:30 5.50 3/122008 00:00 Circulate & PJSM with production to pump FIW from test and active pits to Condition production for injection. Pump rate 2 bpm w/ 80 psi. Total of 540 bbls. Five crew members went to town for tomorrow Sud meeting due I ,to helicopter. _l_. - - - - Chevron • • Chevron - Alaska Daily Operations Summary Well Name Field Name API /UWI Lease /Serial CHEVNO License No. /Prope... Orig KB Elev (ftKB) Water Depth (ft) AN -24RD Granite Point Field 507332028501 207170 AR4483 2071700 53.2 Job Cat Type AFE No. r QC Eng Drilling Redrill & Complete UWDAK -D7004 3/12/2008 00:00 - 3/13/2008 00:00 Operations Summary Service rig, hold prespud meeting for AN -24RD in Kenai 3/13/2008 00:00 - 3/14/2008 00:00 Operations Summary Rig repair and Rig up 3/14/2008 00:00 - 3/15/2008 00:00 Operations Summary Rig repair and rig up 3/15/2008 00:00 - 3/16/2008 00:00 Operations Summary Rig repair and rig up 3/16/2008 00:00 - 3/17/2008 00:00 Operations Summary Rig repair and rig up, prep for BOP test. Notified AOGCC of upcoming BOP test. Witness waived by Chuck Sheve. 3/17/2008 00:00 - 3/18/2008 00:00 Operations Summary rig up and repair, Test BOP's 250/3000 psi 3/18/2008 00:00 - 3/19/2008 00:00 Operations Summary Re- test BOP's to 250/3500 psi per AOGCC PTD regulation. BOP test witness waived by Jimm Regg, repair ram, P/U Whipstock BHA. 3/19/2008 00:00 - 3/20/2008 00:00 Operations Summary RIH w/ Whipstock, Change over to OBM (oil based mud). ;% 3/20/2008 00:00 - 3/21/2008 00:00 Operations Summary Change well over to OBM, Mill window from 8219' to 8237' MD, perform FIT (formation integrity test) to 14.0 EMW (equivalent mud weight), Drill ahead to 8257' MD 3/21/2008 00:00 - 3/22/2008 00:00 Operations Summary Drill ahead to 8274' MD, POOH, PU drilling BHA. 3/22/2008 00:00 - 3/23/2008 00:00 Operations Summary PU Drilling BHA, TIH Drill ahead to 8316' MD 3/23/2008 00:00 - 3/24/2008 00:00 Operations Summary Drill ahead to 9004' MD 3/24/2008 00:00 - 3/25/2008 00:00 Operations Summary Drill ahead to 9315' MD, Mud pump repairs 3/25/2008 00:00 - 3/26/2008 00:00 Operations Summary Drill ahead to 9498' MD, POOH for Bit, UD (lay down) BHA. Notice given to AOGCC of upcoming BOP test. 3/26/2008 00:00 - 3/27/2008 00:00 Operations Summary Test BOP's 250/3500 psi, witness waived by AOGCC Bob Noble. P/U drilling BHA 3/27/2008 00:00 - 3/28/2008 00:00 Operations Summary MU Drilling BHA, TIH (trip in hole), MAD ( measure after drilling pass open hole to 9485' 3/28/2008 00:00 - 3/29/2008 00:00 Operations Summary Finish Madpass, Drill ahead to 9750' MD 3/29/2008 00:00 - 3/30/2008 00:00 Operations Summary Drill ahead to 9903' MD 3/30/2008 00:00 - 3/31/2008 00:00 Operations Summary Drill ahead to 9977' MD, POOH for bit 3/31/2008 00:00 - 4/1/2008 00:00 Operations Summary POOH for bit, Rig Repair, TIH with BHA #4 Chevron • • Chevron - Alaska Daily Operations Summary Well Name Field Name API /UWI Lease /Serial CHEVNO License No. /Prope... Orig KB Elev (ftKB) Water Depth (ft) AN -24RD Granite Point Field 507332028501 207170 AR4483 2071700 53.2 D+ = rations �.x. 4/1/2008 00:00 - 4/2/2008 00:00 Operations Summary TIH to KOP kick off poit), Mad Pass open hole section to 9989' 4/2/2008 00:00 - 4/3/2008 00:00 Operations Summary Drill ahead to 10116' MD 4/3/2008 00:00 - 4/4/2008 00:00 Operations Summary Drill ahead to 10275' & begin POOH. Contacted AOGCC of upcoming BOP test. 4/4/2008 00:00 - 4/5/2008 00:00 Operations Summary POOH, test BOP's (250/2500) Witness waived by AOGCC Lou Grimaldi, M/U Drilling BHA 4/5/2008 00:00 - 4/6/2008 00:00 Operations Summary TIH w/ Drilling BHA, Madpass open hole, Drill ahead to 10,315'MD 4/6/2008 00:00 - 4/7/2008 00:00 Operations Summary Drill ahead to 10353' MD 4/7/2008 00:00 - 4/8/2008 00:00 Operations Summary Drill ahead to 10418' MD, Stuck BHA on bottom, Attempt to Jar BHA free 4/8/2008 00:00 - 4/9/2008 00:00 Operations Summary Run freepoint, Trip in with string shot, Back off string w/ 105' of BHA left in hole, POOH 4/9/2008 00:00 - 4/10/2008 00:00 Operations Summary M/U •clean out BHA, TIH, circulate above top of fish to 10315', POOH. MU fishing assembly RIH 4/10/2008 00:00 - 4/11/2008 00:00 Operations Summary POOH w/ clean out assembly, RIH w/ screw in sub 4/11/2008 00:00 - 4/12/2008 00:00 Operations Summary Wash and ream to top of fish, Top of fish not found, POOH to P&A fish. Notified AOGCC of upcoming BOP test. Witness waived by Chuck Sheve. 4/12/2008 00:00 - 4/13/2008 00:00 Operations Summary UD BHA, Test BOP's (250/3500), witness waived by AOGCC. Service rig, RIH w/ 2 7/8" cement stinger 4/13/2008 00:00 - 4/14/2008 00:00 Operations Summary RIH from casing window, circ & cond, RU for cement job, wait on batch mixer, Starter failed on batch mixer, wait on repairs, mix spacer. Circ @ low rate while troubleshooting. 4/14/2008 00:00 - 4/15/2008 00:00 Operations Summary Mix mud push and cement/spot lower isolation plug from 10280 to 9800, CIP (cement in place) @ 0530 /Mix mud push and cement/ spot KO plug from 9800 to 9250, CIP @ 1140/ POOH, LD cmt stinger. 4/15/2008 00:00 - 4/16/2008 00:00 Operations Summary MU BHA and test same, RIH, CBU (circulate bottoms up) @ csg window, wash and ream to 9225, clean out cement to 9375, CBU, time drill /side track from 9375 4/16/2008 00:00 - 4/17/2008 00:00 Operations Summary Slide drill from 9383 to 9475. Side track original well bore @ 9376. Time drill off of cement plug and increase ROP (rate of penetration) as cement to formation ratio decreases. Attempt to survey @ 9475 (failed to pulse) 4/17/2008 00:00 - 4/18/2008 00:00 Operations Summary Drill from 9475 to 9513, MWD failure (no pulse), CBU, POOH, Down load data, LD BHA, Test BOP and related equipment. Note: Notified AOGCC of BOP test @ 0725. Jim Regg of AOGCC waived to witness @ 0915. 4/18/2008 00:00 - 4/19/2008 00:00 Operations Summary Finish testing BOP and install wear bushing /MU and surface test BHA #10/Trip in hole to casing window, CBU max gas 565 /Slip and cut drlg line/Trip in hole, log and clean out to 9513 /Drill from 9513 to 9530 Chevron Chevron - Alaska Daily Operations Summary Well Name Field Name API /UWI Lease /Serial CHEVNO License No. /Prope... Orig KB Elev (ftKB) Water Depth (ft) AN -24RD Granite Point Field 507332028501 207170 AR4483 2071700 53.2 Dail 0. = ratio.,` ". � � . t °��: �:. '� << 4/19/2008 00:00 - 4/20/2008 00:00 Operations Summary Calculate projected well path and consult with well engineer./ Drill from 9530 to 9842, 14 fph average pipe in ground. 4/20/2008 00:00 - 4/21/2008 00:00 Operations Summary Drill 8 1/2" hole with rotary steerable from 9842 to 10,105. Back ream drilling breaks as necessary. 16 ft/hr average pipe in ground 4/21/2008 00:00 - 4/22/2008 00:00 Operations Summary Drill from 10,105 to 10,137'. Troubleshoot pressure loss, POOH for washout, Washed joint @ std #84, Continue to csg window, service rig, install new PLC program, RIH to 10,137' Drill to 10,200 4/22/2008 00:00 - 4/23/2008 00:00 Operations Summary Drill 8 1/2" hole with Rotary Steerable from 10,200' to 10,270/ Work on pump/ Drill from 10,270 to 10,279'/ CBU /POOH 4/23/2008 00:00 - 4/24/2008 00:00 Operations Summary POOH for bit/ Down load data from MWD/ Rig repair, change strip- o- matic/ MU bit and change out jars, upload data to MWD/ TIH to csg window/ CBU 450 units of gas/ TIH, wash and ream from 10135 to 10279, work tight hole to reduce torque and drag/ Drill from 10,279 to 10,283 4/24/2008 00:00 - 4/25/2008 00:00 Operations Summary Drill 10,283 to 10,290/ work tight hole @ 10,290/ Sweep hole/ Drill 10,290 to 10,301/ Repair pump/ Work tight hole to 10,301/ Drill 10,301 to 10,340, drlg break with high Tq, pipe became stuck/ Attempt to free pipe, jars won't fire/ RU APRS for back -off. 4/25/2008 00:00 - 4/26/2008 00:00 Operations Summary PJSM/ Attempt back -off operation w /APRS, miss fire/ Re -arm string shot, back off BHA @ 10,157' POOH with Dp and HWDP/ LD drilling jars/ MU fishing assy and RIH to 8219/ CBU, max gas 623 4/26/2008 00:00 - 4/27/2008 00:00 Operations Summary CBU @ csg window/ RIH to TOF @ 10,157/ Engage fish, circulate, jar and work torque in string (17 hours attempting to free fish) APRS backed off with string shot @ 10,251. 4/27/2008 00:00 - 4/28/2008 00:00 Operations Summary Back off fish @ 10,251/ POOH and LD APRS/ CBU/ POOH with fish/ LD fish and Baker tools/ Service rig/ Pick up cement stinger/ TIH to 8219/ CBU 4/28/2008 00:00 - 4/29/2008 00:00 Operations Summary TIH to 10245/ RU cmt head / Circ and cond/ Spot 44 bbl, 500' cmt plug to 9745'/ POOH to 9494/ CBU/ POOH, LD cmt stinger/ Slip & cut drlg line/ Test BOPE 250/3500, Filled BOP with test fluid (water) per AOGCC rep. 4/29/2008 00:00 - 4/30/2008 00:00 Operations Summary Test BOPE 250/3500, witnesses by AOGCC Jeff Jones. Make up BHA #14 & test/ Trip in hole/ CBU @ shoe/TIH/Tag cmt @ 9557/ Clean out cmt from 9557 to 9629 4/30/2008 00:00 - 5/1/2008 00:00 Operations Summary Time drill off cement plug from 10100 to 10130'MD, Drill ahead to 10220' 5/1/2008 00:00 - 5/2/2008 00:00 Operations Summary Drill ahead from 10220'MD to 10357'MD 5/2/2008 00:00 - 5/3/2008 00:00 Operations Summary Dril ahead F 10357'md to 10423'MD, POOH for Bit and motor change. Contacted AOGCC for upcoming BOP test. Witness waived by Jim Regg. 5/3/2008 00:00 - 5/4/2008 00:00 Operations Summary LID BHA, Test BOP's 250/3500, AOGCC waived witness. M/U directional BHA 5/4/2008 00:00 - 5/5/2008 00:00 Operations Summary TIH, Wash and ream to bottom, Drill ahead F/ 10423'md to 10450'MD 5/5/2008 00:00 - 5/6/2008 00:00 Operations Summary Drill ahead from 10450' MD to 10,704' MD, POOH to run 7" casing. Notified AOGCC of upcoming BOP test. Chevron • • Chevron - Alaska Daily Operations Summary Well Name Field Name API /UWI Lease/Serial CHEVNO License No. /Prope... Orig KB Elev (ftKB) Water Depth (ft) AN -24RD Granite Point Field 507332028501 207170 AR4483 2071700 53.2 0 . .: rations '? _ � " R . 5/6/2008 00:00 - 5/7/2008 00:00 Operations Summary Short trip to Shoe @ 8220'MD, Circulate TIH to TD @ 10704', Circulate and condition mud, POOH to 815'MD 5/7/2008 00:00 - 5/8/2008 00:00 Operations Summary UD BHA, Change out to 7" rams, test rams 250/3500 psi, test OK, R/U to run 7" liner 5/8/2008 00:00 - 5/9/2008 00:00 Operations Summary RIH w/ 7" liner, wash &ream to bottom, reciprocate and rotate on bottom, cement liner, bump plug 5/9/2008 00:00 - 5/10/2008 00:00 Operations Summary POOH w/ liner running tools, change Ram configuration (remove 7" install 5" variable) AOGCC Jim Regg waived witness of upcoming BOP test 5/10/2008 00:00 - 5/11/2008 00:00 Operations Summary UD BHA, Test BOPs 250/3500 AOGCC witness waived, P/U 6" directional BHA 5/11/2008 00:00 - 5/12/2008 00:00 Operations Summary M/U directional BHA, P/U 3.5" DP, RIH, wash and ream to 10609'MD, test lap to 13.8 EMW. 5/12/2008 00:00 - 5/13/2008 00:00 Operations Summary Drill out float equipment, condition mud to 9.5ppg, drill shoe and 20' of formation to 10724'MD, perform FIT to 12.8 EMW, Drill ahead 5/13/2008 00:00 - 5/14/2008 00:00 Operations Summary Drilled marker sands and coals: C7C @ 10,856' / C6D @ 11,078' / TM44 @ 11,108' / TM43 @ 11,199'. 5/14/2008 00:00 - 5/15/2008 00:00 Operations Summary Drilled marker sands & coals: C -5BBR @ 11,290' / C -5BTR @ 11,356' / C -5ABR @ 11,375' / C -5ATR @ 11,427'. Unconfirmed. 5/15/2008 00:00 - 5/16/2008 00:00 Operations Summary Circulate bottoms up, POOH, L/D BHA 5/16/2008 00:00 - 5/17/2008 00:00 Operations Summary TIH, Madd pass open hole, to 10490'. Drill from 11490' to 11494'. Well total depth reached @ 11,494'. POOH 5/17/2008 00:00 - 5/18/2008 00:00 Operations Summary UD BHA, P/U pressure tools, TIH, Perform formation pressure tests, Log up hole, AOGCC rep, Tom Monder waived BOP test @ 0845 5/18/2008 00:00 - 5/19/2008 00:00 Operations Summary Finish logging, POOH, UD BHA, Begin BOP test.Chuck Sheve waived to witness BOPE test @ 0730. 5/19/2008 00:00 - 5/20/2008 00:00 Operations Summary Test BOPE (250/3500), AOGCC witness waived, RIH w/ 4.5" liner, Circulate and condition. 5/20/2008 00:00 - 5/21/2008 00:00 Operations Summary Set 4.5" Liner on bottom @ 11494'MD, Cement liner, disconnect from liner, Bump plug, 4 bbls cement back,ZXP packer failure, good cement. POOH 5/21/2008 00:00 - 5/22/2008 00:00 Operations Summary POOH, L/D tools, P/U 7 "x4.5" scraper, TIH, Clean out to top of Landing collar @ 11447' MD, test casing to 14 ppg EMW. 5/22/2008 00:00 - 5/23/2008 00:00 Operations Summary Scraper 7" and 4.5" liner, displace well from drilling mud to 7.6 ppg base oil. 5/23/2008 00:00 - 5/24/2008 00:00 Operations Summary POOH, UD BHA, Change out to 2 7/8" x 2 7/8" rams, test to 250/3500 psi, P/U perf guns. 5/24/2008 00:00 - 5/25/2008 00:00 Operations Summary P/U completion, RIH 5/25/2008 00:00 - 5/26/2008 00:00 Operations Summary RIH w/ dual completion Chevron 1 • %AO Chevron - Alaska Daily Operations Summary Well Name Field Name API /UWI Lease /Serial CHEVNO License No. /Prope... Orig KB Elev (ftKB) Water Depth (ft) AN -24RD Granite Point Field 507332028501 207170 AR4483 2071700 53.2 .�. 5/26/2008 00:00 - 5/27/2008 00:00 Operations Summary RIH w/ dual completion, correlate on depth. 5/27/2008 00:00 - 5/28/2008 00:00 Operations Summary Finish GR tie in, Land dual completion @ 11422' MD, R/D surface equipment 5/28/2008 00:00 - 5/29/2008 00:00 Operations Summary N/D BOPE, NU tree, test to 5000 psi, good test, R/U flowline, pump well down. 5/29/2008 00:00 - 5/30/2008 00:00 Operations Summary Slickline operations, place AN -24RD on production 5/30/2008 00:00 - 5/31/2008 00:00 Operations Summary Rig down, prep to move to AN -37 5/31/2008 00:00 - 6/1/2008 00:00 Operations Summary 6/1/2008 00:00 - 6/2/2008 00:00 Operations Summary 6/2/2008 00:00 - 6/3/2008 00:00 Operations Summary 6/3/2008 00:00 - 6/4/2008 00:00 Operations Summary 6/4/2008 00:00 - 6/5/2008 00:00 Operations Summary 6/27/2008 00:00 - 6/28/2008 00:00 Operations Summary Skid rig over An -24 6/28/2008 00:00 - 6/29/2008 00:00 Operations Summary Retrieve standing valve on Slick Line. Circulate the well full with base oil on short and long strings. Restriction noted in long string. 6/29/2008 00:00 - 6/30/2008 00:00 Operations Summary Finish circulating the well. Nipple down tree and nipple up BOP. Witness waived by AOGCC Chuck SheveStart BOP testing. 6/30/2008 00:00 - 7/1/2008 00:00 Operations Summary Finish testing BOP's, witness waived by AOGCC. Circulate well full. Pull hanger and lay down. Trip in hole and tag fill at 11446' (3' above bottom). 7/1/2008 00:00 - 7/2/2008 00:00 Operations Summary Start tripping out of hole laying down dual string of 2 7/8" tubing. 7/2/2008 00:00 - 7/3/2008 00:00 Operations Summary Finish tripping out of the hole and lay down perforating guns. All shots fired. Noted sludge in and on guns. Change out rams in BOP's 7/3/2008 00:00 - 7/4/2008 00:00 Operations Summary Finish testing rams. Trip in the hole with mule shoe. Wash thru perfs 10,673- 10,958 by reverse circulating. 7/4/2008 00:00 - 7/5/2008 00:00 Operations Summary Finish washing thru perfs to 11448. TOOH. Start making up perforating assemblies. 7/5/2008 00:00 - 7/6/2008 00:00 Operations Summary RIH w/ pert guns on drillpipe 7/6/2008 00:00 - 7/7/2008 00:00 Operations Summary Coorelate guns on depth, drop bar, failed to fire guns, POOH Chevron • • ONO Chevron - Alaska Daily Operations Summary Well Name Field Name API /UWI Lease /Serial CHEVNO License No. /Prope... Orig KB Elev (ftKB) Water Depth (ft) AN -24RD Granite Point Field 507332028501 207170 AR4483 2071700 53.2 7/7/2008 00 :00 - 7/8/2008 00 :00 Operations Summary UD perf guns. Tom Maunder of AOGCC notified of upcoming BOP test, 6 hrs prior to test, test BOP's to 250 low /3000 psi high, passed 7/8/2008 00:00 - 7/9/2008 00:00 Operations Summary Change out elements in 13 3.8" annular, test BOP's, M/U perf guns RIH 7/9/2008 00:00 - 7/10/2008 00:00 Operations Summary TIH with perf guns, coorelate on depth, set packer, prepare to fire guns. Notified AOGCC Jim Regg of upcoming BOP test. 7/10/2008 00:00 - 7/11/2008 00:00 Operations Summary Pull detonation bar, POOH w/ Perf guns. Perf the following intervals at 6spf: 10,711'- 10,731', 10,784'- 10,805', 10,817'- 10,859', 10,903'- 10,934', 10,944'- 10,990', 11,030'- 11,038', 11,079'- 11,086', 11,291'- 11,355', 11,380'- 11,423'. Perform BOP test 250 /3000 Witness waived by AOGCC Jim Regg. 7/11/2008 00:00 - 7/12/2008 00:00 Operations Summary Cont. BOP test, Trip in w/ dual 2 7/8x2 3/8" completion 7/12/2008 00:00 - 7/13/2008 00:00 Operations Summary Cont. to trip w/ dual 2 7/8" x 2 3/8" completion 7/13/2008 00:00 - 7/14/2008 00:00 Operations Summary Coorelate guns on depth, land completion, pressure test hanger to 3500 psi, Nipple down BOP's 7/14/2008 00:00 - 7/15/2008 00:00 Operations Summary Nipple up wellhead, bundle test tubing to 3500 psi, test tree to 5000 psi, Prep rig to move to AN -32RD2 7/15/2008 00:00 - 7/16/2008 00:00 Operations Summary Move rig to AN -32RD2 7/16/2008 00:00 - 7/17/2008 00:00 Operations Summary . Actual Wellpath Geographic Report • Report Generated 6/19/2008 at 2:45:14 PM Projection System NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Operator Chevron North Reference True Area Cook Inlet, Alaska (Offshore) Scale 0.999962 Field Granite Point Field Horizontal Reference Point Slot Facility ANNA Platform Vertical Reference Point Anna Rig #428 (RKB) Slot slot #2 -3 MD Reference Point Anna Rig #428 (RKB) Well AN -24RD Field Vertical Reference mean sea level Wellbore AN -24Rd Anna Rig #428 (RKB) to Facility Vertical Datum 124.00 ft Wellpath NaviTrak MWD <10152- 10657' >OnTrak MWD <10718- 114945 Anna Rig #428 (RKB) to mean sea level 124.00 ft Wellbore Last Revised 05/01/2008 Facility Vertical Datum to Mud Line (Facility) 0.00 ft Sidetrack from AN -24RD PB2 at 10098.00 MD Section Origin X E 0.00 ft User Ulricard Section Origin Y N 0.00 ft Calculation method Minimum curvature Section Azimuth 329.88° Local North Local East Grid East Grid North Latitude Longitude [ft] [ft] [USft] [USft] Slot Location - 789.01 - 594.01 60 ° 58'36.968 "N 151 °18'45.150 "W Facility Reference Pt v, ', , „ 60 °58'44.738 "N IIIIIIIMINKEEMEI �, -� 60 °59'36.731 "N Field Reference Pt -��. '. „� �, `� °`� TVD from MD Inclination Azimuth TVD Fld Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Rate Turn Rate Vert Sect Comments [ft] [°] (°] [ft] [ft] [ft] [ft] [ft] [ft] (° /100ft] [ °] [ ° /100ft] [ ° /100ft] [ft] 0.00 0.00 241.00 0.00 - 124.00 0.00 0.00 266856.72 IIEMEMEMI 60 ° 58'36.96814 151 °18'45.150"W 0.00 0.00 0.00 0.00 0.00 19.00 0.00 241.00 19.00 - 105.00 0.00 0.00 266856.72 EMEEKII 60 °58'36.968 "N 151 ° 18'45.150 "W 0.00 - 119.00 0.00 0.00 0.00 540.00 ®" r r IMEMEMBEREMEEIM W 266852.38 2551350.00 60 °58'36.945 "N '® 68.05 WE= 0.00 r r 969.00 MEM 279.00 968.82 844.82 ®® 266841.44 nEganE1 60 °58'36.937 "N 151 °18'45.459 "W IIKIMMISIIIMEM 8.86 4.90 IIIIME 1039.00 ® 319.00 1038.76 914.76 ®® 266839.16 ®' 60 °58'36.952 "N ®r ®MEIEEIUSIEM® 1161.00 mizimmsaaa 1160.29 1036.29 WEIIII® 266833.14 EignME 60 °58'37.033 "N 151 °18'45.631 "W ®' ®MEIEMMZEINIMINEM r r ®r r r ESEIMINUMMENEM® 266829.45 EMMEN 60 °58'37.103 "N 151 °18'45.708 "W MEM 47.90 MEM 20.00 MEEll 1314.00 EIBIEINII 350.00 MingaMIEMEMEEMMEM 266825.53 111=E1111MEES3 151 °18'45.794 "W ®=1=MM= 40.80 1111=11MIEMMESEMIKEEMMEMEENEZIEMIIMM 266822.53 2551405.50 60 °58'37.486 "N 151 °18'45.864 "W =31111MEEMINEEM®MENIMI EIMINIMEMIIMEMEMEEKE 1606.70 =ECM -49.59 266810.19 MiliIIMENI 60 °58'38.466 "N I ®IZIEM®IIIIIM 156.44 1999.00 ® 350.00 MERREEMEMEMmommum 266795.29 2551606.13 60 ° 58'39.455 "N 151 °18'46.498 "W ®MIME® -0.40 MIEMIENIIIIIIIIMI 2262.00 ® 348.00 2188.88 2064.88 111EXEMI -89.69 266774.49 ® 60 °58'40.629 "N 151 °18'46.968 "W 0.40 180.00 MEMM:MMIE1325. 2689.00 MM. 348.00 ESCIENEEMEMEUME - 130.00 266738.00 MEMO 60 °58'42.496 "N '®IEMEM '® 0.00 WEIMININE IMMEMMEIZEIMMEDZIMEEBEEM 2609.98 WEEMEMENIE 266722.29 11E=Ea 60 °58'43.264 "N 151°18'48.134"W 1111MMEMEMIZIMMEEIN 626.92 IIMEIMMENIMI 3184.00 28.00 346.00 MEM 2888.57 MINIM - 180.10 266692.20 ® 60 °58'44.608 "N 151 °18'48.800 "W r®® 0.80 '® 3490.00 30.00 MEM 3280.20 MEHMEMIEDUE102. 266655.32 111EMEEM 60 °58'46.015 "N 151 MI= 86.48 mom -0.98 905.01 3645.00 MUM 348.00 NOME 3290.29 993.99 MM. 266637.38 MEMIEM 60 °58'46.756 "N 151 MEIMIMBEEMILIMMEEM 979.87 3764.00 29.00 WEIMMEEIMIENEMMEMMEMEMMEME 266629.80 2552409.07 60 BZIMENEMEMINCEIMMEEMMIEEM 1034.50 IMMINIMMEMEMIMEMIE IMEEMMORMIEEKIMMEEEKIIMEKEEMEEEMIIMEEMOI 266615.47 IEERNME 60 °58'48.994 "N 151°18 MEM= 80 '®I4 4308.00 IMMEIMMIEEMERIMEMEEMEM 1306.50 Neffimm 266606.72 2552664.00 60 °58'49.834 "N�llaMMEIMIE 0.00 MEMEMIIME 4703.00 MEMINEXEMI 4346.90 MEM 1489.34 - 302.00 266584.62 IlegEMEM 60 °58'51.634 "N ESIERIMINIMM 0.00 '®MEill. 1439.81 4961.00 IIMEIMERIEMEINECE 4448.28 MEMEEEMSEEM 266567.47 MEM. 60 °58'52.855 "N 151 °18'51.669 "W I* 0.48 0.00 MEMIll 5343.00 28.00 ill=111 4906.79 4782.79 IMOMMI® 266537.63 leggEgan 60 °58'54.641 "NIIKEMEMEM -0.46 MEM 1730.60 5749.00 11130CIMMEEM 5266.91 MarSEMEMIEMMEMEM 266500.76 MEM= 60 °58'56.443 "N 151 ° 18'53.169 "W '®IIMEMEAMMEM 1909.26 1111 ° 6001.00 29.00 346.00 5489.41 MEMIIMEEMINEERE 266475.42 IIEREMEEM 60 °58'57.576 "N r® 0.00 MEMMMEMECESI 6065.00 MEM 346.00 EZEKEICEIMEM® I 266468.44 60 °58'57.876 "N 151 ° 18'53.884 "W ®MEM® 0.00 KCEEKINIli 6434.00 MESIMINEEEMI 5860.18 MUM 2309.16 - 479.08 266424.01 2553670.49 60 °58'59.707 "N 151°18'54.860"W 0.89 0.00 0.88 MIMMINEHOMMIE 6801.00 MIREMEMEKIMWEEM 6040.42 EMBEEMENEM 266374.88 2553869.73 60 ° 59'01.659 "N '®' 180 '®' 0.00 magagEmmiommommumn 7079.00 34.00 345.00 Mani 6269.53 2659.48 NM= 266337.18 2554022.60 60 °59'03.156 "N 151 MEM -90.42 =En 0.00 wili 7390.00 34.00 warm 6651.36 IMESEEMIECEMEM - 619.42 266294.07 2554191.07 60 °59'04.807 "NMICIEM -90.42 0.00 mEsuumem 7596.00 111101EMMMEMEMEEN 6698.14 wasEcEmom 266263.58 EMMEN 60 °59'05.894 "N 151 °18'58.368 "W MEMIIIMEM 0.00 inlMn 2868.15 IIIIl 7866.00 IMEMMEERIM 7048.26 6924.26 WM. - 696.47 266222.07 2554443.72 60 °59'07.280 "N 151 ° 18'59.267 "W 0.68 MECIEEMIZEMMEMEMEME 8179.00 sigim 344.00 MEER 7190.06 MEREEMICEM 266176.90 2554602.68 60 °59'08.836 "N M:13MllraMEEM:1321.1.13M1MEB5EEEMMIMMIIIIIIIIMIMMIMMIIIII 8219.00 ® 343.06 7348.19 IMMEEMIEMEI®" 266171.39 2554622.80 60 °59'09.033 "N 151°19'00.367"W ®IIMOM®EICOMM 8417.00 IllEgMEEEMal 7524.00 7400.00 MESEEMEgartal 266146.39 2554709.99 60 °59'09.886 "N INCEMIEIMEMEIMMIMEHIMEMEMINIMENIE 8606.00 MICEMNEom 7699.13 ®ILEMEM - 802.64 266122.56 2554776.86 60 °59'10.540 "N 151°19'01.420"W MEM - 100.83 ® ®EEEMEM 8700.00 MECEMIIIMM 7786.98 7662.98 IIKEEMINEIREM 266107.98 2554806.97 60°59'10.834"N lagEIMMEIMEEM '®MOZEI 8792.00 20.90 MENIMEMEll 7748.97 MM. - 834.76 266091.60 EMMEN 60 ° 5911.109 "N MEIMIMEEEMMXIMIEEEMIIIEMIMIMIIIIIIIIIIMIIMIIIIIIIIIIIMIIIII 8885.00 MIEDEMMELESE 7960.51 MEM 3493.06 MM. 266074.55 2554861.58 60 ° 5911.365 "N 151 ° 19'02.427 "WWEEMI ®MSEEM 3449.16 8977.00 t i NMEMOINEMEM - 867.68 266059.65 2554883.59 60 °59'11.578 "N 151 °19'02.738"W MEM - 169.07 r r 9073.00 IMEEIEMMENEEMKIDER 8017.86 ®' - 881.06 266046.64 MEMEL 60 °5911.758 "N 151 °19'03.009 "WMajIMiNIEUMMEIM 3498.14 9169.00 MINEMINEMM MIEMOM -892.95 266035.08 2554918.70 60 °59'11.91914 151 °19'03.250 "WNEHMEBEEMMI3EMMEZEMEE 9261.00 MIEEKIMMEEMEMEN 8201.68 MEMECEMIEME 266025.09 2554935.06 60 °59'12.078 "N 151 ° 19'03.460 "W 0.84 -90.10 -0.08 4.00 MEMEMINIE 9352.00 MERMIIIIEMEI 8414.69 8290.69 WEIMIONLIEM 266015.26 112EIMEM 60 °59'12.236 "N 151 °19'03.665 "WMEM - 106.38 MIEMMSECIIMIE1111111.1111111111111 9440.00 ® 320.48 8500.81 8376.81 3596.00 NM= 266004.70 2554965.94 60 °59'12.378 "N 151 °19'03.885 "W MIEMMEMEMEMall -6.08 EZZEMIIII 9481.00 MLIEMIIEEEEI 8540.94 8416.94 - 929.95 265999.15 ®r 60 °59'12.439 14 151 °19'04.001"W -54.88 WEEMMISEEIMBEEMINEMINIMENIE 9532.00 IMMO 306.26 8590.73 8466.73 3609.23 - 938.41 265990.83 2554979.45 60 °59'12.509 14 151 °19'04.172 "W WMEMINEUM® Page 1 of 2 • TVD from MD Inclination Azimuth TVD Fld Ref North East Grid East Grid North Latitude Longitude DLS Too!face Build Rate Turn Rate Vert Sect Comments si [ft] [1 [1 [ft] [ft] [ft] [ft] [ft] [ft] [°/100ft] [°] [° /100ft] [ °/100ft] [ft] 9626.00 18.52 303.74 8681.12 8557.12 3623.88 - 959.49 265970.05 2554994.51 60 °59'12.653 "N 151 °19'04.599 "W 5.71 -6.07 5.66 -2.68 3616.08 9724.00 23.20 302.48 8772.68 8648.68 3642.90 - 988.73 265941.19 2555014.12 60 ° 59'12.840 "N 151 °19'05.192 "W 4.80 -6.69 4.78 -129 3647.21 9813.00 27.92 301.30 8852.94 8728.94 3663.15 - 1021.35 265908.99 2555035.02 60 °59'13.040 "N 151 °19'05.853 "W 5.33 -1.18 5.30 -1.33 3681.09 9909.00 32.95 301.11 8935.69 8811.69 3688.33 - 1062.93 265867.93 2555061.02 60 ° 59'13.287 "N 151 °19'06.696 "W 5.24 -2.24 /5.24 -020 3723.74 10003.00 38.54 300.76 9011.95 8887.95 3716.54 - 1110.02 265821.41 2555090.17 60 °5913.565 "N 151 °19'07.651 "W 5.95 -11.21 5.95 -0.37 3771.77 10098.00 43.41 299.36 9083.66 8959.66 3747.70 - 1163.93 265768.13 2555122.40 60 °5913.872 "N 151 °19'08.744 "W 5.22 5.52 5.13 -1.47 3825.77 10152.00 46.33 299.75 9121.92 8997.92 3766.49 - 1197.07 265735.38 2555141.85 60 °59'14.057 "N 151 °19'09.415 "W 5.43 3.10 5.41 0.72 3858.66 10188.00 50.16 300.02 9145.89 9021.89 3779.87 - 1220.35 265712.38 2555155.70 60 °59'14.189 "N 151 °19'09.887 "W 10.65 2.82 10.64 0.75 3881.91 10247.00 55.71 300.35 9181.44 9057.44 3803.54 - 1261.02 265672.19 2555180.17 60 ° 5914.422 "N 151 °1910.712 "W 9.42 -1.57 9.41 0.56 3922.79 10342.00 58.52 30026 9233.01 9109.01 3843.79 - 1329.89 265604.14 2555221.79 60 °5914.818 "N 151 ° 1912.108 "W 2.96 -7.97 2.96 -0.09 3992.17 10381.00 60.32 299.97 9252.85 9128.85 3860.64 - 1358.94 265575.44 2555239.22 60 °59'14.9841N 151 ° 1912.697 "W 4.66 3.58 4.62 -0.74 4021.31 10420.00 61.16 300.03 9271.92 9147.92 3877.65 - 1388.40 265546.32 2555256.81 60 °59'15.151 "N 151 °19'13.294 "W 2.16 - 108.54 2.15 0.15 4050.81 10444.00 61.02 299.55 9283.52 9159.52 3888.09 - 1406.63 265528.30 2555267.61 60 °59'15.254"N 151 °19'13.664 "W 1.85 44.74 -0.58 -2.00 4068.99 10538.00 61.50 300.09 9328.72 9204.72 3929.07 - 1478.14 265457.64 2555310.02 60 °59'15.658 "N 151 ° 19'15.113 "W 0.72 -59.24 0.51 0.57 4140.32 10632.00 62.38 298.44 9372.94 9248.94 3969.61 - 1550.50 265386.10 2555352.01 60 °59'16.057 "N 151 °19'16.580 "W 1.81 -35.39 0.94 -1.76 4211.70 10657.00 62.58 298.28 9384.49 9260.49 3980.15 - 1570.01 265366.81 2555362.93 60 °5916.160 "N 151 °19'16.976 "W 0.98 -12.88 0.80 -0.64 4230.60 10718.00 63.52 298.04 9412.13 9288.13 4005.81 - 1617.95 265319.40 2555389.54 60 °59'16.413 "N 151 ° 19'17.948 "W 1.58 -16.84 1.54 -0.39 4276.86 10814.00 65.17 297.49 9453.70 9329.70 4046.12 - 1694.52 265243.65 2555431.37 60 °59'16.810 "N 151 °19'19.500 "W 1.79 25.16 1.72 -0.57 4350.14 10908.00 66.42 298.13 9492.24 9368.24 4086.12 - 1770.35 265168.64 2555472.88 60 °59'17.204 "N 151 ° 19'21.037 "W 1.47 -35.37 1.33 0.68 4422.79 11004.00 67.78 297.09 9529.59 9405.59 4127.10 - 1848.71 265091.12 2555515.42 60 °5917.607"N 151 °19'22.626 "W 1.73 -0.81 1.42 -1.08 4497.56 11098.00 68.44 297.08 9564.64 9440.64 4166.81 - 1926.37 265014.27 2555556.68 60 °59'17.998 "N 151 ° 1924.200 "W 0.70 -26.25 0.70 -0.01 4570.88 11194.00 71.33 295.58 9597.65 9473.65 4206.78 - 2007.16 264934.31 2555598.26 60 °59'18.391 "N 151 °19'25.838 "W 3.35 -10.47 3.01 -1.56 4645.99 11287.00 73.51 295.16 9625.74 9501.74 4244.76 - 2087.26 264854.99 2555637.83 60 °59'18.765 "N 151 ° 19'27.462 "W 2.38 -30.86 2.34 -0.45 4719.04 el 11381.00 74.82 294.35 9651.39 9527.39 4282.62 - 2169.38 264773.64 2555677.33 60 °5919.138 "N 151 °19'29.127 "W 1.62 38.61 1.39 -0.86 4793.00 11435.00 75.39 294.82 9665.27 954127 4304.33 - 2216.83 264726.64 2555699.99 60 °5919.352 "N 151 ° 19'30.089 "W 1.35 -10.07 1.06 0.87 4835.59 11490.00 76.32 294.65 9678.71 9554.71 4326.65 - 2265.27 264678.66 2555723.27 60 °59'19.571 "N 151 °19'31.071 "W 1.72 0.00 1.69 -0.31 4879.20 Projected Data - NO SURVEY 11494.00 76.32 294.65 9679.65 9555.65 4328.27 - 2268.81 264675.16 2555724.96 60 °59'19.587 "N 151°19'31.143"W 0.00 0.00 0.00 0.00 4882.37 Last Total Depth - Projected • Page 2 of 2 • 0 Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcbn @chevron.com DATE June 20, 2008 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste #100 Anchorage, AK 99501 DATA TRANSMITTAL 1 '::..'' o:, -,-, li 4 - i , it '';;'' ''- r � �� ,� ak .m, a.: , .. b IH � � n + � GRANITE CASING POINT ST EVALUATION PDF, LAS, 18742 24RD USIT GR/CCL 5" 9- Mar -08 300 -8680 PS -2 1 1 PDS, DLIS DIPOLE SONIC GRANITE IMAGER TOOL POINT ST P &S, UPPER PDF, LAS, 18742 24RD DIPOLE LOG 5" 9- Mar -08 1959 -4596 PS -2 1 1 PDS, DLIS GRANITE TCP POINT ST CORRELATION 18742 24RD GR -CCL 5" 26- May -08 10000 -10480 1 1 1 LAS, PDS GRANITE TCP POINT ST CORRELATION 18742 24RD GR -CCL 2" 29- May -08 10000 -10350 1 1 1 LAS, PDS A;11 -110 'Gs /6 /&571 �51J Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. 7 Received By: / .) � / r Date: Chevron • Castro Chevron North A rica Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcbn @chevron.com DATE June 20, 2008 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL ot, z V \ T 4 '1 t , ..' t.. ..0 p sa 3., : Yd .. a e ��. .. Z ... ,_.1 ;1 , , Ii> ', MULTIPLE PROPAGATION PDF, RESISTIVITY ASCII, LAS, GRANITE COMP NEUTRON CGM, POINT ST POROSITY COMP META, 18742 24RD BULK DENS -GR 2" 17- May -08 8168 -11474 2 -13 1 1 DLIS PDF, DENSITY IMAGE ASCII, LAS, GRANITE COMP NEUT CGM, POINT ST POROSITY COMP META, 18742 24RD BULK DENS -GR 2" 17- May -08 8168 -11474 2 -13 1 1 DLIS PDF, ASCII, LAS, GRANITE ONTRACK GR CGM, POINT ST AND LITHOTRACK 10100 - 10670; META, 18742 24RD DENSITY IMAGES 2" 12- May -08 10710 -11440 1 1 1 DLIS ( ) ‘ - - 1 1 - 0 Cfs > /( Please acknowledge receir by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: (. Date: 1 • H fA\ .(-) 7' A U (0 - rA \-\ i U tit, pIp , i n , a i 3 SARAH PAUN, GOVERNOR i � I._.:, Li� a t ) L1 ,f. ALASKA OIL AND GAS i j 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION J ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy Brandonburg UNOCAL PO Box 196247 Anchorage, AK 99519 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Point ST 18742 24RD Sundry Number: 308 -211 Dear Mr. Brandonburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of June, 2008 Encl. I"it.C;,V C, Lor STATE OF ALASKA i o, 0� 1 ALAS OIL A ND GAS CONSERVATION COMM155ION X 4'�1`1IUN � �' `,, ;V� APPLICATION FOR SUNDRY APPROVAL ,Gobs, r�l� S10fl qq �sF,a R i 20 AAC 25.280 / 4'3r8;g£? 1. Type of Request: Abandon El Suspend ❑ Operational shutdown ❑ Perforate CI • Waiver u Other ❑ Alter casing❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Change approved program❑ Pull Tubing 0 • 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 0 , Exploratory ❑ 2.07-4e1-- 7.07 /70 1,. as -60 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P.O. Box 196247, Anchorage AK 99519 50- 733 - 20285 -01 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El Granite Point St 18742 24RD (Anna -24RD) 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ,,�� / , I ,/ �•6 Aldo/ // ADL- 018742 ' 124' MSL -RKB Granite Point Field Nt� /e. 12. PRESENT WELL CONDITION SUMMARY / /0 6 ' /0 Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11494 9680 11449 9669 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 609 20" 609 609 Surface 2000 13 -3/8" 2000 1945 3450 1950 Intermediate 8219 9 -5/8" 8219 7348 5750 3090 Production 2710 7" 10704 9406 11220 8510 Liner 936 4 -1/2" 11492 9679 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10711- 11422' 9409' -9662' 2 -7/8" x 2 -3/8" dual L -80 11,422' Packers and SSSV Type: NA Packers and SSSV MD (ft): NA 13. Attachments: Description Summary of Proposal El 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 Service ❑ 15. Estimated Date for 6/24/2008 16. Well Status after proposed work: Commencing Operations: Oil El Gas ❑ Plugged ❑ Abandoned ❑ 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact v 0 e.. . -- cif Printed Name . / ,�z15 C ;>- ,, Title Signature '---, Date t- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30E-' 1 l Plug Integrity ❑ BOP Test yk Mechanical Integrity Test ❑ Location Clearance ❑ Other: f ' e c? ti � -• Subsequent Form Required: `" A . cc s..), cvsC '� A,.., �(�L\ wL \ "�� v 1 c �' ,` ,-27 APPROVED BY '7 Approved by p COMMISSIONER THE COMMISSION Date: z� Form 10 -403 Revised 06/2006 BFL JUN 2 3 2008 Submit in Chevron • Sanite Point Field Anna 24RD Pull completion / Re- perforate Revision #0 6/17/08 OBJECTIVE: • Pull existing Kobe cavity dual completion. Reperforate existing zones. Re -run Kobe cavity dual completion. PROCEDURE SUMMARY: • Skid Rig #428 over Anna 24RD wellslot. • Circulate out pump. RU slickline. Pull standing valve and gauges. • Kill well w/ base oil. • Set BPV in LS and SS tubing. • ND Tree. NU BOP and Test to 250/3000 psi. • PU dual tubing hanger and pull completion to Kobe cavity. • Lay down Kobe cavity and TCP guns. • CONTINGENCY: If TCP guns are stuck, cut tubing above and fish guns. • TIH w/ 4 -1/2" cleanout BHA. • Cleanout 4 -1/2" to PBTD. POOH. • PU new TCP guns and RIH w/ packer on drillpipe. • Set TCP guns on depth. Existing TCP perforations are between 10,711'- 11,422' MD. • Reperforate all existing zones underbalanced (no new zones added). • POOH w/ TCP and packer. • CONTINGENCY: Make possible 4 -1/2" cleanout run if sand/fill is suspected. • RIH w/ original dual completion and new tubing tail. • Land tubing hanger. Drop standing valve and pump into LS tubing. • Set BPV in LS and SS tubing. ND BOP. NU Tree. Pull BPVs. Set TWCs. Test Tree. Pull TWCs. • RU flowlines. Circ power oil. • RD and prep to skid rig. An -24RD Recomplete Objective and Procedure Summary.doc REVISED BY: STP 6/17/08 Chevron • Anna Platform An -24RD %O. Actual Completion 6 -4 -08 733 - 20285 - CASING AND TUBING DETAIL API # 50- RKB to T 73 Head = 60' SIZE WT GRADE CONN ID TOP BTM. 20" 94# K -55 - 19.124" Surface 609' 1 � A 13 -3/8" 54.5 & 68# K -55 Buttress 12.415" Surface 2,000' 9 -5/8" 40 & 43.5# N -80 & S -95 Buttress 8.755" Surface 8,219' 7" Liner 29# P -110 Hydril 563 6.184" 7,994' 10,704' 4.5" Liner 12.6# L -80 Hydril 563 3.958" 10,556' 11,492' Tubing Long String L S• 2 -7/8 6.4# L -80 IBT (SCC) 2.441" Surface 11,422' Short String 2 -7/8 6.4# L -80 IBT (SCC) 2.441" Surface 7,830' 2 -3/8" 4.6# L -80 IBT (SCC) 1.995" 7,830' 10,386' 2 I I B JEWELRY DETAIL I I C NO. Depth ID OD Item D 60' Tubing Hanger, Cameron, 3 -1/2" X 3 1/2 11" DCB 1 61' 2.441 2.875 X -over 3 -1/2" EUE x 2 -7/8" IBT PxP 3 2 10,160' RA marker in 2 7/8" tubing 3 10,387' 2.250 5.800 Oilwell Hydraulics Type "A" Single Parallel Cavity w/ Stainless Steel Bands 4 4 10,397' 2.441 2.875 XO 2 7/8" IBT x EUE 5 R 5 10,533' 2.188 2.875 2 7/8" R nipple { 6 10,542' 2.441 2.875 3 joints 2 -7/8" Buttress Tubing 6 7 7 10,660' 1.995 2.700 X -over 2 3/8 EUE x 2 7/8 EUE 000 8 8 10,661' 1.995 2.375 2 3/8" Ported sub (8) 1" holes Z 9 9 10,662' 1.995 2.375 l joint 2 3/8" EUE tubing 10 10 10,692' 1.560 3.063 2 3 /4 " mechanical firing head w/ 1.56 no go 11 11 10,697' 2.750 2 %" safety Spacer -= 12 10,710' 2.750 2 3 /4' Vann guns 6 spf 60 deg. HMX 15GR 12 i 13 11,422' 2.750 2 3 /4" Bull plug ' _= Short String • 11 I A 61' X - over 3 - 1/2" EUE x 2 - 7/8" IBT PxP B 7,829' 1.995 2.875 X -over, 2 -7/8" IBT Box x 2 -3/8" IBT Pin • ' � C 10,385' 1.625 2.600 X -over, 2 3/8" SCC.Box x " 1 '/2" IJ Pin • 1.. D 10,386' 1.625 1.900 Integral pup joint 1 'h" IJ - PERFORATION HISTORY = Interval A rim ! ! ° , Zone Top Btm Amt spf Cornrents • C-7E 10,711' 10,731' 20' 6 23/4" guns, 72 phasing C-7D 10,784' 10,805 21' 6 23/4" guns, 72 phasing C-7C 10,817 10,856 42' 6 23/4" guns, 72 phasing r C-7B 10,903' 10,934' 31' 6 23/4" guns, 72 phasing C-7A 10,944' 10,990' 46' 6 2 3/4" guns, 72 phasing CAD 11,030 11,038 8 6 234" gins, 72 phasing CSC 11,075 11,086' 7 6 23/4" guns, 72 phasing - 13 G5B 11,291' 11,355 64' 6 23/4" guns, 72 phasing C-5A 11,376 11,422 43' 6 23/4" guns, 72 phasing Z j� PBTD = 11,449' MD / 9,669' TVD \ TD = 11,494' MD / 9,680' TVD AN -24RD WBD Actual 6-4-08.doc DRAWN BY: STP 6/17/08 Chevron • •knna Platform An -24RD ft. PROPOSED RECOMPLETION API # 50 - 733 - 20285 - CASING AND TUBING DETAIL RKB to TBG Head = 60' SIZE WT GRADE CONN ID TOP BTM. 20" 94# K -55 - 19.124" Surface 609' 1r A 13 -3/8" 54.5 & 68# K -55 Buttress 12.415" Surface 2,000' 9 -5/8" 40 & 43.5# N -80 & S -95 Buttress 8.755" Surface 8,219' 7" Liner 29# P -110 Hydril 563 6.184" 7,994' 10,704' 4.5" Liner 12.6# L -80 Hydril 563 3.958" 10,556' 11,492' Tubing Long String L S 2 -7/8 6.4# L -80 IBT (SCC) 2.441" Surface 10,574' 2 -3/8" 4.6# L -80 IBT (SCC) 1.995" 10,574' 11,424' Short String r 2 -7/8 6.4# L -80 IBT (SCC) 2.441" Surface 7,830' 2 I I B X L 2 -3/8" 4.6# L -80 IBT (SCC) 1.995" 7,830' 10,386' • • I j C JEWELRY DETAIL D NO. Depth ID OD Item similm fir • 60' Tubing Hanger, Cameron, 3 -1/2" X 3 1/2 11" DCB 3 ` l I 1 61' 2.441 2.875 X -over 3 -1/2" EUE x 2 -7/8" IBT PxP i t r • 2 10,160' - - RA marker in 2 7/8" tubing X04 4 3 10,387' 2.250 5.800 Oilwell Hydraulics Type "A" Single Parallel Cavity w/ 5 Stainless Steel Bands R 6 4 10,397' 2.441 2.875 XO 2 7/8" IBT x EUE 7 - 5 10,398' 2.441 2.875 4 joints 2 7/8" Buttress Tubing \XO" 8 6 10,533' 2.188 2.875 2 7/8" R nipple • 9 7 10,542' 2.441 2.875 1 joint 2 -7/8" Buttress Tubing app 10 8 10,574' 1.995 2.875 X -over 2 3/8 Buttress x 2 7/8 Buttress 1 1 9 10,586' 1.995 2.375 1 joint 2 3/8" Buttress Tubing 10 10,622' 1.995 2.375 2 3/8" CMU Sliding Sleeve = 11 10,628' 1.995 2.375 25 joints 2 3/8" Buttress Tubing _ Short String A 61' X - over 3 - 1/2" EUE x 2 - 7/8" IBT PxP B 7,829' 1.995 2.875 X -over, 2 -7/8" IBT Box x 2 -3/8" IBT Pin C 10,385' 1.625 2.600 X -over, 2 3/8" SCC.Box x " 1 'h" IJ Pin D 10,386' 1.625 1.900 Integral pup joint 1 1/2" IJ 1 I I i T I _ PERFORATION HISTORY ' `= Interval Accum I i -_ Zone Top Btm Arrt spf Comments I t I C-7E 10,711' 10,731' 20 6 Re- perforate vv 2 314" 72° TCP guns ' I G7D 10,784' 10,805 21' 6 Re-perforate vi 2 314" 72° TCP guns C-7C 10,817 10,859 42 6 Re-perforate vd 2 314" 72° TCP guns t ; - C-7B 10,903' 10,934' 31' 6 Re- perforate W 2 2 314" 72° TCP gars _ - C - 7 A 10,944' 10,990' 46 6 Re- perforate id 2 3/4" 72° TCP guns C-613 11,030 11,036 8' 6 Re- perforate vd 2 314' 72' TCP gars CSC 11,075 11,086 7 6 Re- perforate vd 2 314 " 72° TCP guns C-5B 11,291' 11,355 64' 6 Re-perforate vd 2 314" 72° TCP guns C-5A 11,380' 11,423' 43' 6 Re- perforate Al 2 3/4" 72° TCP gun /� PBTD = 11,449' MD / 9,669' TVD / f TD = 11,494' MD / 9,680' TVD AN -24RD WBD Proposed.doc DRAWN BY: STP 6/17/08 An -24RD operations summary Page 1 of 1 • • Maunder, Thomas E (DOA) From: Flynn, Tim [ASRC] [Tim. Flynn ©chevron.com] Sent: Thursday, June 19, 2008 3:51 PM To: Maunder, Thomas E (DOA) Cc: PORHOLA, STAN T; Newell, Jack R [FEP] Subject: An -24RD operations summary Tom v The following is an operations summary for activities on Granite Point State 18742 24RD after perforating the well. 5/29/08 — Pert well bring well onto production (Average 59 bbls /day) 5/29/08 to 6/06/08 — Well testing operations (numerous pump and standing valve changes) 6/06/08 — RIH with pressure gauges, Shut in well to record downhole pressures over next 3 weeks 6/6/08 — Move rig over to An -37 Let me know if you need further information. Thank you Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 -3322 907- 263 -7824 phone 907 -317 -5504 cell 6/19/2008 Granite Point Field - Anna 24 (Add Perforations) Page 1 of 2 I I Maunder, Thomas E (DOA) From: PORHOLA, STAN T [stan.porhola @chevron.com] Sent: Wednesday, June 11, 2008 11:04 AM To: Maunder, Thomas E (DOA) Subject: RE: Granite Point Field - Anna 24RD (207 -170) (Add Perforations) Will do. Thanks, Tom. Stan Porhola Drilling Engineer MidContinentlAlaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501 -3322 Tel 907 263 7640 Fax 907 263 7884 CeII 907 229 1769 stan.porhola@chevron.com Mail Confidential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263 -7640. From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, June 11, 2008 10:47 AM To: PORHOLA, STAN T Subject: RE: Granite Point Field - Anna 24RD (207 -170) (Add Perforations) Stan, You are correct; our records do not show that a 407 has been received. It seems that this work is still part of the initial completion. If you would, please provide a summary of the perforations and tests accomplished to date and also identify the additional work to be accomplished. Tom Maunder, PE AOGCC From: PORHOLA, STAN T [ mailto :stan.porhola @chevron.com] Sent: Wednesday, June 11, 2008 10:12 AM To: Maunder, Thomas E (DOA) Subject: Granite Point Field - Anna 24RD (Add Perforations) Tom, 6/18/2008 Granite Point Field - Anna 24$) (Add Perforations) • Page 2 of 2 I'm filling in for Tim Flynn while he's out on vacation. We've finished the Anna 24RD sidetrack and put the well on test. The rig was skidded over Anna 37 starting on June 4th. The production has been low and we would like to pull the dual Kobe cavity completion and perforate additional zones. I'm fairly certain that Mr. Flynn had not sent in a 10 -407. What would be the best way to handle pulling the dual Kobe cavity completion and perforate new zones? Stan Porhola Drilling Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501 -3322 Tel 907 263 7640 Fax 907 263 7884 CeII 907 229 1769 stan. porhola @chevron.com Mail Con f dential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263 -7640. 6/18/2008 ANNA 2411) Kam rta cement • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, May 20, 2008 9:38 PM To: Nienhaus, Doug R Cc: Flynn, Tim (ASRC] Subject: RE: ANNA 24RD Ram Placement Doug, You have accurately described our conversation. Since the casing is tested and not perforated, it is acceptable to not install the 2 -3/8 x 2 -7/8 rams in the lower cavity. Good luck with the operation. Tom Maunder, PE AOGCC From: Nienhaus, Doug R [mailto:nienhausd @chevron.com] Sent: Tue 5/20/2008 4:52 PM To: Maunder, Thomas E (DOA) Cc: Flynn, Tim [ASRC] Subject: ANNA 24RD Ram Placement Tom We have just completed running 4 1/2" liner on Anna 24RDPB2. We plan on moving into the completion phase which is a dual 2 7/8" string. The bottom portion of the completion is dual 2 7/8" x 2 3/8 ". Which is roughly 2200' in length. We plan on testing the well bore casing to 1470 psi with 9.6 ppg Mud, which was tested to 2000 psi with 8.5 ppg salt water before milling the window. The Dual completion will be run into an un perforated well bore, which will be perforated latter with tree on. We plan to Run our dual 2 7/8" rams in the top Cavity of the double gate. And choose not to install our dual 2 7/8" x 2 3/8" in the single gate. But rather Have a 2 7/8" x 2 3/8" cross over contingency joint in the V- Door if needed for shut in while running the dual 2 7/8" x 2 3/8" portion of the completion. 1 Hope this defines our plan forward as per our phone conversation Many Thanks Doug R Nienhaus Drilling Superintendent MidContinent / Alaska Chevron North America Exploration & Production 909 W. 9th Ave Anchorage,Alaska 99501 Office 907 - 263 -7840 Cell 907 - 223 -6947 nienhausd@chevron.com 5/21/2008 AN -24RD liner program chan e Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, May 07, 2008 8:35 AM To: 'Flynn, Tim [ASRC]' Cc: Nienhaus, Doug R; Brandenburg, Tim C Subject: RE: 18742 -24RD (207 -170) liner program change Tim, This is not an issue. When forced to set 7" high, 4 -1/2" is the default. I will place a copy of this message in the file. Please note the well name. Tom Maunder, PE AOGCC From: Flynn, Tim [ASRC] [mailto:Tim.Flynn @chevron.com] Sent: Wednesday, May 07, 2008 8:03 AM To: Maunder, Thomas E (DOA) Cc: Nienhaus, Doug R; Brandenburg, Tim C Subject: AN -24RD liner program change Tom I wanted to follow up with what we spoke of yesterday in regards to An -24RD plan forward. The well was planned to have 8.5" hole drilled to 11800'MD with 7" liner fully cemented up to 7800'MD. Due to an expected fault and the time the hole has been open, we have chosen to set 7" casing early at 10.700'MD. The directional plan will remain the same but we will drill 6" hole to TD, run in w/ 4.5" liner and fully cement with 150' of liner lap up inside the 7 ". Please inform if more information is required. Thank you Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 -3322 907 - 263 -7824 phone 907 - 317 -5504 cell 5/7/2008 AN -24RD BOP test • Page 1 L Regg, James B (DOA) Cf 2M 0q, From: Regg, James B (DOA) l 2 U Ca Sent: Thursday, April 24, 2008 4:50 PM To: 'Flynn, Tim [ASRC]'; Maunder, Thomas E (DOA) Cc: Lawrence, Steve C; Leslie, Mike; Buster, Larry W; Brandenburg, Tim C; Hammons, Darrell Subject: RE: AN -24RD BOP test I spoke to Steve Lawrence about this earlier today and approved the extension until Saturday. The Commission intends to witness your BOPE test. An inspector will be contacting the platform to coordinate, and he will be able to address any further delay in testing should that become necessary. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907 - 793 -1236 fax: 907 - 276 -7542 From: Flynn, Tim [ASRC] [mailto:Tim.Flynn @chevron.com] Sent: Thursday, April 24, 2008 4:45 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Lawrence, Steve C; Leslie, Mike; Buster, Larry W; Brandenburg, Tim C; Hammons, Darrell Subject: AN -24RD BOP test Tom,Jim We are currently temporarily detained on AN -24RD at 10,345' MD. We are due for our weekly BOP test on Friday morning 4/25/08. The following is our plan going forward to minimize the time for the fish being stuck: RIH with slickline and determine free point RIH w/ string shot and backoff below jars POOH w/ Drillpipe RIH w/ screw in sub and attempt to jar fish If successful we will POOH and test BOP's. If unsuccessful retrieving fish, Backoff, POOH and test BOP's This plan forward will require an extension in our 1 week BOP test schedule. Please respond if this plan is acceptable. P P P Thank you Tim Flynn 4/24/2008 AN -24RD BOP test Page 1 of 2 • • Maunder, Thomas E (DOA) From: Flynn, Tim [ASRC] [Tim.Flynn(rchevron.com] Sent: Thursday, April 24, 2008 5:02 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Lawrence, Steve C; Leslie, Mike; Buster, Larry W; Brandenburg, Tim C; Hammons, Darrell Subject: RE: AN -24RD BOP test Thank You r) _ I will give you daily updates to keep you updated on our progress. Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 -3322 907 -263 -7824 phone 907 - 317 -5504 cell From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, April 24, 2008 4:50 PM To: Flynn, Tim [ASRC]; Maunder, Thomas E (DOA) Cc: Lawrence, Steve C; Leslie, Mike; Buster, Larry W; Brandenburg, Tim C; Hammons, Darrell Subject: RE: AN -24RD BOP test I spoke to Steve Lawrence about this earlier today and approved the extension until Saturday. The Commission intends to witness your BOPE test. An inspector will be contacting the platform to coordinate, and he will be able to address any further delay in testing should that become necessary. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907 - 793 -1236 fax: 907- 276 -7542 From: Flynn, Tim [ASRC] [mailto:Tim.Flynn @chevron.com] Sent: Thursday, April 24, 2008 4:45 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Lawrence, Steve C; Leslie, Mike; Buster, Larry W; Brandenburg, Tim C; Hammons, Darrell Subject: AN -24RD BOP test Tom,Jim We are currently temporarily detained on AN -24RD at 10,345' MD. 4/24/2008 AN -24RD BOP test Page 2 of 2 We are due for our weekly BOP test on Friday moming 4/25/08. The following is our plan going forward to minimize the time for the fish being stuck: RIH with slickline and determine free point RIH w/ string shot and backoff below jars POOH w/ Drillpipe RIH w/ screw in sub and attempt to jar fish If successful we will POOH and test BOP's. If unsuccessful retrieving fish, Backoff, POOH and test BOP's This plan forward will require an extension in our 1 week BOP test schedule. Please respond if this plan is acceptable. Thank you Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 -3322 907- 263 -7824 phone 907 - 317 -5504 cell 4/24/2008 0 IIP L I k w [ C§ 6 i _,,,,\ 6 L i r SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION f ANCHORAGE, ALASKA 99501 -3539 t PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 Re: Granite Point Field, Middle Kenai Oil Pool, 18742 -24RD Sundry Number: 308 -137 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. the When providing notice for a representative of th Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, de Daniel T. Seamount, Jr. Chair DATED this Z sday of April, 2008 Encl. ■ I 4•U� STATE OF ALASKA 'i. APR 1 4 2008 � 1 ALA OIL AND GAS CONSERVATION COM 0ION APPLICATION FOR SUNDRY APPRO11664a8i1 & Gas Cons. Commission 20 AAC 25.280 Anchor e 1. Type of Request: Abandon Suspend ❑ Operational shutdown❑ Perforate ❑ Waiver LI 9ther Alter casing❑ Repair well ❑ Plug Perforations❑ Stimulate El Time Extension 0 "7/ 0 -- u sk Change approved progran❑ Pull Tubing❑ Perforate New PoolO Re -enter Suspended Well ❑ //- " �� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: /� Union Oil Company of California Development E1 . Exploratory El 24:7-41c) / n,... 3. Address: Stratigraphic ❑ Service ❑ 6. API NumberD P.O. Box 196247, Anchorage AK 99519 50- 733 - 202850 t.t'j•d$ 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: Rd Ab4,14,0V Spacing Exception Required? Yes ❑ No ri Granite Point St 18742 24 (Anna - 24RD) 9. Property Designation: 10. KB Elevation ft : 11. Field/Pool(s): P Y 9 O � �/ �A i ADL- 018742 124' MSL -RKB Granite Point F ield / K6,1,,, C ,6 L a y.�/.v$ 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): Casing Length Size MD TVD Burst Collapse Structural Conductor 609 20" 609 609 Surface 2000 13 -3/8" 2000 1945 3450 1950 Intermediate 8219 9 -5/8" 8219 7348 5750 3090 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NA NA NA NA NA Packers and SSSV Type: NA Packers and SSSV MD (ft): NA 13. Attachments: Description Summary of Proposal ❑ 14. Well Class after proposed work: Detailed Operations Program ig BOP Sketch 0 Exploratory ❑ Development 0 • Service ❑ 15. Estimated Date for 4/12/2008 16. Well Status after proposed work: Commencing Operations: Oil ig • Gas ❑ Plugged ❑ Abandoned 0 17. Verbal Approval: Date 4/11/2008 WAG ❑ GINJ ❑ WINJ ❑ WDSPL Commission Representative: Cathy Foerster i A1 OA 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tim Flynn 907 317 5504 Printed Name Timothy C. Brandenbur. Title Drilling Manager Signature / �ho Date Z_ J/ • COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30E 1 S7 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required:, f\(,� � .,, v, e LAC cV �� „ AQ p APPROVED BY Approved by. ,� /�% � COMMISSIONER THE COMMIS ION Date: 1-//V RRJA/) tflalaN 5p-L. . 1.(4/..air Form 10 -403 Revised 06/20 R 1 G 1 N A L Submit in D - • Chevron Anna Platform Well AN -24RD IWO &A Sidetrack Program AN -24RD Well Operations Summary Anna AN -24RD was sidetracked off a Whipstock at 8219' MD. 4 bit runs were completed to a depth of 10, 275'MD. Bit run #5 drilled to a total depth of 10,418' MD where the BHA become stuck and unable to move. Jarring commenced for 12 hours with no movement of the BHA. A free point was run on slickline and string shot was used to back off a tool joint leaving 100' of BHA in the hole. A clean out trip too the top of the fish was done due to the large amounts of coal being circulated to surface. One fishing attempt with a screw in sub was attempted but due to poor hole conditions, the top of fish was never found. Indication were that the hole could have been as large as 13" OD. The stuck BHA consisted of a bit, rotary steerable assembly, MWD components and 1 non -mag drill collar. A radioactive source was within the MWD assembly. Top of the BHA after backing off was at 10,318'MD. Attached to this report is a BHA schematic used on Bit run #5. The plan will be to place (2) 500'MD 17.0 ppg cement plugs over the top of fish. Plug # 1: F/ 10318'MD up to 9800'MD Plug # 2: F/ 9800'MD up to 9300'MD Once the top plug has set a minimum of 12 hours, the well will be sidetracked at approximately 9380' MD. Well Control Summary Hole Section Equipment Test Pressure (psi) 13 5/8" 5M Annular " 13 5/8" 5M Double Gate, 8'/2" 13 5/8" 5M Mud Cross, 13 5/8" 5M Single gate, 250/3500 3' /s" 5M Choke Manifold* * Schematics of the well control equipment are attached for reference 4/15/2008 Page 1 of 1 • • DRILL AND COMPLETE PROCEDURE SUMMARY AN -24RD 4.14.* Rig Operations: (Sidetrack An -24RD) 1. P/U and RIH 21 jts of 2 7/8" tubing 2. Circulate well clean 3. Pump and spot (2) 17.0 ppg balance plugs Plug #1: F/ 10300'MD to 9800'MD (TOF 10,318' MD) Y3 . Q • 4l� S� ' °°`- Plug #2: F/ 9800'MD to 9300' MD (KOP 9380'MD) sic C r' ® 'lS`Ac = 43 b5 <S 4. POOH Wait on cement a minimum of 12 hours - Qx\` Z-29711 Lt(tK 5. M/U and RIH w/ kickoff BHA, Sidetrack off cement plug 6. Directionally drill ahead to TD w/ 8.5" directional assembly. Wiper trips will be performed as hole dictates. 7. RIH for clean out run to TD and POOH. 8. Run and cement the 7 ", 29# P -110 production casing back inside the 9 -5/8" cas ng. Displace cement w/ diesel. 9. After setting the liner top packer circulate well clean. 10. Clean out 7" liner with scraper, swap well over to base oil. 11. Test casing to 2000 psi 12. Trip in with 2 7/8" by 2 3/8" dual completion assembly with Kobe Cavity pump with 400' of pert guns. 13. Correlation to place guns on depth. 14. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 15. Circulate pump out, fish standing valve and drop bar to fire pert guns. 16. Trip standing valve on seat, circulate pump in place, flow well. 17. Rig down and move off. 1'' s 0 Well Name: An -24RD ‘hevron Field: Granit Point Field I I Surface Location: 'Conductor: 30 ", 194 ppf, K -55 to 256' Anna Platform RF: 59' Seal level base flange: 65' Anna RKB: 124' d X:266856.72 Y: 2551352.29 Sec. 12, T1ON, R12W, SM A p Surface Casing: 20 ", 94 ppf, K -55, BTC to 605' I Cement to surface I I Intermediate Casino pirectional Data 13 3/8 ", 54868 ppf, K -55, BTC to 2000' Good cement 8209' MD KOP 6400' MD Drop to 17deg inc 10000' MD Build to 70 degrees Intermediate Casing 11800' MD TD of well 9 5/8 ", 43 &40 ppf, S- 95 &N -80, BTC to 9181' Fair cement to 7300' MD P&A program i 8880' Set cement retainer Open hole interval: 8880' to 8540' diplacement of cement 8219'MD - 10418'M D Bring cement 150' over 7" Liner lap ' Pressure test to 2000 psi ,a; a w 4' "` 1 IPBTD = 8500' MD - e n 'Proposed KOP: 9380' MD $3 .I Plug #2: I � ? ►_ ,, a 9800 "M D - 9300' M D x Plug #1: y 10318 "MD - 9800'MD / ITOF: 10,318' MD I — 3#� 4 r 4( KI�G�e �UG.[i'GG, t TD: 10418'M D /� // OQ TD = 10400' MD ;11 , Extrapolated Inc: 37.5 deg j TO TVD: 9220' TVD ' - 1 • • i ■ TDMD = 11800' MD TVD = 9963' MD I I i WBD AN -24RD Proposed vl.xls October 28, 2007 Drawn by: TSF I ' 0 40 1500 1800 1700 1800 1900 2000 2100 2200 2300 2400 2500 2800 2700 2800 2900 3000 3100 3200 3300 3400 • 8 8 .. 850 i 8 87 i I ,80 $ � C -3 8 r C-4 C - 5 8 R 9300 94 4 M IOW 9800 C -7 ✓ 97 0/ • 98 21 , ✓ 99 C -8 , s AN -24RD new ,..; t . '''"--,r2.. 1 ,0200 03.. 104, , 103.+ b ti W 1, ,. 10 AN -24RD actu 108. , TD10418'MD s 1 \ \ 108.. 1 10•.. { 8 11... g s- \ 111 .,• s 112k. 113... \ AN-24RD Orig to t1 ir A: to i Aro ... g 1 o s $- 1 1500 1800 1700 1800 1900 2000 2100 2200 2300 2400 2500 2800 2700 2800 2900 3000 3100 3200 3300 3400 • • 1 1 1 Chevron I Will Chevron BAKER Location: Cook Inlet, Alaska (Offshore) Slot: slot #2 -3 ''// HUGHES Field: Granite Point Field Well: AN- 24RDj) 1(.06 INTEQ Facility: ANNA Platform Wellbore: AN -24RD rt•(1k. Plot reference wellpath is AN -24RD Version #18 True vertical depths are referenced to Anna Rig #428 (RKB) Grid System: NAD27 / TM Alaska State Plane, Zone 4 (504), US feet Measured depths are referenced to Anna Rig #428 (RKB) North Reference: True north Anna Rig #428 (RKB) to mean sea level: 124 feet Scale: True distance mean sea level to Mud line (Facility: ANNA Platform): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: ulricard on 4/12/2008 • Well Profile Data 1 Design Comment MD (ft) Inc ( °) Az ( °) TVD (ft) Local N (ft) Local E (ft) DL$ ( °/100ft) VS (ft) Tie On 9380.00 12.028 324.824 _ 8442.08 3586.31 - 916.74 10.75 0.00 End of 3D Arc 10141.32 41.558 297.838 9116.00 3773.73 - 1192.60 14.10 307.37 End of Tangent 10427.65 41.558 297.838 9330.25 3862.43 - 1360.55 10.00 489.51 End of 3D Arc 11628.57 77.687 259.604 9944.00 3947.62 - 2348.36 14.00 1474.74 End of Tangent 11828.00 77.687 259.604 9986.53 3912.46 - 2540.00 0.00 1655.70 S .7S0 Easting (ft) -3000 -2625 -2250 -1875 -1500 -1125 -750 -875 0 375 Z 4500 N D An24Rd Target Top C.5A 24- Oct -2007 1 4125 F. ill SD: AN-4 O ` I .1� p v , An -24R." Contingengi Target 10 -Apn1 -2008 4.14 • 2 °�c 3750 cca 1 1 3375 7, 8000 2 A Tie On 11 Z A 10 1100 0 ,,_cc.' ec< c 9000 0\ o <S a \ c acg 10 FPn -2p0a 0,- o\ o cn 4 e ro ARd � y a o 0 NI' 'Z IQ c Imo Zq . Oot -2p0 AN 2 4RD � � ` A Pn2�Ra S ar9et C 5P ' • -2000 -1000 0 1000 2000 i Vertical Section (ft) Scale Ind,.1000ft Azimuth 281.38' with reference 3586.31 N, - 916.74 E ' '.. • 4 Chevron adayp-ii. REM Planned W?path Report BAKER AN-24RD Version#18 HUGHES Pa e of 4 INTEQ " REFERENCE WELLPATH IDENTIFICATION I Operator Chevron , Slot islot #2-3 Area Cook Inlet, Alaska (Offshore) Well IAN-24RD_ I Field Granite Point Field ,Wellbore iAN-24RD f ( 4,.. 4116"- I Facility ANNA Platform 'Sidetrack from AN-24RD at 9369.00 MD REPORT SETUP IN FORMATMN Projection System NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet 1 Software System WellA hitect® 2.0 North Reference True lUser i Ulrica d Scale 0.999962 Report Generated 4/12/2108 at 2:13:39 PM Convergence at slot 1.15° West ,Database/Source file WA , nchorage/AN-24RD2.xml WELLPATH LOCATION 1 _ ,-, Local coordinates , Grid coordinates Geog . hhic coordinates ...-.. North[ft] East[ft] Easting[USft] ' Northing[USft] Latitude ' Longitude -1--- _ Slot Location -789.01 -594.01 . 266856.72 2551352.29 60 151°1845.150"W Facility Reference Pt 26746635 2552129/4 II I II 60°5844.738 I 151°18 33.113 W Field Reference Pt 267571.89 i 2557407.98 60°5936.731" 151°1433.112"W i WELLPATH DATUM Anna Rig #428 (RKB) to Facility Vertical 124.00ft : Calculation method Minimum curvature , I Datum — — - Horizontal Reference Pt t Slot iAnna Rig #428 (RKB) tomeansea level 1 124.00ft Vertical Reference Pt Anna Rig #428 (RKB) ;Facility Vertical Datum to Mud Line (Faci ity)!0.00ft MD Reference Pt Anna Rig #428 (RKB) ISection Origin N 3586.31, E -916.74 ftl . 1 Field Vertical Reference ,mean sea level !Section Azimuth ,281.36° --- , -- ■ 1 1 • Chevron MI Planned WV.path Report BAKER AN-24RD Version#18 HUGHES Page 2 of 4 A‘k- INTEHQ 1 REF'ERENC'E NN ELITA"I'll IDENTIFICA LION ' !Operator Chevron --1 1 - lot slot #2-3 . / =Area _ ;Cook Inlet, Alaska (Offshore) Well AN-24RD We XA A. o tb Field Granite Point Field 1llbore AN-24RD - - - Facility 'ANNA Platform !Sidetrack from AN-24RD at 9369.00 MD .......i WELI.PATH DATA (73 stations) t = interpolated/extrapolated station 1 MD Inclination Azimuth TVD TVD from Vert Sect North East Grid East , Grid North , DLS i [ft] , [°1 11 ' [ft] FM Vert Ref i [ft] [ft] , [ft] fsry ft] ' [sry ft] 1°/100ft] .., _ ■ _ _ __ [ft] ' 1 --- 0.00t 6.000 241.000 (17.( -124.00 -1605.24 0.00 0.00 1 266856. g 2551352.29 0.00 E 19.00 L 0.000 241.000 19.00 - 105.00 - 1605.24 0.00 0.00 266856. 9 2551352.29 0.00 540.00 ' 1.080 241.000 539.97 1 415.97 - 1601.49 - 2.38 - 4.29 i 266852. i 2551350.00 0.21 r ----- 969.00 ' 2.0001 279.000 968.82 ' 844.82 -1590.93 -3.17 -15.221 266841. , 2551349.43 0.31 .::-:-.:'`' -'''' ''''' ' ''''' 7 •' _....4,2,.., :...„.. ..4___ 1.....,_:' 1_ ''''' 7i-fAA iiiit,AINCV:«-:,,,, ':iii -14-.4.= 1 161.00 ' 7.000 325.000 1160.29 1036.29 2 6.59 -23.72 266833. ri, 2551359.35 3.50 1221.00 8.500 337.000 1219.75 1 1095.75 j -1575.53 13.67 -27.55 1 266829. 2551366.51 3.66 1314.00 1 11.0001 350.000 1311.41 1187.41 1 -1568.42 28.74 -31.78 1 266825.1 2551381.66 3.57 1424.00 14.250 353.000 1418.74 1294.74 -1560.33 52.52 -35.25 266822. 3 2551405.50 : 3.01 1752.00 21.500 S1.000 1730.70 FVZ4 -1526.66 152.08 -49.59 266810.19 255151,64" - 1999.00 27.250 350.000 1955.59 1831.59 -1490.28 252.56 -66.51 266795.29 2551606.13 r --__ 2.33 2262.00 27.7501 348.0001 2188.88 ' 2064.88 , -1444.07 371.75 1 -89.69 1 266774. 2551725.75 1 0.40 2689.00 r 26.250 348.0001 2569.33 2445.33 I -1367.20 561.37 -130.00 r 266738.1 2551916.12 0.35 ' 2872.00 1--- 25.500 347.000 2733.98 2609.98 -1334.91 639.33 -147.27 266722. 4 2551994.42 0.47 _,_1,.._ * - 3490.00 30.000 343.000 3280.20 3156.20 -1208.71 918.73 -219.85 , 266655.3M 2552275.20 0.81 3645.00 30.2501 348.0001 3414.29 3290.29 -1174.82 993.99 -239.30 266637.33 1711317E1 1.63 3764.00 297000 355.0001 3317.76 I 3393.76 -1154.80 1052.07 -248.05 266629.84 l 2552409.07 1 3.09 4122.00 27.750 353.000 3832.75 ' 3708.75 1 1104.10 1221.25 , -265.77 266615.4 I 2552578.571 0.44 : g9, ; .,.,,*, 27.250 353.000 3997.73 94.;;7:','''.,"3873.73 -1077.04 777 1306.0 2 ' ';,W!/;'%"4. := I i' : 416.06 , 28.500 351.000 4346.90 4222.90 -1015.76 1489.34 -302:06: 266584.6' r * 12532847.32 -, 0.40 1 * 4961.00 7 29.750; 351.000 - 4572.28 4448.28 -972.07 { 1613.37 -321.65 266567.45 2552971.71 I . 0.48 5343.00 7 28.000 348.000 4906.79 4782.79 -903.53 1794.71 1111=9 266537.65 2553153.68 0.59 t-- 5749.00 - 27.000 347.000 5266.91 5142.91 -827.73 1977.73 -395.67 266500.73 2553337.47 0.27 6065,00 ; 29.750 34.666 5545.18 5421.18 -764.52 2123.22 -430.91 266468. 31 155371.8376 1.17 6434.00 33.000 345.000 5860.18 5736.18 -680.66 2309.16 -479.08 266424.01 2553670.49 0.89 - 6801.00 : 35.000 345.000 61 6040.42 1 -589.54 2507.38 -532.20 - 266374.83 2553869.73 r 0.54 7079.00 1 34.000 345.000, 6393.53 ; 6269.53 1 -519.63 ' 2659.48 -572.95 266337.1:1 2554022.60 ' 0.36 .... ,c, "*".;i7i.4", 71 441 71:1-!*4-Asgie07#1,.1 ' - 7596.00 34.000 343.000 - 6822.147 -- 6698.14 1 -387.22 2937.5 i -652.14 266263.5: , _ 2554302.15T 6727 7866.00 - * 32.250 342.0001 7048.26 6924.26 r -316.03 1 3078.22 -696.47 I 266222.0' - 2334443.721 0.68 8179.00 ' 31.500 344.000i 7314.06 ' 7190.06 -237.50 3236.25 -744.82 266176.9) 2554602.68 0.41 8219.00 31.370: 343.058 7348.19 1 7224.19 -227.76 ; 3256.26 -750.74 266171.3i 2554622.80 1.27 _5.550 _ rivq=„14.4041040)4 iviwv0 8606.00 21.000 335.550 7699.13 i 7575.13 -146.73 1 3409.32 -802.64 r 266122.5 2554776.86 1 1.82 - 8700.00 20.7301 330.434 7786.98 I 7662.98 , -125.97 1 3439.12 r -817.82 1 266107.9 2554806.97 1.93 8792.00 20.900 327.1001 7872.97 1 7748.97 -103.86 3467.07 1 -834.76 ' 266091.61 2554835.24 1.31 8885.00 18.550 324.630 7960.51 7836.51 -81.50 3493.06 r -852.34 ' 266074.5 2554861.58 " 2.68 8977.00 15.040 324.910 8048.57 7924.57 -62.19 3514.71 v780:68 -----7, 010\10: wit-.. - :C: 0, ... ... _ 9073.00 12.250 .322.360 8141.86 8017.86 -45.47 3533.03 , -881.06 266046.6 : 2554902.12 2.97 -- 9169.00 12.070 325.6101 8235.70 1 8111.70 I -30.60 3549.38 -892.95 266035.0: 2554918.70 0.74 - f - 1-- i 9261.00 1 12.000 329.2901 8325.68 i 8201.68 -17.30 3565.54 -903.27 r 266025.01 2554935.06 0.84 I - 9352.00 12.020 323.830 8414.69 ' 8290.69 -4.20 3581.51 -913.42 , 266015.24 2554951.23 0.79 "1.: i 1 1 , 1 0 • Chevron Planned. W 1 path Report '�` BAKER IWO AN -24RD Version #18 HUGHES Page 3 of INTEQ REFERENCE WEIA,PATIl 1l)ENTIFICATION ___. __ or Chevron _M____ . __ -'-__ ;Slot slot #2 -3 a Area (Cook Inlet, Alaska (Offshore) Well AN - 24RD � - Field _ Point Field �� _ - _ Wellbore AN -24RD • _� M Facil ANNA Platform Sidetrack from AN -24RD at 9369 .00 D WELLPATH DATA (73 stations) t = interpolated /extrapolated station MD Inclination Azimuth TVD TVD from Vert Sect North East Grid East Grid North DLS (ffl °] 1 °J _ [tit] ( FId Vert Ref [ft] [ft] [ft] lsry ft] Isry ft] ( ° /10 ___ � +� . �.__. I I � _- 9 480 80 0 f 00 15.549 315.99 8539.19 8415.19 18.61 3604.46 932.07 265997. t � 2554974.974.55 4.10 i __ 9580 00t _ 19.2971 310.3051 8634.59 8510.59 44.12 3624.78 r - 954.01 265975. 255499531 I _ 4.10 1 9680 00t 23 .162 306.487 8727.79 _ 8603.79 76.40 ;__3647.17 - 982.43 265947.1 2555018.26 ! 4.10 9780.00f; 27.094' 303.718 8818.32 8694.32 115.28 3671.52 1017 20 265913. 1 2555043 30 , 4.10 1. : 9 ` it4 lw© �¢S C e - - , ' ,,,,. 1 , �,�� ° � „:""1,„,1 � � �!„� -. � ° .:.:.r �� #, . ,r b .,..s � ' � E� � . ; � a �7 �� s ^ =' '�� ._. u�wa . t � �:° � .-.. t 9980 OOt r i 35.067 299.9351 8989.48 - 8865.48 212.03 MORI - 1105.02 265826. 1 2555099.09 i 4.10 10080.00t1 39.086 298.566 9069.25 8945.25 269.40 3754.99 - 1157.63 265774.1 2555129.561 4.10 5 10141.32 1 41.5581 297.838 ; 91 : _ = 8992.00 307.37 __ 4.10 10180.00t; 41.5581 297.838 9144,94 9020.94 331.98 3785.71 ' - 1215.28 2_65717..6 , - 2555161.43 - 1 0,00 t , t, ;AY)t ,E . t 97.838 9219.774 ? i 't`, � ' �' " . ..I . ¢ ' ; e `A • s :. , t kg 10380 00f 41.558 297.838 9294.60 9170.60 r 45920 ; 3847.67 ` -1332 60 265601. 2555225.72 0.00 - 1_0427.65 41.558 297.83 9330.25 9206.25 489.517 3862.43 - 1360.55 265573. 2555241.04 0.00 � - 1391.99 265542. 2555257.39 ' 4.00 10480.001 42.804 295.332 9369.05 9245.05 523.43 3878.15 265 _ _ ' 10580.001 45.326 290.865 9440.92 V 9316.92 591.49 3905.36 - 1455.95 265479. 3J 2555285.87 4.00 10780 OOt 50.82 < 2 3 038 9574.62 __.,... a..._ . __� 9450.62 , .. _� 739 _. _ . _a- .._,.-� j..... a._. .�. .I.�: -_...L_______;_ _. . ---...-1...,- .�; • :.j 8 .36 3948.25 - 159815 J 265338. 2555331.60 w 4.00 , 10880.00f1 53.746 279.587_9635.80 9511.80 818.43 3963.71 -1675 69 - 265260.; 2555348.61 4.00 i 10980 OOt", 56.762 276.389 9692.80 9568.80 900.43 , 3975.09 1 , -175_7 04 265179. / 2555361.61 __ 4.00 1 11080.00f; 59.855 273.407; 9745.33 j 9621.33 , "§i4.95 3982 31 ' -1841 80 265095. g 2555370.53 1 : a 70 608 `. 6 ` 0 5 a 985 3 l® I t o v t t. ' _11280.00t1 66.219! 267.963 9836.02 j 9712.02 I 1159.89 i 3984.20' - 2019.87 264917. i 2555375.99 , 4.00 j 1380.0011 69.470 265.446 9873.73 9749.73 1249.47' 3978.85 - 211231 264824.a 2555372.50 4.00 11480.0011 72.756;__ 263.035 9906.10 9782.10 , 1339.87 3969.34 1 - 2206.42 264730. ' 1 2555364.87 4.00 11580.00f 76.070 260.709' 9932.97 9808.97 1 1430.65 1 3955.71 j - 2301.75 1 264634. a 2555353.15 ; 4.00 ' - 4 56 ®�7 2 1 # '.: ';'''.-.`.1.";.' r r,. "jy r t: ?a 1114Argrij ; 11680.00t 77.687 259.604 9954.97 9830.97 1521.41 1 3938.56 ; -2397 78 264538.' IL_ . 2555337.92 0.00 11780.001* 77.6871 259.604', 9976.29 � 9852.29 1612.15 1 3920.921 - 2493.87 264441.' 255532222 0.00 11828 00 r 77.687 259.604 9986.53 1 9862,53 ' 1655. ; 3912.46 - 2540.00 264395. 1 2555314.69 0.00 --- . - _ HOLE &CASING SECTIONS Ref Wellbore: AN- 24RD Ref Wellpath: AN -24RD 1 ,04.'"" ersion #18 String/Diameter Start MI) End MD Interval Start TVD End TVD Start N/S ' Start E/W End N/S End E/W [ft] [ft] [ft] 1 [ft] [ft] [ft] [ft] [ft] I [ft] 8 .5in Open Hole I 8219.00 9380.00 1161.00 7348.19 8442.08 3256.26 -750. 3586.31 - 916.74 8.Sin Open Hole 1 9380.00 11828.00 2448.00 8442.08 9986.53 3586.31 -916. 3912.46 - 2540.00 0 Chevron En Planned W el path Report BAKER IWO AN -24 Version #18 HUGH P ge 4 of 4 INTE T CP REFERENCE WELLPATII IDENTIFICATION 11 0 erator Chevron Slot slot #2 -3 Area !Cook Inlet, Alaska (Offshore) Well AN -24RD' i v% �Field !Granite Point Field Wellbore AN -24. 1K ‘ i Facility sANNA Platform Sidetrack from AN -24RD at 9369.00 MD TARGETS r_ .. ._ i Name ,,pp MD TVD North East Grid East Grid North Latitude Long Shape ∎V (ftl [ft] [ft] [ft] [ ft] [sry ] 1) An -24R Contingency ; 32 � i °2"®r ' 4 - 7,,.6 � t�` . '4 , tI point Target 10- pril -2008 12) An24Rd Target Top C -SA 24- 11628 " 4 : a i e m ® . ® ,P; , 4. 4 rectangle a e !Oct -2007 . . /h•k44612 /41k12% SURVEY PROGRAM Ref Wellbore: AN -24RD Ref Wellpath: AN-24RDVersion#18 r- Start MD End MD Positiona c ertainty Model Log Name / Wellbore ____. [ft] [ft] _._ 1_ - — < _ 19.00! 8219.00 Photomechanical Magnetic (Standard) �� AN -24 — 821976 9169.00 AutoTrak _______ G3 (SAG, M_ agCorr) I 4 1 AN -24RD 9169.00 9380.00AutoTrak G3 (SAG} ~� AN- 24RD_ i ,F— 11828.00 AutoTrak G3 (SAG) 1 _ jAN -24RD .1 1. !Well: AN -24RD !Path: !Reference North is: TRUE !Magnetic Declination is: 19.01 !True to Grid Convergence: 0.00 !Tie In Point data: !MD 8219.00 INC 31.37 Azicorr 343.06 TVD 7348.19 N/S 3256.26 E/W - 750.74 ! !Measured Depth Inclination Azimuth Planar VS Dogleg Position North Vertical Depth Position East 8417.00 23.21 342.59 57.86 4.12 3342.93 7524.00 - 777.48 8606.00 21.00 335.55 106.51 1.82 3409.32 7699.13 - 802.65 8700.00 20.73 330.45 131.94 1.95 3439.13 7786.97 - 817.83 8792.00 20.90 327.10 158.29 1.31 3467.08 7872.97 - 834.78 8885.00 18.55 324.63 184.48 2.68 3493.08 7960.51 - 852.36 8977.00 15.04 324.91 206.95 3.81 3514.79 8048.57 - 867.70 9073.00 12.25 322.36 226.30 2.98 3533.05 8141.85 - 881.08 9169.00 12.07 325.61 243.54 0.74 3549.39 8235.70 - 892.97 9261.00 12.00 329.29 259.26 0.84 3565.56 8325.67 - 903.29 9352.00 12.02 325.83 274.76 0.79 3581.53 8414.68 - 913.45 9446.00 12.06 322.46 291.44 0.75 3597.42 8506.61 - 924.93 9483.00 11.97 321.62 298.15 0.54 3603.50 8542.80 - 929.67 9573.00 12.54 319.95 314.97 0.74 3618.29 8630.75 - 941.75 9672.00 14.21 313.54 335.84 2.26 3634.89 8727.07 - 957.47 9763.00 16.05 307.67 358.42 2.63 3650.27 8814.92 - 975.53 9855.00 17.93 303.97 384.57 2.36 3665.96 8902.90 - 997.35 • 9947.00 21.65 301.83 415.21 4.11 3682.83 8989.45 - 1023.52 9963.00 21.79 301.73 421.05 0.93 3685.95 9004.32 - 1028.56 10054.00 27.14 298.14 458.41 6.10 3704.63 9087.12 - 1061.25 0 -1 -500 29.89 _ __ 3725.26_ _ -9 172.35 -- -110248- -- --- 294.94 5_04_.5_8__ _._- __.3 -24 10233.00 32.69 292.85 547.14 3.66 3742.48 9242.42 - 1141.62 10298.00 34.57 291.29 583.14 3.18 3756.00 9296.54 - 1174.98 Floor An- •4RD. Annulmr ��' � i 4 13 5■Ir" 9A Iii. dale V( 4,44, Ada t3 5B 5u k Rig Floor to BF = 59' s s i ge' m Z 4" tt '� R E � '.; 8 Cancrats '� 13178'x9 -- 7 ...elite. — Q. ' c. :, . hcad , I Cellar Floor (BF) ' I If .-ar BF to MSL =65' Mean Seal Level MSL (Rig floor to BF) + (BF to MSL) = RKB 59' + 6 ,' = 124' An -24RD sidetrack • • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, April 11, 2008 12:55 PM To: 'Flynn, Tim [ASRC]' Cc: Nienhaus, Doug R; Buster, Larry W Subject: RE: An -24RD sidetrack Tim, I wondered if there was a "source" tool involved. You are correct to follow NRC guidelines. Given that there is a nuc involved, it is probably best to submit a sundry. I realize that it Is possible that cement will be pumped this weekend. I will speak with the Commissioners. Call or message with any questions /additional information. Tom Maunder, PE AOGCC From: Flynn, Tim [ASRC] [mailto:Tim.Flynn @chevron.com] Sent: Friday, April 11, 2008 12:12 PM To: Maunder, Thomas E (DOA) Cc: Nienhaus, Doug R; Buster, Larry W Subject: RE: An -24RD sidetrack TOF is at 10318'MD We are still working out the engineering plan to float a 500' plug over a weighted high vis sweep. We had circulation throughout jarring operations and up to the point we backed off above the MWD with a string shot. No reservoir issues have been determined with leaving AN -24RD as it is. The liner will be fully cemented for completion. / There is a density source in the stuck BHA. We will be following guidelines in accordance with NRC to properly abandon the source. Thank you Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 -3322 907 - 263 -7824 phone 907 -317 -5504 cell From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, April 11, 2008 11:14 AM To: Flynn, Tim [ASRC] Cc: Nienhaus, Doug R; Buster, Larry W Subject: RE: An -24RD sidetrack 4/14/2008 An -24RD sidetrack • Page 2 of 3 Tim, Is your TOF at 9800'? Can you circulated through the fish? Based on your drawing, are there any issues with the zones that are open in the to -be- abandoned well segment? Thanks in advance. Tom Maunder, PE AOGCC From: Flynn, Tim [ASRC] [mailto:Tim.Flynn @chevron.com] Sent: Friday, April 11, 2008 11:06 AM To: Maunder, Thomas E (DOA) Cc: Nienhaus, Doug R; Buster, Larry W Subject: An -24RD sidetrack Tom Current operations on AN -24RD, we are circulating over the fish at 10,318 MD preparing to screw in and attempt to jar free. Heading into the weekend, our plan forward if we cannot screw into the fish or jar free will be the following: POOH w/ out BHA BOP test TIH w/ cement stinger Lay cement plug from 9800'MD to 9300'MD POOH, M/U sidetrack BHA, TIH Kickoff cement plug at approximately 9360'MD and directionally drill new plan The new directional plan is very similar to AN -24RD and will target same reservoir and completion plans. «AN- 24RD2_Version 16 Plan -Vert Veiw Plot (8.5x11) .pdf» «AN -24RD2 Version 16 Planned Wellpath Report.pdf» «AN -24RD sidetrack.pdf» «Stuck BHA schematic.pdf» Please let us know if a written sundry and additional information is needed to remain in compliance with our current drilling permit. Thank you Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 4/14/2008 Chevron • • Mill ADVANTAGE String Report - Run #5 BAKER MOM INTEQ Operator Chevron Fields Tyonek Oil Sands Facility Anna Platform Location S12 T1ON R12W Well Anna 24RD Welibore Anna 24RD Rig Chevron Rig #428 Job AN -24Rd String Components Item # Component G ap e OD ID Length Total Len in in in ft ft 19 Drill pipe x 303 6 1/2 5 4.276 9527.08 10319.00 I 18 HWDP x 16 6 3/8 5 3 476.53 791.92 17 Jar 6 1/2 2 3/4 32.03 315.39 i 16 HWDP x 4 6 3/8 5 3 119.66 283.36 15 Sub - X/O 6 11/16 2 13/16 2.83 163.70 i 14 Drill pipe - compressive 6 13/16 5 2 13/16 30.49 160.87 i 13 Drill pipe - compressive 6 13/16 5 2 13/16 31.08 130.38 12 Drill pipe - compressive 6 13/16 5 2 13/16 30.76 99.30 11 NM Sub - X/O 6 1/2 2 13/16 2.28 68.54 U 10 NM Sub - filter 6 13/16 3 4.77 66.26 9 NM Sub - float 6 1/8 2 7/8 2.26 61.49 U 8 NM Sub - stop 6 3/4 2 5/16 2.16 59.23 7 ORD 8 3/8 8 1 7/8 9.98 57.07 6 BCPM 7 1.570 10.32 47.09 5 MWD stab mod 8 3/8 7 2.300 3.88 36.77 Page 1 Chevron • • BAKER P I ADVANTAGE String Report - Run #5 HUGHES y INTEQ Operator Chevron Fields Tyonek Oil Sands Facility Anna Platform Location S12 T1ON R12W Well Anna 24RD Wellborn Anna 24RD Rig Chevron Rig #428 lob AN -24Rd String Components 1 Item # Component OD a OD ID Length Total Len in in in ft ft 4 OnTrak - MWD 7 7 2.300 16.88 32.89 tit 3 Flex sub w/ Stab 8 3/8 7.024 2.299 7.99 16.01 2 ATI< Steerable Stab 8 1/4 7 3/4 1.543 7.12 8.02 I j il 1 Bit - PDC - fixed cutter 8 1/2 8 1/2 2 1/4 0.90 0.90 19 String components with a total length of 10319 ft. Page 2 RE: BOP Test Page 1 of 2 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, April 02, 2008 10:32 AM . Cl *?7, To: 'Lawrence, Steve C'; aogcc_prudhoe_bay @admin.state.ak.us Cc: Nienhaus, Doug R; Flynn, Tim [ASRC] Subject: RE: BOP Test Steve — Your request to delay the BOPE test on Nabors 428 (Anna Platform) until Friday (4/4/2008) is approved. I appreciate the clarification you provided today during our phone conversation as to why testing was not performed prior to tripping in the hole with the new BHA on 3/31/2008. Jim Regg � --_? g "nc vet5e1 eleeedee, - (.der e ? - d s bas `ntr& Gv AOGCC OF 'RAJ 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907- 793 -1236 fax: 907 -276 -7542 From: Lawrence, Steve C [mailto:Iawrences @chevron.com] Sent: Wednesday, April 02, 2008 6:53 AM To: Lawrence, Steve C; aogcc_prudhoe_bay @admin.state.ak.us Cc: Nienhaus, Doug R; Flynn, Tim [ASRC] Subject: RE: BOP Test Lou, sorry I was looking at the calendar wrong we will be anticipating tripping out on 4 -3 -08 or 4 -4 -08. Thanks Steve From: Lawrence, Steve C Sent: Tuesday, April 01, 2008 7:02 PM To: ' aogcc _prudhoe_bay @admin.state.ak.us' Cc: Nienhaus, Doug R; Flynn, Tim [ASRC] Subject: BOP Test Lou, We are due a BOP test on Rig 428 on the ANNA Platform, on 4 -2 -08, we are currently in the hole and would like to delay our test untill we are out of the hole. We ran in with this BHA on the morning of the 3- 31 -08, we have encountered problems W/ our SCR and some issues W/ madd pass that has put us behind the 8 ball. I am anticipating tripping out of the hole on the 27th or 28th Thanks ? — /a 4/2/2008 RE: BOP Test Page 2 of 2 Steve Lawrence Drilling Site Manager Mid Continent BU Chevron North America Exploration and Production Anchorage Alaska. 99502 -3322 Telephone: 907 - 776 -6617 Fax: 907 - 776 -6625 HM: 907 - 283 -5497 CeI: 907 - 252 -4841 lawrences@chevron.com 4/2/2008 Granite Point State 18742 24RD (AN -24RD) Page 1 of 1 1 Maunder, Thomas E (DOA) From: SHAFER, DAVID C [ShafeDC @chevron.com] Sent: Monday, March 17, 2008 12:06 PM To: Maunder, Thomas E (DOA) Cc: Flynn, Tim [ASRC]; Shannon, Coleen C. Subject: Granite Point State 18742 24RD (AN -24RD) Tom, on our permit (207 -170) to drill this well, the permit indicates that samples are not required by the State, nor is a mudlog required. Epoch will be describing the cuttings, so if you need a copy of the mudlog please let me know the format, i.e., paper or digital, so that I can ask for an additional paper copy. I also need clarification on the format for the logs and how many copies are required. Do you need paper copies along with the digital files? If you need paper copies, how many and at what scale? 1 assume the same number of paper copies and scales also hold true for cased hole USIT and GR -Sonic logs. Thanks for your time and answers. David C. Shafer Development Geologist Advisor MidContinent/Alaska SBU Chevron North America Exploration and Production 909 West 9th Avenue, Anchorage AK 99501 Tel 907 263 7864 Fax 907 263 7847 ShafeDC @chevron.com 8/26/2009 RE: BOP test frequency on Rig 44 Page 1 of-2' Regg, James B (DOA) From: Regg, James B (DOA) l Sent: Tuesday, March 11, 2008 2:34 PM c 314(0(e0 To: 'Flynn, Tim [ASRC]' Cc: Nienhaus, Doug R; DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Subject: RE: BOP test frequency on Rig 428 Tim — Tom Maunder and I have discussed your request to change BOPE test frequency to 14 days for Granite Point Field, Anna platform development drilling. We would like to see open hole drilling before making a decision. As such, you will need to continue testing on a frequency not exceeding every 7 days for Anna 24RD. We will assess the testing experience on Rig 428 after Anna 24RD for possible extension to 14 day BOPE testing. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907 -793 -1236 fax: 907- 276 -7542 From: Flynn, Tim [ASRC] [mailto:Tim.Flynn @chevron.com] Sent: Wednesday, March 05, 2008 11:00 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Nienhaus, Doug R Subject: RE: BOP test frequency on Rig 428 Tom,Jim Chevron has initiated a 5 to 7 month drilling program with Rig 428 on the Anna Platform in Cook Inlet. Currently, BOP tests are being completed every 7 days. The recent BOP test, completed on March 4th was completed in 13.5 hrs. We have completed a full BOP test on our previous well An -32RD on February 22nd 2008 and all wells currently planned to be drilled from Anna are for Granite Point development consisting of sidetracks out of current wells on the platform. Based on the tests that have been completed and the confidence in the system, Chevron would request that the BOP testing frequency be extended to 14 days for drilled wells on the Anna platform. Please review the attached most recent BOP test results and feel free to contact me with concerns or clarifications. Thank you «BOP Nabors Rig 428 03- 04- 08p.xls» Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 -3322 3/11/2008 9 0-4- 1 `9-0, AN -24RD data to State Page 1 of 1 Maunder, Thomas E (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, March 06, 2008 8:15 AM To: 'Tim.Flynn @chevron.com' Cc: Maunder, Thomas E (DOA) Subject: RE: AN -24RD data to State Tim, The permit did not require samples or a mud log, but if you have extras, we'll gladly accept them. Please send them to Howard Okland. I can't speak for any other state agency concerning their reporting requirements. You'll have to contact them directly. Thanks, Steve Davies AOGCC P.S. The well name AN -24RD will be confusing to our clerical staff who are responsible for filing correspondence. The name of the well from the permit app submitted by Unocal is GP St 18742 24RD. Including the permit to drill number on all correspondence will also help greatly too. Thanks. SD From: Maunder, Thomas E (DOA) Sent: Wednesday, March 05, 2008 1:13 PM To: Davies, Stephen F (DOA) Subject: FW: AN -24RD data to State r better able to answer this than I. If the of the info, an updated mud log think you are be p 9 from out there would be a Y Y9 good thing, I think. From: Flynn, Tim [ASRC] [mailto:Tim.Flynn ©chevron.com] Sent: Wed 3/5/2008 7:06 AM To: Maunder, Thomas E (DOA) Subject: AN -24RD data to State Tom We are currently pulling our dual completion string out of AN -24RD on the Anna and have 2 questions posed to me by Geology. Do we need to provide the AOGCC, or any other State agency, with cuttings' samples for Anna development wells? Do we need to provide a bound Epoch mud log report to the AOGCC, or any other State agency? Let me know and we will plan accordingly. Thank you ' 8/26/2009 BOP test waiver for AN -32RD Page 1 of 2 1110 11, Regg, James B (DOA) From: Flynn, Tim [ASRC] [Tim. Flynn @chevron.com] Sent: Saturday, March 01, 2008 3:44 PM To: Maunder, Thomas E (DOA); AOGCC North Slope Office Cc: Nienhaus, Doug R; Raney, John [Cenergy]; Lawrence, Steve C; Buster, Larry W Subject: RE: BOP test waiver for AN -32RD Attachments: Anna 24 RKB1.jpg AOGCC North Slope We are currently moving Rig 428 over to AN -24RD for decomplete and Sidetrack operations. An -24RD is completed with dual 3'/2" by 2 7/8" tubing strings. Due to the complexity of testing the blind rams we requested and received a waiver to forgo testing the 13 5/8" blind rams until the completion was out of the hole on An -32RD. We would like to request a waiver to not test the 13 5/8" blind rams on AN -24RD until the dual completion is out of the hole. Please contact the Chevron DSM, Steve Lawrence or John Raney on e Anna Platform (776 6617) for further I clarification. 1 I have attached Tom Maunders approval for An -32RD for reference. Thank you V (5Cw(.Ss-J e i lj f ie S 4 / c� Tim Flynn j f OW 4 Operations Drilling Engineer R» l l l Chevron North America Exploration and Production I - 909 W. 9th Avenue 1Q i 1CC / C. + b IdAA to .1.t 1 o ' i -t i Anchorage, AK 9950 1 -3 32 2 `1 v,(,4- (i h' vl e,,, Ie_ r� -4e +- c G I 907 - 263 -7324 phone c- ��p 907- 317 -5504 cell ' a�^ ?ttlit ca Ci(,w( o . 4-3keek hIA 4 seitd col-f-‘ 1 ,___ ftd?S (Aet r }' if ( to u s'' From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] �--� Sent: Thursday, February 14, 2008 2:49 PM 3 ) 3 ) To: Flynn, Tim [ASRC] / Subject: RE: AN- 32RD /AN -24RD Blind ram variance Tim, Thanks for arranging the conference call. Based on the discussion between yourself, the rig (with Inspector Chuck Scheve present) and myself, it is acceptable to delay testing the blind rams. Call or message with any questions. Tom Maunder, PE AOGCC From: Flynn, Tim [ASRC] [mailto:Tim.Flynn @ chevron.com] Sent: Wednesday, February 13, 2008 8:46 AM To: Maunder, Thomas E (DOA) Subject: AN- 32RD /AN -24RD Blind ram variance 3/3/2008 BOP test waiver for AN -32RD Aik Page 2 of 2 Tom We are currently getting ready to nipple up on AN -32RD to do our decomplete and P &A. One item that was overlooked when submitting our PTD was to request a variance from testing our 13 5/8" double gate blind rams prior to pulling the dual completion out of the well. We will plan on testing the 13 5/8" DBL gate pipe rams above. AN -24RD will request the same variance when pulling the 3 %2" by 2 7/8" dual. Please advise if you find this acceptable and if so what you will require from Chevron for documentation. Thank you «WBD An -32RD Actual 01- 16- 08.doc» «428 stack.jpg» «Anna 24 RKB1.jpg» Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 -3322 907 - 263 -7824 phone 907 -317 -5504 cell Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 -3322 907- 263 -7824 phone 907- 317 -5504 cell 3/3/2008 • Rig Fro � > .... F D �a a r ,,,,..4 R i g Roar to BF t % ✓�`�r j�� %�?, , N s x :11.5A = 65' C.$ ((afl${Sr ..- M ean Seat Level �4S r V IEj 816[ to E'R . ' RE: BOP test frequency on Rigo8 • Page 1 of 2 Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Tuesday, March 11, 2008 2:34 PM To: Flynn, Tim [ASRC] Cc: Nienhaus, Doug R; DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Subject: RE: BOP test frequency on Rig 428 Tim – Tom Maunder and I have discussed your request to change BOPE test frequency to 14 days for Granite Point Field, Anna platform development drilling. We would like to see open hole drilling before making a decision. As such, you will need to continue testing on a frequency not exceeding every 7 days for Anna 24RD. We will assess the testing experience on Rig 428 after Anna 24RD for possible extension to 14 day BOPE testing. Jim Regg e ra AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907 - 793 -1236 fax: 907 -276 -7542 From: Flynn, Tim [ASRC] [mailto:Tim.Flynn @chevron.com] Sent: Wednesday, March 05, 2008 11:00 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Nienhaus, Doug R Subject: RE: BOP test frequency on Rig 428 \ C 6 1 ( 0 - 5 Tom,Jim Chevron has initiated a 5 to 7 month drilling program with Rig 428 on the Anna Platform in Cook Inlet. Currently, BOP tests are being completed every 7 days. The recent BOP test, completed on March 4th was completed in 13.5 hrs. We have completed a full BOP test on our previous well An -32RD on February 22nd 2008 and all wells currently planned to be drilled from Anna are for Granite Point development consisting of sidetracks out of current wells on the platform. Based on the tests that have been completed and the confidence in the system, Chevron would request that the BOP testing frequency be extended to 14 days for drilled wells on the Anna platform. Please review the attached most recent BOP test results and feel free to contact me with concerns or clarifications. Thank you «BOP Nabors Rig 428 03- 04- 08p.xls» Tim Flynn Operations Drilling Engineer 3/11/2008 AN- 32RD /AN -24RD Blind ram�arance Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, February 14, 2008 2:49 PM To: 'Flynn, Tim [ASRC)' Subject: RE: AN- 32RD /AN -24RD Blind ram variance Tim,h" V 1° Thanks for arranging the conference call. Based on the discussion between yourself, the rig (with Inspector Chuck Scheve present) and myself, it is acceptable to delay testing the blind rams. Call or message with any questions. Tom Maunder, PE AOGCC From: Flynn, Tim [ASRC] [mailto:Tim.Flynn @chevron.com] Sent: Wednesday, February 13, 2008 8:46 AM To: Maunder, Thomas E (DOA) Subject: AN- 32RD /AN -24RD Blind ram variance Tom We are currently getting ready to nipple up on AN -32RD to do our decomplete and P&A. One item that was overlooked when submitting our PTD was to request a variance from testing our 13 5/8" double gate blind rams prior to pulling the dual completion out of the well. We will plan on testing the 13 5/8" DBL gate pipe rams above. AN -24RD will request the same variance when pulling the 3 1/2" by 2 7/8" dual. Please advise if you find this acceptable and if so what you will require from Chevron for documentation. Thank you «WBD An -32RD Actual 01- 16- 08.doc» «428 stack.jpg» «Anna 24 RKB1.jpg» Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 -3322 907 - 263 -7824 phone 907- 317 -5504 cell 2/14/2008 AN -24RD 401 clarifications • Page 1 of 2 Maunder, Thomas E (DOA) From: Flynn, Tim [ASRC] [Tim.Flynn @chevron.com] Sent: Friday, December 21, 2007 10:16 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Buster, Larry W; Brandenburg, Tim C Subject: AN -24RD 401 clarifications Attachments: BOP stack up 428.xfs; drill and complete procedure summary TSF 12_21.doc Tom As per our conversation on 12/21/2007: Clarification #1: Line 4a. of 401 20 AAC 25.005 4a. Location of Well (Governmental Section): Surface: 790' FNL, 600' FEL, Sec 12, T1ON, R12W, SM Top of Productive Horizon: 2214' FNL, 2531' FEL, Sec 1, T1ON R12W SM Total Depth: 2110' FNL, 3047' FEL, Sec 1, T1ON, R12W, SM Top of production Horizon and Total Depth changed from Sec 12 to sec 1. Clarification #2: A FIT test to 16 ppg EMW will be performed, after 20' of new formation is cut. Casing pressure tests for An -24RD: Prior to milling window, the 9 5/8" casing will be tested to 2000 psi. Once the hole is drilled and the 7" liner is set and cemented, the casing will be tested to 2000 psi for 30 minutes prior to running completion. See "drill and complete procedure" The BOP's will be tested to 3500/250 psi. Information attachments: Attached is a schematic of our BOP stack on Rig 428. Please call if you have any questions or concerns. «BOP stack up 428.xts» «drill and complete procedure summary TSF 12_21.doc» Tim Flynn Operations Drilling Engineer 12/21/2007 S 97' E SARAH PALIN, GOVERNOR ALASKA OIL AND 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 CONSERVATION ►7►7 PHONE (907) 279 -1433 FAX (907) 276 -7542 Tim Brandenburg Drilling Manger Union Oil Company of California PO Box 196247 Anchorage, AK 99519 Re: Granite Point Field, Tyonek Oil Pool, GP St 18742 24RD (Anna) Union Oil Company of California Permit No: 207 -170 Surface Location: 790' FNL, 600' FEL, SEC.12, T1ON, R12W, SM Bottomhole Location: 2110' FNL, 3047' FEL, SEC.1, T1ON, R12W, SM Dear Mr. Brandenburg: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) • 9 -3607 (pager). 4/an ,, / Chai DATED this ! day of December, 2007 cc: Department of Fish as Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 40 0 Chevron Timothy C Brandenburg Union Oil Company of California ✓ 1/14011 Drilling Manager P.O. Box 196427 Anchorage, AK 99519 -6247 1 %I. Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt @chevron.com November 13, 2007 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7 Avenue Anchorage, Alaska 99501 Re: Anna AN -24RD Dear Commissioner, Enclosed for review and approval is the application for the Permit to Drill to Anna AN -24RD. Rig operations are expected to commence approximately Dec 20, 2007 depending on the progress of other ongoing projects. Our records indicate bond number 086S103515406BCM replaced bond number 5534278. It appears that your records might indicate bond number 5534278 is still in effect. vi If you have any questions, please don't hesitate to contact myself or Tim Flynn at 907 - 263 -7824. Sincerely, / RECEIVED Nov 1 0 NV Timothy C. Brandenburg Ahlsio Oil �,;.rmislon Drilling Manager rahar Attachments: Form 10-401 in Duplicate AN -24RD Cementing Calculations AN -24RD Well Plan Summary AN -24RD Casing Design AN -24RD Summary Drilling Procedure AN -24RD MASP Calculations AN -24RD Summary Mud Program AN -24RD FIT / LOT Procedure AN -24RD Planned Well Sketch AN -24RD Spider Plots AN -24RD Planned Well Trajectory AN -24RD BOP Schematic AN -24RD Choke Manifold Schematic AN -24RD Drilling Hazards Notice Cc: File 1 - 'RIINAL Union Oil Company of California / A Chevron Company Page 1 of 1 R CEIVEb 0 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION V NOV 1 6 i 2007 � PERMIT TO DRILL Alaska Oil & Gas Cons, Commission 20 AAC 25.005 Anchorage 1 a. Type of Work: 1 b. Current Well Class: Exploratory ❑ Development Oil 0 1 c. Specify if well is proposed for: Drill ❑ Redrill 0 Stratigraphic Test ❑ Service ❑ Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Ell Single Well ❑ 11. Well Name and Number: Union Oil Company of California Bond No. 086S103515406BCM / GP St 18742 24RD (Anna) ` 3. Address: 6. Proposed Depth: 12. Field /Pool(s): PO Box 196247, Anchorage, AK 99519 MD: 11,800 TVD: 9963 Granit Point Field 4a. Location of Well (Governmental Section): 7. Property Designation: Tyonek Sands Surface: 790' FNL, 600' FEL, Sec 12, T1ON, R12W, SM ✓ ADL 18742 Top of Productive Horizon: A, 8. Land Use Permit: 13. Approximate Spud Date: 2214' FNL, 2531' FEL, Sec '/., T10 R12W SM N/A 12/20/2007 Total Depth: 1 Ali 12.40- aq 9. Acres in Property: Y 14. Distance to Nearest 2110' FNL, 3047' FEL, Sec)T10N, R12W, SM 5060 Property: 1900' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x- 266857 y- 2551352 Zoi 4 (Height above GL): 114 AMSL feet / Within Pool: 1200' AN -28RD 16. Deviated wells: Kickoff depth: 8209 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 74 degrees Downhole: 4169 Surface: 3200 r 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8 1/2" 7" 29# P -110 Hyd 563 3591 8000 7135 11800 9963 560 sks "G" TOC 8000' (TOL) 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 10400 9220 8880 10105 8966 10140 Casing Length Size Cement Volume MD TVD Conductor /Structural 609.00 20" Cement to surface (1967) 609 609 Surface 2,000.00 13 3/8" 900 sx "G" @ 13.1 ppg 2000 1945 Intermediate 9,161.00 9 5/8" 600 sx of "G" cmt @ 15.8 ppg 9161 8099 Production Liner 1,697.00 7" 300 sks "G" TOC 7506' 10,400.00 9220 Perforation Depth MD (ft): 11051 to 11574 Perforation Depth TVD (ft): 9750 to 9899 20. Attachments: Filing Fee ❑ BOP Sketch 0 Drilling Program El Time v. Depth Plot 151 Shallow Hazard Analysis ❑ Property Plat 0 Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements SI 21. Verbal Approval: Commission Representative: Date 11/12/2007 22. I hereby certify that the foregoing is true and correct. Contact Tim Flynn 907 - 263 -7824 Printed Name Tim Brandenburg Title Drilling Manager ^ Signature \ 4 C Phone 263 -7657 Date 11/13/2007 /� Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: ��'" �� 50- 733 - 202.8S Date: 12 1 •6 requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: a Samples req'd: Yes❑ No: Mud log req'd: Yes❑ Not - � ©O i V�� H measures: Yes[✓]'No❑ Directional svy req'd: YesE No❑ 1 cf0 I c V A — C -5(-1'6\'f- � '■'PROVED BY THE COMMISSION 4 „, s ---, t -- lt DATE: �� 0 (�� , COMMISSIONER Form 10 401 Revised 12/2005 1J ',/ Submit i Duplicate 1 Chevron 11111111 Anna Platform Well AN -24RD Well Design Summary AN -24RD Well Design Summary Anna AN -24RD is a sidetrack out of An -24 drilling in a westerly direction from slot 3 in leg 2 on the Anna Platform. The well penetrates multiple primary and secondary Tyonek targets from the C-3 at 7304' TVD to the C -5B at 8314' TVD. Due to geology the well penetrates the reservoir again in the C- 7A at 8554' TVD and TD's in the C -5A at 9925' TVD. AN -24RD is designed as a "Hockey Stick" shaped well kicking off a whipstock at approximately 8180' MD, 7312' TVD. The well is planned to drill 3400' and through the Tyonek reservoir reaching a maximum angle of 74 deg inclination with a proposed TD of 1 1800'MD, 9950' TVD. Basic Well Information Platform: Anna Well Name: AN -24RD Rig Name Chevron 428 Estimated Spud Date: 12/20/07 Field: Granite Point Productive Horizon: Tyonek C sands ' PTD: TBD Total Depth: 1 1800' MD, 9950' TVD Slot: Slot 3, Leg #2 Surface Location: 790' FNL, 600' FEL, Sec 12, T10N, R12W, SM X= 266857,`Y= 2551352; NAD27, ASP, Zone 4 Planned BHL: 2110' FNL, 2223' FEL, Sec ),2"TlON, R12W, SM Original KB Elevation: 105' AMSL Current KB to BF: 49' - Elevation An -24 to BF: 65' Current RKB (KB +EL): 114' 11/14/2007 Page 1 of 3 Chevron 4WI Anna Platform Well AN -24RD Well Design Summary i Anti - Collision Evaluation Summary There is one close approach planned for AN -24RD. The well is outside all center to center ellipses Close Approach M -17 Path Ellipse Separation Diverging From Well (MD ft) (ft) (ft) AN -28RD 10506 63 feet (ellipse to ellipse) 10653 Formation Integrity Testing Test Point, 20' Pro Depth d Test Type Projected Test Below... (TVD) (EMW ppg) 9 5/8" KOP 8229 FIT 16.0 Mud Program Summary Depth Density Viscosity Section (MD ft) Mud Type (ppg) (sec) PV YP API FL 8 1 /2" Prod 8180-11800 OBM 9.0 -9.5 / 55 -80 18 -20 9 -18 <_6 Cementing Summary See Attachments Formation Markers Target Top TVD /SS Depths Measured Pore Pressure EMW Requirement Depth (RKB) V5 (PSI) (RKB) C -3 Crestal -7832 94 1590 3.5 ppg C 5A Crestal -8050 62 1241 2.9 ppg C -7A Crestal -8440 54 1412 3.17 ppg C -7D inverted -8591 23 1590 3.5 ppg C -5A inverted -9811 60 1898 3.6 ppg 11/14/2007 Page 3 of 3 Chevron Anna Platform Well AN -24RD 1%0 Well Design Summary Casing and Tubing Program Current Wellbore Hole Tube Top Btm Size O.D. Weight Length MD /TVD MD /TVD (in) (in) (Ibs / ft) Grade Conn (ft) (ft) (ft) Driven 20" 94# X -55 Weld 609 BF 609 17 1/2 13 3/8 68 K -55 BTC 2000 BF 2000/1945 12 9 5/8 43.5/40 S -95/L- BTC 9161 BF 9161/8099 80 8 7 26 L -80 BTC 1697 Hanger 10400/9220 ��`� TBG 2 7/8 6.4 L -80 SCBT 8804 BF 8804/7850 p TBG 3 1/2 9.2 L -80 SCBT 8002 BF 8002/7133 Proposed Sidetrack Hole Tube Top Btm Size O.D. Weight Length MD /TVD MD /TVD (in) (in) (Ibs / ft) Grade Conn (ft) (ft) (ft) 8 1/2 7" 29 P -110 H563 3600 8209/7338 11800/9964 Well Control Summary Hole Section Equipment Test Pressure (psi) 13 5/8" 5M Annular " 13 5/8" 5M Double Gate, 8'/2" 13 5/8" 5M Mud Cross, 13 5/8" 5M Single gate, 250/3000 3 1 /8" 5M Choke Manifold* * Schematics of the well control equipment are attached for reference 11/14/2007 Page 2 of 3 • DRILL AND COMPLETE PROCEDURE SUMMARY Pre -Rig Work: (P &A of AN -24) (Procedures are covered under P&A Sundry). Rig Operations: (Sidetrack An -24RD) 1. RIH with whipstock system set whipstock with MWD and displace well to OBM. 2. Mill window as per recommended practices. 3. Directionally drill ahead to TD w/ 8.5" Directional Assembly. Wiper trips will be performed as hole dictates. 4. RU Baker's Testrack (Formation Tester) and Sonic and RIH for clean out run to TD and POOH. 5. Run and cement the 7 ", 29# P -110 production casing back to 200' inside the 9-518" casing. Displace cement w/ diesel. 6. After setting the liner top packer circulate well clean reverse diesel throughout well. 7. Clean out 7' liner if required. 8. Test casing to 2000 psi. 9. Trip in with 2 7/8" by 2 3/8" dual completion assembly with Kobe Cavity pump with 400' of pert guns. 10. Correlation to place guns on depth. 11. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 12. Circulate pump out, fish standing valve and drop bar to fire perf guns. 13. Trip standing valve on seat, circulate pump in place, flow well. 14. Rig down and move off. 1 '-Or7 S ed a ri k it? DRILL ND COMPLETE PROCEDURE SUMMARY Pre -Rig Work: (- of AN -24) (Procedures are covered under P&A Sun. . �'� s �� Rig Operations: (Si. track An -24RD) \c, 1. RIH with whipstock tem set whipstock with MWD and displac- ell to OBM. 2. Mill window as per reco 'mended practices. _► f VT . b \I ∎..) 3. Directionally drill ahead t. D w/ 8.5" Directional Asse . Wiper trips will be performed as hole dictates. 4. RU Baker's Testrack (Forma Tester) and So ' and RIH for clean out run to TD and POOH. 5. Run and cement the 7 ", 29# P -11 .roducti• casing back to 200' inside the 9 -5/8" casing. Displace cement w/ diesel. 6. After setting the liner top packer circul- well clean reverse diesel throughout well. (� 7. Clean out 7" liner if required. Wc4 .\\ vsk\\ \r3(z. QrCcsS� - 5� Pt`°c- \c yekv4.5 8. Trip in with 2 7/8" by 2 3/8" d completio - ssembly with Kobe Cavity pump with 400' of pert guns. 9. Correlation to place guns • depth. 10. Nipple down the BOP- ipple up and test the tree 5000 psi. 11. Circulate pump ou sh standing valve and drop bar t. re pert guns. 12. Trip standing v- le on seat, circulate pump in place, flow ell. 13. Rig down an. ove off. 1 Halliburton BAROID Chevron Mud Program BAM.MW tli lJ Chevron AN -24 RD Anna Platform Baroid Mud Program Halliburton Baroid Name (Printed) Signature Date Originator Dave Soquet Reviewed by Dave Higbie Customer Approval Tim Flynn Version No: Date: 1.1 November 2, 2007 AN -24 RD v1.1 1 11/2/07 • 1 Halliburton BAROID Chevron Mud Program AN -24 RD Introduction: The following mud program was prepared for a sidetrack of the AN -24 well on the Anna platform. The dual completion will be pulled. The existing perforations will be plugged and abandoned. The well will then kick off out of the 9 -5/8" casing and 8 -1/2" hole will be drilled to TD at 11,800' MD (9963' TVD). A 7" liner will then be run, cemented and well completed with a dual completion. Seawater will be used to kill and decomplete the well. Prior to milling the window in the 9 -5/8" casing, the well will be displaced to a 9.0 ppg INVERMUL oil -based system. Recycled OBM from the GP -54 workover will be reconditioned for use on this well. Primary Drilling Objectives: • Zero fluid related HSE incidents • Maintain well control at all times • Achieve wellbore stability • Achieve good hole cleaning considering hole angle, geometry and anticipated ROP rates • Lost circulation mitigation /control • Achieve good Zonal Isolation as per plan • Achieve minimal formation damage • Minimize fluids related NPT • Minimize drilling wastes Critical Fluid Issues: • Maintain well control • Eliminating /controlling losses. • Maintaining a low ECD in the production zone to reduce risk of lost returns. • Maintaining a stable wellbore through coal seams. Well Specifics: Casing Program MD ND Footage 9 -5/8" casing (KOP @ 8160' MD) 8,209' 7,320' 0' 8 -1/2" hole ( 7" liner) 11,800' 9963' 3,398' AN -24 RD v1.1 2 11/2/07 Halliburton BAROID Chevron Mud Program Production Interval: (8 -1/2" hole, 7" Liner) to 11,558' MD Mud Type: Invermul System Mud Properties Density Viscosity PV YP ES HTHP FL WPS O/W 8160' — TD 9.0 55 - 80 18 -29 9 - 18 1000- <6 270 to 290K 80/20 1100 • Additional mud weight may be required for effective coal or shale stabilization. System Formulation: Recycled OBM from the GP -54 workover will be reconditioned for use on this well. Condition the used OBM to specifications as follows: Product Concentration Recycled Fluid 0.813 bbl EZ MUL NT 2 ppb INVERMUL 2 ppb Lime 3 ppb Water 0.127 bbl CaCl2 8.32 ppb BAROID to a 9.0 ppg Mud Type: INVERMUL System. 1. Mud weight: Begin with an initial mud weight of 9.0 ppg. If abnormal pressures exist or the well bore exhibits instability, increase the mud weight accordingly. Maximize solids control equipment. 2. Rheology: Maintain a YP between 9 and 18. Pump high viscosity or Barolift sweeps throughout the interval as needed, particularly prior to POH for liner. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this deviated wellbore. Maximize pipe rotation. 3. Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. Operations Summary: Seawater will be used to kill and decomplete the well. Prior to milling the window in the 9 -5/8" casing, the well will be displaced to a 9.0 ppg INVERMUL oil -based system. Approximately 900 bbl of oil mud will be required to displace the well and fill the pits. Prepare the pit system for the INVERMUL as follows: • Clean pits, solids control equipment, all lines and pumps. • Flush all lines with a small volume of oil and discard. • Disconnect all water lines to the pit area and rig floor. • Check all steam fittings in pit room for leaks and repair as needed. Prior to milling, displace the well to the INVERMUL system designated for this interval of the well. Pump a 25 bbl spacer ahead of the oil mud as follows: Spacer Formulation: • 20 barrels of the OBM treated with GELTONE to a YP > 30 (app. 4 -6 sx). Weight this pill to 2 ppg over the OBM weight. • Follow with INVERMUL mud system. AN -24 RD v1.1 3 11/2/07 +� • Halliburton BAROID Chevron Mud Program Displacement procedure: • Monitor pump strokes to obtain correct displacement. • Maintain maximum pump rates. • Have the bit on bottom as the oil mud exits the bit. • Reciprocate the drill string by one joint every 15 minutes • Rotate the pipe as rapidly as allowed during the actual displacement. • Do not shut down during the displacement. • Use an E.S. meter at the flow line to determine when the fluid is water free enough to start taking the returns back into the system. An ES of 300 -500 should be sufficient to indicate when displacement is complete. A retort should also be run at this time to confirm fluid quality. • Clean possum belly and any troughs which were used. Maintenance: 1. Additions of Geltone V and RM -63 will maintain /modify the system rheology to a YP between 9 and 18 to provide effective hole cleaning while controlling ECD and surge /swab pressures. 2. OMC 2 and OMC 42 will be available to condition (thin) the mud as required; however, caution should be used when using these oil mud thinners (particularly the OMC -2) to avoid over - thinning the system. 3. Drill this interval with a tight DURATONE HT / AK -70 filtration mechanism (< 6 cc /30 min @ 200° F). Barablok and Barotrol will also be available to improve the filtration control mechanism. 4. For formation bridging /LCM, graded calcium carbonate (Baracarb(s)), cellulose fiber material (Barofibre) and SteelSeal are available. 5. The electrical stability of the mud should be run in the 1000 -1100 volt range with INVERMUL and EZ MUL as the primary and secondary emulsifiers. DRILTREAT will be available as an effective wetting agent, if needed. 6. Maintain the water phase salinity between 270,000 — 290,000 mg /I range with sack calcium chloride. This level of salinity will provide an effective mechanism for good wellbore stabilization. 7. The excess lime content will be maintained in the 3 ppb range to provide an effective reserve alkalinity source and to improve the emulsion stability of the mud system. Suggested Drilling Parameters Pump rate and drill string rotation should be optimized through the real -time use of the DFG software for the actual ROP while drilling. The table below highlights the maximum ROP recommendations above which hole cleaning will become an issue. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM—> 350 450 550 60 rpm 138 182 214 80 rpm 174 231 269 100 rpm 188 257 317 Baroid recommends a flowrate in the 400 -450 gpm range to maximize solids - control efficiency while still maintaining good hole cleaning capabilities at elevated penetration rates. Pump rates above 550 gpm cause a sharp increase in ECD and should be avoided. ROP rates above these levels or with no (sliding) or low rpm will require an increased frequency of the following remedial hole cleaning practices: AN -24 RD v1.1 4 11/2/07 • Halliburton BAROID Chevron Mud Program • wiper trips • back reaming • extended periods of circulation (with maximum pipe rpm, targeting > 80 rpm) • hole cleaning sweeps (change flow regime of base mud by using fibers, density or rheology for carrying capacity) • connection practices - employing extended gpm, rpm and back reaming during the connection Sweeps p Two types of hole cleaning sweeps can be used: • Increase the sweep density with barite to 2 ppg over system density. • To reduce the density /viscosity build up in the system, sweeps can be built by adding 0.25 ppb BAROLIFT. The fibrous BAROLIFT will be removed at the shakers. Check with MWD personnel to ensure no plugging of tools will occur. Note: Properly size all sweeps for 300 - 400 ft of annular coverage Supplement the hole cleaning of the drilling fluid as dictated by hole cleaning indications. Monitor all sweeps pumped and report on their effectiveness. Maximize drill pipe rotation at high rates on a frequent basis (particularly during connections) to assist in disturbing any potential cuttings accumulations down - hole. The objective of the sweep is to change the flow characteristics / carrying capacity that are inherent with the mud system. Select sweep type accordingly. Coal Drilling The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The hole stability risks when drilling coal seams are often high, and the fluid design and drilling operations have been optimized to combine reduced risk with reduced costs. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt -type additives to further stabilize coal seams. • Increase fluid density as required to control the running coal. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. In the event that sloughing coal is encountered, consider spotting a 30 ppb BAROTROL /AK 70 pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss (based on ECD values using the DFG software). System density increases can also be employed in increments of 0.5 ppg. Solids Control Equipment Maximize the use of all solids control equipment to ensure that the solids content of the system is kept to a minimum during this interval. 1. Run the shale shakers with as fine a screen size as possible. • Size shakers screens with coarse mesh initially • Adjust screen size as solids loading, mud rheology and flowrates allow • Inspect the shakers frequently, taking time to repair / replace damaged screens 2. Maximize the use of the centrifuge, keeping the fluid as clean as possible. AN -24 RD v1.1 5 11/2/07 • Halliburton BAROID Chevron Mud Program Running Casing / Cementing Preparation Monitor hole fill /returns closely while running the liner to insure losses haven't occurred. Refer to Baroid's DFG+ program if calculated surge /swab values are needed. Condition the mud prior to the cement job. Displace the cement with base diesel oil — ensure availability. Production Hole - Hazards / Concerns: • Optimize solids control equipment to minimize colloidal solids build up and dilution requirements. • Maintain flow profile based on PV, YP and tau flow parameters. • Pump sweeps as required to enhance hole - cleaning efforts. Monitor the effectiveness of any sweeps pumped. No sweeps have been needed in this hole section to date. • Follow the hole cleaning guidelines to assist in drilling parameter selection. Use connections for high RPM and pump rate support when these parameters are limited during drilling operations. • Follow the coal drilling guidelines. Estimated Fluid Costs: P10 P50 P90 8 -1/2" Intermediate 230,000 278,000 565,000 Total $230,000 $278,000 $565,000 AN -24 RD v1.1 6 11/2/07 • • Halliburton BAROID Chevron Mud Program Losses Chevron Lost Circulation Decision Tree fl Payzone Mud Systems ♦ 4 4 Seepage Partial Severe Total 20.60 bbllhr 5 -20 bbllhr Static Static 60-200 bbllhr Static > 200 bbllhr Static i * Treat Active System Treat Active System + + V with 5 sx/hr Baracarb with 10 sxlhr Baracarb 160 -150 bbl/hr Static 1150 -200 bbllhr Static' I Drill Across Fault 1 50/150 150 4' + + Drill Across Fault I Drill Across Fault Pump reverse gunk l squeeze pill to allow �ynami Dynamic 100 ppb LC IMud Pill: POH (Volume to be Losses < 15 Yes < 15 Y 20 ppb Baroseal f Pump reverse determined based bbl/hr bbl/hr 20 ppb Baracarb 50 gunk squeeze pill upon losses + 30 ppb Barofibre to allow POH i Drill Ahead Drill Ahead 20 ppb SteelSeal (Volume to be Contact Drilling No 10 ppb Baracarb 150 * No determined based Engineer or Engineer Increase Treatment to 7 4, upon losses) on call 10 sx/hr Baracarb 50/ 50 ppb LCMIMud Pill: Contact Drilling Engineer or 150 Engineer "On Call" • 20 bbls Base mud • 10 ppb Baracarb 25 Contact Drilling Engineer 20 ppb Baracarb 50 or Engineer on call Iynamic y 20 ppb Baracarb 150 • Losses < 15 Yes Plan to pump a second bbl/hr 50-80 bbl reverse gunk Drill Ahead • squeeze pill if massive No losses continue. v Pump reverse Consider cement / 20 ppb LCMIMud Pill: Dynamic gunk squeeze pill plugback contingency Losses < 20 Yes (Volume to be 20 bbls base mud bbl/hr j determined based 10 ppb Baracarb 50 Drill Ahead upon losses 10 ppb Baracarb 150 No i Contact the Engineer 1)Chevron must approve any steps past PARTIAL losses. on call to detemline if 2) Doll across fault or loss zone 1.5.2.0 times the length of the a dditional LCM throw before spotting reverse gunk squeeze pills. Dynamic 3) PBL sub should be run in BHA to spot pills if 'Partial Loss' cases or Losses < 15 Yes treatments are to be above are anticipated poor to drilling to allow the spotting of LCM bbl/hr 1 made or to proceed to pills. reverse gunk squeeze 4) LCM pill volume = 300'-600' column based upon actual hole Drill Ahead pill diameter. 5)PRIOR TO ANY LCM PILL APPROPRIATE DISCUSSIONS AT No THE RIG MUST BE MADE TO MINIMIZE THE POTENTIAL FOR * PLUGGING THE DRILL STRING. Proceed to 'Partial Losses' Pill I AN -24 RD v1.1 7 11/2/07 Halliburton BAROID Chevron Mud Program Reverse Gunks (OBM) Description This is the reverse procedure compared with ordinary Gunks. Typically, organophilic clay is mixed into an aqueous suspension and pumped down the drill pipe. The oil mud is pumped simultaneously down the annulus and gelation occurs when the two fluids meet. The gunk is squeezed into the formation. Note that it is not possible to add cement to strengthen the pill (unlike DOB2C used for WBM applications). Benefits: • Temperature is not very important • Soft set avoids sidetracking problems (easy to wash /drill out) • Slurry will pass through most BHAs • Procedures are well established • Suitable for large fractures /voids Limitations: • Placement — need to generate gunk in the right place • Suitable experience required • Avoid premature mud contamination • Mixing time /placement often greater than 6hrs • Effect can be short -lived due to soft plug formed • The type of clay used to make the treatment can be quite critical Procedures: Formulations (per 1 bbl) Formulation for "Unweighted Rev erse" Cunt: Pill Water 0.66 bbl Caustic Soda 1.51b Dispersant (Desco CF) 3.5 lb Organophilic clay (Geltone) 2501b This formulation is provided as a guide only. The yield obtained will vary greatly dependant on the particular clay used. Pilot testing of the pill formulation is strongly recommended. The formulation given above will have a density of approximately 11.0 ppg. The slurry density can be increased to that of the active mud weight by viscosifying the water /clay slurry with XC polymer and adding barite. Formulation for "Weighted 13.0 ppg Rev erse" Gunk Pill Water 0.63bb1 Caustic Soda 1.51b Dispersant (Desco CF) 4.01b Organophilic clay (Geltone) 1501b Barite 1751b AN -24 RD v1.1 8 11/2/07 • • Halliburton BAROID Chevron Mud Program Mixing / Displacement Procedure The pill should preferably be prepared in the cement batch tank. Ensure that the batch tank and all associated lines are clean by flushing thoroughly with a water based rig wash followed by large volumes of water. Add the ingredients in the order shown utilising as much shear as possible to disperse the organophilic clay (Geltone). A pill of approximately 30bbI is recommended. The resultant slurry is preferably pumped through open ended pipe but may be pumped through the bit if it is not practicable to POOH. The following displacement procedure should be strictly followed to prevent gelation within the drill pipe. Before the displacement the string should be pulled back to a height sufficient to leave the pill volume of open hole. 1. Pump 10bbI diesel base fluid 2. Pump 10bbI water 3. Pump the slurry (30bbI) 4. Pump 10bbI water 5. Pump 10bbI diesel base fluid 6. Displace the pill to the bottom of the drill string 7. If the hole is full, close the annular and squeeze at 300 — 500 psi into the formation 8. If the hole is full, close the annular and pump the pill at 1 bbl /min down the drill pipe and mud at 1 bbl /min down the annulus. 9. Allow at least 4 hours for the plug to set. Note: Ensure that the entire pill is pumped out of the string. Do not attempt to reverse circulate. AN - RD v1.1 9 11/2/07 • • Halliburton BAROID Chevron Mud Program Production Hole Cleaning Modeling 'Operatoramon Rig 428 INVEPMUL 1,522ZCulligTod :onhalorNahcss Wet 424RD F fide-4500w fide-4500w POP =100 Itk 1.5067. CullrgEB Cu4tr Ttampod image Hats ECD MudWei¢1= 9.41Ngal *Da. Load,X EHavgZ 4,I1/aan Ards algal H1 s @1001Uhi490 rpm 1HG33ipn5m /C=3m1 CEO f � tr y ro � o 100)' 1 8.8350 Aril �' 1202.011231 GIN — 6 962919148 bled A100� 3110= 8,8350 43 410801 4.OIfl 961619.819 bagel 5000 4.x134x106900fJ ,w= 1000 .au 88350 moo 11235 O1fl A --, 965519. ',to — I 9000 850 9160.01'rn1 - 10000— 214 9„ 119. t, I6lgal 11000 2563 x660O8 850 H C 118. 0[1110]fl — y6.75x2813x200081 1 111330 9101 19.:0 blgal 5 10 15 20 25 0 50 100 0 201 113 33 60 90 940 9,90 10.40 1,74 UT Irne Baroid recommends a flowrate in the 400 -450 gpm range to maximize solids - control efficiency while still maintaining good hole cleaning capabilities at elevated penetration rates. Pump rates above 550 gpm cause a sharp increase in ECD and should be avoided. AN -24 RD v1.1 11/2/07 Chevron 0 0 Ir/,lig ■golo C hevron BAKER °1110. Location: Cook Inlet, Alaska (Offshore) Slot: slot #2 -3 INTEQ NY6NES Field: Granite Point Field Well: AN -24 Facility: ANNA Platform Wellbore: AN -24RD Plot reference wellpath is An -24Rd Version 14 True vertical depths are referenced to Anna Rig _ (RT) Grid System: NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Anna Rig _ (RT) North Reference: True north Anna Rig _ (RT) to mean sea level: 114 feet Scale: True distance mean sea level to Mud line (Facility - ANNA Platform): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: ulricard on 11/1012007 Well Profile Data Design Comment MD (ft) Inc ( °) Az ( °) TVD (ft) Local N (ft) Local E (ft) DLS ( ° /100ft) VS (ft) Tie On 8209.00 31.370 343.058 7338.19 3256.26 - 750.74 0.00 3163.12 End of WS 8229.00 33244 339.722 7355.10 3266.38 - 754.15 12.93 3173.53 End Drop -Tum 8943.95 11.941 332.388 8011.49 3518.69 - 857.56 3.00 3442.48 Begin Build Tum 9557.39 11.941 332.388 861166 3631.16 - 916.39 0.00 3569.05 End Build Tum 11260.71 74.446 275.921 9819.00 3905.00 - 1937.40 4.00 4339.77 End of Tangent 11689.58 74.446 275.921 9934.00 3947.62 - 2348.36 0.00 4592.54 TI) 11800.00 74.446 275.921 9963.61 3958.60 - 2454.17 0.00 4657.62 • 0 6750,- Targets Noma MO (6) TVD (a) Local 6 (a) Loc.) 5 (3) Oro E.0 (1156) end Norm (1151) L0604. Longitude • An24R47er9et Bae C-70 24-0.742007 981890 385493 - 193740 26499700 2555245.00 90 5914.92e5 151 24.4235W 06064144 Target TOp C55 24-01-2007 11609.58 993400 394762 - 2349.36 26458800 255534660 60 59' 15.109 151'1032.754'45 a • 7000 Hole and Casing Sections i Start End Start End 51en titan End End Name MD (10 MD (ft) Interval (6) TVD (6) TVD (6) Local N (ft) Local E (ft) Local N (6) Lech E (n) Welber* 30in Casing 9.00 28100 272.00 900 28100 0.00 0.00 '0.85 417 604-24 20in Casing 900 61800 60900 900 61795 0.00 0.00 -3.05 .591 06-24 7250 - 9.625in Casing Surface :31.37° Inc, 8209.0011 MD 13376n0asing 800 2009.00 200000 9.00 196337 0.00 0.00 261.59 -88.11 064-24 Tie On : 31.37° Inc, 8209.00ft MD, 7338.19ft TVD, 3163.12ft VS 96250 Caning Surface 900 9208.00 8700.00 800 1330.19 0.00 6.00 3250.26 456.74 AN -24 8.5in Open Nola 8209.00 11000.00 359100 733919 996381 3256.26 - 75074 3958.60 4454.17 06-2450 70 Liner 800900 11800.00 3791.00 716792 996391 3155.67 - 720.82 3958.60 - 2454.17 95-2460 7500 • .00 °/1 00ft N 7750 - , \ c , 9.625in Casing Surface : 31.04° Inc, 8712.00ft MD, 7769.15ft TVD, 3600.31ft VS 1e(n ■ 8000 m En• • rop -Turn : 11.94° Inc, 8943.95ft MD, 8011.49ft TVD, 3442.46ft VS 9GGId (1945.0 to 20090) Dip: 73.77' Field: 55581.5 nT Magnetic North in 19.10 degrees East of True North (at 12/10/07) To correct azimuth from Magnetic to True add 19.10 degrees iR 8250 - r 0. 0 D To; 8500 7 E Begin Build Tur • : 11.94° Inc, 9557.39ft MD, 8611.66ft TVD, 3569.05ft VS 0) 2 8750 - I- 9000 - 9250 - 4.00 9500 - 9750 �_�_ End Build Tum : 74.45° Inc, 11260.71ft MD, 9819.00ft TVD, 4339.7711 VS An24Rd Target Base C -7D 24- Oct -200 1 7in Liner : 74.45° Inc, 11800.0011 MD, 9963.61ft TVD, 4657.6211 VS 10000 An24Rtl Target Top C -5A 24- Oct -2007 /IA, .24R TD : 74.45° Inc, 11800.00ft MD, 9963.61ft TVD, 4657.62ft VS 10250 1 1 1 1 1 1 1 1 1 1 1 1 1 1 3000 9250 3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 6000 8250 Vertical Section (ft) scam 1 inch = 500 ft Azimuth 328.20° with reference 0.00 N, 0.00 E from wellhead • • Chevron C hevron BAKER � Location: Cook Inlet, Alaska (Offshore) SIDt: slot #2 -3 .IUGNES F ield: Granite Point Field Well: AN -24 INTEQ Facility: ANNA Platform Wellbore: AN -24RD Plot reference wellpath is An -24Rd Version 14 V True vertical depths are referenced to Anna Rig _ (RT) Grid System: NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Anna Rig _ (RT) North Reference: True north Anna Rig _ (RT) to mean sea level: 114 feet Scale: True distance mean sea level to Mud line (Facility - ANNA Platform): 0 feet Depths are in feet • Coordinates are in feet referenced to Slot Created by: ulricard on 11/10/2007 • Targets Name MD (ft) TVD (ft) Local N (ft) Local E (ft) Grid East (USft) Grid North (USft) Latitude Longitude An24Rd Target Base C -7D 24- 000-2007 9819.00 3854.83 - 193740 264997.00 2555245.00 80° 59' 14.926 "14 151° 19' 24.423"W An24Rd Target Top C -5A 24- Oct -2007 11689.58 9934.00 3947.62 - 2348.36 264588.00 2555346.00 60° 59' 15.839 "14 151° 19' 32.754"W Hole and Casing Sections Start End Start End Start Start End End Name MD (ft) MD (ft) Interval (ft) TVD (ft) TVD (ft) Local N (ft) Local E (ft) Local N (ft) Local E (ft) Wellbore 30in Casing 9.00 281.00 272.00 9.00 281.00 0.00 0.00 -0.65 -1.17 AN -24 20in Casing 9.00 618.00 609.00 9.00 617.95 0.00 0.00 -3.05 -5.91 AN -24 13.375in Casing 9.00 2009.00 2000.00 9.00 1963.37 0.00 0.00 261.59 -68.11 AN -24 9.625in Casing Surface 9.00 8209.00 8200.00 9.00 7338.19 0.00 0.00 3256.26 - 750.74 AN -24 8.5in Open Hole 8209.00 11800.00 3591.00 7338.19 9963.61 3256.26 - 750.74 3958.60 - 2454.17 AN -24RD 7in Liner 8009.00 11800.00 3791.00 7167.92 9963.61 3155.67 - 720.92 3958.60 - 2454.17 AN -24RD a ai = efr Easting (ft) -3400 eO -3200 -3000 -2800 -2600 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 1 1 1 1 1 1 1 1 1 1 1 1 1 1 r 4800 N rrtue _ 4� �� r. 6 0 ( 1 9 4 1 . 0 0 0 2 0 0 0 0 ) Olp'. 73.77 Field: 55581.5 nT ® 4400 Magnetic North 9 19.10 degrees East of True North (at 12/10107) OG1 2o01 To o correct azimuth from Magnetic to true add 19.10 degrees G yP 2 A' 0 2 00 -coy 2A a,0 ` a s e 0.10 - 4200 0 P� 2AF � 6 1%e ) P • - 4000 z AN -24RD 0 3 2464.1715 W 3g59 601' N - 2 g5 4 1 - - 7 Ivo, W 996tt ND. 395g N, -V N -2348'361°14 23g8361c - 3800 43 TD 9 9 6 3.6 39 4 a E ^d of ja ^ gent 99 °91t O �O• 1g 37 40tt Y,1 - Tin 39p6 ODft N OOtt Begin Build Turn : 8611.66ft TVD, 3631.16ft N, - 916.39ft W - 3600 • 981 9 ' B�Ud jum Eend End Drop -Turn : 8011.49ft TVD, 3518.69ft N, - 857.56ft W S?' - 3400 Tie On : 7338.19ft TVD, 3256.26ft N, - 750.74ft W.'\ - 3000 • 0 Chevron Viral %SO Planned Wellpath Report BAKER An-24Rd Version 14 HUGHES 4400 Page 1 of 4 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron Slot slot #2-3 Area Cook Inlet, Alaska (Offshore) Well AN-24 Field Granite Point Field Wellbore AN-24RD Facility ANNA Platform Sidetrack from AN-24 at 8169.00 MD REPORT SETUP INFORMATION Projection System NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Software System WellArchitectTM 1.2 North Reference True User Ulricard Scale 0.999962 Report Generated 11/10/07 at 11:43:18 Wellbore last revised 09/05/07 Database/Source file WA_Anchorage/AN-24RD.xml . , , _ . _ •. . , , _ — WELLPATH LOCATION Local coordinates Grid coordinates -.) Geographic coordinates North [feet] East [feet] Easting [US feet] Northing [US feet] Latitude [ Longitude [ Slot Location -789.01 -594.01 266856.72 . 2551352.29 / 60 58 36.968N 151 18 45.150W Facility Reference Pt 267466.35 2552129.24 60 58 44 738N 151 18 33.113W Field Reference Pt 267571.89 2557407.98 60 59 36.731N , 151 18 33.112W WELLPATH DATUM Calculation method Minimum curvature Anna Rig (RT) to Facility Vertical Datum 114.00 feet .---- Horizontal Reference Pt Slot Anna Rig (RT) to mean sea level 114.00 feet Vertical Reference Pt Anna Rig _ (RT) Facility Vertical Datum to Mud Line (Facihty) 000 feet MD Reference Pt Anna Rig _ (RT) Section Origin N 0.00, E 000 ft Field Vertical Reference mean sea level Section Azimuth 328.20° 0 • Chevron 1011111 Planned Wellpath Report An-24Rd Version 14 BAKER HUGHES 11111110 Page 2 of 4 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron Slot slot #2-3 ' Area Cook Inlet, Alaska (Offshore) Well AN-24 Field Granite Point Field Wellbore AN-24RD Facility ANNA Platform Sidetrack from AN-24 at 8169.00 MD WELLPATH DATA (75 stations) t = interpolated/extrapolated station MD Inclination Azimuth TVD TVD from Vert Sect North East : Grid East Grid North , DLS [feet] [ [ [feet] Fld Vert Ref [feet] [feet] [feet] [us survey feet] [us survey feet] [°/100ft] [feet] 0.00t 0.000 0.000 0.00 -114.00 0.00 0.00 0.00 26685612 2551352.29 0.00 i 9.00 0.000 0.000 9.00 -105.00 0.00 0.00 0.00 266856.72 2551352.29 0.00 530.00 1.080 241.000 529.97 415.97 0.24 -2.38 -4.29 266852.38 2551350.00 0.21 ' , 959.00 2.000 279.000 958.82 844.82 5.33 -3.17 -15.22 266841.44 2551349.43 0.31 1029.00 2.750 319.010 . 1028.76 914.76 7.78 - 1.71 - 17.53 = 266839.16 =. 2351350 93 2.53 1151.00 7.000 325.000 1150.29 1036.29 18.10 6.59 -23.72 266833.14 2551359.35 3.50 i 1211.00 , 8.500 337.000 1209.75 1095.75 26.13 13.67 -27.55 266829.45 2551366.51 3.66 1304.00 11.000 350.000 1301.41 1187.41 41.17 28.74 -31.78 266825.53 2551381.66 3.57 1414.00 14.250 353.000 1408.74 1294.74 63.21 52.52 -35.25 26682253 2551405.50 3.01 1742.06 21.560 351 1.n0.70 1606.70 155.39 152.08T 149.54 266810.19 255/505.53 = 2.221 1989.00 27.250 350.000 1945.59 1831.59 249.70 252.56 -66.51 266795.29 2551606.13 2.33 2252.00 27.750 348.000 2178.88 2064.88 363.22 371.75 -89.69 266774.49 2551725.75 0.40' 2679.00 26.250 348.000 2559.33 244533 545.61 561.37 -130.00 266738.00 2551916.12 0.35 2862.00 25.500 347.000 2723.98 2609.98 620.98 639.33 -147.27 266722.29 2551994.42 0.47 3174,00 28,000 346,000 3002,57 == 754.31. 775.86 i -180.10 * 266692.20 , .2552131,57 3480.00 30.000 343.000 3270.20 3156.20 896.69 918.73 -219.85 266655.32 2552275.20 0.81 " 3635.00 30.250 348.000 3404.29 3290.29 970.90 993.99 -239.30 266637.38 2552350.83 1.63 3754.00 29.000 355.000 3507.76 3393.76 1024.87 1052.07 -248.05 266629.80 2552409.07 3.09 '. 4112.00 27.750 353.000 3822.75 3708.75 1178.00 1221.25 -265.77 ' 266615.47 2552578.57 0.44 4298.00 27.250, 353000' 3987.73 3873.73 1255.97 1306.50 ' - 276.24 I 266606.72 25 , 011 4693.00 28.500 351.000 4336.90 4222.90 1424.95 1489.34 -302.00 ' 266584.62 2552847.32 0.40 4951.00 29.750 351.000 4562.28 4448.28 1540.71 1613.37 -321.65 266567.47 2552971.71 0.48 5333.00 28.000 348.000 4896.79 4782.79 1712.48 1794.71 -355.12 266537.63 2553153.68 0.59 5739.00 27.000 347.000 5256.91 5142.91 1889.40 1977.73 -395.67 266500.76 2553337.47 0.27 5991.00 29.650 346.000 5419.41 536541 2001.72 = 2092.15 ! = - 423.32 i 266475.42 '2$53453.02j 0$2 6055.00 29.750 346.000 5535.18 5421.18 2031.61 2123.22 -430.91 266468.44 2553483.63 1.17 6424.00 33.000 345.000 5850.18 , 5736.18 2215.03 2309.16 -479.08 266424.01 2553670.49 , 0.89 ; 6791.00 35.000 345.000 6154.42 6040.42 2411.49 2507.38 -532.20 266374.88 2553869.73 0.54 ‘. , 7069.00 34.000 345.000 6383.53 6269.53 2562.23 2659.48 -572.9D ' 266337.18 2554022.60 0.36 = 7380.00 34.000 344000 6641.36 6527.36 2729.15 282705 - 619.42 = 266294.07 = - 2554191.07 ' . 0.181 7586.00 34.000 343.000 6812.14 6698.14 2840.26 2937.50 -652.14 266263.58 2554302.15 0.27 7856.00 32.250 342.000 7038.26 6924.26 2983.22 3078.22 -696.47 ' 266222.07 2554443.72 0.68 8169.00 31.500 344.000 7304.06 7190.06 3143.01 3236.25 -744.82 ' 266176.90 2554602.68 0.41 8209.00 31.370 343.058 7338.19 7224.19 3163.12 3256.26 -750.74 266171.39 2554622.80 0.00 i 8229.00 ' 33.244 339.722 = 735510 7241 10 317333 326638 = - 75415 266168.i7 ' - 255463299 1293 8309.00f 30.850 339.384 7422.90 7308.90 3215.14 3306.15 . -768.98 266154.15 2554673.05 3.00 8409.00f 27.860 338.888 7510.05 7396.05 3263.27 3351.96 -786.43 266137.62 2554719.19 3.00 8509.00f 24.872 338.284 7599.64 7485.64 3306.94 3393.30 -802.63 266122.26 2554760.85 3.00 8609.00f 21.887 337.527 7691.42 7577.42 3346.05 3430.07 -817.54 266108.09 2554797.91 3.00 8709.1 lOt 18.907' - 336.544 = 7785.14 = = 7611.14 3380.48 = 3462,16 i 431.11 = 26609546 255483627 ' =, 300 • Chevron WP PAWS Planned Wellpath Report An-24Rd Version 14 BAKER HUGHES 110 Page 3 of 4 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron Slot slot #2-3 Area Cook Inlet, Alaska (Offshore) Well AN-24 Field Granite Point Field Wellbore AN-24RD Facility ANNA Platform Sidetrack from AN-24 at 8169.00 MD WELLPATH DATA (75 stations) t= interpolated/extrapolated station MI) Inclination Azimuth TVD TVD from Vert Sect North East Grid East Grid North DLS [feet] [O] [1 [feet] Fld Vert Ref [feet] [feet] [feet] [us survey feet] [us survey feet] r/100ft] [feet] 8809.00f 15.933 335.209 7880.54 7766.54 3410.14 3489.49 -843.32 266083.50 2554857.84 3.00 8909.00? 12.972 333.282 7977.37 7863.37 3434.95 3511.98 -854.12 266073.15 2554880.54 3.00 8943.95 11.941 332.388 8011.49 7897.49 3442.46 3518.69 -857.56 266069.84 2554887.31 3.00 9009.00f 11.941 332.388 8075.13 7961.13 3455.89 3530.62 -863.80 266063.85 2554899.36 0.00 9109.00 11.941 332.188 8172.97 805897 3476.52 3548.95 - 873.39 26605401 2554917, 0.00 9209.00f 11.941 332.388 8270.81 8156.81 3497.16 3567.29 -882.98 266045.41 2554936.40 0.00 9309.00f 11.941 332.388 8368.64 8254.64 3517.79 3585.62 -892.57 266036.19 , 2554954.93 0.00 9409.00f 11.941 332.388 8466.48 „ 8352.48 3538.43 3603.95 -902.16 266026.97 2554973.45 0.00 9509.00f 11.941 332.388 8564.32 8450.32 3559.06 3622.29 -911.75 266017.75 2554991.97 0.00 9557.39 11 3323 8611:66 849766, 3569.05 3631.16 26601328 - 2555000 93 400! 9609.00? 13.096 324.481 8662.04 8548.04 3580.21 3640.65 -922.26 266007.60 2555010.54 4.00 9709.00f 15.861 312.847, 8758.88 8644.88 3604.70 3659.17 -938.87 265991.37 2555029.39 4.00 ' 9809.00f 19.059 304.802 8854.27 8740.27 3632.87 3677.79 -962.30 265968.31 2555048.47 4.00 I 9909.00f 22.507 299.068 8947.76 8833.76 3664.59 3696.42 -992.45 265938.55 , 2555067.70 4.00 10009.00 26.107 294.817 9038.89 8924.89 3699.69 371496 - 1029.17 26590221 255508697 4.00 10109.00f 29.802 291.543 9127.21 9013.21 3738.02 3733.33 -1072.27 265859.49 2555106.20 4.00 10209.00f 33.561 288.938 9212.30 9098.30 3779.37 3751.43 -1121.55 265810.58 2555125.28 4.00 10309.00f 37.366 286.805 9293.74 9179.74 3823.55 3769.18 , -1176.77 265755.74 „ 2555144.13 4.00 10409.00f 41.202 285.014 9371.12 9257.12 3870.35 3786.49 -1237.65 265695.21 2555162.66 4.00 10509 45.062 283.480 9444.09 i., 9330.09 3919.53 3803.28 - 1303.91 - - 2 2 5 55 11 ' ,1,77 4 .1* 10609.00? 48.940 282.139 9512.28 9398.28 3970.86 3819.47 -1375.21 265558.34 2555198.38 4.00 10709.00? 52.832 280.948 9575.35 9461.35 4024.08 3834.97 -1451.22 265482.66 2555215.40 4.00 10809.00? 56.735 279.874 9633.01 9519.01 4078.94 3849.71 -1531.56 265402.64 55231.75 4.00 10909.00? 60.646 278.892 9684.97 9570.97 4135.17 3863.62 -1615.84 265318.66 2555247.35 4.00 11109.00 64.564 277.983 973097 9616 97 4192.50 3876 65 4703.65 265231.13 ; 255526212 4.180 11109.00? 68.487 277.131 9770.80 9656.80 4250.64 3888.69 -1794.56 265140.49 2555275.98 4.00 11209.00? 72.414 276.324 9804.25 9690.25 4309.32 3899.71 -1888.12 265047.16 ' 2555288.89 4.00 11260.71 74.446 275.921 9819.00 9705.00 4339.77 3905.00 -1937.40 264998.00 2555295.16 4.00 11309.00? 74.446 275.921 9831.95 9717.95 4368.24 3909.80 -1983.67 264951.84 2555300.88 0.00 , 1140900 74.446 275.921' 9858.76 9144.76; 4427.17 391914 - 2079.50 264856.24 255531274 0.00 11509.00? 74.446 275.921 9885.58 9771.58 4486.11 3929.68 -2175.32 264760.63 2555324.59 0.00 11609.00? 74.446 275.921 9912.39 9798.39 4545.05 3939.61 -2271.15 264665.03 2555336.45 0.00 11689.58 74.446 275.921 .143414J01 i 9820.00 4592.54 394742 .41481'16 264588.00 2555346.00 0.00 11709.00? 74.446 275.921 9939.21 9825.21 4603.99 3949.55 -2366.97 264569.43 255534830 0.00 11800,00 - 74.446 275.921 9963.61 9849.61 4657.62 395800 -245 26448243 2555359A9 , tUJO Chevron 0 0 irll IWO Planned Wellpath Report BAKE An-24Rd Version 14 R HUGHES NINO Page 4 of 4 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron Slot slot #2-3 Area Cook Inlet, Alaska (Offshore) Well AN-24 Field Granite Point Field Wellbore AN-24RD Facility ANNA Platform Sidetrack from , AN-24 at 8169.00 MD HOLE & CASING SECTIONS Ref Wellbore: AN-24RD Ref Wellpath: An-24Rd Version 14 , String/Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W End N/S End E/W [feet] [feet] [feet] [feet] [feet] [feet] [feet] [feet] = [feet] .30in Casing 9.00 281.00 272.00 9.00 281.00 0.00 0.00 -0.65 -1.17, 20in Casing 9.00 618.00 609.00 9.00 617.95 0.00 0.00 -3.05 -5.91; 13.375in Casing 9.00 2009.00 2000.00 9.00 1963.37 0.00 0.00 261.59 -68.11 , 9.625in Casing Surface 9.00 8209.00 8200.00 9.00 7338.19 0.00 0.00 3256.26 -750.74 --i 8.5in Open Hole 8169.00 11800.00 3631.00 7304.06 9963.61 3236.25 -744.82 3958.60 -2454.17; Tin Liner 8009.00 11800.00 3791.00 7167.92 9963.61 3155.67, -720.92 3958.60 -2454.17; TARGETS Name MD TVD North East Grid East Grid North Latitude Longitude ' Shape : [feet] [feet] [feet] [feet] [us survey [us survey [0] [01 feet] feet] An24Rd Target Base C 24 9819.00 3854.83 -1937.40 264997.00 2555245.00 60 59 14.926N 151 19 24.423W rectangle .-. ,Oct-2007 '1) An24Rd Target Top C-5A 24- 11689.58 8930L083941,62 4348,36 264I8t OOt -- ,- ,* 0,60 * ifit3ONlit 1 Oct-2007 SURVEY PROGRAM Ref Wellbore: AN-24RD Ref Wellpath: An-24Rd Version 14 = Start MD End MD Positional Uncertainty Model Log Name/Comment Wellbore [feet] [feet] 9.00 8209.00 Photomechanical Magnetic (Standard) AN-24 8209.00 10009.00AutoTrak G3 (MagCorr) AN-24RD 10009.00 11800.00AutoTrak G3 (MagCorr) AN-24R1) . , . 0,_ • • Chevron Actual Wellpath Report BAKER E R r /4110. MSS <0- 10400'> HUGHES Page 1 of 3 INTEQ REFERENCE WELLPATH IDENTIFICATION (,Operator [Chevron Slot [slot #2-3 Area Cook Inlet, Alaska (Offshore) Well ; AN -24 — __ .___ Field Granite Point Field Wellbore AN -24 'Facility 'ANNA Platform REPORT SETUP INFORMATION 1Projection System NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet ", € Software System WellArchitectTM 1.2 North Reference 'True - User Ulricard 'Scale 0.999962 Report Generated ;11/09/07 at 13:15:04 Wellbore last revised [10 /26/07 Database /Source file!WA _Anchorage /AN- 24.xml # WELLPATH LOCATION 1 Local coordinates j Grid coordinates I Geographic coordinates North [feet] 1 East [feet] 1 Easting [US feet] Northing [US feet] Latitude [ Longitude [ °] _ Slot Location - 789.01 - 594.01 266856.72 - 2551352.29 ,., 60 58 36.968N 151 18 45.150W 'Facility Reference Pt I 26746635 2552129.24 1 60 58 44.738N 1 151 18 33.113W �Field Reference Pt 267571.89 2557407.98 60 59 36.731N ' 151 18 33.112W WELLPATH DATUM Actual Datum (RKB) to Facility Vertical 'Calculation method Minimum curvature ;105.00 feet •Datum 'Horizontal Reference Pt Slot Actual Datum (RKB) to mean sea level 1105.00 feet 'Vertical Reference Pt Actual Datum (RKB) Facility Vertical Datum to Mud Line (Facility) ; 0.00 feet [MD Reference Pt 'Actual Datum (RKB) Section Origin N 0.00, E 0.00 ft [Field Vertical Reference mean sea level iSection Azimuth 346.28° • • Chevron Actual Wellpath Report BA R ■ MSS <0- 10400'> HUGHES Page 2 of 3 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator IChevron Slot slot #2 - Area Cook Inlet, Alaska (Offshore) Well AN -24 Field Granite Point Field Wellbore AN -24 Facility ANNA Platform j I WELLPATH DATA (46 stations) MD Inclination Azimuth ! TVD TVD from Vert Sect North East Grid East Grid North DLS [feet] i [ °] 1 [°] [feet] Fld Vert Ref [feet] [feet] [feet] [us survey feet] [us survey feet] [ %100ft] [feet] 0.00 0.000 0.000 0.00 - 105.00 0.00 0.00 0.00 266856.72 2551352.29 0.00 521.00 1.080 241.000 520.97 415.97 - 1.29 - 2.38 -4.29 266852.38 2551350.00 0.21 950.00 !__ 2.000 279.000 949.82 844.82 0.53 -3.17 - 15.222 266841.44 2551349.43 0.31 1020.00 2.750, 319.000 1019.76 914.76 2.50 -1.71 -17.53 266839.16 2551350.93 2.53 • t 7 325.000 1141.29 1036.29 12.03 6.59 -23.72 266833.1 < 1 _,_ '.35 3.50 F 1202.00 r 8.500, 337.000 1200.75 1095.75 19.81 13.67 - 27.55 266829.45 2551366.51 3.66 1295.00 11.000 350.000 1292.41 1187.41 35.46 28.74 -31.78 266825.53 2551381.66 3.57 1405.00 14.2501 353.000 1399.741 1294.74 59.38 52.52 -35.25 266822.53 2551405.50 3.01 1733.00 I 21.500 351.000 1711.70' 1606.70 159.51 1 152.08 ! -49.59 266810.19 2551505.33 2.22 m,';3 t ° 350.000 1936.59 1831.59 261.13 252.56 -66.51 266795.29 2551606.13'. 2243.00 27. 750 348.000 2169.88 2064.88 382.42 371.75 - 89.69 266774.49 2551725.75 0.40 2670.00 26 .250 348.000 2550.33 2445.33 576.18 561.37 -130.00 266738.00 2551916.12 0.35 2853.00 25.500 347.000 2714.98 2609.98 656.02 639.33) -147.27 266722.291 2551994.42 0.47 3165.00 28.000; 346.000 2993.57 2888.57 796.43 775.86 - 180.10 266692.201 2552131.57 0.81 30,00P , 343.000 3261.20 3156.20 944.66 918,73 - 219.85 2666 2552275.20 ; 0.81 3626.00 30.250 348.000 3395.29 3290.29 1022.39 993.99 - 239.30 266637.38 2552350.83 li 1.63 V4 3745.00 ! 29.000 355.000, 3498.76 3393.76 1080.88 1052.07 - 248.05 266629.80 2552409.07 3.09 4103.00 ; 27.750 353.000' 3813.751 3708.75 1249.44 1221.25 - 265.77 266615.47 2552578.57 0.44 289.00 27.250 353.000 3978.73 3873.73. 1334.73 1306.50 - 276.24 1 266606.72 2552664.00 0.27 11- 4684.00 28.500 351.000 4327.90 4222.90 1518.47 1489.34 - 302.00 266584.62 2552847.32 0. 4942.00 29.7501 351.000 4553.28 4448.28 1643.62 1613.37 - 321.65 266567.47 2552971.71 0.48 1 5324.00 28.000 348.000 4887.791 4782.79 1827.72 1794.71 i -355.12, 266537.63 2553153.68 0.59 5730.00 27.000 347.000 5247.91 5142.91 2015.141 1977.73 - 395.67 r 266500.76 2553337.47 0.27 1 29.000 346.000 5470.41 5365.41 2133.44 2092.75 - 423.32 266475.42 2553453.02 0.82 6046.00 29.750 346.000 5526.18 5421.18 2164.83 2123.22 - 430.91 266468.44 6415.00 ; 33.000 345.000, 5841.18 5736.18 2356.90 2309.16 - 479.08 266424.01 1 2553670.49 0.89 1 6782.00 35.000 345.000' 6145.42 6040.42 ' 2562.06 2507.38 - 532.20 266374.88 2553869.73 0.54 7060.00 34.000 345.000 6374.53 6269.53 2719.48 2659.48 - 572.95 266337.18 2554022.60 0.36 7371.00 34.000 344.000 6632.36 6527.36 2893.30 2827.05 - 619.42 266294.07 2554191.07 0.18 7577.00 34.000 343.000 6803.14 6698.14 300135 2937.50 652.14 266263.58 2554302,15 027 7847.00 32.250 342.000 7029.26 6924.26 3155.57 3078.22 - 696.47 266222,07 2554443.72 0.68 8160.00 31.500 344.000 7295.06 7190.06 3320.56 3236.25 - 744.82 266176 90 7 0.41 8328.00 31.000 340.000 7438.70 7333.70 3407.43 3319.10 - 771.72 266151.67 2554686.05L 1.27 8490.00 31.000 345.000 7577.59 7472.59 3490.62 3398.62 - 796.79 266128.20 2554766.05 1.59 8645.00 31.000 345.000 7710.45 7605.45 3570.43 3475.73 - 817.4 'n_ 266109.08 2554843.55 0.00 9014.00 31.250 343.000 8026.33 7921.33 3761.00 3659.05 - 870.03 r - 266060.19 2555027.89 0.29 F 9073.00 33.500 343.000 8076.16 7971.16 3792.53 3689.26 - 879.27 266051.56 2555058.27 3.81 9250.00 33.500 343.000 8223.76 8118.76 3890.071 3782.68 - 907.83 266024.88 2555152.25 0.00 9490.00 31.250 344.000 8426.44 8321.44 4018.41 3905.88 - 944.36 265990.82 2555276.15 0.96 9613.00 29.750 344.000 8532.42 8427.42 4080.79 3965.89 - 961.57 265974.82 2555336.48 1.22 411/ • Chevron Actual Wellpath Report BAKER ' IWO MSS <0- 10400'> HUGHES Page 3 of 3 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron Slot slot #2 - Area Cook Inlet, Alaska (Offshore) Well AN -24 Field Granite Point Field Wellbore AN -24 Facility ANNA Platform WELLPATH DATA (46 stations) MD Inclination Azimuth TVD TVD from Vert Sect North i East Grid East Grid North DLS [feet] [°] 1°] [feet] Fld Vert Ref [feet] [feet] I [feet] [us survey feet] [us survey feet] [ ° /100ft] [feet] 9696.00 29.750 343.000 8604.48 8499.48 4121.92 4005.38 - 973.26 , 265963.92 2555376 20 0.60 9796.00 29.750 343.000 8691.30 8586.30 4171.46 4052.83 - 987.77 265950.37 2555423.93 0.00 9958.00 29.500 346.000 8832.13 8727.13 4251.48 4129.97 1009.17 265930.51 2555501.48 0.93_ 10174.00 28.750 347.000 9020.82 8915.82 4356.61 4232.19 - 1033.72 ' 265908.02 2555604.17 0.41 10360.00 25.750 346.000 9186.16 9081.16 4441.76 4315.00 - 1053.5 265889.84 2555687.35 1.63' 10400.00 25.750 346.000 9222.19 9117.19 4459.14 4331.86 - 1057.77 I 265885.97 2555704.30 0.00 1 HOLE & CASING SECTIONS Ref Wellbore: AN - 24 Ref Wellpath: MSS <0 10400'> String/Diameter Start MD I End MD Interval Start TVD End TVD Start N/S Start E/W End N/S End E/W j [feet] [feet] [feet] [feet] [feet] [feet] [feet] [feet] [feet] 30in Casing r 0.00 272.00 272.00; 0.00 272.00 0.00, 0.00 -0.65 -1.17 20in Casing 0.00 609.00 609.00 0.00 608.95 ! 0.00 0.00 - 3.05 -5.91 13.375in Casing 0.00 2000.00 2000.00 0.00! 1954.37 0.00 0.00 261.59 68.11 ,9.625in Casing Surface 0.00 8703.00 8703.00 0.00 7760.15 0.00 0.00 3504.58 -825.27 � 7in Open Hole 8703.001 10400.00 1697.00 7760.15 9222.19 3504.58 - 825.27 4331.86 -1057.77 WELLPATH COMPOSITION Ref Wellbore: AN -24 Ref Wellpath: MSS <0- 10400'> Start MD End MD Positional Uncertainty Model Log Name /Comment Wellbore [feet] [feet] 1 0.00 10400.00 Photomechanical Magnetic (Standard) 1 MSS <0- 10400'> AN -24 (1---- — SENT UP DERMA 3' 1502 WIGAN 5111E 50 180' STNOFwE GOOSE to 411 WINLAVALLS - 3' RELIEF VALVE SE V AT b P9 JX1 SUMMER I) UNION AW'ipP J - I 5.000 PSI • • (( 10" SENT U0E 2' ID 10,000 P9 WORM' PRESSURE r -- 10' 150 M. RANGE • SEMNIESS S11F1 3/440010 HOSE 41 01" 1 tE 69, s' P•AC LC6 9IREl 4 HAVE • EE i 5' 100 1002 105 _ - � 511 - 2 04 ENE HMIMER 08606 �� CNO� I . I 4' 5.000 PSI 56 GIS II EMS VA11f(711p � RS PO4T EWER `-' 2 1502 144114 MEW lI 5' FIG. 1003 7. / / TAW( 1.7-'-' N4N41 LNION G / B' ISO b. fiAYGE 0-10,0110 PS GAUGE TOR / J' OpNV� WE 5' FO 100.1 � HUB ��~ �Wflf:!1;IS:J HONER wwN 3" 1502 W4114ES UNION 10000 H 2' x 5,000 PSI • / - /// ---' WIEURION 5" X 1, 11 ' PSI LO-TORO 2 TAO VALVE /ILD VILSE OYCO /5 SAMP W /&X 155 � � 10 PRODUCTION ' % ill :::: 10,000 P9 / MANPOD Y X $.Q10 P9 CA . - _ 1 ` ! \ • • • 2 " STA/&14'PE- --- • (STAND PIPE BLEED LN1) 111...333 3 1501 NTEVCR4C TEE �, dOW OOwN u l w4a�H J DEMCO BP.. VALVE • TAMZT • p--- 445 ION REDLGE15 fw TO 1511 NIPPLE BLIND HAN �I' v �" - - - - ` UNOCAL K CHGKE WELT AMMO 16900) WEIMER !NON CONNECTION s' CO CLAMP 119E XX LONG SWEEP FIG. I2 COOK NLET Y / C J" 1502 110ERORAL ELL � p UNION DIG ad- I'12592 3 1/16 -101 x 3' Fb6 C C W' XXN ML FLOW RE. - ADAPT RACE S4EkP TEE LONG !' FIG. 1003 �T� \ MINER WK. X0I BOLL RUG J' 1502 INiFRGRAL QL T \ _ - I" lNN1 NI 104 COFllX 3 1/16 -101 FIG WI BX 154 ( tAEIO NUB CONNECTION 41 4f SE35 5IFI7. ARMORS) NOSE 3 1 /I6 -101 OINETOA WAR HUB 9110 )AN J t /1' ID Y 5,000 P9 11.1.1 i F 1002 400170/4 HOSE 11411/4 UNON� BO' 6 7 LONG J' I.O. 10,000 P9 WOWING P J" L0. 5,000 PSI ARMORED 1%1531/41 SWEEP SWEEP Rf • STAINLESS ST AIAESS 511111 Afdw.V60 NOSTAINLESS ETS STEEL 0/4X) NOSE 4 I /1/ -1W w /80193 oe FA x 4 I /16 -91 W/R39 LONG OW 7 rsw m 9X WO 00 40 SEE > 426 MUSE 373/X,(0 ADA HOR FULL FLOW TEE N> 101 W 410019 1E SF£ 411501 fo VOW 8771 ON Oq1 414 191 SEE 4.185030 3 1/16 -5M FLG W/R35 1 1503 HAMMER 030. -T 4 1/16 -5M FLG — nII/7IIu— 3 1/16-101,1 Fl.G. W/ 00151 — �uIR111u FROM —35/16 -101 OnVET04 'I ....,.M- 144 �. 9 ASINX10. Pm On VOO DAB 1i/l4N YMEN0 - .•. —.UII—.01.111i.— - « IWe91 a. ] wOW F J" 1501 60691840 ELL J 1/13-511 0/635 X .15 a A cnonlx 0.10% u Av�OU MOOG ST µ 3 1/16 -101 w/BX154 all HAUSER 'N's 4 ! /J6�5M no. ( TMs ocscx a rtwss.c on Nmlan® - HOME 5MISOM ACAPTOR / ^ A I �lL�/�®J F..n..s. MU wr. 4s 20 3 /4' • 3000 P9 8002007 0000110 01001 HIGH PRESSURE D AND 0975RP9 009 LONG SWEEP 4' FIG 1003 4' G 100 i F)AL RD WIRER UNION WELL CONTROL SCHEMATIC 444110 WON 4 > " • • f -711041 MOO PUMP VP RUG amm : LAS. tom " ..ma..d6' MOW I.1 TCR yl.• 09 TS ,.. I 428.5024 A` -- - ---___ 0 t .. . 4• ,, ------- 4; 4. O. ----- -------_____ i (R S , \ --,...„ N t. 4- ______ ______ s ,• d. 01 006- ' t .. e; -------------- a ca 0 es to / • '--, - ‹o \'''''' ca os q ‘ 'Z A ‘ i 4 li 1111! 0006.- 11W ilii; , ..: ___--------_ 0099 •(!. sz --"4"111111 lin s s •.: 00 _ .. , , .o. e a s-s • so ,, oa , ,ks -\ ' 'It• ' ‘• co \ • \ I ci a. / : P :,:.. ,.. , .1, firc.<„, ---- • ---- <4 '11M16.111111k •• • t 4 1 i 1 41 .. -..441111111111.411 0 11111.1.116,4'*ilr • • f't ,+.40% t:Will.."1",1711111011.. : ......x.. ---- _•'_________---------- ..... rins I I.- -------------- — / � :,. ' / .. , 7 / § "6" - 110 ‘11°IfA3FP 19,,, ... 40 51.04 ro - •91.13 ^ryp o I _3 c; 4:,r, - 52P81 BR42 -10 ^a / )pt _•529. b O ^ p 6 gyp` 2 / BR4231 ^ ^ f fr AN-11 as A�l 2 AN - - -8665. • • • - 8825.19 AN 2R oO � 0 N i , I - 9••7.17 ' 2RoR13 � •:.:. 1 0 •p •1.48 rn I � :: / i l AN - 27R / 7 o . :1 . 20 TY o / 8 37 - o / A N0 7.D2 - / 7 d < - D2P: -07R• 3 t-:-.:"' � � I i ! e•: 348 \ ; R . / �� ON-39 • _: 95..: o• :': :40 " A J9RD A i 0001: - O -9' 11.09 i. ... dig, / // / / ,' p.; 67 •• ::7 87 AN -03 AN-r " AN-35P r. to---.40--- �• 6p81 :';'' : "fl /I ' Of ` o PB rn a r -101 • r . �•- ci it • .r •� / '9.02 AN3 AN -5 / P + : 1 -13RD ^ a pp ',4: � r1O ir, , AN -03RD/ / , 23 / A n a P atfor C -?lDB ructu� :54 . 38 • ... / 1111°.' Ai • i 0 2.0 500 75 1000 1250ft _. ..._ 600 800 1000 • 1200 1400 1600 • 1800 2000 2200 v 0 . A AN -24 Vers - I , ° o o 8 700 ° o �s 6. 0 1111111 ° 0 0 6. 41 1■3 0 •300 0 o 9400 4 ` 5E S T 2 0 ° 9700 a •%° , 0 10000 co ° ' 9 900 100 0 rn io 0 S °°ii 0600 ° o ' �0 b � ,�� , a) 7 4t6 o o • et F 0p a rn 7 / ° 0 0 0 o 0 Por 0.225 c 0 0.2 0 0.155 0.15 AN - 24RD Vers 13 Survey ° 0.125 0.1 0 0.075 0 100 200 300 400 — Oft c 0 0.05 0 0.025 . /41 0 600 800 1000 1200 1400 1600 1800 2000 2200 • I ANNA PLATFORM WELLSLOT DIAGRAM SHALE 01/01/06 SHALE WATER SHAKER SHAKER FLOOD 0 I=1 i ❑ 7RD2 FLOOD 39 24 4 7, 11 RD j % 28RD2 32RD i 36 FIRE ,,./ PUMP A S /I` S/I S/I 27RD 8 50 37 6' 4 5/ / 17 P &A / 6 ` / 52 3RD 15 38 Leg #1 Leg #2 North Corner East Corner j / / j A INTAKE / MO DISCHARGE Producer Dual Gas Well Injector Completion SHALE 25 23RD SHAKER 46 MUCI 3 j j ❑ / , j S/I 2 / ❑ WATER S SEWAGE 5 19 / �' ' % �/� FLOOD . S4/ 29 8 SHALE PRODUCED SHAKER WATER WATER WATER o ❑ �� o FLOOD FLOOD / Di S /I ' 13RD fio 0 •/I E 5 26 * 8 / v / 5�9 j r s% / in 4 5 33 21 ❑ LZ WATER 0 Leg #4 Leg #3 FLOOD 0 West Corner South Corner a An -24 Sidetrack out of Leg 2 Slot 3 • 0 Anna Platform Well No. 24 Chevron Actual Completion 11/11/82 CASING AND TUBING DETAIL RKB to TBG Hgr = 43.2' SIZE WT GRADE CONN ID TOP BTM. 20" 94 # K -55 - 19.124" Surface 609' "-I 13 -3/8" 54.5, 68# K -55 BUTT 12.415" Surface 2,000' .el L. 9-5/8" 40, 43.5# N -80 & S-95 BUTT 8.755" Surface 9,161' 7" Liner 26# N -80 BUTT 6.276" 8,703' 10,400' Tubing Long String L , 2 -7/8" 6.4# L -80 SCBT 2.441" 0' 8,804' Short String 3 -1/2" 9.2# L -80 SCBT 2.992" 0' 8,002' JEWELRY DETAIL L .S. NO. Depth ID OD Item 35' - - Tubing Hanger, Cameron, 3 -1/2" x 10" Dual Long String 1 36' - - 3 -1/2" x 2 -7/8" XO 2 8,780' - - 2 -7/8" Butt x 2 -7/8" 8RD XO 3 8,802' - 5.600 Kobe 2 -1/2" Type `D' Cavity S/N -0051 4 10,043' - - Mule Shoe Short String 6 8,607' - - 3 -1/2" x 2 -3/8" XO 7 8,774' - - 2 -3/8" x 1 -1/2" XO Fish /Fill/Plugs NO. Depth (Top) Length Item - - A 10,140' 10' Fill (Tagged 6/16/07 @ 10,105') fi PERFORATION HISTORY Interval Accum. I 1 S- Date Zone Top Btm Amt spf Comments E -E--1 6/9/1976 C -3 8,900' 8,932' 32' 4' Reperf - 2 -1/8" Enerjet i u u i 6/9/1976 C -3 8,940' 8,962' 22' 4' Reperf - 4" Casing 6/9/1976 C -3 8,970' 8,988' 18' 4' Reperf - 4" Casing . 6/9/1976 C -4 9,018' 9,023' 5' 4' Reperf -4" Casing 6/9/1976 C-4 9,032' 9,069' 37' 4' Reperf - 4" Casing I I 6/9/1976 C -5 9,180' 9,232' 52' 4' Reperf - 4" Casing 6/9/1976 C -5 9,254' 9,259' 5' 4' Reperf - 4" Casing 6/9/1976 C -5 9,272' 9,348' 76' 4' Reperf -4" Casing 6/9/1976 C -6 9,578' 9,583' 5' 4' Reperf -4" Casing 6/9/1976 C -7 9,660' 9,676' 16' 4' Reperf - 4" Casing 6/9/1976 C -7 9,710' 9,716' 6' 4' Reperf -4 "Casing 6/9/1976 C -7 9,808' 9,813' 5' 4' Reperf - 4" Casing - 6/9/1976 C -7 9,824' 9,842' 18' 4' Reperf -4 "Casing II 4 6/9/1976 C -7 9,862' 9,884' 22' 4' Reperf - 4" Casing 0 a 6/9/1976 C -7 9,946' 9,956' 10' 4' Reperf -4 "Casing '. 6/9/1976 C -8 10,054' 10,059' 5' 4' Reperf -4" Casing TD = 10,400' MD, 9,220' TVD Max angle = 35° @ 6,782' PBTD = 10,150' MD = 8,996' TVD O:\DRILLING\Anna- 24.doc DRAWN BY: STP REVISED: 10/16/06 Well Name: An -24RD Chevron Field: Granit Point Field Completion: Proposed Surface Location `/ Conductor: 30 ", 194 ppf, K -55 to 256' Anna Platform RF: 47' Seal level base flange: 67' Anna RKB 114 X:266856.72 Y: 2551352.29 Sec. 12, T10N, R12W, SM d Surface Casing 20 ", 94 ppf, K -55, BTC to 605' Cement to surface L , Intermediate Casing 13 3/8 ", 54 &68 ppf, K -55, BTC to 2000' Directional Data Good cement 8209' MD KOP 8400' MD Drop to 17deg Inc 10000' MD Build to 70 degrees Intermediate Casing 11800' MD TD of well 9 5/8 ", 43 &40 ppf, S- 95 &N -80, BTC to 9161' Fair cement to 7300' MD P&A program 8880' Set cement retainer 8880' to 8540' diplacement of cement Production Liner Bring cement 150' over 7" Liner lap 7 ", 29 ppf, P -110, IBT -Mod liner from 7900' - 11800' Pressure test to 2000 psi Baker ZXP packer, HMC liner hanger & tieback sleeve at .............. 3550' PBTD = 8500' MD Production Tubing Long String 2 7/8 ", 6.4 ppf, L -80, IBT -Mod to 11580' Short String 2 7/8 ", 6.4 ppf, L-80, l8T -Mod to 7900' 2 3/8" 4.6 ppf, L -80, IBT -Mod to 10950' Completion Dual string OilWell Hydraulics Cavity Pump a gnu II n u' 1 n I 11 ill • I Zones: (Planned perferated intervals) TD = 10400' MD C -7DB 10974.87 MD TD ND: 9220' ND • I I C -7DT 10997.87 MD • C -7CB 11011.87 MD • C -7CT 11048 87 MD C -7A8 11110.87 MD C -7AT 11178.87 MD C -5BB 11428.87 MD C -5BT 11513 87 MD • C -5AB 11520.87 MD C -5AT 11580 87 MD Perf guns will be run with completion TDMD= 11800'MD ✓ ND = 9963' MD WBD AN -24RD Proposed v1.xls October 28, 2007 Drawn by. TSF Chevron %.11 Granite Point Field Well AN -24RD Cement Program 7" Liner (8 -1/2" Hole from 11800 to 8000' MD): Cement volume based on open hole volume plus 30 %, shoe joints and annulus. This will be a single stage cement job, pumping cement from 11,800' and up to 8000' md. Estimated volume is as follows: Mud push: = 40 bbls 13.5 lb /gal @ 80 degF Cement Slurry: 3760' X 0.1268 cuft/ft (8 -1/2" x 7 ") X 1.3 = 626 cuft = 540 sks (1.16 yield) 40' shoe joint X 0.2148 cuft/ft = 8 cult = 7 sks (1.16 yield) TOTAL: 626 + 8= 634 cuft (547 sks) Chase cement with OBM. Cement Properties Type Class G Density 15.8 lb /gal Yield 1.16 ft3 /sk Cementing Program An -24RD 1 11/12/2007 Calculation & Casing Design Factors C h ev ro n Anna Platform An -24 Cook Inlet, Alaska WELL: Anna 24RD FIELD: Granite Point DATE: 6- Nov-07 DESIGN BY: Tim Flynn 9.0 Sect. 1 8 1/2" hole MUD WT. 9.3 PPG MASP= 3200 psi Sect. 2 8 1/2" hole MUD WT. 9.5 PPG MASP= 5465 psi Production Mode TENSION MINIMUM COLLAPSE COLLAPSE WEIGHT TOP OF STRENGTH PRESS @ RESIST. MINIMUM • DESCRIPTION W/O BF SECTION TENSION WORST CASE BOTTOM w/o TENSION WORST CASE MASP YIELD WORST CASE SECTION CASING BOTTOM TOP LENGTH WT. GRADE THREAD LBS LBS 1000 LBS SF TENSION PSI* PSI SF COLL. PSI ** PSI SF BURST 1 9 5/8" 8,209 0 8209 40 N -80 Butt 328,360 328,360 1005 3.06 3,317 3,810 1.15 3,200 6,330 1.98 TVD 7,339 0 2 7" 11,800 1 8000 3800 29 P -110 Hyd 563 110,200 110,200 929 8.43 4,504 8,510 1.89 3,200 11,220 3.51 TVD 9,964 7200 * Collapse pressure is calculated; Normal Pressure Fluid Gradient for external stress (.435 psi/ft) and the casing evacuated for the internal stress (.1 psi /ft) ** See attached sheet for calculation of MASP is • 1 AN -24RD Predicted Pore and Frac Pressures Pressure (psi) 0 2000 4000 6000 8000 10000 12000 0 1000 • • • • c— Min Frac Gradient 0.866 psi /ft 2000 — ® • AN -24 Midperf SI Pressure • •Minimum Reservoir Pressures Bruce Disp Frac 9.5 lbs/gal slurry Bruce Disp 11 lbs/gal slurry 3000 — • Bruce Disp 9.8 lbs/gal slurry \ AN -25 didn't frac at this pressure • • 1988 Amoco Frac Pressures • 4000 • E • 5000 - \ • • 1- 6000 — -- \ - — • • 7000 — • Crestal Reservoirs • 8000 -- • 9 — * N 000 West Flank Reservoirs 4179psi/.052/9585ft= 8.38ppg ‘, 10000 • . h yr C n e o Maximum Anticipated Surface Pressure Calculation Anna platform Well An -24RD Cook Inlet, Alaska Assumptions: 1. Based on offset drilling & well test data, the pore pressure gradient is predicted to be a 0.435 psi/ft gradient from surface to planned total depth at 9963' TVD BRT. 2. The M.A.S.P. during drilling operations will be govemed by the 7" shoe frac gradient, and is calculated based on a full column of gas between the 9 5/8" KOP and the surface. The KOP for AN -24RD is at 7135' TVD. 3. The M.A.S.P. during production operations will be the estimated SIBHP minus the gas hydrostatic pressure between TD & the surface. M.A.S.P. During Production Life: Max. pore pressure at T.D. = 9,585 ft. x 0.435 psi /ft = 4169 psi M.A.S.P. (tbg leak at surface) = 4169 psi - (0.1 psi /ft * 9585 ft) = = 3200 psi M.A.S.P. While Drilling 8 112" hole at 10,000' TVD: Max. Est. Frac pressure at KOP = 7135 ft. x 0.866 psi /ft = 6179 psi M.A.S.P. during drilling = 6179 psi - (0.1 psi /ft x 7135 ft.) _ = 5465 psi QpSS\'J Vc 49 \ahC� • Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Note that the terms used in the procedures and the spreadsheet of FIT /LOT results are defined as follows: • Formation Integrity Test (FIT) - Formation is tested to a pre- determined equivalent mud weight. • Leak -Off Test (LOT) - Pressure is exerted against the formation until fluid begins to discernibly pump away. Pressure at which this first occurs is the Teak -off point. • LOT Limit - 16.0 ppg EMW for all surface casing shoe tests; determined from previous experience with formation breakdown problems by attempting higher leak -offs. • Open Hole LOTs (OH LOTs)- Leak -off tests performed with open hole from the casing shoe to some point above the target reservoir. Generally done when leak -off is required but could not be achieved just below the casing shoe; or where weaker formations are suspected above the target reservoir but below the casing shoe, and assurance is required of being able to achieve estimated mud weight. Procedure for FIT: 1. Drill 20' of new hole below the casing shoe. 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drillpipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1- minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre- determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Formation integrity tests are conducted on all casing shoes with the exception of some surface casing situations. Where annular pumping will be done on a well, the formation below the surface shoe is taken to leak -off. This ensures that future disposal fluids can pumped away without risk of damage to the surface shoe. If two attempts at establishing leak -off at the shoe are unsuccessful (using 16.0 ppg EMW LOT limit per definition above), then an open -hole LOT is performed. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre - determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. • • Chevron 1 %11 10 LEAK OFF TEST PROCEDURE 1. Clean out the rathole below the shoe, and drill 20' of new hole. Circulate and condition mud. 2. Pull the drill string into the shoe. Rig up to observe annulus pressures. 3. Close the pipe rams and pump down the drilipipe at a slow rate (1/4 - 1/3 BPM) if exposed formation is permeable. A non - permeable formation should be step tested to a predetermined pressure. 4. Measure the volume pumped and plot annulus pressure -vs- cumulative volume pumped. Compare annulus pressure to drill pipe pressure and confirm both are the same. Record and plot pressure versus volume pumped. The pumps should be shut down immediately upon indication of leak -off. Record the inital, shut down pressure and the pressure after 1, 2, and 3 minutes. 5. Release pressure and record the volume of fluid recovered in the trip tank. The point "B" shown in the attached graph at which the plot of drilipipe pressure stops increasing equally as the volume is pumped is called the P.I.T. limit, Leak Off, or pressure integrity test limit. The leak -off pressure is calculated as follows: Leak -off (EMW) = Mud weight in hole + P.I.T. (PSI) (0.052) X (shoe depth in TVD ft.) This equivalent mud weight should be made known to all drilling personnel to ensure it is not exceeded. See the drilling procedure for guidelines on expected LOT's or pressure integrity test limits for each casing shoe. C � D SURE PR ESS . FAC TYPICAL PIT PLOT (psi) VOLUME PUMPED SHUT -IN -TIME (BBLS) (MIN) NOTES: Point "A" will have some variance until the system begins to pressure up. Point "B" is the leak off and is abbreviated LOT. Point "C" is known as the injection pressure and is usually dependent on rate. Point "D" is known as the fracture closure pressure and may not stabilize if permeable formations are exposed. • • AN -24RD BOP Stack up Bottom of Rotary Table 1 - 13 5/8" 5M Annular I I 13 5/8" 5M DBL Gate Pipe Rams ■ I I I 13 5/8" 5M DBL Gate ` Blind Rams _C 13 5 /8" SM C 3i Mud Cross yLL Wina valves 3 1/8" 5M „,.. 13 5/8" 5M Single Gate , Pipe Rams L_ ' ■ l — [ �� Cameron C _ 13 3/8 x 9 5/8" x 7" wellhead system 5M — or starting head E c 20" • • Chevron An -24RD PTD No. 176 -022 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) Drilling Hazards 13 3/8 — 9 5/8" annulus pressure • Pressure ( <300 psi) has been recorded between the 13 3/8" and 9 5/8" annulus. Currently it is being monitored on a daily basis but poses no immediate concern. • Daily monitoring of the pressure will continue through the rig operations to ensure the pressure does not build to un acceptable levels ( >500 psi) 8 -1/2" Hole / 7" Casing (Intermediate) Event Risk Level Mitigation Strategy Sloughing shale, Tight hole High Increased mud weight, controlled connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring Lost circulation Low Reduced pump rates, reduced trip speeds, real time ECD monitoring, mud rheology, lost circulation material Hole swabbing on trips Medium Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time ECD monitoring, use weighted sweeps Directional Control Medium BHA Design, Rotary Steerable Abnormal Reservoir Low Well control drills, check Pressure 1/ for flow during connections, increased mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Sticking BHA in Coals Moderate Control drill through coals. Frequent reaming and trips through coals until sticking tendency abates. Surveys for GP 18742 -24D • Page 1 of 2 Davies, Stephen F (DOA) From: Flynn, Tim [ASRC] [Tim.Flynn @chevron.com] Sent: Friday, December 07, 2007 4:48 PM To: Davies, Stephen F (DOA) Subject: RE: Surveys for GP 18742 -24D Steve They take monthly readings, this month was 0 PPM and in a twelve month period highest reading was 12 PPM, average is <8 PPM. Let me know if you need further info. Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 -3322 907- 263 -7824 phone 907- 317 -5504 cell From: Davies, Stephen F (DOA) [mailto:steve.davies @alaska.gov] Sent: Friday, December 07, 2007 3:57 PM To: Flynn, Tim [ASRC] Subject: RE: Surveys for GP 18742 -24D Thanks Tim. Glad you're doing well. Say, I have a couple of additional questions: does Chevron have any compilation of H2S measurements for their wells in the Cook Inlet? I get a report every 6 months from ConocoPhillips for their properties, but haven't had an update on the Cook Inlet for several years? If so, could I get a copy to use when processing well permits? But for the moment, what are the H2S levels for the Anna wells? Thanks a lot. Steve Davies AOGCC 793 -1224 From: Flynn, Tim [ASRC] [mailto:Tim.Flynn @chevron.com] Sent: Friday, December 07, 2007 3:54 PM To: Davies, Stephen F (DOA) Subject: Surveys for GP 18742 -24D As requested. Let me know if you need further information. Good to here from you. 12/10/2007 Surveys for GP 18742 -24D • Page 2 of 2 «AN- 24RD_Version 14 Planned Wellpath Report.pdf» «AN- 24RD_Version 14 Plan Veiw Plot (8.5x11) .pdf» «AN- 24RD_Version 14 Vert Veiw Plot (8.5x11) .pdf» Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 -3322 907 - 263 -7824 phone 907 -317 -5504 cell i 12/10/2007 w Surveys for GP 18742 -24D • • Page 1 of 1 Davies, Stephen F (DOA) From: Flynn, Tim [ASRC] [Tim.Flynn @chevron.com] Sent: Friday, December 07, 2007 3:54 PM To: Davies, Stephen F (DOA) Subject: Surveys for GP 18742 -24D Attachments: AN- 24RD_Version 14 Planned Wellpath Report.pdf; AN- 24RD_Version 14 Plan Veiw Plot (8.5x11) .pdf; AN- 24RD_Version 14 Vert Veiw Plot (8.5x11) .pdf As requested. Let me know if you need further information. Good to here from you. «AN-24RD_Version 14 Planned Wellpath Report.pdf» «AN- 24RD_Version 14 Plan Veiw Plot (8.5x11) .pdf» «AN- 24RD_Version 14 Vert Veiw Plot (8.5x11) .pdf» Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 909 W 9th Avenue Anchorage, AK 99501-3322 907 -263 -7824 phone 907 - 317 -5504 cell 12/10/2007 w • TRANSMITTAL LETTER CHECKLIST WELL NAME $:172.0"1/ " 4//2' l � Ali 2cI/L'I PTD# /Development Service Ex lorato Strati hic Test Exploratory f�P Non - Conventional Well Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new welibore segment of existing well (If last two digits in Permit No. , API No. 50- API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. , assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non - Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 7/13/2007 WELL PERMrT CHECKLIST Field & Pool GRANITE PT, MIDDLE KENAI OIL - 280150 Well Name: GRANITE PT ST 18742 24RD _Program DEV Well bore seg ❑ PTD#: 2071700 Company UNION OIL CO OF CALIFORNIA Initial Class/Type _DEV / PEND GeoArea 820 Unit On /Off Shore Off Annular Disposal ❑ Administration 11 Permit fee attached NA 2 _Lease number appropriate Yes 1 3 Unique welt name and number Yes 4 Well located in a defined pool Yes Granite Pt Middle Kenai Oil Pool - 280150, governed by CO 76 � 5 Well located proper distance from drilling unit boundary Yes Conforms with CO 76, Rule 2: well bore will lie >500' fromproperty line. 16 Well located proper distance from other wells Yes Conforms with CO 76, Rule 2: well bore will lie >1000' from other wells capable of_producing from sarne_pool, _ . _ 17 Sufficient acreage_available in drilling unit Yes Conforms with CO 7e, Rule_2: well bore will be first well bore in the NW /4 of Section 1. 8 If deviated, iswellborepiat_included Yes 1 9 Operator only affected party Yes 110 Operator has _appropriatebond in force Yes Bond number on 10-407 is correct. 11 Permit can be issued without conservation order Yes Appr Date 112 Permitcan be issued without administrative_approval Yes SFD 12/10/2007 1 13 Can permit be approved before 15-day wait Yes 1 14 Well located within area and_strata authorized by Injection Order # (put 10# in comments) (For Yes A1O 6 governs this pool. 115 All weft within 1 /4rnile area_of review identified (For service well only) NA 16 Pre- produced injector, duration_of pre production less than 3 months_ (For service well only) _ _ NR ; 17 _Nonconven. gas_conforms to AS31,05.03Q(j,,1.A)42.A -D) NA Engineering 18 Conductor string provided NA Conductor set_in 18742-24 (An -24) (176-022). 1 19 Surface_casingprotects all known USDWs NA All aquifers exempted 40 CFR 147.102(b)(2)(i). 20 CMT_v_ot adequate to circuiate_on_conductor & surf csg NA Surface casing set in An -24. 21 CMT v_oi adequate_ to tie- iniong string to surf csg NA Production_ casing set in An -24. New 7" liner will be fully cemented. 1 1 22 CMT_will cover all known_productive horizons Yes 23 Casing designs adequate for C,_T, B & permafrost Yes 24 Adequate tankageorreserve pit Yes Offshore platform. Class II disposai_well available on platform. 1 125 Ifare -drill has_a 10-403 for abandonment been approved Yes 307 -350 126 A lequate_w_ellbore separation_proposed Yes Proximity analysis performed. Nearest segment is P &A portion of An -24 and paths diverge. 1 27 Ifdiverterrequired, does it meet regulations NA BOP stack will be in place. Appr Date 28 Drilling fluid program schematic_& equipiist adequate Yes Formation pressures severely depleted. Normal pressure other wise. MW planned 9.0 - 9.5 ppg. TEM 12/21/2007 129 BOPEs,_do they meet regulation Yes � 1 30 BOPE_press rating appropriate; test to_(put psig in comments) Yes MAP calculated at 3200 psi. 3500_psi_BOP testplanned. 31 Choke_manifold compiles w /API_ RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 133 is presence of H2S gas probable Yes Low H2S is reported on Anna. _Mud should preclude H2S on rig._ Rig equipped with sensors and alarms. 1 34 _Mechanical_condition of wells within ACM verified (For service well only) NA Geology 1 35 Permitcan be issued w/o hydrogen sulfide measures No Email from Tim Flynn, Unocal,12/7 /2QQ7; _reservoir contains low levels of H2S; precautions needed, 136 Data_presented ort potential overpressure zones Yes Reservoir pressure _is severiy depleted (as low_as about 3 ppg), non - reservoir portions of_section are Appr Date ' 37 Seismic_analysis of shallow gas zones NA normally pressured. This re -drill will utilize 9.Q -9.5 ppg EMW oil -base mud. SFD 12/10/2007 38 Seabed condition survey (if off -shore) NA 139 Contact name/phone for weekiy_progress reports [exploratory only] NA Geologic Engineering P Re -drill targeting untapped reservers. Commissioner: Date. Commissione . Date Date C t r s 12_(21 17 /z -e' -07 , a -2-/-077-,