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195-004
1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 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): 13,351 N/A Casing Collapse Structural Conductor Surface Intermediate 1,950 psi Production 4,760 psi Liner 7,020 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: 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 See Attached Schematic 10,875' N/A Length N/A & N/A N/A & N/A 10,829 13,263 10,795 Granite Pt St 18742 51N/A Same 9,841'9-5/8" ~777psi Granite Point Middle Kenai Oil Pool Size September 19, 2025 13,351'2,652' LS 2-7/8" SS 2-7/8" & 2-3/8" 10,828' 10,875' Perforation Depth MD (ft): 3,798' 7" See Attached Schematic 3,450 psi3,797' 1,130' 13-3/83,798' 1,130' MD 18-5/8" 6.5# / L-80 6.5# / L-80 & 4.6# / L-80 TVD Burst 12,429' 12,378' 6,870 psi 1,130' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018742 195-004 50-733-20464-00-00 Hilcorp Alaska, LLC Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 AOGCC USE ONLY 8,160 psi Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: Operations Manager 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: PRESENT WELL CONDITION SUMMARY 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 7:43 am, Sep 08, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.09.05 15:38:55 - 08'00' Dan Marlowe (1267) 325-547 A.Dewhurst 10SEP25 DSR-9/10/25 10-404 MGR10SEP2025JLC 9/11/2025 Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.09.11 08:44:09 -08'00'09/11/25 RBDMS JSB 091125 Tubing Patch Well: AN-51 Well Name: AN-51 API Number: 50-733-20464-00 Current Status: Offline Oil Well Leg: Leg #1 (N corner) Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 195004 First Call Engineer: Eric Dickerman 307-250-4013 Second Call Engineer: Casey Morse 907-777-8322 Maximum Expected BHP: 1,826 psi at 10,493’ tvd Shut in BHP survey – (March 2025) Max. Potential Surface Pressure (MPSP): 777 psi Using 0.1 psi/ft gradient to surface Brief Well Summary AN-51 is a C5 lateral drilled in the East flank of the Granite Point field in June 1995. The well initially produced ~440 bfpd at 0% WC but experienced steep decline in the first 2 years of production. Minimal interventions were performed 1995-2010. In March 2009, the Redoubt eruption shut down oil shipping and AN-51 was used as an oil injection well to maintain production and keep the platform warm. Following that period, the well struggled to lift due to jet pump issues. In Feb 2010, the Jet Pump and Standing Valve were pulled and full of rubber pieces. A D&D hole finder determined the Kobe cavity was failed. The well stayed shut-in. In April 2015, a RWO was performed to repair the failed Kobe cavity. The cavity was also moved down to 12,389’md which is in the middle of the perforated interval. This provided 600’ tvd additional lift from the Jet Pump, but obstructed the ability to reperf the upper C5 interval. During the RWO, the lowest C5 perfs from 13,147’ - 13,224’md were added. In February 2025, the well again struggled to lift. Diagnostics have identified a possible hole in tubing around 6,450’ 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 May 25, 2016. 1/27/25 Replace jet pump. Unable to drawdown. 2/05/25 Replace standing valve. Unable to draw well down. 2/19/25 Unable to drift out tubing tail, tag at 12,435’ md. 3/01/25 Caliper long string, no holes logged, potential scaling noted in tubing tail. Fluid level logged at 6,450’ md. Tubing Patch Well: AN-51 Slickline Procedure: 1. MIRU on longstring. 2. Pressure test PCE to 250 psi low / 2,500 psi high. 3. Confirm leak depth with holefinder. Test tubing below and above leak. 4. Set standing valve in the jet pump cavity at 12,389’. 5. Set jet pump in jet pump cavity at 12,389’. 6. Set 2-7/8” tubing patch across tubing leak. a. Leak expected at ~6,450’ based on log. 7. MIT-T (Bundle test) to 1,500 psi. a. Bundle test pressures up the long string and short string against the standing valve. 8. RDMO. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Updated by: JLL 06/01/15 Anna Platform Well # 51 Completion: 05/02/15 SCHEMATIC API # 50-733-20464 3 1 1 1 2 RN CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 18-5/8” 97# X-56 - Surface 1130’ 13-3/8” 68# K-55 - Surface 3798” 9-5/8” 47# L-80 Buttress 8.681” Surface 10875’ 7” Liner 29# L-80 Buttress 6.184” 10699’ 13351’ TUBING PBTD 13,263’ Long String 2-7/8” 6.5 L-80 EUE 2.441 Surf 10,643’ 2-7/8” 6.5 L-80 Sprmx SC 2.441 10,643’ 12,429’ Short String 2-7/8” 6.5 L-80 8RD EUE 2.441 Surf 10,625’ 2-3/8” 4.6 L-80 Sprmx SC 1.995 10,625’ 12,378’ Note: Discrepancy of 11.25’ between the LS & SS beginning at the bottom of the KOBE JEWELRY DETAIL NO. Depth ID OD Item Hanger 1 12,389’ 2.441 5.562 KOBE Cavity 2 12,395’ 2.441 3.450 RN Nipple 3 12,429’ 3.000 Ratcheting Mule Shoe PBTD = 13,263’ MD (10,795’ TVD) TD = 13,351’ MD (10,829’ TVD) Perforation Detail Zone Top (MD)Btm (MD)Top (TVD) Btm (TVD)Amt SPF Date Comments C-5 11,180' 11,274' 10,072' 10,124' 94' 6 6/21/1995 HRS 4-5/8" Tbg. Conv. C-5 11,293' 11,940' 10,133' 10,354' 647' 6 6/21/1995 HRS 4-5/8" Tbg. Conv. C-5 12,250' 12,520' 10,458' 10,554' 270' 6 6/21/1995 HRS 4-5/8" Tbg. Conv. C-5 12,630' 13,150' 10,592' 10,758' 520' 6 6/21/1995 HRS 4-5/8" Tbg. Conv. C-5 13,147’ 13,224’ 10,757’ 10,782’ 77’ 5 04/29/15 Updated by: EPD 09/05/25 Anna Platform Well # 51 Completion: 05/02/15 PROPOSED API # 50-733-20464 3 1 1 1 2 RN 4 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 18-5/8” 97# X-56 - Surface 1130’ 13-3/8” 68# K-55 - Surface 3798” 9-5/8” 47# L-80 Buttress 8.681” Surface 10875’ 7” Liner 29# L-80 Buttress 6.184” 10699’ 13351’ TUBING PBTD 13,263’ Long String 2-7/8” 6.5 L-80 EUE 2.441 Surf 10,643’ 2-7/8” 6.5 L-80 Sprmx SC 2.441 10,643’ 12,429’ Short String 2-7/8” 6.5 L-80 8RD EUE 2.441 Surf 10,625’ 2-3/8” 4.6 L-80 Sprmx SC 1.995 10,625’ 12,378’ Note: Discrepancy of 11.25’ between the LS & SS beginning at the bottom of the KOBE JEWELRY DETAIL NO. Depth ID OD Item 1 ± 6,450’ 2-7/8” Long string tubing patch 2 12,389’ 2.441 5.562 KOBE Cavity 3 12,395’ 2.441 3.450 RN Nipple 4 12,429’ 3.000 Ratcheting Mule Shoe PBTD = 13,263’ MD (10,795’ TVD) TD = 13,351’ MD (10,829’ TVD) Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Comments C-5 11,180' 11,274' 10,072' 10,124' 94' 6 6/21/1995 HRS 4-5/8" Tbg. Conv. C-5 11,293' 11,940' 10,133' 10,354' 647' 6 6/21/1995 HRS 4-5/8" Tbg. Conv. C-5 12,250' 12,520' 10,458' 10,554' 270' 6 6/21/1995 HRS 4-5/8" Tbg. Conv. C-5 12,630' 13,150' 10,592' 10,758' 520' 6 6/21/1995 HRS 4-5/8" Tbg. Conv. C-5 13,147’ 13,224’ 10,757’ 10,782’ 77’ 5 04/29/15 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: 3/18/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250318 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN-51 50733204640000 195004 3/1/2025 READ CAliperSurvey AN-51 50733204640000 195004 3/1/2025 READ CaliperSurvey/SBHPS BCU 18RD 50133205840100 222033 2/25/2025 AK E-LINE Perf BCU 18RD 50133205840100 222033 2/26/2025 AK E-LINE Plug/Perf BRU 212-26 50283201820000 220058 2/28/2025 AK E-LINE PT Survey BRU 221-26 50283202010000 224098 2/27/2025 AK E-LINE PPROF BRU 241-34S 50283201980000 224077 3/1/2025 AK E-LINE PPROF IRU 11-06 50283201300000 208184 2/26/2025 AK E-LINE DepthDetermination IRU 11-06 50283201300000 208184 3/8/2025 AK E-LINE PlugSetting MPU E-42 50029236350000 219082 2/22/2025 AK E-LINE Caliper MRU A-12RD 50733200760100 171029 3/7/2025 AK E-LINE Correlation MRU A-13 (REVISED)50733200770000 168002 2/6/2025 AK E-LINE TubingPunch MRU M-32RD2 50733204620200 217091 3/4/2025 AK E-LINE Correlation PBU 13-24B 50029207390200 224087 1/4/2025 HALLIBURTON RBT PBU 16-24A 50029215360100 224158 2/23/2025 HALLIBURTON RBT-COILFLAG PBU F-21 50029219490000 189056 2/25/2025 READ CaliperSurvey SD37-DSP01 50629234510000 211089 2/28/2025 HALLIBURTON WFL-TMD3D Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40221 T40221 T40222 T40222 T40223 T40224 T40225 T40226 T40226 T40227 T40228 T40229 T40230 T40231 T40232 T40233 T40234 AN-51 50733204640000 195004 3/1/2025 READ CAliperSurvey AN-51 50733204640000 195004 3/1/2025 READ CaliperSurvey/SBHPS Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.18 15:55:41 -08'00' Or TtJ 7 s THE STATE • y Alaska Oil and Gas �w • 9A OfA TASKA Conservation Commission kltfih= _ _ 333 West Seventh Avenue z_= .'r0,- C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF , „_ Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov June 20, 2016 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification SCANNED JJN 0 4 2017 Granite Pt State 18742 Anna-51 PTD 1950040 Dear Mr. Golis: On May 25, 2016 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Granite Point State 18742 Well #51 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 Anna-51 prior to the test. The well performance was monitored for three hours with resulting in flow of gas and liquid at rates less than the allowed limits,passing the no-flow test. Anna-51 may be produced without a subsurface safety valve. 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 Anna-51 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 Granite Point Anna Platform. Sincerely, \Re James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission l 146 TO: Jim Regg c4111 DATE: 5/25/16 P. I. Supervisor FROM: Jeff Jones SUBJECT: No Flow Test Petroleum Inspector Granite Pt State 18742 Anna-51 Hilcorp PTD 1950040 May 25, 2016: I traveled to Hilcorp's Granite Point State Field Anna platform and , witnessed a No Flow verification test on well A-51. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 900 , 0 • <150 SCFH < 1 cup 930 0 <150 SCFH - < 1 cup 1000 ' 0 • <150 SCFH < 1 cup - 1030 0 - <150 SCFH < 1 cup - 1100 0 <150 SCFH < 1 cup 11:30 0 - <150 SCFH ' < 1 cup 12:00 0 - <150 SCFH < 1 cup 1 Pressures are T/IA/OA Summary: I witnessed a successful No Flow verification test on well Anna-51. Gas production from the well was less than 150 SCFH throughout the 3 hour test period and less than a quart of fluid was produced. Attachments: none SCANNED DEC 1 62016 2016-052 5_No-Flow_GranitePt_State_18742_Anna-51_j j.docx Page 1 of 1 STATE OF ALASKA AlIA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing El Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate El Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool Cl Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development I] Exploratory❑ 195-004 3.Address: 3800 Centerpoint Drive,Suite 1400 StratigraphicEl Service 0 6.API Number: Anchorage,AK 99503 50-733-20464-00. 7.Property Designation(Lease Number): 8.Well Name and Number: I . . , ADL0018742 Granite Pt St 18742 51 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): MAY 1 8 (,, 3: N/A Granite Point Field/Middle Kenai Oil Pool 11.Present Well Condition Summary: AOGV Total Depth measured 13,351 feet Plugs measured N/A feet v true vertical 10,829 feet Junk measured N/A feet Effective Depth measured 13,263 feet Packer measured N/A feet true vertical 10,795 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,130' 18-5/8" 1,130' 1,130' Intermediate 3,798' 13-3/8" 3,798' 3,797' 2,450 psi 1,950 psi Production 10,875' 9-5/8" 10,875' 9,841' 6,870 psi 4,760 psi Liner 2,652' 7" 13,351' 10,828' 8,160 psi 7,020 psi Perforation depth Measured depth 11,180-13,224 feet True Vertical depth 10,072-10,782 feet LS 2-7/8" 6.5#/L-80 12,429'(MD) 10,521 (ND) Tubing(size,grade,measured and true vertical depth) SS 2-7/8"&2-3/8" 6.5#/L-80&4.6#/L-80 12,378'(MD) 10,503'(ND) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): - , ;7 � rr't 11 ,180'-13,224' SCO�b ��ppE Treatment descriptions including volumes used and final pressure: 110 gallons WAW-5206,330 gallons xylene, 1210 gallons Oil Safe AR acid, 110 gallons FIW displacement,with a final 400 bbl oil cap.Final pump pressure 100 psi.72 hour soak. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 27 7 0 84 85 Subsequent to operation: 29 9 1 78 83 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ El WAG El 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: 316-099 Contact Trudi Hallett(907)777-8323 Email thallettOhilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature 1/(--. Phone (907)777-8356 Date S/i$ r I L Form 10-404 Revised 5/2015 � > ,RBDMS L tr Submit Original Only MAY 1 9 1016 0 • Anna Platform SCHEMATIC Well # 51 Completion: 05/02/15 Hilcorp Alaska,LLC API#50-733-20464 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. i r V 18-5/8" 97# X-56 Surface 1130' 13-3/8" 68# K-55 Surface 3798" 9-5/8" 47# L-80 Buttress 8.681" Surface 10875' 7"Liner TUBING 29# L-80 Buttress 6.184" 10699' 13351' PBTD 13,263' Long String 2-7/8" 6.5 L 80 EUE 2.441 Surf 10,643' 2 7/8" 6.5 L-80 Sprmx SC 2.441 10,643' 12,429' Short String 2-7/8" 6.5 L-80 8RD EUE 2.441 Surf 10,625' 2 3/8" 4.6 L 80 Sprmx SC 1.995 10,625' 12,378' Note: Discrepancy of 11.25'between the LS&SS beginning at the bottom of the KOBE JEWELRY DETAIL NO. Depth ID OD Item Hanger 1 12,389' 2.441 5.562 KOBE Cavity 2 12,395' 2.441 3.450 RN Nipple 3 12,429' 3.000 Ratcheting Mule Shoe L Perforation Detail Top Btm Zone (Mp) Btm(MD) (TVD) (TVD) Amt SPF Date Comments 1 C-5 11,180' 11,274' 10,072' 10,124' 94' 6 6/21/1995 HRS 4-5/8"Tbg.Cony. C-5 11,293' 11,940' 10,133' 10,354' 647' 6 6/21/1995 HRS 4-5/8"Tbg.Cony. Z. C C-5 12,250' 12,520' 10,458' 10,554' 270' 6 6/21/1995 HRS 4-5/8"Tbg.Cony. C-5 12,630' 13,150' 10,592' 10,758' 520' 6 6/21/1995 HRS 4-5/8"Tbg.Cony. C-5 13,147' 13,224' 10,757' 10,782' 77' 5 04/29/15 III ....... 2 CM MI3 PBTD=13,263'MD (10,795'TVD) TD=13,351'MD(10,829'TVD) Updated by: JLL 06/01/15 o S • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 18742#51 Pumping Unit 50-733-20464-00 195-004 4/29/16 5/2/16 Daily Operations: 04/29/2016-Friday MIRU pumping equipment. Pressure Test surface lines to 300 psi. Shut off Hydraulic Jet Pump. Mixed chemicals and pumped in the following sequence: Open annulus valve and pumped 440 gallons of pre-flush (110 gallons of WAW-5206 mutual solvent blended with 330 gallons of Xylene). Pumped 1210 gallons of Oil Safe AR acid. Flushed with FIW. RD injection Pump. RU Power Oil to annulus and pumped 400 bbl oil for oil cap. SD and let soak for 2-3 days. 04/30/2016-Saturday Well SI-con't acid soak. 05/01/2016-Sunday Well SI-con't acid soak. 05/02/2016-Monday Well SI,cont acid soak. Returned well to production. 0 • N 9s O4( "-OF Tk, .. (i.5-6, ��\1%%ins, THE STATEMask Oil end C as - d -`�a p f TT Conservation Commission '. .01--.-_:--_,-;,:.",,i, 333 West Seventh Avenue u = = �rM,, , GOVERNOR BILL WALKER Anchorage, Alaska 99501 3572 Main: 907.279.1433 FALASY'� Fax: 907.276.7542 www,aogcc.alaska.gov Stan Golis Operations Manager Hilcorp Alaska, LLC ` I ri : 2 .3 ;v- 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 18742 51 Permit to Drill Number: 195-004 Sundry Number: 316-099 Dear Mr. Golis: 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, P:- 51-4- '711--\. Cathy P. oerster Chair DATED this /1)day of February, 2016. RBDMS LA- FEB 1 1 2016 S RECEIVED STATE OF ALASKA FEB 0 4 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION fg'i Z/4 I APPLICATION FOR SUNDRY APPROVALS Anrr 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate 0 (Acid)• Pull Tubing ❑ Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0 • 195-004 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service CI6.API Number: Anchorage,AK 99503 50-733-20464-00 . 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 i Granite Pt St 18742 51 - 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0018742 Granite Point Field/Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): -13,351 10,829 13,263 10,795 100 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,130' 18-5/8" 1,130' 1,130' Intermediate 3,798' 13-3/8 3,798' 3,797' 3,450 psi 1,950 psi Production 10,875' 9-5/8" 10,875' 9,841' 6,870 psi 4,760 psi Liner 2,652' 7" 13,351' 10,828' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11,180-13,224 , 10,072-10,782 LS 2-7/8" 6.5#/L-80 12,429' SS 2-7/8"&2-3/8" 6.5#/L-80&4.6#/L-80 12,378' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A N/A&N/A 12.Attachments: Proposal Summary E Wellbore schematic 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ StratigrapD Development❑ - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/19/2016 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 the procedure approved herein will not be deviated from without prior written approval. Contact Trudi Hallett(907)777-8323 Email thallett@hilcorp.com Printed Name G�� Stan W.Golis Title Operations Manager Signature c.-�t',--- •. Phone (907)777-8356 Date 2 I (� COMMISSION USE ONLY Conditions of approval: Notify Com ission so that a representative may witness Sundry Number: 3\R — O99 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Q — Spacing Exception Required? Yes ❑ No Subsequent Form Required:0 tU APPROVED BY Approved by: 19 COMMISSIONER THE COMMISSION Date: L ® — �o 91Q3 0511c- Submit z��l�b OPRoleGiiIiNk6 Submn Form ane Form 10-403 Revised 11!2015 for 12 months from the date of approval. Attachments in Duplicate RBDMS ci- FEB 1 1 2016 • Well Work Plan Well: AN-51 Hilcorp Alaska,LL Date:02/03/2016 Well Name: AN-51 API Number: 50-733-20464 Current Status: HYD Lifted Producer Leg: Leg#1 NW Corner Estimated Start Date: February 19, 2016 Rig: N/A Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 1950040 First Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 300 psi @ 10,782' TVD (Fluid level, Gradient &Annulus Pressure) Maximum Expected BHP: 2200 psi @ 10,782 TVD (Based on Static Fluid level @ last No-Flow, Gradient &Annulus Pressure). Max. Potential Surface Pressure: 100 psi treatment pump pressure limit Well Summary The AN-51 is an oil producer which is currently on Hydraulic Jet Pump artificial lift. Total fluid production from this well decreased after being shut in in 2010 and brought back on in the spring of 2015 after a workover. The pump has completely scaled off several times and inflow to the well bore is very low. Scale has been prevalent in this well since 2002. The scale has been shown to be acid soluble. Diagnostics of the well indicate that there is a restriction in the wellbore which is choking back inflow. This decrease is believed to have been caused by scale formation in the well bore at the X nipple located at 12,249' or at the slotted liner. Well Obiective Hilcorp plans to pump an Oil Safe AR acid soak down the annulus, and leave soak across the perfs for 2 to 3 days to clean up any scale deposition at the perforations. The spent acid will then be pumped out of the well with produced fluids via the normal Hydraulic Jet Pump artificial lift. Procedure: 1. MIRU pumping equipment. 2. Pressure test surface lines to 1,000 psi. 3. Shut off Hydraulic Jet Pump. 4. Mix chemicals and pump in the following sequence: a. Open Annulus valve and pump ±440 gallons (±11 bbls) of pre-flush (±3 bbls WAW-5206 mutual solvent blended with ±8 bbls of ) X lene . Y b. Pump ±875 gallons of"Oil Safe AR" acid (± 21 bbls). c. Pump ±875 gallons (± 21 bbls) of FIW flush following the acid. 5. Shut down pump and let acid soak for 2 to 3 days. 6. RD Pumping equipment. 7. Return well to production. 8. Schedule a No-Flow test within 14 days of stable production. Attachments: 1. As-Built Schematic 2. Pumping Unit Diagram • • Anna Platform SCHEMATIC Well # 51 Completion: 05/02/15 Hilcorp Alaska,LLC API#50-733-20464 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. i It 1 r 718-5/8" 97# X-56 Surface 1130' 13-3/8" 68# K 55 Surface 3798" 9-5/8" 47# L-80 Buttress 8.681" Surface 10875' 7"Liner 29# L-80 Buttress 6.184" 10699' 13351' TUBING PBTD 13,263' Long String 2-7/8" 6.5 L L-80 EUE 2.441 Surf 10,643' 2 7/8" 6.5 -80 Sprmx SC 2.441 10,643' 12,429' Short String 2 7/8" 6.5 L-80 8RD EUE 2.441 Surf 10,625' 2 3/8" 4.6 L-80 Sprmx SC 1.995 10,625' 12,378' Note: Discrepancy of 11.25'between the LS&SS beginning at the bottom of the KOBE JEWELRY DETAIL NO. Depth ID OD Item Hanger 1 12,389' 2.441 5.562 KOBE Cavity 2 12,395' 2.441 3.450 RN Nipple 3 12,429' 3.000 Ratcheting Mule Shoe L Perforation Detail Top Btm Zone (Mp) Btm(MD) (TVD) (TVD) Amt SPF Date Comments i C-5 11,180' 11,274' 10,072' 10,124' 94' 6 6/21/1995 HRS 4-5/8"Tbg.Cony. C-5 11,293' 11,940' 10,133' 10,354' 647' 6 6/21/1995 HRS 4-5/8"Tbg.Cony. Z Z C-5 12,250' 12,520' 10,458' 10,554' 270' 6 6/21/1995 HRS 4-5/8"Tbg.Cony. C-5 12,630' 13,150' 10,592' 10,758' 520' 6 6/21/1995 HRS 4-5/8"Tbg.Cony. C-5 13,147' 13,224' 10,757' 10,782' 77' 5 04/29/15 HEE S 1k-.1. -_... 2 3 -tea m PBTD=13,263'MD (10,795'ND) Z „ilk. ,� TD=13,351'MD(10,829'ND) Updated by: JLL 06/01/15 • o 5 )D z� § § 3§ ! z § k$ o \o.o. \ H | | | || il! q_ . . �. • 5 ■ . � to rt rc b. rc j § . § ■ V OF Tye ///;,7;4-4_,,?, THE STATE Alaska Oil and Gas N ► �iM of LAsKA Conservation Commission A 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Op.vil *•�•� Main907 279.1433 ALAS" Fax 907 276 7542 www.aogcc alaska.gov June 19, 2015 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification �CAN�E© L.1 N 2 ( 201s Granite Point State 18742 #51 PTD 1950040 Dear Mr. Golis: On May 28, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Granite Point State 18742 Well #51 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 #51 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 #51 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, _.,a1/2.E 4Se-77 James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg cif (� 6 161 1-:".; DATE: 5/28/15 P. I. Supervisor FROM: Johnnie Hill SUBJECT: No Flow Test Petroleum Inspector Granite Pt State 18742 Anna #51 Hilcorp Alaska LLC PTD 1950040 - 5/28/2015: I traveled to Granite Point Field Anna Platform (Cook Inlet) to witness a no- flow test of Well #51. This well is a jet pump completion (recently worked over to replace the failed jet pump completion). The jet pump operates with power fluid down the short string tubing and produces up the long string. Refer to pictures for rig-up: Tubing-Casing Annulus: 2-inch ball valve; tie-in "tee" for tubing; camlock-style quick connect reducing line from 2-inch by 3/4-inch; calibrated pressure gauge; calibrated no-flow meter. Tubing (Long string): Line coming off long string was 3/8-inch diameter with gauge and quarter turn valve, tied in upstream of the calibrated 0-30psi pressure gauge. Outlet from the no-flow meter was rigged to an open top drum. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 11:00 a.m 0/0/60 - 0 0 start with valve closed 11:30 0.5/0/60 0 0 shut in 12:00 0.75/0/60 1800 0 opened 12:30 0.5/0/60 200 0 opened-it took 5min to bleed down to 300 scf/hr 13:00 0.3/0/60 200 0 opened 13:30 0.2/0/60 100 0 opened 14:00 0/0/60 - 0 0 - opened 1 Pressures are T/IA/OA Summary: Everything went very well on the no flow test. SCANNED JUL 0 2 2015 Attachments: Photos (3) 2015-0528_No-Flow_GranitePt State_18742_Anna-51_jh.docx Page 1 of 3 No Flow Test— Granite Pt State 18742 Anna #51 Photos by AOGCC Inspector J. Hill 5/28/2015 c w i :',,,, -1. , , 4 Ao i , , .,-, ,,,;-- ir a- it4 , . *, ...ft,,,.,,.,,,,, , ,,,,,, ',. , ' it,,, Tubing-Casing �,, annulus equipped ::::: ;, :a with(L to R)ball valve,tie in from ,''''''- 1 r, 4 '1, _.,..4,,,,,,,,,74.40,44,t'f-k41.,...„ .*' ''''': ,- ' tubing,calibrated low pressure gauge 11010:, T a. ' mom- - , V f 7 � Calibrated No '°" Flow Meter ` -14 i 2015-0528 No-Flow GranitePt_State_18742_Anna-5I jh.docx Page 2 of 3 o-..,.. , 0 r r Jam;:ti �$. V. r 0 a , 4i - =+111114x' 4. ' I 11111F 1 C Piping associated with tubing outlet from tree allikomi' p _ .. .. _ , ,.. ... 1' .,t. , . . . I . ik r t,.. ,,1 ,,,. ., _.,,,,, ,fr 2015-0528_No-Flow_GranitePt_State_18742_Anna-51,jh.docx Page 3 of 3 ' 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 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑l Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool❑ Repair Well 2 Re-enter Susp Well❑ Other: Re-Run Jet Pump CI 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 2 Exploratory El 195-004 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: ED Anchorage,AK 99503 50-733-20464-00 E C E I 6 �. 7.Property Designation(Lease Number): 8.Well Name and Number: V ADL0018742 Granite Pt St 18742 51 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): JUN 0 1 2015 N/A Granite Pt Field/Middle Kenai Oil Pool 11.Present Well Condition Summary: ,AOGCC Total Depth measured 13,351 feet Plugs measured N/A feet true vertical 10,829 feet Junk measured N/A feet Effective Depth measured 13,263 feet Packer measured N/A feet true vertical 10,797 feet true vertical N/A feet Casing Length Size MD ND Burst Collapse Structural Conductor Surface 1,130' 18-5/8" 1,130' 1,130' Intermediate 3,798' 13-3/8" 3,798' 3,797' 3,450 psi 1,950 psi Production 10,875' 9-5/8" 10,875' 9,841' 6,870 psi 4,760 psi Liner 2,652' 7" 13,351' 10,828' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Long String 2-7/8"6.5#L-80 12,429'(MD) 10,521'(ND) Tubing(size,grade,measured and true vertical depth) Short String 2-7/8"6.5#L-80& 12,378'(MD) 10,503'(ND) 2-3/8"4.6#L-80 Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/ASCANNED , U�N 1 8 'C i i Treatment descriptions including volumes used and final pressure. N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure • Prior to well operation: 0 0 0 100 88 Subsequent to operation: 0 0 0 73 88 14.Attachments(required per 20 AAC 25.070..25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ 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: 315-155 Contact Ted Kramer Email tkramer(a�hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature . /` Phone (907)777-8420 Date 6/1/2015 Form 10-404 Revised 5/2015 C =Y—i,d.e ��--RBDM ubmit Original O;201 _. 14 Anna Platform SCHEMATIC Well #51 Completion: 05/02/15 Ifilcorp Alaska,LLC API#50-733-20464 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. i f ' • 18-5/8" X-56 Surface 1130' 13-3/8" 68# K-55 Surface 3798" 9-5/8" 47# L-80 Buttress 8.681" Surface 10875' 7"Liner 29# L-80 Buttress 6.184" 10699' 13351' TUBING PBTD 13,263' Long String 2-7/8" 6.5 L 80 EUE 2.441 Surf 10,643' 2-7/8" 6.5 L-80 Sprmx SC 2.441 10,643' 12,429' Short String 2-7/8" 6.5 L 80 8RD EUE 2.441 Surf 10,625' 2 3/8" 4.6 L 80 Sprmx SC 1.995 10,625' 12,378' Note: Discrepancy of 11.25'between the LS&SS beginning at the bottom of the KOBE JEWELRY DETAIL NO. Depth ID OD Item Hanger 1 12,389' 2.441 5.562 KOBE Cavity 2 12,395' 2.441 3.450 RN Nipple 3 12,429' 3.000 Ratcheting Mule Shoe L Perforation Detail Top Btm Zone (Mp) Btm(MD) (TVD) (ND) Amt SPF Date Comments C-S 11,180' 11,274' 10,072' 10,124' 94' 6 6/21/1995 HRS 4-5/8"Tbg.Cony. C-S 11,293' 11,940' 10,133' 10,354' 647' 6 6/21/1995 HRS 4-5/8"Tbg.Cony. Z 21 C-5 12,250' 12,520' 10,458' 10,554' 270' 6 6/21/1995 HRS 4-5/8"Tbg.Cony. C-S 12,630' 13,150' 10,592' 10,758' 520' 6 6/21/1995 HRS 4-5/8"Tbg.Cony. C3 13,147' 13,224' 10,757' 10,782' 77' 5 04/29/15 1.1T 1 --.1. -•- m 2 = 3 - C . PBTD=13,263'MD (10,795'ND) • ' •�` TD=13,351'MD(10,829'ND) Updated by: ILL 06/01/15 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GRANITE PT ST 18742 #51 50-733-20464-00 195-004 4/18/15 5/2/15 Daily Operations: 04/18/15-Saturday CONTINUE RIGGING UP. FINISH INSTALLING TOTAL SAFETY GAS MONITOR SYSTEM AND QUADCO RIG SENSE. TEST BOTH, OK.TOOK ON 180 BBLS DRILL WATER FROM PRODUCTION IN MUD PITS. HOOKED UP POWER TO ACCUMALATOR. CAMERON TESTED HANGER TO 5000 PSI, GOOD TEST. R/U ON SHORT STRING DISPLACED TUBING VOLUME WITH 85 BBLS. R/U ON LONG STRING AND DISPLACED TUBING WITH 90 BBLS. NO PRESSURE WHILE PUMPING ON BOTH SIDES. SET BACK bP PRESSURE AT 1600 HR, REMOVE FLOW LINE FROM TREE. REMOVED TREE, INSPECT HANGER. INSTALLED FLANGE OVER�-' DSA FOR WELL HEAD. N/U BOP'S. HOOK UP ACCUMALATOR LINES. SECURE STACK. BOP TEST WITNESS WAIVED BY JIM REGG WITH AOGCC AT 18:29 HRS ON THE 4-18-2015. I. 04/19/15-Sunday ` s ATTEMPT TO PULL TWO WAY CHECK ON SHORT STRING AND LONG STRING. BOTH HAD PRESSURE UNDERNEATH. TAKE ON DRILL WATER FROM PRODUCTION INTO MUD TANK. PUMP 100 BBLS DOWN BOTH STRINGS THROUGH CHECK. PULL TWO WAY CHECKS. INSTALL BACK PRESSURE VALVE. INSTALL TEST JOINT WITH BLANKING SUB. FILL STACK, SHELL TEST STACK. TEST GOOD, NO LEAKS, TEST BOP'S TO 250 PSI LOW AND 3000 PSI HIGH AS PER HILCORP AND AOGCC SPECS HOLDING 5 MIN EACH ON CHART. R/D TESTING EQUIPMENT( HELD FIRE AND ABANDON DRILL). R/U SCAFFOLD AROUND BOP'S. R/U BELL NIPPLE AND DRIP PAN TOP SECTION RISER. R/U WIRELINE AND LUB TEST TO 1500 PSI. RIH AND CORRALATE 10 SHOT HOLE PUNCH GUN ON DEPTH. PUNCH HOLES 10,4391-10,441', POOH. 04/20/15 - Monday R/U AND PUMP 20 BBLS DOWN SHORT STRING. MAKE CUT @ 10,437' W/RTC CUTTER. POOH. REMOVED RIG FLOOR AND REPOSITIONED BELL NIPPLE. INSTALL FLOOR BACK. MADE UP JT. SCREWED 8 1/2 TURNS TO LEFT TO UN-SNAP RING. PULL ON TBG WORKING UP TO 165K. INNER HANGER MOVING UP BUT BOTTOM TBG NO MOVEMENT. PULL 140K SET SLIPS. R/U E-LINE. RIH WITH RTC CUTTER, MADE CUT AT 10,438'. PIPE MOVED WHEN CUT, POOH WITH E-LINE R/D. LATCH ONTO TBG PULL ON PIPE. PIPE FREE, PULL INTER HANGER TO RIG FLOOR. REMOVE SAME. POOH LAYING DOWN 3 1/2" 9.3 # L-80 TBG. 100 JTS. STARTED GETTING OIL AND LITTLE GAS FUMES BACK TO SURFACE. CIRC PUMP 100 BBLS DOWN TBG. OIL BACK ON ANNULAS. R/U TO REVERSE OUT. TOTAL FLUID LOST TO HOLE 420 BBLS. 04/21/15-Tuesday R/U AND REVERSE OUT HOLE VOLUME @ 7,733'TAKING RETURNS UP SHORT STRING DUE TO OIL AND GAS BACK AT SURFACE. CLEAR FLUID COMING BACK. WELL STATIC. POOH, L/D 3 1/2" 9.2 # L-80 PRODUCTION TBG. L/D TOTAL 140 JTS. BOTTOM OF SHORT STRING @ 3,000'. HOLE TAKING PROPER FILL. STARTED GETTING OIL AND GAS BACK TO SURFACE. R/U AND PUMP HOLE VOLUME DOWN SHORT STRING TAKING RETURNS TO SHAKES TILL CLEAN. LET SET AND MONITOR WELL. AFTER 10 MIN STARTED GETTING GAS BACK. PUMP ANOTHER HOLE VOLUME GOT BACK OIL AND GAS RIGHT AWAY. WHILE WAITING ON KCL TO ARRIVE TO WEIGHT UP FLUID, PUMP RIG TANK TO PRODUCTION.TOTAL 155 BBLS. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GRANITE PT ST 18742 #51 50-733-20464-00 195-004 4/18/15 5/2/15 Daily Operations: 04/22/15 -Wednesday WHILE WAITING ON FRAC TANKS AND KCL TO ARRIVE, SERVICED RIG. PUMPED OIL OUT OF MUD TANK TO PRODUCTION. CHANGED OIL IN DRAWWORKS ENGINE &TRANSMISSION. CHANGED OUT ALTERNATOR ON DRAWORKS. ADDED 100 BBLS TO MUD TANK. OFFLOAD BOAT. CONNECTED RETURN LINE TO FRAC TANK. START PUMPING IN REVERSE POSITION 250 BBLS MIXED & 3% KCL WEIGHT 8.5', PUMP PRESSURE 250 PSI AT 3 BBLS PER/MIN. GETTING OIL AND GAS BACK TO SURFACE TILL CLEAN FLUID. MONITOR WELL, HOLE STABLE. POOH LAYING DOWN REMAINDER OF SHORT STRING.TOTAL JTS 3 1/2"TBG (329) PUP JTS (5) ONE CUT PIECE 9.45'. MAKE UP CAMERON LEFT HANDED X-O TO HANGER LONG STRING. MAKE UP FOSV AND PUMP IN SUB. START DISPLACING ANNULUS IN REVERSE POSITION WITH 765 BBLS AT 3 BBLS PER/MIN, TAKING RETURNS TO FRAC TANKS. R/U HANGER PULLER WITH DUAL ELEVATORS. SLACK OFF AND LATCH SAME. PULL AND WORKING HANGER (FLUID LOST TO HOLE 700 BBLS HOLE TAKING 6 BBLS PER/HR). LOST 80 BBLS WHILE DISPLACING GOT BACK 325 BBLS OIL. 04/23/15-Thursday CONTINUE WORKING PIPE. PULLED HANGER FREE OUT OFF BOWL, BUT PIPE STUCK DOWN HOLE. CONTINUE WORKING PIPE UP TO 185K. LAID DOWN HANGER PULLER. R/U ON LONG STRING. OFFLOADED E-LINE EQUIPMENT AND RIGGED UP SAME. TEST LUB TO 1500 PSI. RIH WITH 1 11/16" 10 SHOT TBG PUNCHER AND COLLAR LOCATOR. SET DOWN 10,538' ELM PUNCH HOLES F/ 10,523'-10,526' POOH. RIH WI 1.68 RTC CUTTER MADE CUT 10,527' ELM. POOH RID E-LINE. LAY DOWN SINGLE TBG. P/U HANGER PULLER ON DUAL STRINGS. LAND AND RELEASE SNAP RIG. WORK TILL FREE. PULL HANGER AND LONG STRING TO RIG FLOOR. R/D DUAL ELEVATORS AND EQUIPMENT REMOVED FROM RIG FLOOR. LAID DOWN HANGER AND PULLER. POOH LAYING DOWN LONG STRING 3 1/2" 9.3# L-80 TUBING.TOTAL JTS LAID DOWN AT REPORT TIME, 143 AND TWO PUP JTS.TOTAL FLUID LOST TO HOLE 725 BBLS. 04/24/15 - Friday FINISH LAYING DOWN LONG STRING RECOVERED 239 JTS OF 3 1/2" 9.2# L-80 PRODUCTION TBG, ONE JT 2 7/8" CUT PIECE FROM BLANK SUB, PTS SUB.ALL ABOVE ITEMS RECOVERED. CLEAN RIG FLOOR. PREP TO PICK UP BHA#1. OFFLOAD WORK BOAT AND BACKLOAD. STRAP BHA. P/U BHA#1, 5 3/4" OVERSHOT, PUMP OUT SUB, 4 3/4"JARS, 6 4 3/4" DRILL COLLARS,ACC JARS, X-O.TOTAL LENGTH 235.96'. PICKING UP 3 1/2" PH6 12.95#WORK STRING FROM DECK, STRAP AND DRIFT SAME. JTS PICKED UP 6:00 ( 295 ) DEPTH @ 9,500'. TOTAL FLUID LOST TO WELL 750 BBLS TO DATE. 04/25/15 -Saturday SERVICE EQUIPMENT AND RIG. CONTINUE PICKING UP 3 1/2" PH6 WORKSTRING. TAGGED TOP OF FISH @ 10,634'. ENGAGED FISH, PULL 40K OVER LET JARS HIT. FISH CAME FREE. HOOK LOAD 200-204K. POOH WITH FISH SLOWLY TO 1,741.00' TOP AND BOTTOM OF FISH 4,389.00'. HELD TRIP DRILL WITH CREW. FIRE AND ABANDON DRILL. CONTINUE POOH TO BHA. RACK BACK DRILL COLLARS IN DRK. LAY DOWN 20 JTS 2 7/8"TBG. PREP RIG FLOOR AND LAY DOWN 3 3/8" AND 4 5/8" PERF GUNS. TOTAL FISH LAID DOWN 2,648.00'. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GRANITE PT ST 18742 #51 50-733-20464-00 195-004 4/18/15 5/2/15 Daily Operations: 04/26/15-Sunday CLEANED RIG FLOOR AND PIPE RACK. PLACED PERF GUNS IN RACK FOR LOAD OUT. RIGGED UP 3 1/2"TEST JOINTS. INSTALLED TEST PLUG. FILLED STACK. PERFORMED PRE-TEST. FOUND AND REPAIRED TWO LEAKS. SHELL TEST STACK, OK. TEST BOPS AS PER HILCORP AND AOGCC SPECS TO 250 PSI LOW AND 3000 PSI HIGH. RETESTED BLINDS DUE TO VALVE HALF CLOSED, TEST GOOD. HELD EACH TEST 5 MIN EACH ON CHART. PERFORM ACCUMALATOR TEST. MATT HERRERA WITH AOGCC WITNESSED TEST. ALL WENT GOOD. PULLED TEST PLUG AND RIGGED DOWN. ATTEMPTED TO RUN MONCLA BACK UP POWER PACK. KEPT THROWING BREAKER. FOUND HYDRAULIC PUMP BAD. CONNECT TO RIG FLOOR HYDRAULIC. PICK UP BHA#2 7" CLEAN OUT ASSY, 6" BIT, 7" CSG SCRAPPER, BIT SUB, I DC, DRLG JAR, 6 DC, ACC JAR, X-O. TOTAL LENGTH 268.63'. TRIP IN HOLE TO 11,123'. P/U PIPE OFF DECK. DEPTH AT REPORT TIME 12,923'. 04/27/15- Monday Continue tih with 3-1/2" workstring and drifting tag @ 13,254' DPM. Pooh 35 stands. Pump 20 down tubing. Change out hydraulic motor on spare tongs. Change out tongs. Continue pooh with bit and scraper. Ooh with bit and scraper. Change hydraulic pump on rig motor. Check fluid level 4,600'. M/u Muleshoe, x-over, 7"test packer= 13.78'.Tih to 10,869', 160k p/u weight 112k s/o weight. Set pkr with 32k down. Mix 150 bbls drill water with 3% kcl. Fill annulus 118 bbls to fill. Close pipe rams and pressure up to 1500 psi on annulus and hold for 30 mins. 04/28/15 -Tuesday FILL HOLE,TEST 9 5/8" CSG X 7" LINER LAP TO 1500 PSI. SLIGHT LOSS IN PRESSURE. CHECK SURFACE EQUIPMENT, OK. CIRC OIL OUT OF ANNULUS.TOTAL 30 BBLS AT SURFACE,TILL CLEAN. RE-TEST 9 5/8" CSG AND 7" LINER TO 1500 PSI USING RIG PUMP, TEST OK. PULL PACKER LOOSE. LET FLUID EQUILIZE. POOH WITH 7 " PACKER, L/D SAME. CLEAN RIG FLOOR AND GREASE EQUIPMENT. RUN MONCLA GENERATOR. CHECK ALL EQUIPMENT FOR PROPER ROTATION. POWER PACK STILL NOT COMING ON. WENT BACK TO PRODUCTION POWER. HELD JSA AND SAFETY MEETING WITH E-LINE CREW. R/U LUB AND SHEAVES.TEST LUB TO 1500 PSI. P/U FIRST PERF GUN RIH TO PERF G-5 ZONE. Tag @ 13,258'TD with guns, pick up and correlate, send correlation log to Anchorage, advised to move perforation interval up 3'. Fire gun 13,207' - 13,224'.4.5 O.D. 17' gun 5 SPF. Pooh with gun run #1. Ooh. M/u gun run #2, 20'gun 5 SPF and tih to 13,211' tag, unable to get to TD 13,258'. Made several attempts. P/u and fire gun 13,187'- 13,207' pooh with gun run#2. Ooh with gun run #2. M/u gun run#3 20' gun 5 SPF TIH. 04/29/15-Wednesday CONTINUE E-LINE OPERATIONS. PERFORATED FROM 13,167'TO 13,187' (20') 5 SPF. POOH AND RUN IN WITH GUN #4 LOG ON DEPTH PERFORATED FROM 13,147' TO 13,167' (20') 5 SPF. POOH AND RIGGED DOWN E-LINE. ALL PERF GUNS FIRED. R/D E-LINE EQUIPMENT. RUN 48 STDS OUT OF DERRICK IN HOLE. PULL OUT LAYING DOWN TO MAKE ROOM TO RUN DUAL STRING. CHANGED OUT 2 7/8"X5" VARIABLE RAMS TO 2 3/8"X 3 1/2" DUAL RAMS. R/U AND TEST DUAL RAMS ON 2 7/8" AND 2 3/8"TESTED TO 250 LOW 3000 HIGH AND TESTED 2 IBOP AND TWO TIW VALVES ALL ON CHART 5 MIN EACH TEST GOOD. PULL TEST PLUG AND R/D TESTING JOINTS. HELD JSA AND SAFETY MEETING. CHANGE OUT BELLS. R/U WEATHERFORD DUAL TUBING EQUIPMENT. MAKE UP KOBE CAVITY BHA. • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GRANITE PT ST 18742 #51 50-733-20464-00 195-004 4/18/15 5/2/15 Daily Operations: 04/30/15-Thursday M/U KOBE PUMP CAVITY&XOVERS, P/U 1-JT 2-3/8" SUPERMAX, 1-JT 2-7/8" SUPERMAX. R/U STABBING BOARD. TIH P/U, DRIFTING,TALLYING 2-3/8" L-80 4.6#SHORT STRING SUPERMAX TORQUE TO 1300FT/#. 2-7/8" 6.5# L-80 LONG STRING SUPERMAX TORQUE TO 1800 FT/#TO 1,789.47'. CHANGE OUT 2-3/8" INSERTS IN SLIPS& ELEVATORS TO 2-7/8". CHANGE OUT X-OVERS FOR SURFACE SAFETY VALVES. TIH P/U, DRIFTING, TALLYING 2-7/8" 6.5 L-80 EUE TUBING BOTH LONG/SHORT STRING TORQUE TO 1800 FT/#to 6,419' AT REPORT TIME. 05/01/15 - Friday CONTINUE TIH DRIFTING AND TALLYING 2-7/8" 6.5# L-80 DUAL COMPLETION TUBING TORQUING TO 1800 FT/# PER CONNECTION. P/U HANGER AND RUNNING TOOL AND M/U TO DUAL LANDING JOINTS. M/U DUAL HANGER SEALS/ DUAL RUNNING TOOLS. R.0 HYDRAULIC HOSES AND COMPRESS SNAP RING AND HANGER PRIMARY SEAL. RUN IN ALIGNMENT PINS ON WELLHEAD, LAND HANGER. P/U WT. 160K, S/0 WT 120K. E.O.T. LONG STRING 12,431.17'. RN NIPPLE ON LONG STRING. 12,396.21'. KOBE. 12,388.84'. R/D WEATHERFORD TONGS AND DUAL SLIPS. PRESSURE TEST PRIMARY SEALS ON DUAL HANGER TO 5000 PSI , GOOD TEST. RELEASE RUNNING TOOLS AND B/O LANDING JOINTS. R/D DUAL ELEVATORS, BELLS& R/U REG SET OF BELLS. SET BPV'S IN BOTH LONG AND SHORT STRING. REMOVE EQUIPMENT OFF OF RIG FLOOR. REMOVE FLOOR PLATES AND H-BEAM. CLEANOUT DRIP PAN. N/D BELLNIPPLE AND FLOWMETER. OFFLOAD WEATHERFORD DUAL COMPLETION TO MV CHAMPION. N/D BOP AND HANG FROM MASTER SKID. 05/02/15-Saturday N/D RISER AND ADAPTER FLANGE. N/U TREE, CHANGE OUT ANNULUS VALVE. TEST VOID AND PRIMARY SEALS TO 5000 PSI. GOOD TEST. M/U FLOW LINE, AND PULL BPV'S, INSTALL 2-WAY CHECK, SHELL TEST TREE TO 5000 PSI GOOD TEST. PREPARE TO SKID RIG. REMOVE HARD LINES AND STAIRS AND LANDINGS, MOUSE HOLE AND V- DOOR. LOOSEN CAPPING BEAM CLAMPS, R/U JACKS ON CAPPING BEAMS. INSTALL RIG FLOOR (WENT ON WELL 11RD AFE @1800 HRS), REMOVE BACK CURTAIN WALL,LOOSEN BACK CLAMPS ON MASTER SKID,WHILE PRODUCTION IS PREPARING AN-51 FOR FLOW. SKID RIG SOUTH 2', R/D JACKS FOR SUB BASE, HOSES AND HYDRAULIC UNIT. SPOT HYDRAULIC UNIT ON MASTER SKID INSTALL MASTER SKID JACKS. SWAP ROTATION OF HYDRAULIC UNIT. R/U HYDRAULIC LINES TO JACKS ON MASTER SKID, REMOVE ODS DOGHOUSE AND SET ON DECK, REMOVE ROOF PLATES. REPAIR PANCAKE AND ONE CYLINDER, SKID WEST 2'. R/D MASTER SKID JACKS CCC-t ¶ 6-7 4-z_ ii— r i t5oo4o Regg, James B (DOA) From: Terry Lopez - (C) <tlopez@hilcorp.com> 'F-6M 41-2,11( Sent: Monday, April 20, 2015 10:32 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA);Juanita Lovett Subject: Bop test results Moncla 301 Granite PT. 18742 #51 Anna Platform Attachments: Chart 1.pdf; Chart 2.pdf; Chart 3.pdf; 10-424 RIG 301 4-19-15.xlsx SCANNED MAY 0 4 2015 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regg@alaska.gov AOGCC.I nspectorsna.alaska.gov phoebe.brooksalaska qov Contractor. Moncla Rig No.: 301 - DATE: 4/19/15 Rig Rep.: Anthony Edmond Rig Phone: 776-6754 Operator Hilcorp Op. Phone 776-6751 Rep.: Terry Lopez E-Mail tlopez@hdcorp corn Well Name: Granite PT. 18742#51 - PTD# 1950040 Sundry# 315-155 Amn &.P/F Operation Drilling. Workover: x - Explor.: Test: Initial: x Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250/3000 - Annular 250/3000 - Valves: 250/3000 MASP: 1493 - MISC.INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P - Well Sign P - Upper Kelly 0 NA Housekeeping P Rig P Lower Kelly 1 • P • PTD On Location P . Hazard Sec. NA Ball Type 1 • P Standing Order Posted P Misc. NA Inside BOP 1 - P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" P Pit Level Indicators P - P #1 Rams 1 2 7/8x5"var P . Flow Indicator P - P #2 Rams 1 Blind P Meth Gas Detector P - P #3 Rams 0 NA H2S Gas Detector P - P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 3 1/8 - P Inside Reel valves 0 NA HCR Valves 2 3 1/8 • P Kill Line Valves 2 3 1/8 2 1/16 ' P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 3000 P - CHOKE MANIFOLD: Pressure After Closure(psi) 1800 P Quantity Test Result 200 psi Attained (sec) 41 - P No. Valves 11 - P Full Pressure Attained (sec) 157 P Manual Chokes 1 P Blind Switch Covers. All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles Avg (#and psi): 402225 P • CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures. 0 Test Time. 5.0 " Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Tested on 3 1/2"Tbg,Gas system installed and tested.Tested from main functioned from remote AOGCC Inspection ��� 24 hr Notice YES Date/Time 4-17-15 15:38 `� -H\1Ib Waived By Jim Regg Test Start Date/Time: 4/19/2015 13:00 hrs (date) (time) Witness Test Finish Date/Time. 4/19/2015 18.00 hrs Form 10-424(Revised 06/2014) 10-424 RIG 301 4-19-15.xlsx ir _� V C Ss — getAckt, 3c.1 • Cis ,� 5)r-.te_ 16 74z (10\0 /I ,!jQ 4000 Jo O - -------- `SOD p ir �0 X00 i"~ �.Zso0 <5' 00p \ , ,,----- oo ''"-- ,'/CN, \ /, 2'D >(\\ \ \p 000 -r 100p \ \ ,apo - �soo \ \ \ \/ \ \ \ \\ `0pc vi! \,\� \ [[ 1/ / / <0 0 ‘‘ ,‘,50 , \ �,` 0 OO\`Z` 7 `\ \ O \ n 0 Q O ' O ' p j J f 3 p` �Q(30$'13` o, �... � r G • � aFF ' � 1 lj , (el N-N, k -0- , 1 I i 1 \ \ , i f / r el � > / i . - a opo ;4.-4—‘ �Q 0 / i ° ) / -vi5l i „ , \ OGP c> 4_, p”er j 0� `k / / //I/ t9; Vgl ‘ N ,,--\ \ C' c‘t `, \\ / \ (§) / f it \\ \ 0OS� - yam po � \ '-- � off' / � 000� jam/ pp O oosr— _� 0 -/ �G i ," 6c \ ,- , - oo / ...,14 Op /1/ r, ',, 000 i o 00s� �. 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Z‹ N NU` O r O p 0 / t ' / �J°° �a..• i`°1',� �o. crpa ` p o O :\'\--\''c .\ - • \ V . • . • j-`f /' 30 o: 1 1 1 \.- ' ' \‘`'' .Ace,..) / I/---1----i-- ' , , ' 1 44 t ` , • ,.tip oa k�i �'i1Sc+� / P W ,' ,, , `` ` o Qo ooh ��4` , G� �� � I// // /Tt* l O 0 \ 0 9 \e'?' ,O ' �� O / / 1 j \. O 0 O O 00 - \ • es- SP /. O� / �� �" \: - // / / - z / / :`:,..,,,,, ,..._ ' - 0001- '' ''177- ' °‘. o%‘C ///1.1.' ''/7/ '''' \, 0002----- G° ,� OOSZ 4 _,. ,,,,,N.414 ��, oos�po�i--,-___ , / %`� °\ :� \� CP r00 N. _ -- b s r P5-;_ yof Ty 0w\\\\I�j,-s, THE STATE Alaska Oil and Gas • ti�►;,-s���, o JALAsKA Conservation Commission et 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov QED . - ,' , . Dan Taylor 4 Operations Engineer 1 a 6 -D Hilcorp Alaska, LLC 1 f 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Pt Field, Middle Kenai Oil Pool, Granit Pt St 18742 51 Sundry Number: 315-155 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 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, 1 ?))—t„.3 k4-- _, Cathy P oerster Chair DATED this 25 day of March, 2015 Encl. ` t D STATE OF ALASKA c U�3 y ALASKA OIL AND GAS CONSERVATION COMMISSION /t S 3 OG C APPLICATION FOR SUNDRY APPROVALS 20 AAC 25280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well Change Approved Program❑ Suspend❑ Plug Perforations❑ ,mac Q Perforate❑ . PuN Tubing❑ , Time Exten 9n El Operations Shutdown❑ Re-enter Susp.Well 0 Stimulate❑ Alter Casing❑ Other 4R,�_re Je fW- 2.Operator Name: 4.Current Wel Class: 5.Permit to Drill Number: Pc4.4 ) Hilcorp Alaska,LLC - Exploratory ❑ Development ❑ , \195-004- 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-2046400 1 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 76 Will planned perforations require a spacing exception? Yes 0 No[ I Granite Pt St 18742 51 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018742 , Granite Pt Field/Middle Kenai Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): 'Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 13,351 10,829 •13,263 10,797 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,130' 18-5/8" 1,130' 1,130' Intermediate 3,798' 13-3/8" 3,798' 3,797' 3,450 psi 1,950 psi Production 10,875' 9-5/8" 10,875' 9,841' 6,870 psi 4,760 psi Liner 2,652' 7" 13,351' 10,828' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 3-1/2"Dual 9.2*/L-80 10,442'&10,442' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 4/5/2015 Commencing Operations: Oil E1 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 to the best of my knowledge. Contact Dan Taylor Email dtaylor@hilcorp.com Printed Name Dan-1-_,APIP Title Operations Engineer Signature _=-- Phone (907)777-8319 Date 3/19/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: —// 31 -155 Plug Integrity ❑ BOP Test Et Mechanical Integrity Test ❑ Location Clearance ❑ Other: tE �.300D psc 670 r /sf nn (MA Si = /403 ps) -$ Ilio rr7...., " ( c-5(- re0 ���Y l X- q s, a c<_S, -J- rct......:-r-� ( I c o o p c`l Spacing Exception Required? Yes ❑ No L/ Subsequent Form Required: /0—L/O 9 APPROVED BY _ Approved by:aii �t, COMMISSIONER THE COMMISSION Date: 2 ' —IS — Submit tS j. 23 /s /yy ��21,1:--;approval. Submit Form and Form 10-403(Revised 10/2012) OuRd 13l 4In \12 months from Attachments in Duplicate RBDMS-X\ APR - 3 2015 `n43.,1(A5 Well Prognosis Well: An-51 llilcorp Alaska,LL Date:03/19/15 Well Name: GRANITE PT ST 18742#51 API Number: 50-733-20464-00 Current Status: Oil Producer Leg: 1 Estimated Start Date: April 5, 2015 Rig: Moncla 301 Reg.Approval Reqd? N/A Date Reg.Approval Rec: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 195-004 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: —2,500 psi at 10,075ft TVD Based on surrounding well data. Maximum Expected BHP: —2,500 psi at 10,075ft TVD Based on surrounding well data. Max.Allowable Surface Pressure: — 1,493 psi Based on 0.1 psi/ft gradient to 10,075ft TVD. Brief Well Summary An-51 was completed in the Tyonek C sands in 1995 as an oil producer. In 2009 the down hole Jet Pump BHA developed a hole and went off line. The below procedure outlines pulling and re-running a new Jet Pump completinn _! 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. a. Work over fluid 3% KCL. 5. Rig up slick line on long string and run in hole and remove standing valve. 6. Run in hole on long string with 2in bailer to tag and pull sample. 7. Ensure well is dead. 8. Set BPV. (xZ) 9. Nipple down tree/Nipple up BOPE. a. Function test BOPE(notify AOGCC of test 48hrs prior to expected test). 10. Test BOPE: a. Test BOPE 250psi low and 3,000psi high and chart. 11. Remove BPV. (g1-) ) 12. Pick up long and short string pulling to floor and remove hanger. 13. Rig up e-line on short string.,'/ a. Run in hole with cutter making cut above BHA. /ci 3eo' 14. Pull out of hole with short string. 15. Pull out of hole with long string. k5T C5 7 ? 16. Pick up and run in hole with clean out assembly cleaning out to PBTD. � 5 17. Pick up and run in hole with tubing conveyed perforating guns spacing out over the following intervals: c,5 Bench Top Ni)(ft) Btm Ni)(ft) Net Ft(ft) Top TVD(ft) Btm TVD(ft) Net TVD(ft) /'5 ccs, C5A 11,134 11,180 46 10,042 10,072 30 C5A 11,938 12,245 307 10,353 10,456 103 C5B 13,150 13,227 77 10,758 10,783 25 18. Pick up and run in hole with ratcheting mule shoe,jet pump BHA,and duals strings setting BHA at+/-13,000ft. 19. Land hanger. 20. Set BPV and test. 21. Nipple down BOP, nipple up tree and test. 22. Turn well over to production. 23. Complete'No Flow'test in accordance with AOGCC regulations(20 AAC 25.265.Well safety valve systems, section.h). Well Prognosis Well: An-51 llilrot ‘111.1,1i.i.i. Date:03/19/15 Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. Current/Proposed Wellhead Diagram(same) 4. BOP Stack kieligresti nna Platform Well No. 51 UNOCAL 76 Actual Completion 6/21/95 CASING AND TUBING DETAIL API#50-733-20464 SIZE WT GRADE CONN ID TOP BTM. 18-5/8"" 97# X-56 - Surface 1130' 13-3/8" 68# k-55 - Surface 3798" 1 A 9-5/8" 47# L-80 Buttress 8.681" Surface 10875' 7"Liner TUBING 29# 9.2# L-80 Buttress 6.184" 10699' 13351' PBTD 13,263' Long String 3-1/2" L-80 Buttress 2.992" 53.7' 10442' Short String 3-1/2" 9.2# L-80 Buttress 2.992" 51.9' 10442' JEWELRY DETAIL NO. Depth ID OD Item 53' Cooper Hanger 1 55' 2.992 3.920 Pup,3-1/2"Buttress x 2' 2 10427' 2.992 3.920 Pup,3-1/2"Buttress x 8' 3 10441' 3.000 3.865 X-Over,3-1/2"Buttress x 3-1/2"8rd EUE 4 10442' 2.55 7.250 Kobe,3" `Double D' Cavity 5 10470' 3.000 4.500 X-Over,3-1/2"8rd EUE x 3-1/2"Buttress 6 10502' 2.992 4.250 Ported Sub—3-1/2"x 2' 7 10503' 2.992 3.920 Pup,3-1/2"8rd EUE x 8' 8 10511' 2.441 3.125 X-over,2-7/8"BTC x 3.5"BTC 9 10543' 0 3.5 Combination Blank sub,PTS sub 10 10544' 2.441 3.250 20 Jts.2-7/8" 6.4#,L-80,BTC Tubing 11 11169 2.441 3.500 X-over,2-7/8"8rd x 2-7/8"BTC L. , 12 11170' 2.375 4.700 Pressure Transfer Sub 13 11171 0 3.4 K-II Firing Head 14 11172 0 3.700 APF-C Firing Head 2 V B 15 11180 1.220 4.625 HRS 4-5/8 6spf 32 Gram RDX Perf Guns 16 13150 0 4.625 Bull plug 3 C 4 SHORT STRING 5 A 53' 2.992 3.500 Pup,3-1/2"Buttress x 1.5' 6 B 10430' ? ? X-over,3-1/2"EUE x 3-1/2" Buttress 0 0 Seal at top of pump is C 10431' 1.995 2.375 Pup,2-3/8"4.6#L-80 Buttress x 10' partially washed 7 8 could fail at any 9 time PERFORATION HISTORY ✓ Interval Accum. 10 Date Zone Top Btm Amt spf Comments 6/21/1995 C-5 11,180' 11,274' 94' 6 HRS 4-5/8"Tbg.Cony. I 12 14 6/21/1995 C-5 11,293' 11,940' 647' 6 HRS 4-5/8"Tbg.Cony. 13 6/21/1995 C-5 12,250' 12,520' 270' 6 HRS 4-5/8"Tbg.Cony. 14 • 6/21/1995 C-5 12,630' 13,150' 520' 6 HRS 4-5/8"Tbg.Cony. y 15 w 'wf • Nwe 016 • , it . PBTD=13,263' MD (10,795'TVD) Aef y ` -, TD=13,401' MD(10,845' TVD) O:\A1aska\Fields\Granite Point\Anna\Wells\An-51\Schematics\An-51 Schematic 95.doc DRAWN BY:BMB 6/16 Anna Platform PROPOSED Well # 51 . fi Completion: Future Hilcorp Alaska,LLC API #50-733-20464 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. i N 18-5/8" 97# X-56 - Surface 1130' 13-3/8" 9-5/8" 68# K-55 Surface 3798" 47# L-80 Buttress 8.681" Surface 10875' 7"Liner 29# L-80 Buttress 6.184" 10699' 13351' TUBING Long String PBTD 13,263' 2-7/8" 6.5 L 80 EUE 2.441 Surf ±10,650' 2 7/8" 6.5 L-80 Sprmx SC 2.441 ±10,650' ±13,040' Short String 2 7/8" 6.5 L 80 EUE 2.441 Surf ±10,650' 2 3/8" 4.6 L 80 Sprmx SC 1.995 ±10,650' ±13,000' JEWELRY DETAIL NO. Depth ID OD Item Hanger 1 ±13,000' Jet Pump BHA 2 ±13,040' Ratcheting Mule Shoe SHORT STRING A ±13,000' Jet Pump BHA L Perforation Detail ,Top Btm , Zone (Mp) Btm(MD) (TVD) (TVD) Amt SPF Date Comments 15 ±11,134' +_11,180 ±10,042' ±10,072' 46' C-5 11,180' 11,274' 10,072' 10,124' 94' 6 6/21/1995 HRS 4-5/8"Tbg.Cony. C-5 11,293' 11,940' 10,133' 10,354' 647' 6 6/21/1995 HRS 4-5/8"Tbg.Cony. C-5 ±11,938' +12,245' ±10,353' ±10,456' 307' Future C-5 12,250' 12,520' 10,458' 10,554' 270' 6 6/21/1995 HRS 4-5/8"Tbg.Cony. C-5 12,630' 13,150' 10,592' 10,758' 520' 6 6/21/1995 HRS 4-5/8"Tbg.Cony. C-S ±13,150' ±10,758' ±10,783' 77' Future I K 1 A .. 2C PBTD= 13,263' MD (10,795'TVD) ' w;► ' ` 6,_ TD=13,351' MD(10,829'TVD) Updated by: JLL 03/19/15 Anna Platform . if An-51 Current 03/16/2015 Itilrnrp:1I:n.ka.I.I3. An-51 Tbg hgr,dual,13 5/8 nom 185/8X133/8X95/8X3'/: X 3'/: compact X 12"LH acme lift, w/2-od body 5 seals and 2- 5'A nom mandrel hangers on 5.650 centers,w/3'A btc susp threads X 3"nominal LH acme lift,3"type H BPV profile,top of hanger on 5.047 centers,1-'''A npt control line and 1-'''A npt control line in each mandrel Kobe Assy i IJP Tree assy,dual block,CIW-FL, I51m:r� 13 5/8 5M Flamp bottom X � 3 1/8 5M run and wing, 1 �-'-, prepped for 5.047 centers,3" I OO nom dual hanger neck pockets, 00 00 4-'''A npt control Ine ports,DD - o O trim I 4 MI Control line exits 11•_ ill___ Qty 4 i '': la 1 � Unihead,CIW-compact,20'/.3M F II 1 FLAMP bottom x 13 5/8 5M FLAMP `r= o .i't e top,w/4-2 1/16 5M SSO,prepped IjI ��.1I (3::o l Iiii All annularvalves2 1/16 SM l.Is a I' .. ,it4lh1.1. If' ems_ J1 Starting head,CIW-compact,20'A I I 3M FLAMP X 18 5/8 casing pin,w/ It it 2 1/16 SM SSO,2-3"LPO 1111 I -4 '9-Q[ lhal r'IrlA-1 I" ► � 1 - I =1� i Landing Ring for 30"casing Iii pstub and starting head l 1 30" 18 5/8" _13 3/8" 9 5/8" _-^3 W' Anna Platform Moncla BOP 03/16/2015 Hilru�p:Alaska.LLC. ufU lit til Iii lillil �nO\ /o\I d.50' Ll lil 111 1111111 1 1.1 .7— ti 4P _I 111 Ili 0 a-8 67. I1 135/8-5000 p '#I III III II1111 Iii oxe31/8 5,1 es 26' •�'��,' 111 111 111 Iil 111 /JI ►�' 111 11 1 1 1 1 1 1 11 .-.6_-44:041110.01 111111111 i!t Ili 2.83' I11'Iil iil ill Iii 111 III 111 111 111 135/8Ala%135/8SMEE 11.00' 111 III 111 lit til 111 1!11111!11 111 2,UP Spacer spool 135/85M X 13 5/8 5M i1 I That 1 111 2.)5' Spacer spool 1111111111 111 135/85MEE%115M 111 lit 111 Iii 111 Moncla 301 BOP Test Procedure Ei n�aakn.�.�.�. Attachment#1 ikon) Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Moncla 301, Grayling Platform WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test)joint to lift-threads d) For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 2) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness.As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure Moncla 301 BOP Test Procedure Hilcorp Alaska,L11. Attachment#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 system following the normal test procedure (floor valves,gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 3) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 4) If a rolling test was conducted, remove the old hanger, MU new hanger 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) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 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 space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with 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 rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. Schwartz, Guy L (DOA) From: Daniel Taylor <dtaylor@hilcorp.com> Sent: Monday, March 23, 2015 10:41 AM To: Schwartz, Guy L(DOA) Cc: Bettis, Patricia K(DOA) Subject: RE:GPS#51 (PTD 195-004) Guy, It has not been tested within that time frame sir. I will make sure to place that within our well work procedure (30min at 1,500psi). Thank you. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, March 23, 2015 10:39 AM To: Daniel Taylor Cc: Bettis, Patricia K(DOA) Subject: GPS #51 (PTD 195-004) Dan, Looking at the sundry to rerun a jet pump completion. Has the 9 5/8" casing been tested recently? This data/research should be part of any packerless RWO procedure. If it hasn't been tested in the 6-8 yrs it needs to have a 30 min 1500 psi test. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I~od'"(~t~/-/ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: . Scanned by:~ Dianna TO RE-SCAN Vincent Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ ~ /"""\ ~~&\~Œ ffi)~ &\~&\~[{&\ / .U,J\SIiA OIL AND GAS / CONSERVATION COMMISSION / May 12, 2004 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279.1433 FAX (907) 276-7542 Dwight Johnson Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verifications Well GP-50, PTD 195-003 Well GP-51, PTD 195-004 Dear Mr. Johnson: On May 3, 2004, AOGCC Petroleum Inspector Chuck Scheve witnessed "no flow tests" for Unocal's Granite Point State 18742 Wells 50 and 51 located on the Granite Point Platform. Each well was opened to atmosphere through flow measurement equipment with suitable range and accuracy after being shut in and monitored for several hours. There was no flow of gas or liquid to surface during the tests. Based on the results of these no-flow tests, the subsurface safety valves may be removed from service in Wells GP-50 and GP-51. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in each of the wells as required in 20 AAC 25.265. The subsurface safety valve must be returned to service in any well that demonstrates an ability to flow unassisted to surface. Please retain a copy of this letter on the Granite Point platform. Sincerely, á~gK~J James B. Regg 1 Petroleum Inspection upervisor cc: Bob Fleckenstein { MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 12; J /; ~l'lt ùtt P. I. Supervisor 1~1 DATE: May 3, 2004 FROM: Chuck Scheve, Petroleum Inspector SUBJECT: No Flow Granite Point Platform 50 195-003 51 195-004 Mondav. Mav 3. 2004: I traveled to Unocal's Granite Point Platform and witnessed no- flow tests on wells 50 and 51. I arrived on location and found all both wells opened to atmosphere with no .flow of gas or fluid evident. Both wells were shut in and observed for several hours with a minimal pressure build up,<30 psi, observed. I recommend Wells 50 and 51 all the Granite Point Platform be approved no flow status for the purpose of removing the Sub Surface Safety Valve. SUMMARY: Wells 50 and 51 on the Granite Point Platform meet the AOGCC requirements for no flow status. Attachments: THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03,2001 M PL A T W E IA L U N D ER T H IS M ARK ER C'i, ORI~tFILM.DOC F:' E F.i: f"11 'F ,:.;ieoJo,~i~cal Ha'ter'ials Inver"~?..or.y ,~807--1335i 'i I') --/t/.) 7 ~ 10770~-'1:33'i5 C,H/' DI.I.../CNL/DEN/'GR &FO', c,'hi~F'L,,: FIC, N [?;ATE I r'~ 'i 'I-'i' ,:::n 'J C C, kJ H E f'! l' G --- STATE OF ALASKA ALASi~ IL AND GAS CONSERVATION COME/ !ON WELL COMPLETION OR RECOMPLETION R , ORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED ~ ABANDONED['-] SERVICE 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 4. Location of well at surface Anna Platform Leg #1, Slot 2 725' FNL & 633' FEL, SEC. 12, TION, R12W, SM At Top Producing Interval At Total Depth 2044' FNL & 454' FEL, SEC. 7, TION, R12W, SM (13351 ') MD 7. Permit ~tzr~ber 8 APl Nur~be(~'i 50- 733- ~464 ' 9. Unit or Le~e Name GRANITE POINT 10. Well Number GP State 18742- #~]1' 11. Field and Pool GRANITE POINT FIELD MIDDLE KENAI "C" SANDS 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 127' RKB ABOVE MSL I ADL 18742 01/20/95 (Batch) 06/15/95 06/21/95 77' Feet MSL 1 17~T~ta~Depth(MD+TVD)18~P~gBackDepth(MD+TVD)~19~Dir~cti~na~Surve~v~2~Depthwher~SSSVs~t [ 21. Thickness of Permafrost 13,351' MD/10829' 'I'VD 13,263' MD/10797' TVD YES [] NO [] N/A feet MD N/A 22. Type Electric or Other Logs Run MLL/DLIJCDL/CNL/G R 23. I CASING SIZEI WT. PER FT. GRADE 18- 5/8" 97# X- 56 13-3/8" 68# K-55 9 - 5/8" 47 # L- 80 7" 29# L-80 CASING, LINER AND CEMENTING RECORD ISETTINGDEPTHMDll TOP I BO'I-I'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 69' 1130' 24" 2375 cf 0 69' 3798' 17-1/2" 2594 cf 0 69' 10876' 12-1/4" 904 cf 0 10699' 13351' 8-1/2" 752 cf 0 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) MD TVD 11180'-13150' 10072'-10758' 4-5/8" 6 spf 32 gm 25. TUBING RECORD SIZE I DEPTH SET (MD) I PACKER SET (MD) 3-1/2", 9.2#, L-80 BTC @ 10442' 3-1/2", 9.2#, L-80 BTC @ 10442' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED NONE 27 Date First Production 6/22/95 Date of Test 08/08/95 Flow Tubing Press. 130 Hours Tested 6 Casing Pressure 160 PRODUCTION TEST i Method of Operation (Flowing, gas lift, etc.) Hydraulic pump PRODUCTION FO~ OIL-BBL GAS-MCF TEST PERIOD / 99 42 CALCULATED / OIL-BBL GAS- MCF 24-HOUR RATE ~ 395 167 28. ~, CORE DATA WATER-BBL 1 WATER-BBL 5 CHOKE SIZE GAS-OIL RATIO 412 OIL GRAVITY-APl (corr) 41 deg. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ¢... Gas Cons. Commission Anchorage Form 10-407 rev..7-1 - 80 CONTINUED ON REVERSE SIDE Submit in duplicate 30. GEOLOGIC MARKE[__ [' ~ATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TM 1 ? 6096' 5904' C- 1 10175' 9241' C-5 10942' 9896' 31. LIST OF A'I-DACHMENTS 32. I hereby,certify that the_fo.,reg~inG, is true .a~C,,correct to the best of my knowledge Signed G. RUSSELLSCHMIDT Title DRILLING MANAGER Date 08/10/95 _ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should showthe details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ~-~'. .~.l ~ [:~' ~ Item 28: If no cores taken, indicate 'none". AUG 8 995 A~$~ 0ii & Gas Cons. Commission Anchorage ANNA 51 290'~290' DAY 1-2 (01/20-21/95) 30" @ 282' 9.6 PPG SKID RIG F/ANNA 50. NU 30" RISER. RIH W/14" MAGNET TO 281' NO RECOVERY. RIH W/CENTER PUNCH ASSBY. TAG @ 281' & WORK TO 282'. POH. LD BIT & RIH WI17-112" MILL ON CENTER PUNCH ASSBY. MILL F/282'-283'. POH. RUN GYRO. RIH W/MILL ASSBY. MILL F/283'-285' AND FELL THRU. CO TO 290', SET DOWN ON 25.2". STRING MILL @ 275'. POH. LD 17-1/2' MILL. RIH W/25.2" STRING MILL & MILLED F/275'-279'. POH. RIH WI23.5' BLADED MILL. MILL FI281'-282'. POH. MILL WORN OUT. RELEASE RIG TO ANNA #52 @ 1800 HRS 1/21/95. PREPARE TO MILL CONDUCTOR. DAY 3 (01/24/95) 30" ¢___.. 282' 9.6 PPG SKID RIG F/ANNA #52. NU RISER. RIH W/21" BLADED MILL. MILL F/282'-285' & FELL THRU. CLEAN OUT F/290'-294', RUNNING ON JUNK. POH. MILL 1/2" UNDERGAUGE. RIH W/21" MILL, WORK FI280'-285' SEVERAL TIMES TO POLISH. MILL ON JUNK F/294'-295'. POH, MILL FULL GAUGE. MADE 22 TRIPS W/MAGNETS JUNK BASKETS AND BIT. RECOVERED ABOUT 40 LBS OF IRON, CLEAN OUT TO 350'. ANNA 51 675'/325' DAY 4 (01/25/95) 30" @ 282' 18-5/8" @ 1130' 9.6 PPG CONT W/CLEANOUT RUNS, RECOVERY DIMINISHING, JUNK APPEARS TO BE ON BOTTOM & STUCK IN WALL. RIH W/PENDULUM ASSBY. DRILL F/350'-372'. STILL RUNNING ON JUNK. POH. RIH W/JUNK BASKET, NO RECOVERY. RIH W/PENDULUM ASSBY. KICKED JUNK TO SIDE AND DRILL F/372'-675'. DAY 5 (01/26/95) 30" @ 282' ,~dG '~ 8 '~995 ,~$~ 0il .& Gas Cons. Cornmissior~ , 'Anchorage 9.7 PPG DRILLED F/675'-1150'. GYRO HOLE. POH. RECOVER 15 LBS JUNK IN BOOT BASKET. RIH W/24" UNDERREAMER. OPEN HOLE FI17-112" TO 24" F/290'-625'. REPAIR TOP DRIVE. DAY 6-8 (01/27-29/95) 30" @ 282' 18-5/8" C 1130' 9.7 PPG TIME REQ'D: 47 DAYS OPEN HOLE FI17-112" TO 24" F/625' TO 1145'. POH. R&C 18-5/8" CSG @ 1130' W/870 SX LEAD @ 12.8 PPG FIB 550 SX TAIL @ 15.8 PPG. CIP @ 0505 1/28/95. CIRC 80 BBL CMT. POH W/INNER STRING. ND 30" RISER. NU AND TEST 20" STACK. REPAIR TOP DRIVE. RIH W/ROTARY ASSBY. CO CMT Fl1107'-1150'. DRILL NEW HOLE Fi1150'-1170'. BOTTOM APPEARS TO BE CLEAN. POH AND CONDUCT LOT. 22 PGG EMW (UNCORRECTED). POH. FOUND 3# JUNK IN BOOT BASKET. RIH W/ROTARY ASSBY. DRILL F/1170'- 1266'. DAY 9 (01/30/95) 30" @ 282' 18-5/8" C 1130' 9.8 PPG DRILL 17-1/2" HOLE F/1266' TO 1500' MWD FAILURE. POOH FOR ROTARY ASSY. DRILL FROM 1500' TO 2525'. DAY 10 (01/31/95) 30" @ 282' 18-5/8" C 1130' 9.7 PPG TIME REQ'D: 47 DAYS DRILL 17-1/2" HOLE F/2525' TO 2943' PENTRATION RATE SLOWEDi POOH FOR NEW BIT. RIH W/ROTARY ASSY DRILL 2943' TO 3235'. DAY 11 (02/01/95) 30" @ 282' 18-5/8" C 1130' 9.9 PPG DRILL 17-1/2" HOLE TO 3807'. POOH TO RUN 13-3/8" CASING. TIGHT HOLE HAD TO BACK REAM. R/U AND START TO RUN CASING DAY 12 (02/02/95) 30" @ 282' 18-5/8" C 1130' 13-3/8" C 3798' 9.9 PPG RUN & CEMENT 13-3/8" CSG TO 3807'. ClP AT 1045 HRS. INSTALL PACKOFF & TEST SAME TO 3500 PSI, OK. REM BOP & INSTALL "B" SECTION OF WELLHEAD. TEST WELLHEAD TO 5000 PSI. REL R428 AT 2400 HRS. DAY 13 (05/14/95) 30" ¢_____. 285' 18-5/8" C 1130' 13-3/8" C 3798' 9.O PPG SKID RIG & NU BOP, TEST SAME. MU BHA & RIH TO 3702'. PRESS TEST 13-3/8" CSG TO 2800 PSI Fl30 MINS, OK. CLOUT FC & CMT TO 3783', RETEST CSG TO 2800 PSI, NEG. DRILL OUT SHOE & NEW HOLE TO 3820'. PERFORM LOT TO 12.9 PPG EMW. POOH. RIH W/OEDP. DAY 14 (05/15/95) 30" @ 285' 18-5/8" C 1130' 13-3/8" C 3798' 9.8 PPG CONT RIH TO 3820'. M&P 75 BBL BAL PLUG OF CMT AT 15.8 PPG. DN SQZ 55 BBLS CMT AT 900 PSI, CIP AT 0315 HRS 3/15/95. HELD 800 PSI F/45 MINS & REL SAME. POOH. MU BHA & RIH. TAG TOC @ 3675'. CLEAN OUT TO 3820' & DRILL 10' OF NEW HOLE. CONDUCT LOT. CHANGE OVER MUD SYSTEM, DRILL AHEAD TO 3895'. APPEARS TO HAVE JUNK IN HOLE. POH. DAY 15 (05/16/95) 30" @ 285' 18-5/8" C 1130' 13-3/8" C 3798' 10 PPG RIH W/GLOBE BASKET, CUT CORE & POH. REC. 18 LBS IRON. RERAN GLOBE BASKET, CUT CORE & POH. NO RECOVERY & SHOE RAN SMOOTH ON BOTTOM. RIH W/MILL TOOTH BIT & BOOT SUB. DRILL F/3900' - 3955'. BOTTOM APPEARS TO BE CLEAR OF JUNK. POH. RIH W/MOTOR ASSBY. DAY 16 (05/17/95) 30" @ 285' 18-5/8" C 1130' 13-3/8" C 3798' 9.7 PPG DRILL 12-1/4" HOLE F/3955'- 4830'. DAY 17 (05/18/95) 30" ¢____.. 285' 18-5/8" C 1130' 13-3/8" C 3798' 9.7 PPG DRILL 12-1/4" HOLE F/4830' - 5236'. POH F/BIT. DAY 21 (05/22/95) 30" ¢_____, 285' 18-5/8" C 1130' 13-3/8" C 3798' 9.7 PPG D.C. $ 48,184 CUM: $ 1,295,436 AFE: $ 3,823,000 AFE ¢/:751201 TIME REQ'D: 47 DAYS DRILL 12-1/4" HOLE F/6785' - 7620'. DAY 22 (05/23/95) 30" ¢_____. 285' 18-5/8" C 1130' 13-3/8" C 3798' 9.8 PPG DRILL 12-1/4" HOLE F/7620'- 8073'. POH F/BIT. HOLE TIGHT IN SPOTS. DAY 23 (05/24/95) 30" @ 285' 18-5/8" C 1130' 13-3/8" C 3798' 9.8 PPG FINISH OUT OF HOLE. RIH W/ROTARY ASSBY. TRIP IN WENT OK. DRILLED 12-1/4" HOLE F/8073'-8545'. DAY 24 (05/25/95) 30" ¢___. 285' 18-5/8" C 1130' 13-3/8" C 3798' 9.8 PPG /XLJG '~ 8 't995 ~,s~ oi~ & Gas Cons. Commissior~ Anchorage DRILLED 12-114" HOLE F/8545'-8600'. POH DUE TO TORQUE. HOLE TIGHT 8600'- 7950', NOT BAD. RIH W/ROTARY ASSBY. TIH, OK. DRILLED 12-1/4" HOLE F/8600'- 8995'. DAY 25-28 (05/26-29/95) 30" @ 285' 18-5/8" C 1130' 13-3/8" C 3798' 9.8 PPG TIME REQ'D: 47 DAYS DRILLED 12-114" HOLE F/8995'-9320'. POH F/BHA. CONDUCT BOP TEST. RIH W/ROTARY ASSY. DRILL 12-1/4" HOLE F/9320'-9595' WHILE CIRC WELL OVER TO NEW MUD SYSTEM. MWD FAILED. POH. CHANGE OUT MWD. RIH W/ROTARY ASSBY. DRILL 12-114" HOLE F/9595'-10246'. POH F/BIT & BHA. DAY 29 (05/30/95) 30" @ 285' 18-5/8" C 1130' 13-3/8" C 3798' 9.8 PPG CONT POH. RIH W/ROTARY ASSBY. DRILL 12-1/4" HOLE F/10246'- 10530'. DAY 30 (05/31/95) 30" @ 285' 18-5/8" C 1130' 13-3/8" C 3798' 9.8 PPG DRILL 12-1/4" HOLE F/10530'-10888', 9-5/8" CSG PT. SHORT TRIP TO 9000', HOLE TIGHT 10756'-9829'. DAY 31 (06/01/95) 30" @ 285' 18-5/8" C 1130' 13-3/8" C 3798' 9.9 PPG RIH. REAM 10773'-10886'. POH F/CSG, HOLE TIGHT 10803'-10760'. STRING TO 12 LINES, CHANGE PIPE RAMS & RU CSG CREW. RIH W!9-518" CSG. DAY 32-34 (06/02-06/95) 30" @ 285' 18-5/8" C 1130' 13-3/8" C 3798' 9.6 PPG CONT RIH W/9-5/8" CSG. SET DOWN @ 10858', WORK TO 10876'. CCH F/CMT. CMT 9-5/8" CSG W/786 SX CMT. ClP @ 0840 HRS 6/2/95. SET & TEST PACK OFF. TEST BOP. STRING TO 10 LINES. RIH W/MOTOR ASSBY & DRILL FIE. DRILL 8-1/2" HOLE F/10876'- 10900', CONDUCT FIT, 16.8 PPG EMW. DRILL 8-1/2" HOLE F/10900'- 11233'. POH F/BIT. RIH W/MOTOR ASSBY. DRILL 8-1/2" HOLE F/11233'-11385'. FELL OUT BTM OF C-5 @ 11328'. ClRC BTMS UP & PULL INTO CSG. DAY 36 (06/06/95) 30" @ 285' 18-5/8" C 1130' 13-3/8" C 3798' 9.5 PPG CLEANOUT CMT F/10556'-10890'. START SIDE TRACK @ 10890'. DRILL 8-1/2" HOLE F/10890'-11137'.' DAY 37 (06/07/95) 30" @ 285' 18-5/8" C 1130' 13-3/8" C 3798' 9.5 PPG DRILL 8-1/2" HOLE F/11137'-11154'. POH F/BIT. RIH W/MOTOR ASSBY. DRILL 8-1/2" HOLE F/11154'-11285'. HAVING TROUBLE SLIDING, POH TO CHECK TOOLS. DAY 38 (06/08/95) 30"@ 285' 18 5/8" @ 1130' 13 3/8" @ 3798' 9 5/8"@ 10874' 9.5 PPG CONTINUE POOH CHANGE BIT AND BHA. RIH TOOK WT AT 10,927'. WORK THROUGH SPOTTY TIGHT SPOTS FROM 10,927'TO 11,188'. SPOT REAM FROM 11,188' TO 11,285'. DIRECTIONALLY DRILL AND ROTARY DRILL FROM 11,285' TO 11,465'. DIFFICULTIES GETTING THE ASSEMBLY TO SLIDE DRILL. DAY 39-41 (06/09-11/95) 30"@ 285' 18 5/8" @ 1130' 13 3/8" @ 3798' 9 5/8" @ 10874' 9.5 PPG DRILL 8-1/2" HOLE F/11465'-11517'. POH F/MWD. RIH W/MOTOR ASSBY. DRILL 8-1/2" HOLE F/11517'-11913'. PUMP PRESSURE INDICATED PROBLEM W/MOTOR. CHANGE OUT MOTORS. REPAIR TOP DRIVE & CONDUCT BOP TEST. RIH W/MOTOR ASSBY. DRILL 8-1/2" HOLE F/11913'-12328'. DAY 42 (06/12/95) 30"@ 285' 18 5/8" @ 1130' 13 3/8" @ 3798' 9 5/8"@ 10874' 9.5 PPG DRILL 8-1/2" HOLE F/12328'-12407'. POH TO CHECK BIT & MWD. RIH W/MOTOR ASSBY. BROKE CRANK ON PUMP #2 ON TIH. DRILL 8- 1/2" HOLE F/12407'-12443'. DAY 43 (06/13/95) 30"@ 285' 18 5/8" @ 1130' 13 3/8" @ 3798' 9 5/8" @ 10874' 9.5 PPG DRILL 8-1/2" HOLE FI12443'-12858'. POH F/BIT. DAY 44 (06/14/95) 30"@ 285' 18 5/8" @ 1130' 13 3/8" @ 3798' 9 5/8" @ 10874' 9.6 PPG AUG 1 8 1995 OJt & Gas Cons. Commission Anchorage RIH W/MOTOR ASSBY. DRILL 8-1/2" HOLE F/12858'-13171' DAY 45 (06/15/95) TIME REQ'D: 47 DAYS 30"@ 285' 18 5/8" @ 1130' 13 3/8" @ 3798' 9 5/8"@ 10874' 9.6 PPG DRILL 8-1/2" HOLE F/13171'-13319'. BIT QUIT, CCH F/TRIP. POH. RIH W/MOTOR ASSBY. DRILL 8-1/2" HOLE F/13319'-13351' ATTEMPTING TO SLIDE TO DROP ANGLE. STICKING BHA WHEN EVER SLIDE IS ATTEMPTED AND PROBLEM GETTING PROGRESSIVELY WORSE. CALLED 13351' TD. DAY 46-48 (06/16-18/95) 30"@ 285' 18 5/8" @ 1130' 13 3/8" @ 3798' 9 5/8"@ 10874' 9.9 PPG CCH. POH. RU LOGGERS & RIH W/TRIPLE COMBO PCL TOOLS. LOG OPEN HOLE F/13351'-10876'. POH. RIH W/7" LINER & WORKED SAME TO 13351'. TOL @ 10699'. CEMENTED LINER W/654 SX CLASS "G" CMT W/ADDITIVES. BUMPED PLUG & SET HANGER & LINER TOP PKR. ClP 1230 6/17/95. REVERSE OUT, TRACE CMT. POH. RIH W/CO ASSBY & TAGGED FC @ 13263'. TEST CSG & LINER TO 3500 PSI. LOST 620 PSI/30 MIN. POH. RIH W/PKR & SET UP 10690'. TEST LINER LAP & 7" CSG TO 3500 PSI, OK. TEST 9-5/8" CSG TO SAME, OK. POH TO 5000' INSTALL MSV. DAY 50 (06/20/95) 30"@ 285' 18 5/8" @ 1130' 13 3/8" @ 3798' 9 5/8"@ 10874' 8.4 PPG RIH FINISH PU 3-1/2" TUBING. POH. CHG RAMS TO 3-1/2" & TEST SAME. MU TCP GUNS, KOBE BHA & RIH W/DUAL 3-1/2" 9.2# L80 COMPLETION DAY 51 (06/21/95) 30"@ 285' 18 5/8" @ 1130' 13 3/8" @ 3798' 9 5/8"@ 10874' 7" L F/9826'-13351' 8.4 PPG TAG LC AT 13263'. SPACE OUT & LAND HGR W/TCP GUNS ON DEPTH TO DIL. INSTALL BPV, ND BOP & INSTALL TREE. PRESS TEST TREE ASSY TO 5M, OK. RELEASE RIG AT 1800 HRS. INSTALL SURFACE FLOWLINES. DISPL WELL W/CRUDE OIL. INSTALL DN HOLE PUMP. DAY 52 (06/22/95) 30"@ 285' 18 5/8" @ 1130' 13 3/8" ¢__. 3798' 9 5/8" @ 10874' 7" L F/9826'-13351' 8.4 PPG SEAT PUMP AT 0330 HRS. PUMPING FLUID LEVEL DN. DETONATE TCP GUNS AT 1245 HRS. WELL ON TEST.. ANNA PLATFORM WELL # 51 GRANITE POINT (GP) COMPLETION 6/21/95 COMPLETION DESCRIFrION 1) Dual 3-1/2" 9.2# L-80 SCBT 0 - 10442' 2) Kobe BHA F/10442'-10470' 3) 4-5/8" TCP guns ~ 6 spfF/11180'-13150' RKB = 127' ETD 13263' TD 13351' 30" Structural Casing ~ 282' RKB (78'BML) ~. 18-5/8" 97#X-56 QTE60 Surface Casing~ 1130' 13-3/8" 68# k-55 BTC Intermediate Casing ~ 3798' TOL ~ 10699' 9-5/8" 47# L-80 BTC Production Casing ~ 10876' 7" 29# L-80 BTC Liner ~ 13351' UNOCAL ANNA Platform 51 St slot #1-2 Granite Point Field Cook Inlet, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : GMS <0 - 269'> GSS <338 - 1349'> PMSS <1507 - 15351'> Our ref : svy4634 License : Date printed : 11-Jul-95 Date created : 7-Jun-95 Last revised : 11-Jul-95 Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 58 44.738,w151 18 33.113 Stol location is n60 58 37.599,w151 18 45.940 Slot Grid coordinates are N 2551417.059, E 266819.011 Slot local coordinates are 725.00 S 633.00 W Reference North is True North Grani UNOCAL ANNA Platform, 51 St te Point Field,Cook Inlet, Alaska SURVEY LISTING Page 1 Your ref : PMSS <10893 - 13351'> Last revised : 11-Jul-95 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 ~ 0.00 0.00 50.00 0.50 216.00 50.00 0.18 S 0.13 ~ 1.00 -0.08 100.00 0.50 216.00 100.00 0.53 S 0.38 ~ 0.00 -0.25 150.00 0,75 228.00 149,99 0.92 S 0.76 W 0.56 -0.52 200.00 0.50 129.00 1942.90 1.28 S 0.83 ~ 1.93 -0.50 250.00 1.00 71.00 249.99 1.28 S 0.25 ~ 1.70 0.06 269.00 1.00 98.00 268.98 1.24 S 0,07 E 2.46 0.37 338,00 1.00 115.00 337.98 1.58 S 1.22 E 0.43 1.56 484,00 0.70 113.00 483.96 2.47 S 3.19 E 0,21 3.68 574.00 0.50 47.00 57'5.96 2.42 S 3.98 E 0.75 4.44 663.00 0.40 185.00 662,95 2,46 S 4.24 E 0.94 4.70 752.00 0.60 276.00 751.95 2.72 S 3.75 E 0.82 4.29 842.00 0.60 275.00 841.95 2.63 S 2.81 E 0.01 3136 932.00 0.20 35.00 931.94 2.46 S 2.43 E 0.80 2.95 1021.00 0.50 26.50 1020.94 1.99 S 2.70 E 0.34 3.09 1110,00 0.70 353.50 1109.94 1.10 S 2.81 E 0.44 2.99 1164,00 0.50 357,00 1163.94 0.54 S 2.76 E 0.38 2.81 1258.00 1.25 63.00 1257.93 0.34 N 3.65 E 1.21 3.46 1349.00 1.75 76.00 1348.89 1,12 N 5.88 E 0.66 5.45 1507.00 1.80 77.80 1506.82 2.23 N 10.65 E 0.05 9.82 1599.00 1.80 73.40 1598.77 2.95 N 13.44 E 0.15 12.36 1693.00 1,40 65.60 1692.74 3.85 N 15.91 E 0.48 14.54 1788.00 1.30 57.20 1787.71 4.91 N 17.87 E 0.23 16.20 1883.00 0.90 47.70 1882.69 6.00 N 19,33 E 0.46 17,35 1975.00 0.89 35,50 1974,68 7.06 N 20,28 E 0.21 18.02 2066.00 0.77 5.70 2065.67 8.25 N 20.75 E 0.49 18.20 2160.00 0.66 356.00 2159.66 9,42 N 20.77 E 0.17 17.95 2253.00 0.72 345.00 2252.66 10.51 N 20.58 E 0.16 17.50 2347.00 0.96 322,40 2346.65 11.71 N 19.95 E 0,43 16.60 2440.00 1.02 310.70 2439.64 12.87 N 18,85 E 0.23 15.26 2535.00 0.81 298.20 2534.62 13.73 N 17.61 E 0.30 13.86 2628.00 1.11 288.80 2627.61 14.34 N 16.18 E 0.36 12.32 27"21,00 1,10 280,50 2720.59 14.79 N 14.45 E 0.17 10.53 2816.00 1.10 277.20 2815.58 15.07 N 12.65 E 0.07 8.72 2909.00 1,20 277.30 2908.56 15.30 N 10.80 E 0.11 6.86 3001.00 1.40 280.00 3000.53 15.62 N 8.74 E 0.23 4.78 3096.00 1,40 279,00 3095.50 16.00 N 6.45 E 0.02 2.47 3190.00 1,40 238,80 3189.48 16.56 N 4.23 E 0.25 0.18 3282.00 1.48 282,00 3281.45 17.16 N 2.00 E 0.20 -2.13 3376.00 1.40 283.50 3375.42 17.68 N 0.30 W 0.09 -4.49 AUG 1 8 1995 3469.00 1.80 265.20 3468.38 17.83 N 2.86 W 0.69 3563.00 1.80 260.00 3562.34 17.45 N 5.79 W 0.17 3655.00 2.20 265.70 3654,28 17.06 N 8.97 ~ 0.48 3749.00 2.10 274.10 3748,21 17.05 N 12.49 ~ 0.35 3773.00 2.10 275.40 3772.20 17.12 N 13.37 ~ 0.20 -7.01 Alaska.Oil & Gas Cons. Commission -9.76 Anchorage -12.76 -16.18 -17,04 3936.00 2.40 275.70 3935.07 17.74 N 19.74 W 0.18 -23.38 4031.00 1.10 270.50 4030.02 17.95 N 22,63 ~ 1.38 -26.24 4124,00 1.30 45.10 4123.02 18.70 N 22.77~ 2.38 -26.56 4218.00 3.80 60.10 4216.92 21,01 N 19.32 ~ 2,73 -23.75 4312.00 6.00 64.50 4310.57 24.68 N 12.18 W 2.37 -17.68 ALL data is in feet unless otherwise stated Coordinates from slot #1-2 and TVD from RKB (127.00 Ft above mean sea [eve[). Vertical section is from wellhead on azimuth 103.71 degrees. Declination is 22.84 degrees, Convergence is -1.14 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL ANNA Platform,51 St Granite Point Field,Cook inlet, Alaska SURVEY LiSTiNG Page 2 Your ref : PMSS <10893 - 13351'> Last revised : 11-Jul-95 Measured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 4406.00 8.60 70.20 4403.80 29.17 N 1.13 W 2.87 -8.02 4499.00 11.10 ~5.40 4495.42 33.79 N 14.08 E 2.85 5.66 4593.00 13.50 75.60 4587.26 38.80 N 33.46 E 2.55 23.31 4686.00 16,40 75.90 46~7.10 44.70 N 56.72 E 3.12 44.50 4782.00 19,60 75,90 4768.39 51.92 N 85.48 E 3.33 70.74 4873.00 21,10 78.90 4853.71 58.79 N 116.36 E 2.01 99.10 4968.00 23.30 79.90 4941.66 65.38 N 151.64 E 2.35 131.82 5063.00 25.70 81.10 5028.10 71.86 N 190.50 E 2.58 168.03 5157.00 27.40 '86.30 5112.20 76.42 N 232.23 E 3.06 207.49 5247.00 27.80 90.30 5191.96 77.64 N 273.88 E 2.11 247.67 5341.00 29.30 96.10 5274.55 75.08 N 318.69 E 3.35 291.80 5434.00 30.20 101.20 5355.30 68,12 N 364.27 E 2.89 337.73 5530.00 32,60 102.20 5437.24 57,96 N 413.24 E 2.56 387.'71 5623.00 34.30 101.40 5514.83 47.49 N 463.41 E 1.89 438.94 5717.00 34.10 102.60 5592.58 36,50 N 515.09 E 0.75 491.75 5811.00 34.60 102,90 5670,18 24.80 N 566.82 E 0.56 544.78 5905.00 34.60 102.50 5747.56 13.06 N 618.90 E 0.24 598.15 5999,00 35.00 102.00 5824.75 1.68 N 671.32 E 0.52 651.78 6093.00 35,20 101.70 5901.65 9.42 S 724.22 E 0.28 705.80 6185,00 35.10 100.50 5976.88 19.61 S 776.19 E 0.76 758.71 6279.00 35.30 101.70 6053.69 30.05 S 829.36 E 0.77 812.84 6372.00 36.50 101.60 6129.02 41.06 S 882.77 E 1.29 867.33 6505.00 36.00 101.20 6236.28 56.60 S 959.86 E 0.42 945.91 6599.00 35.90 101.80 6312.38 67.60 S 1013.94 E 0.39 1001.06 6691.00 35.80 101.40 6386.95 78.44 S 1066.72 E 0.28 1054.90 6785.00 35.90 101.80 6463,14 89.51 S 1120.65 E 0.27 1109.92 6878.00 35.80 100.90 6538,52 100.23 S 1174.05 E 0.58 1164.34 6972.00 35.80 100.70 6614,76 110.53 S 1228.06 E 0.12 1219.25 7065.00 36.30 101.50 6689,95 121.07 S 1281.76 E 0.74 1273.92 7160.00 36.50 100.90 6766.42 132.02 S 1337.06 E 0.43 1330.24 7253.00 36.70 100.60 6841.08 142.36 S 1391.54 E 0.29 1385,62 7345.00 37.10 102.00 6914.65 153.19 S 1445.70 E 1.01 1440.80 7439.00 37.10 101,60 6989.62 164.78 S 1501.21 E 0.26 1497.47 7533.00 3?.00 101,80 7064.65 176.27 S 1556.67 E 0.17 1554.07 7625.00 37.00 100,90 7138.12 187.16 S 1610.95 E 0.59 1609.39 7719,00 36,60 102.20 7213,39 198.44 S 1666.11 E 0.93 1665.66 7812.00 35.90 101.20 7288.39 209.59 S 1719.96 E 0.98 1720.61 7905.00 35,20 101.60 7364.06 220.28 S 1772.96 E 0.79 1774.64 7998.00 34,30 103.40 7440.47 231.74 S 1824.72 E 1.47 1827.63 8042.00 34.10 102.70 7476.86 237.32 S 1848.81 E 1.00 1852.36 8090.00 34.00 103.90 7516.63 243.51 S 1874.96 E 1.42 1879.24 8184.00 33,20 105.60 7594.93 256.74 S 1925.26 E 1.31 1931.24 8276.00 33.70 106.70 7671.69 270.85 S 1973.97 E 0.85 1981.90 8368.00 33.00 106.80 7748.54 285,42 S 2022.40 E 0.76 2032.41 8463.00 32,10 110,30 7828,62 301.66 S 2070.85 E 2.20 2083.32 8559.00 32.40 109.00 7909.82 318,88 S 2119.09 E 0.79 2134.27 8652.00 33.00 110.70 7988.08 335.95 S 2166.34 E 1.18 2184.22 8746.00 33.40 110.60 8066.73 354.10 S 2214.50 E 0.43 2235.32 8840.00 34.40 110.90 8144.75 372.68 S 2263.53 E 1.08 2287.35 8934,00 35.30 110.80 8221.89 391.79 S 2313.73 E 0.96 2340.65 At[ data is in feet unless otherwise stated Coordinates from slot #1-2 a~d TVD frem~l~{127.00 Ft above mean sea level). Vertical section is from wet[hea~t~azimuth 103.71 degrees. Declination is 22.84 degrees, Convergence is -1.14 degrees. Calculation uses the minimu~ curvature method. Presented by Baker Hughes [NTEQ Grani UNOCAL ANNA Platform, 51 St te Point Field,Cook Inlet, Alaska SURVEY LIST%NG Page 3 Your ref : PHSS <10893 - 13351'> Last revised : 11-Ju[-95 Heasured Inc[in. Azimuth True Vert. *R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOFt Sect 9026,00 35,80 110.50 8296,74 410.66 S 2363.78 E 0.58 2393.74 9121.00 36.30 110.10 8373.55 430.05 S 2416.21 E 0.58 2449.28 9215.00 37.00 111.70 8448.97 450,07 S 2468.63 E 1.26 2504.95 9308.00 37.30 112.00 8523.10 470.98 S 2520,75 E 0.38 2560.55 9395.00 37.20 111.00 8592,35 490,28 $ 2569,'~ E 0.70 2612.72 9501.00 36,10 111.00 8677.39 512.95 S 2628.82 E 1.04 2675.48 9595,00 35,00 110.80 8753.87 532.45 S 2679.88 E 1.18 2729.70 9689.00 34,70 110.10 8831.01 551.22 S 2730.20 E 0,53 2783.05 9783.00 33.60 111.10 8908.80 569.78 $ 2779.60 E 1,31 2835.43 9876.00 33.00 110.70 8986.53 587.99 S 2827.30 E 0.69 2886.09 9970.00 32.40 111.50 9065.63 606.27 S 2874.67 E 0.79 2936.45 10064.00 31.30 112.50 9145.48 624.84 S 2920.66 E 1.30 2985.54 10157.00 30,30 113.40 9225.36 643.41 S 2964.52 E 1.18 3032~54 10248,00 29.60 113,50 9304.21 661.49 S 3006.20 E 0.77 3077.31 10342,00 29.80 114,?0 9385.86 680.50 S 3048.71 E 0.67 3123,12 10435.00 30.40 115.20 9466.32 700.18 S 3090.99 E 0.70 3168.87 10528.00 30.60 115.80 9546.45 720.50 S 3133.60 E 0.39 3215.07 10621.00 31.30 116.50 9626.21 741.58 S 3176.53 E 0.85 3261.78 10715.00 31.80 117.50 9706.32 763.91 S 3220.35 E 0.77 3309.64 10809.00 32.50 117.30 9785.90 786.93 S 3Z64.76 E 0.75 3358.24 10851.00 32.60 117.60 9821.30 797.35 S 3284.81 E 0.45 3380.20 10893.00 33.30 116.90 9856.55 807.81 S 3305.12 E 1.90 3402.40 10994.00 37.60 108.40 9938.86 830.10 S 3359.14 E 6.47 3460.17 11085.00 43.80 104.60 10007.82 846.82 $ 3416.02 E 7.33 3519.40 11177.00 51.30 106.00 10069.88 864.77' $ 3481.44 E 8.23 3587.20 11243.00 57.90 107.10 10108.09 880.10 S 3532.97 E 10.09 3640.90 11303.00 62.00 107.50 10138.13 895.55 S 3582.54 E 6.86 3692.72 11387.00 67.80 109.20 10173.75 919.51 S 3654.70 E 7.14 3768.50 11447.00 70.56 108.80 10195.07 937.76 S 3707.72 E 4.64 3824.34 11489.00 71.20 107.60 10208.83 950.16 S 3745.42 E 3.10 3863.90 11607.00 71.32 108.10 10246.74 984.41 S 3851.79 E 0.41 3975.36 11699.00 69.40 106.30 10277.66 1010.04 S 3934.55 E 2.78 4061,84 11791,00 72.16 105.50 10307.94 1033.83 S 4018.09 E 3.11 4148.64 11887.00 72.20 105,00 10337.32 1057.87 S 4106.26 E 0.50 4240.00 11981.00 71.60 104.40 10366.53 1080.54 S 4192.69 E 0.88 4329.33 12073.00 70.40 103,80 10396.48 1101.74 S 4277,05 E 1.44 4416.31 12169.00 69.30 102.90 10429.55 1122.55 S 4364.74 E 1.44 4506.43 12261.00 69.50 101.80 10461.92 1140.97 S 4448.86 E 1.14 4592.52 12353.00 69.40 100.60 10494.22 1157.70 S 4533.36 E 1.23 4678.59 12447.00 69.30 101.80 10527.37 1174.78 S 4619.65 E 1.20 4766.46 12541.00 67.40 102.30 10562.04 1193.02 S 4705.09 E 2.08 4853.79 12635,00 72.30 100.00 10594.42 1210.05 $ 4791.64 E 5.70 4941.91 12727.00 71.20 100.10 10623.23 1225.30 $ 4877.67 E 1.20 5029.10 12820.00 71,20 98.30 10653.20 1239,37 S 4964.57 E 1.83 5116.86 12915.00 71.40 98.00 10683,66 1252.13 $ 5053.65 E 0.36 5206.42 13010.00 70.20 100~00 10714.91 1266.16 S 5142.25 E 2.36 5295.83 13103.00 72.70 99.40 10744.49 1281.01S 5229.15 E 2.76 5383.77 13196,00 70.50 98.40 10773,84 1294.66 S 5316.33 E 2.58 5471.70 13281.00 68.80 99.60 10803.40 1307.12 $ 5395.04 E 2.40 5551.12 13313.00 68.50 100.60 10815.05 1312.35 S 5424.38 E 3,06 5580.86 All data is in feet unless otherwise stated Coordinates from slot #1-2 and TVD from RKB (127.00 Ft above mean sea [ever). Vertical section is from we[[head on azimuth 103.71 degrees. Declination is 22.84 degrees, Convergence is -1.14 degrees. Calculation uses the minimun curvature method. Presented by Baker Hughes %NTEQ UNOCAL ANNA Platform, 51 St Granite Point Field,Cook Inlet, Alaska SURVEY LISTING Page 4 Your ref : PMSS <10893 - 13351'> Last revised : 11-Ju[-95 Measured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 13351.00 68.14 101.79 10829.09 1319.21S 5459.02 E 3.06 5616.14 Projected Data - NO SURVEY All data is in feet unless otherwise stated Coordinates from slot #1-2 and TVD from RKB (127.00 Ft above mean sea [eve[). Vertica[ section is from wellhead on azimuth 103.71 degrees. Declination is 22.84 degrees, Convergence is -1.14 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL ANNA Ptatform~51 St Granite Point Field,Cook Inlet, Alaska SURVEY LISTING Page 5 Your ref : PHSS <10893 - 13351'> Last revised : 11-Ju[-95 Co~ts in wet[path MD TVD Rectangular Coords. Co~aent 13351.00 10829.09 1319.21S 5459.02 E Projected Data - NO SURVEY Targets associated with this wel[path Target name Position T.V.D. Local rectangular coords. Date revised A-51 T/ C-5 270200.000,2550520.000,0.00009927.00 829.36S 3398.37E 12-Sep-94 A-51 T/ C-5 #2 271880.000,2549910.000,0.000010687.00 1405.69S 5090.28E 12-Sep-94 AUG 1 8 '199,.5 A~as~.Oil .& Gas Cons. Commission ' ~ch0rage Att data is in feet unless otherwise stated Coordinates from slot #1-2 and TVD from RK8 (127.00 Ft above mean sea level). Bottom hole distance is 5616.16 on azimuth 103.58 degrees from wellhead. Vertical section is from wellhead on azimuth 103.71 degrees. Declination is 22.84 degrees, Convergence is -1.14 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Unocal Energy Resources Di 909 West 9Ih, P.O. BOX 1962~.~=t' Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 263-7828 UNOCAL ) Debra Childers Clerk DATA TRANSMITTAL #21 To: Larry Grant 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas July 17, 1995 From: Debra Childers . 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Granite Point 18742-51 (Sidetrack 1) 2' I 5" Blueline I SepiaComp Densilog / Neutron. Gamma Ray / Caliper 2' / 5' Blueline / SepiaDual Laterolog I Gamma Ray 2' Blueline / SepiaFormation Mudlog Tape LIS Tape and listing RFCF!V [) Please acknowledge receipt by signing and retuming one copy of this transmittal or FAX to (907) 263-7828. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David J '~on, Chairmafi"~ DATE: June 2, 1995 THRU: Blair Wondzell,,.,~,,~.¢' FILE NO: P. I. Supervisor FROM: Doug Amos, ~('~~ SUBJECT: Petroleum Inspector ao9hfbcd.doc BOPE Test Pool 428 Unocal Granite Pt. No. 51 Granite Point Field PTD No. 95-04 Friday, June 2, '1995: I witnessed the BOPE Test at Unocal's Anna Platform, Granite Point No. 51 well on Pool Rig No. 428. As the attached AOGCC BOPE Test Report indicates there were no failures. I found the rig in excellent condition and all personnel very professional. In addition to the BOPE test l conducted a walk through inspection of the Platform Piping and Well Rooms. I found the Platform clean and in good condition. SUMMARY: Witnessed the successful BOPE Test on Pool Rig No. 428 and conducted a walk through inspection of the Platform and it's production facilities. Test time 2.5 Hours 18 Valves Tested No Failures Attachment: AO9HFBCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Pool Alaska Operator: Unocal Well Name: Granite Pt. # 51 Casing Size: g 5/8" Set @ Test: Initial Weekly X Rig No. 428 PTD# Rep.: Rig Rep.: 10,876 Location: Sec. Other DATE: June 2,1995 95-04 Rig Ph.# 776-6628 Don Byrne John McCoy 12 T. 10N R. 12 W Meridian Umiat MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes Well Sign OK Drl. Rig OK Hazard Sec. Yes BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F I 3OO/3,0OO P I 500/5,000 P I 500/5,000 P I 500/5,000 P I 500/5,000 P 2 500/5,000 P I 500/5,000 P N/A N/A N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK =it Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK TEST DATA . FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 500/5,000 P I 500/5,000 P I 500/5,000 P 1 500/5,000 P CHOKE MANIFOLD: No. Valves 12 No. Flanges Manual Chokes 1 Hydraulic Chokes 2 Test Pressure P/F 5OO/5, OOO P 34 500/5,000 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 12 ~ 2100 2,900 P 1, 750 P minutes 23 sec. minutes 42 sec. Yes Remote: Yes Psig. ~ii TEST RESULTS Number of Failures: 0 ,Test Time: 2~5 Hours. Number of valves tested" 18.. Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659.3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good test rig is clean and in excellent shape. Distribution: odg-Well File c - Oper./P, ig c- Database c - Trip Rpt File c- InsP~l~[L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: W~tnessed By: FBCD.XLS Doug Amos MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: David Joh~~ · Chairmah~ Blair Wondzell, P. !. Supervisor Bobby Fost~r-~,. -~-'F' Petroleum InslS~ctor DATE: FILE NO: SUBJECT: January 27, 1995 QOAIA1CD.doc BOPE Inspection - Pool 428 UNICAL - GP Field - Anna PIft. PTD # 95-OOO4 Granite Point Field Friday, January 27, 1995: I traveled this date to UNOCAL's Anna platform-this dato to witness the upcoming BOPE test. Standby for BOPE test. Saturday, January 28. 1995: Due to several time delays, I wa unable to witness the actual pressure test of the BOPE as planned. I did. however, visually inspect all of the components. The BOPE stack was broken down on the deck and I inspected each one and all appeared to be in good shape. All of the ram rubbers were in good condition as were the ring groves which were full of grease, which ! wiped out to see if there were any pits or rough areas, and found none. The choke manifold valves had been greased and all valves worked good. The accumulator was full of oil and appeared to be in good shape. The nitrogen bottles (12) averaged 2300 psig each. The rig was clean and seemed to be in good working order. All of the floor safety valves were in place on the floor as.wee the wrenches for closing. Summary: ! inspected the BOPE on Pool rig 428 rigged up on UNOCAL platform well #51. No ATTACHMENT: QOAIA2CD.XLS Note: I spoke with Don Byrne, UNOCAL rig forman, 1-29-95 and he informed me that the test went good and a report had been faxed to the AOGCC office. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RIG I BPS INSPECTION REPORT OPERATION: Drig Contr: Operator: Location: Drilling X Workover ~ Cmpl. UlC Well Name: ANNA # 51 POOL ANTIC Rig No. 428 Rep. UNOCAL Rep. DON BYRNE Section 12 T. 10N R. 12N M. SM DATE: 1/28/95 PTD# 95-0004 JOHN McCOY Rig Ph.# 776-6627/28 (A.) B.O.P. STACK Wellhead fig wkg press Stack wkg press iAnnular preventer Pipe rams Blind rams Stack anchored Chke/kill line size All turns targeted ( chke & kill Ln.) HCR valves (chke & kill Ln.) Manual valves (chke & kill Ln.) Connections (Flgd, Whd, Clamped Drilling spool Flow Nipple Flow monitor Control lines fire protected (B.) CLOSING UNIT Working pressure Fluid level Operating pressure Pressure gauges Sufficient valves Regulator bypass 4-way valves (actuators) Blind rams handle cover Driller control panel Remote control panel Firewall Nitrogen power source (backup) Condition (leaks, hoses, ect.) REMARKS: ITEMS MUD SYSTEM Pit level floats installed Flow rate sensor Mud gas separator Degasser Separator bypass Gas sensors Choke line connections Tdp tank (O.) RIG FLOOR Kelly cocks (upper, lower, IBOP) Floor valves (dart, ball, ect.) Kelly & floor valve wrenches Drillers console (flow monitor, flow rate indicator, pit level indicators, gauges) Kill sheet up-to-date Gas detection monitors (H2S & methane) Hydraulic choke panel~ Choke manifold ~ ~:-~i:.iiiiii::~:i:. INSPECTIONi ITEMS (E,) MISC. EQUIPMENT Flare/vent line All tums targeted (downstream choke lines) Reserve pit tankage Personnel protective equip, avail. All Drillsite Supervisors Trained For Procedures H2S probes Rig housekeeping IN COMPLIANCE IN COMPLIANCE methane IN COMPLIANCE RECORDS: Date of Last Rig / BPS Inspection Date of Last'BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Properly Entered On Daily Record? NONE Kill Sheet Current? Distribution: orig - Well File C - Oper./Rig c - Database c - Trip Rpt File c- Inspector AOGCC REP: OPERATOR REP: FI-022 (Rev. 3/93) BOBBY D. FOSTER DON BYRNE QOAIA2CD.XLS ALASKA OIL AND GAS 'CONSERVATION COMMISSION . TONY KNOWLE$, GOVEI~NOI~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 _. January18,1995 G. Russell Schmidt Drilling Manager Uuion Oil Company of California (UNOCAL) P O Box 196247 Anchorage, AK 99519-6247 Re: Granite Point St.. 18742 No. 51 UNOCAL Permit No: 95-04 Sur. Loc. 725'FNL, 633'FEL, Sec. 12, T10N, RI2W. SM Btmhole Loc. 2131'FNL, 823'FEL, Sec. 7, TION, RllW, SM Dear Mr. Schmidt: Enclosed is thc approved application for permit to drill the above referenced well. Thc Commission granls your request to waive thc divcrtcr requirements on both thc 30" structural casing and the 18 5/8" surface casing. It is understood that UNOCAL will install a flow nipple on the structural casing and a 3M BOPE stack on the surface casing in lieu of the diverter The permit to drill does not exempt you from obtaining additional permits required by law from other govcrmnental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. _. Blowout prevention equipment (BOPE) must be tested in accordance wilh 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe musl be given so that a represcnlative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. . dif/Enclosurcs Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA OIL AND GAS 'CONSERVATION COMMISSION Jalmary 13, 1995 TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 76.29 Re: The application of Ulfion Oil Company of California to drill and complete the Granite Point State 18742 No. 51 well as a Middle Kenai Oil Pool production well. G. Russell Schmidt Regional Drilling Manager UNOCAL Corp. P. O. Box 190247 Anchorage, Ak 99502-0247 Dear Mr. Schmidt: Your application of Deccmbcr 30, 1994 for a permit to drill and complete the Granite Point State 18742 No. 51 well requires exception to spacing requirements set forth in Conservation Order No. 76. The drilling and completion of the Granite Point State 18742 No. 51 well is expected to provide additional oil recovery from the Middle Kenai Oil Pool in the Granite Point Field. The Alaska Oil and Gas Conservation Conunission hereby authorizes the drilling and completion of the Granite Point State 18742 No. 51 well pursuant to Rule 7 of Conservation Order No. 76. DONE at Anchorage, Alaska and dated January 13, 1995. o Commission ,.,,.:.::,. ---~, .,).. Russell A. Douglass, Commissio~r Alaska Oil and Gas Conservation Commission Memoranc .um State of Alaska Oil and Gas Conservation Commission To: Commission ~, ~1~'~l~)~' January 13, 1995 k . Unocal Request for D~verter Waiver -- Graffite Pt. ~na Wells 50,51 & 52 Fm~ Subj: Unocal has requested a waiver of diverter requirements on the subject wells. They propose to drill the 30"x18 5/8 conductor hole to 1100' with a flow nipple then drill the 17 1/2"x13 3/8" surface hole to +/-4500' with a 20 3/4% 3000 psi. BOPE system. They state in their application letter that the fracture gradient anticipated at the casing shoes is .80 psi/foot and the rock will be competent enough to shut in the well and circulate a kick rather than divert. The fracture gradients are based on recent leak off tests done in the Granite Pt. Field and Cook Inlet area. A review of 4 wells which offset the subject wells showed 2 had elevated gas, Anna 35 at about 3900' and Anna 37 which had to be shut in to circulate out gas at 3800 feet. Both situations were handled without undue procedures and drilling resumed. In Anna 35, mud weight was raised from 8.9 ppg at 3700 feet to 10.2 at 3900 feet and remained in that range to 9000 feet. In Anna 37 mud weights ranged from 8.8 to 9.4 ppg from 1000 to 4900 feet and increased to 10 ppg by 9800 feet. None of the 4 wells indicated abnormal pressures or mud weights above 4500 feet. Unocal states that there is no gas above 1100' in the vicinity of the Anna platform based on the information available to them. Regulation 20 AAC 25.035 (b) (3) and (c) (2) authorizes the Commission to waive diverter requirements if drilling experience in the near vicinity indicates a diverter system is not necessary. The same approach and arguments were the basis of the diverter waiver granted on Dillon wells 16 & 17 in April, 1994. The proposal to drill the surface hole to 1100' with a drilling nipple means there is no annular preventer to divert the well and returns go straight to the shakers and pits. For the hole sections from 1100-4500', their permit application shows a 20 3/4" BOP system with a 2000 psi annular preventer and a diverter spool which will be blinded off and not used. Unocal believes the diverter is not appropriate and would rather use positive control measures and shut in on kicks where the formation is competent. In sumInary, a review of AOGCC well histories on four wells in the vicinity of the proposed wells indicated no shallow gas above 1100' noted on drilling summaries. Two cases of elevated gas were noted between 3700 and 3900 feet which were handled by ordinary drilling and circulating procedures. Recommendation: Absent shallow gas above 1100 feet and other notable drilling problems in the vicinity of the well to be drilled, we recommend approval of the waiver of diverter requirements. Gas kicks below 1100 feet can be shut in and circulated if fracture gradients are in the range stated. If there are other circumstances which the Commission thinks would cause a need for diverter use, Unocal should be allowed to address those circumstances. Subjecl: Gas Show,; in Granite Point Field, Platfoml canna Wells: G.P. 187:t2 No. 30. G.P, 18742 No. 3'7, and G.P. '!W,'t2 No. 3F; A review of Ihe mud 1,-,..o.:; iu the A~o"e t:zf:renced wells the p_eneral vicb;itv of P!atf",nn AJma. Irt Ihe section ubove aI:3:rc,:dmately 2000' su_bsea. c, oal $~llllS. qqle Ml'CtlglJl oflJle shOWS is dependent on two t~ctol'$~ pelleh-atio[I rate ~lld coal nde ol'i)enelralion off these :~oams. Any poteuti~ drilling hazard associated with th~ portion can be avoided lhrouizh exercising some degree of conh'oHed ddl.hng. ,,,.,o,1 ..... · ....... . ..... ~ ;,, II .... t.; .... ~ .... ~)o tlg'otla[l mi ...... 4; ..... ~'~ ...... ,; .... J'lk't'lcltl J~(Ii '~':tl ~ ) It Lit ~ ~ '. .~ttt~gk.t )~ bl~) . [lelbmie charued sandstones are presenl below lhe 2000' subsea dci)Ht. Most of Ibc strouge<l :<)~ ,,.v~ in ~his ....,,o, , ,,,,l"- ~d'lhe ¢c:clion. . appear below 3500' subsea. P,,qdle lhese san&; ............... topic>::,,, a p~,,en~im' ~ r~;~c.~ltc'-:~. J,,::~t ...... iq ,t(~ <lmug i,~dications they omstimte an unusual drd[mg hazard ifstanda~'d pi'eca~!t/onq are l.:,'cen. ALASKA STATE OF ALASKA L AND GAS CONSERVATION COM,~ 0SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill [~ 1 lb. Type of well. Exploratory ~ Stratigraphic Test [--] Development Oil [~ Re-Entry~ Deepen~J Service D Development Gas ["] Single Zone D Multiple ZoneO 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California (UNOCAL) 127' RKB above MSL feet Granite Point Field 3. Address 6. Property Designation Middle Kenai "C" Sands P.O. Box 196247, Anchorage, AK 99519 ADL 18742 4. Location of well at sLrface 7. Unit or property name 11. Type Bond (SE~ ~^CC~.0~ 725' FNL & 633' FEL, Sec. 12, T10N, R12W, SM Granite Pt Field //)/~;/,~,.-~. AK Statewide Oil & Gas Bond At top of productive interval 8. Well number ~ 5'/ Number 1554' FNL &2515' FEL, Sec7, T10N, R11W, SM ',~t~'''~'~Jf/~-''f°'~ 5'"~7/¢-- /~.~,,,z~ U62-9269 At total depth 9. Approximate spud date Amount 2131' FNL & 823' FEL, Sec. 7, T10N, R11W, SM 1/15/!tiit' ~,.~ $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth ¢~,,~ wu) property line 3200 feet ¢¢Vell #36) 950 feet 5060 12900' MD/10687' '[VD feet 16. To be completed for deviated wells 17. Anticipated Pressure(se~ 30AAC2S.035(~)(a) Kickoff depth 3800 feet 75 MaximLrn hole angle M~r, ur, surface 962 ps~aAtto~Ud,,pthpVU) 4809 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (i ncl ude stage data) 24" 18-5/8 97 X52 QTE 60 1031' 69' 69' 1100 1100 2300 cu. ft. 17-1/2" 13-3/a 68 1455 BI.I'IT 3731' 69' 69' 3800' 3800' 2700 cu. fL 12-1/4" 9-5/8" 47 LBO BUTI' 10831' 69' 69' 10900' 9920' 1200 cu. fL 8-1/2" 7" 29 LBO 1'KC BUTT 2175' 10725' 9745' 12900' 10687' 650 cu. ft. 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary Total depth: measured 282' feet Plugs (measured) true vertical 282' feet Effective depth: measured 282' feet Junk (measured) true vertical 282' feet Casing Length Size Cemented Measured depth True vertical depth Structural 224' 30" Driven 282' RKB (78' BML) Conductor iSn~erfaj:diateR E C E IV E D Production dAt~ - 9 1995 Liner Perforation depth: measured ~!~,.0il & Gas Cons. Commission -.', ~ch0r~ true vertical 20. Attachments Filing fee ~: Property plat ~ BOP Sketch~ Diverter Sketch ~ Drilling program [~ Drilling fluid program ~ Time vs depth plot [~ Refraction analysis ~ Seabed report ~] 20 AAC 25.050 requirements ~ 21. I hereby certify that the foregoing~!~s true ~ .~;~-'orrect to the best of my knowledge Signed G. RUSSELL SC H MI D'k~,]~/~il~,~j~.~,{~'~ i' j Title DRILLING MANAGER Date-~l~ Commission Use Only Permit Number APl number IApproval date I See cover letter c~..~"_ ~ 4//' 50- 7,~2~ - .~_0 ,CZ ~ ~I/''~-' ,'/? ?"-~I for other requirements Conditions of approval Samples required r'"] Yes ,~ No Mud Icg required ~ Yes ~ No Hydrogen suffide measures ["] Yes ,~ No Directional survey required .~ Yes ~ No Required working pressure for DOPE ~ 2M; J~ 3M; ,[~SM; ['"] 1OM; ~ 15M Other: ur~g~nai Signed By by the order of //~ //~ Approved by Oavid W. Johnston Commissioner the commission Date,/ ~ ~'~ Form 10-401 Rev. 12-1-85 Subrni plicate Anna Well #51 December 26, 1994 Drilling Hazards: Lost circulation zones: None Low pressure zones: None Over pressured zones: None Shallow gas zones: None Time Est. Preliminary Procedure: 2 1 1 2.5 3.5 2.5 17 1. MIRU, Leg #1, Conductor #2, Install 30" flow riser system. 2. Drill 17-1/2" hole to 18-5/8" csg point of+1100'. 3. Open hole from 17-1/2" to a 24" section. 4. Run and cement 18-5/8" casing. Install 20" BOPE. 5. Drill 17-1/2" hole to 13-3/8" csg point +3800' (ROP 835') 6. Run and cement 13-3/8" casing. Install 13-5/8" BOP 7. Directionally drill 12-1/4" hole from approx 3800'-10900' (Top C-5). ROP=675 fpd (ff3800'-7500') ROP=300 fpd (ff7500'-10900') KOP DLS Angle Range 3800' 2.50 0-32 1.5 1.5 7 8. Run open hole logs. 9. Run and cement 9-5/8" casing to 10900' MD. 10. Directionally drill 8-1/2" hole from 10900'-12900'. ROP=285' KOP DLS Angle Range ±10906' 5.5 32-75° 1.5 .75 1.5 .75 1 1.5 .5 1 .5 1 11. Run open hole drill pipe conveyed logs. DIL-Phasor-GR-SP/LDT-CNL. 12. RIH, CCH for 7" liner. 13. Run and cement 7" liner from TD to 10,725' MD. 14. Clean out inside liner, change over to 3% KCL. 15. Run CET/GR log from ETD to TOC in 9-5/8" casing. 16. Install liner top packer & test "Draw-down" same. 17. Make up TCP guns / Kobe BHA and dual 3-1/2" tbg completion. 18. RIH w/Kobe BHA and dual 3-1/2" tbg completion. 19. Set BPV. Nipple down BOP's. Install wellhead. 20. Displace well to oil, detonate guns. Release rig & turn well over to production. 49.5 days total time Fi lename: anna~Procedur~anna5 l~P051, doc -2 Depth Anna 51 Depth vs. Days -4 -6 -8 -"-- Anna #51 -10 -12 -14 0 5 10 15 20 25 30 35 40 45 50 55 60 Days December 26, 1994 ANNA PLATFORM WELL # 51 GRANITE POINT (GP) PROPOSED COMPLETION J COMPLETION DESCRIPTION 1) Dual 3-1/2" 9.2# L-80 SCBT 2) Kobe BHA F/?'-?' 3) 3-1/2 ....R" landing nipple ~ ?' 4) 4-5/8" TCP guns ~ 4 spfF/?'. -.?' RKB = 127' 30" Structural Casing ~ 282' RKB (78'BML) X 18-5/8" 97# X-56 QTE60 Surface Casing ~ 1100' 13-3/8" 68# k-55 BTC Intermediate Casing ~ 3800' 9-5/8" 47# L-80 BTC Production Casing ~ 10900' RECEIVED T' 29# L-80 BTC Liner ~ 12900' 4O0 -- 800 _ _ 1200 _ _ 1600_ _ 2000_ _ 2400 _ 28O0 52O0 35o0 4400_ _ 4800 _ _ 5200 _ - 6000_ ,400 7200 g400. 8800_ _ 10~0_ 10400_ _ 108O0_ UNOCA Structure ' ANNA Platform Well · 51 Field : Granite Point Field Location : Cook Inlet, Alaska Begin Due East Nudge 0.75 End of Build End of Hold 1.50 O.75 End of Nudge i WELL PROFILE DATA Deg/lO01 Point MD Inc Dir TVD North East iTie on 0 0.00 90.00 0 0 0 0.00 iEnd of Hold 500 0.00 90.00 500 0 0 0.001 ~ i iEnd of Build 767 2.00 90.00 767 0 5 0.75! J 0.00 iEnd of Hold 1000 2.00 90.00 1000 0 15 iEnd of Drop 1267 0.00 90.00 1266 0 17 0.75! }End of Build 3800 0.00 90.00 3600 0 17 O.00j iKOP 4800 25.00 70.00 4768 73 219 2.50I iEnd of Build 5594 33.46 107.65 5466 64 589 2.501 iTarget 10941 33.46 107.65 9927 -829 3398 0.00] iEnd of Build 11688 74.56 108.97 10357 -1017 3960 5.501 iTorqet 12928 74.56 108.97 10687 - 1406 5090 0.00! I I I I I I I I I I I I I I I i I iol i i i i i i i i i i i0 400 0 400 800 1200 1600 2000 2400 2800 .32 0 3600 4000 4400 4800 5200 56 0 Scale 1 : 200.00 Vertical Section on 10,3.71 azimuth with reference 0.00 N, 0.00 W from slot #1-2 oo,. E asf = = > 350 0 350 700 1050 1400 1750 2100 2450 2800 .3150 3500 3850 4200 4550 4900 5250 I I I I II II II I I I I I I I I I I I I I I I I I I I I I I I KOP 3,50 2.50 10.00 ~ 0 · 12.50 17.50 ~ 2O.0O It22.50 · ~ _'°5° _1400 _ _1750 Tgl~l ~egln Build & Turn ~ 'Created by : jones ~ Tgt i/2 / T~ I Dote potted : 27-Dec-94- Plot Reference is A--51 Version #4. Coordinates ore in feet reference slot #1-2.', True Vertical Depths ore reference RKB. --- Baker Hughes INTEQ UNOCAL ANNA Platform 51 slot #1-2 Granite Point Field Cook inlet, Alaska CLEARANCE REPORT by Baker Hughes INTEQ Your ref : A-51 Version #4 Our ref : prop1112 License : Date printed : 27-Dec-94 Date created : 12-Sep-94 Last revised : 27-Dec-94 RECEIVED dAN - 9 i 95 Aii~$k~ 0~ & Gas Cons. Commission Anchor; Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 58 44.738,w151 18 33.113 Slot location is n60 58 37.599,w151 18 45.940 Slot Grid coordinates are N 2551417.059, E 266819.011 Slot local coordinates are 725.00 S 633.00 W Reference North is True North Main calculation performed with 3-D Minimum Distance method Object wellpath PM$S <3269 - 10856'>,,11Rd#1,ANNA Platform MSS <0-102(>4'>,,11,ANNA Platform MSS <1957-12303'>,,9,ANNA Platform PGM$ <0-11741'>,,37~ANNA Platform PGMS <0-11453'>,,38,ANNA Platform GMS <0-10674'>,,17,ANNA Platform MSS <3631-9270'>,,39,ANNA Platform MSS <4033 - 10400'>,,39Rd,ANNA Platform MSS <9180-11455'>,,33,ANNA Platform PGMS <0-10575'>,,21,ANNA Platform GMS <0-10480'>,,29,ANNA Platform MSS <0-9455'>,,46,ANNA Platform MSS <2020-10000'>,,19~ANNA Platform PGM$ <0-10302'>,,13Rd,ANNA Platform MSS <7962-10700'>,,13,ANNA Platform MSS <2015-10803'>,,5,ANNA Platform MSS <7440 - 10523'>,,7,ANNA Platform GMS <0-10225'>,,7Rd,ANNA PLatform MSS <3281-10138'>,,23fANNA Platform GMS <0-9950'>,,23Rd,ANNA Platform MSS <0-10300'>,,25,ANNA Platform MSS <11363-11930'>,,35Rd4,ANNA Platform MSS <9634-10292'>,,35Rd3fANNA Platform MSS <9565-12547'>,~35Rd2,ANNA PLatform MSS <9045-9237'>,,35Rd1,ANNA Platform PGMS <0-10277'>,,35Rd5,ANNA Platform MSS <8786-8938'>,,35,ANNA Platform PM$S <7859 - ???'>,,3 Rd#1,ANNA Platform GCT Gyro <0-7969'>,,3,ANNA Platform Closest approach with 3-D minim~n distance method Last revised Distance M.D. Diverging from M.D. 5-Dec-94 4.1 260.0 5066.7 24-0ct-94 4.1 260.0 260.0 13-May-94 120.6 200.0 9940.0 13-May-94 53.6 800.1 7560.0 13-May-94 72.8 480.0 480.0 13-May-94 79.2 100.0 120.0 13-May-94 52.7 1200.2 5500.0 13-May-94 52.7 1200.2 5500.0 13-May-94 120.5 100.0 120.0 13-May-94 122.5 100.0 120.0 13-May-94 118.7 100.0 5960.0 13-May-94 110.9 460.0 460.0 13-May-94 107.9 650.0 650.0 13-May-94 92.5 420.0 9920.0 13-May-94 92.5 420.0 420.0 13-May-94 89.3 100.0 120.0 13-May-94 3.4 140.0 140.0 13-May-94 3.4 140.0 140.0 13-May-94 84.9 320.0 6600.0 20-May-94 84.9 320.0 1300.2 13-May-94 85.8 100.0 10320.0 13-May-94 96.7 100.0 8200.0 13-May-94 96.7 100.0 120.0 13-May-94 96.7 100.0 120.0 13-May-94 96.7 100.0 120.0 13-May-94 96.7 100.0 8520.0 13-May-94 96.7 100.0 120.0 27-Dec-94 11.4 0.0 0.0 12-Dec-94 11.4 0.0 0.0 GMS ,8000-13114'~,,3,ANNA Platform GMS <0-11387'~,,32,ANNA Platform PGMS ,4100-11329'~,,32Rd,ANNA Platform MSS <7045-10077'>,,27,ANNA Platform GMS <0-9844'~,,27Rd,ANNA Platform PGMS <8162-9921'>,,28,ANNA Platform PGMS <0-10680'>,,28Rd,ANNA Platform MSS <1972-9983'>,,4,ANNA Platform GMS ,0-10860'~,,26,ANNA Platform GMS <0-11065'>,,MUCI3,ANNA Platform MSS <0-10400'~,,24,ANNA Platform MSS <3225-10330'>,,15,ANNA Platform PGMS <0-11135'~,,36,ANNA Platform A-52 Version #3,,52,ANNA Platform A-50 Version #3,,50,ANNA Platform 14-Nov-94 13-May-94 13-May-94 13-May-94 13-May-94 13-May-94 13-May-94 13-May-94 13-May-94 13-May-94 13-May-94 13-May-94 13-May-94 20-Sep-94 20-Dec-94 11.4 67.4 67.4 9.1 9.1 7.0 7.0 82.6 90.6 113.9 18.7 52.7 76.1 10.3 10.2 Oo 2800. 2800. 300. 300. 140. 140. 2700. 500. 160. 1500. 1066. 400. 500. 500. 0.0 2800.2 2800.2 300.0 300.0 2100.2 2100.2 2700.2 500.0 12601.6 1500.2 7260.0 8440.0 500.0 3800.0 iCreated by : jones iDate plotted : 27-Dec-94 iPIot Reference is A-51 Version #4-. iCoordinates are in feet reference slot #1-2. !True Vertical Depths are reference RKB. i --- Hughes INTEQ Baker UNOCAL Structure : ANNA Platform Well: 51 Field : Granite Point Field RECEIVED JAN - 9 1995 Location : Cook Inlet, Alaska~!aSKS, Oil & Gas Cons. 60m$1~8[l~1 ~chorr Scale 1 : 5.00 E a st -- > 20 10 0 10 20 ~ 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 A ! I /'% 20 10 0 10 20 30 4-0 50 60 70=, 80 90 100 110 120 130 140 150 lCD 170 180 190 200 f Scale 1 : 5.00 C~ S --- ,,% I I Z O iCreated by : jones iDate plotted : 27-Dec-94 iPIot Reference is A-51 Version #¢. iCoordinates are in feet reference slot #1-2. iTrue Vertical Depths (]re reference RKB. --- Baker Hughes INTEQ UNOCAi Structure : ANNA Platform Well : 51 Field : Granite Point Field Location : Cook Inlet, Alaska ~oo,~,. ~o.oo East --> 160 200 240 280 320 ,360 400 44-0 480 520 560 600 640 680 720 760 800 840 880 920 960 ~0 I I I I I f I I I I I I I I I I I f t II I I I I I I I I I I I I I I I I I I I I II -- _ .. ~ 360 _ ~ /~ _360 " ~ 320 __ ~24~ ~~ 320 160 160 ~ /~0 O0 ~o~ 120 ~o° ~~ _120 - - ~2~ - ~22~ _ 160 5~ 2~ _ 240 2~- ~ ~ ~ 28O 22 ~- I I I I I I I I I I I I I I 480 I I I ~ I I I I I I I I I I ~ I I I I I I I I ~ I ~ I I 1~ 200 240 280 320 560 4~ 440 ~ 520 560 ~ 640 ~0 720 760 800 840 880 920 960 1~0 ~o,~ ~: ~o.0o E a s f -- > iCreated by : jones iDote plotted : 27-Dec-94 iPIof_ Reference is A-51 Version #4. iCoordinates ore in feet reference slot /~1-2. iTrue Vertical Depths are reference RKB. --- Baker Hughes INTEQ UNOCA Structure : ANNA Platform Well : 51 Field : Granite Point Field Location · Cook Inlet, Alaskai 700 0 lO0 700 800_ 900_ 1000_ 1100_ _ 1200_ _ 1500_ _ 1400_ _ 1500_ ~o,~,: ~o.oo East --> 900 1000 11 O01200 1500 1400 1500 1600 1700 1800 1900 2000 21 O02200 2300 2400 2500 2600 2700 2800 2900 5000 I fI II II II II II I I I I I I I I I I II II II II I I I I I I I I I I I I 7~~ 7~ ~ 102~ 0 ' ' ' ' ''''''''' ' ' ' ' ' '~' ' ' ' ''''''o' ' ' ' ' ' ' ' ' ~''' ' 9~ ~000 ~ 1200 ~ ~0 15~ 1800 ~7~ ~8 0 1900 2~ 2~00 22~ 2S 0 24~ 2500 26~ 2700 28 2900 ~0 ~c~,~,: ~o.oo Eosf --> 400 2O0 200 soo I 700 1500 900 Notes: Notes: DEPTH CASING SIZE HOLE SIZE MUD TYPE UNOCAL ANNA PLATFORM WELL #50, #51, & #52 +/-1100' 18-5/8" 17-1/2" OPEN HOLE 24" F.I.W. / GENERIC MUD #2 AaNTICIPATED MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels Huid Loss AP1 pH 8.8 - 9.4 ppg 45 - 100 sec/qt 10 - 15 cps 10 - 30 # / 100 9.2 8 - 20 N.C. 8.5 -9.5 Use bentonite prehydrated in freshwater and filtered Inlet water. DEPTH CASING SIZE. HOLE SIZE MUD TYPE +/-4500' 13-3/8" 17-1/2" F.I.W. / GENERIC MUD #2 .&NTICIPATED MUD PROPERTIES Mud Density. Funnel Viscosity. Plastic Viscosity. Yield Point Gels Fluid Loss AP1 pH 9.0 - 9.6 ppg 40 - 70 sec/qt 10 - 15 cps 10- 20 #/100 fl2 6-12 N.C. 8.5 - 11.0 Treat for cement contamination. jAN - 9 1995 A!~ka 0il & 6as Cons. Commission Anch0rt DEPTH +/- 11050' CASING SIZF~ 9-5/8" HOLE SlZlq 12-1/4" MUD TYPE F.I.W./GENERIC MUD #2 (with PHPA) ANTICIPATED MUD PROPERTIES Mud Density 9.5 - 10.5 ppg Funnel Viscosity 40 - 60 sec/qt Plastic Viscosity 10 - 15 cps Yield Point 10 - 25 # / 100 fl2 Gels 4 - 12 Fluid Loss API 8 HPHT Fluid Loss 20 Notes: Build new PHPA Generic Mud #2. 9-5/8" X 13-3/8' ANNULUS MAY BE USED TO PUT AWAY MUD AND DRILLING WASTE FROM DRILLING RIG. DEPTH +/- 13020' LINER SIZE 7" HOLE SIZE MUD TYPE 8-1/2" F.I.W. / GENERIC MUD #2 (with PHPA) Notes; ANTICIPATED MUD PROPERTIES Mud Density 9.5 - 10.5 Funnel Viscosity 45 - 80 sec/qt Plastic Viscosity 10 - 15 cps Yield Point 15 - 30 # / 100 ft2 Gels 6- 12 API Fluid Loss 5 HPHT Fluid Loss 10 Treat for cement contamination. Increase yield point and gels in high angle section. Add lubricants for torque and drag. ANNA PLATFORM WELL # 51 GRANITE POINT (GP) ROTARY KELLY BUSHING (RKB) Elev. 127' DRILL DECK LEVEL Elev. 87' PRODUCTION DECK LEVEL Elcv. 69' x SEA LEVEL (MLW) Elev. 0' MUD LINE Elev. -77' 30" Structural Casing ~ 282' RKB (78'BML) 18-5/8" 97# X-56 QTE60 Surface Casing ~ 1100' 13-3/8" 68# k-55 BTC Intermediate Casing ~ 3800' 9-5/8" 47# L-go BTC Production Casing ~ 10900' T' 29# L-80 BTC Liner ~ 12900' FILL-UP i FLOW ~ HSP ANNULAR BOP 20~'4"2000 psi SPOOL ,[-DIVERTER SPOOL BLIND FLANGED DURING BOP OPERATIONS , PiPE RAMS i g0~'f' 3000 psi ,~" ~ n~, I BLIND RAMS CHE°C~ ?A~'~VE HCR [ ZO*j3000 p.s,i ! HOR KI" % ? MANUAL ~DPJm/NGi ~t~NUAL SPOOL LINE ~~o',~ooo ~s,~:'<~>~ CHOKE 3"-. t0M'~' i } \~ 4"- IOM GATE VALVES [ PiPE RAMS J20~/Z3000 psi GATE VALVES ! 20~/~ 3000 pm I LINE'-~ RECEIVED JAN - 9 199,5 At~ska Oil & Gas Cons. Commission Anchor~ CHAKACHATNA RIG 428 BOP/DIVERTER STACK 21 %l' 2000psi/2Oaa'' 3000psi FILL- UP -~> ~ FLOW- ,r ANNULAR BOP 13%"5000 ~sz i [ PIPE RAMS 136/i'5000 3"- i0M [ BLIND RAMS CT-T~'r'~ ~^~,~r i 13~/~'5000 ~~ -~' ~ HCR ~ ~ ' - HCR TzT~ ~ ' i ' MANUAL i DRII.I.ING[ MANUAL "ij ~~ ~~' ~~ ~ spOOL LINE ~~ ~~ooo psi~~ CHOKE MNE~ . RISER. [ CHAKACHATNA RIG 428. BOPE STACK 13 %" 5000 psi Pet Pit' I I - .~ .4,- ................. I __~ / : · 1,4 ,I, .~: o,..~e i j :"': ...... PC I I I : I I i I : I I : I I ,~ ....... i t ? ! ~ , .................... ~l~._.~_,~.:i' ' .......................... ~:~ _.~;~,.,1~ _ ~-- ~1~-,:~ 'l , ~.,,,,-'~: ..... · " _~-~ ~ER II · ' '~ '~ u ~ i I N--I'.¢ .... ...... H i I -~-~ ~[~ J I ",. ~ .' t_~._ ~ ......... RECEIVED dAN - 9 1995 ¢il.& Gas Cong. Commiss[on I r'.-.- · 'J I I i I ii ii T8-6 CUTTINGS cLrilIN¢2 DtSC/~GE IFI ' I6 : I~ I uu~ ! ,~. i ::,','~,','F'~' ~:;.,,,., J ~' IKAtt'.;I t It I : ~11~ /'l/All' il : I ISSUED ~ ' - '¢ '~' I:" ~ LOW PRES~ MUD ~ U~ IDtAIg~DIIA1NA PROJECT PM RIG 428 I i i I ! ! ! ! ! I ! I ,. m-..m' mI.~ i - ~,,~ Iii ' -'fiN. l'Y ........ 1515[J E IJ I' .{ 2 ,I POOL AHCTIC AI. ASKA OlVERIER HI'iE N0¢~ LIg0 POSI110N P00L It~ ~,28 A ~rln'W 4 . 4 i i i i II ! ! II ! ! I~bIJkD I ~{ ~!.1 I,)J4 !,_I_:~_IN !'!!';}? '.!'.}71 !!{~.'!'!! !',',l~iT ~ATFOR~S RECEIVED ~'" ~ ~,as Cons Co~rSl~: t~n~o~ -' , .' : I:oR itlFORMA i lu~ '" ONt¥ 1830ED M~R 2 4 ~994 PA& I~ 428 ~ VENT OUTSIDE OF MNDWALLS 't' PANIC LINE ,~' 5,000 BALL 4 V16-SM ac. x ~ ~/~6-~ HU~ BLIND HUB BLIND W1LLI$ ADJ. VENT UP DERRICK ..r RELIEF VALV~ SET AT 40 PSI -- ~o' ~5o lb. ~UNO FL~CE !0' 150 lb. FLANGE ClAI~P HUB CONNECTION TAIVK UUD C.45 SEPERA TOR SIPHON LINE 150 lb. FLANGE II i fO SH~E~ t5 c~P ,//ex~55 10,000 PSI HID. Cl~KE TO PRODUCTION SEPARATOR MUD RETURN UNE UNOC, U. CHOKE I, UVqlFOL~ COOK INLET DWi. C11-I:12592 UNOCAL QtOKE MANIFOLD COCg II~tEl' CASING DESIGN WELL: ANNA ~51 FIELD: GRANITE POINT DATE: 26-Dec-94 1. MUD WT. I 8.8 PPG 2. MUD WT, II 9.4 PPG 3, MUD WT. III 9.3 PPG DESIGN BY: P.A. RYAN M.S.P. 385 psi 818 psi 962 psi TENSION WEIGHT TOP OF W/O BF SECTION CASING SIZE BOq-I'OM TOP WT.__.~. LB_._~S LB~S 1 18-5/8" 1100 69 1031 97 X-52 QTE-60 100007 100007 1594 'I'VD 1100 69 2 13~3/8" 3800 69 3731 68 K-55 BTC 253708 253708 1069 -I'VD 3800 69 3 9-5/8" 10900 69 10831 47 L-80 BTC 509057 509057 1086 TVD 9920 69 4 7" 12900 10725 2175 . 29 L-80 BTC 63075 63075 ' 676 TVD 10687 9745 MINIMUM STRENGTH INTERVAL DESCRIPTION TENSION LENGTH GRADE THREAD 1000 LBS TD__EF 15.94 4.21 2.13 10.72 NOTES: See attached for calculation of M.S.P. including assumptions & estimates. * Collapse pressure is calculated; Difference between two cement slurries (i.e. Avg of a 15.8 ppg (tail) & 12 ppg (lead) = 14 ppg, subtract a mud of 9.5 ppg = 5.5 ppg = .286 psi/ft gradient X TVD of the csg string). ** Burst pressure is calculated; (BHP {~ depth next csg X TVD next csg) X (0.5 half evacuated). COLLAPSE COLLAPSE PRESS @ RESIST. Bo3-rOM TENSION PSI..._.~* PS_._[I 315 960 1087 1950 2837 4750 3056 7020 BURST MINIMUM PRESSURE YIELD CDF PSI** PS___[ BDF 3.05 855 2630 3.08 1.79 2232 3450 1.55 1.67 2405 6870 2,86 2.30 2405 8160 3.39 Anna Platform Well # 51 Granite Point (GP) December 26, 1994 Hole Section 1 Depth Interval: 0 - 1100' 17-1/2" & 24" hole size 18-5/8" casing to 1100' Mud Weight: Shoe depth (18-5/8"): Est. fracture gradient of 18-5/8" shoe: BHP gradient: 8.8 ppg = 0.46 psi/ft. 1100' MD / 1100' TVD 0.90 psi/ft. 0.35 psi/ft The maximum surface pressure cannot exceed the maximum bottom hole pressure; MSP = 1100' x 0.35 psi/ft. = 385 psi Hole Section 2 Depth Interval: 1100' - 3800' 17-1/2" hole size 13-3/8" casing to 3800' Mud Weight: Shoe depth (13-3/8"): Est. fracture gradient of 13-3/8" shoe: Depth of next hole section (12-1/4"): BHP gradient: Gas gradient (assume worst case) 9.4 ppg = 0.49 psi/ft. 3800' MD / 3800' TVD 0.80 psi/ft. 10900' MD / 9920' TVD 0.45 psi/ft 0.0 psi/ft. Gas kick situation in the wellbore, assume; 3/4 mud & 1/4 gas. MSP = BHP - Hydrostatic Pressure MSP = BHP - (3/4 mud + 1/4 gas) MSP = (9920' x 0.45 psi/ft) - ((0.75 (9920' x 0.49 psi/ft)) + (0.25 (9920' x 0.0 psi/ft.))) MSP = 818 psi Therefore, the hydrostatic pressure at the 13-3/8" shoe (HPsh) is the greatest when the gas (kick) bubble reaches the 13-3/8" shoe, if a constant BHP is applied. A conservative estimate would be the MSP plus the hydrostatic pressure at the 13-3/8" casing depth (HPcsg). HPsh = MSP + HPcsg HPsh = 818 + (3800' x 0.49) HPsh = 2680 psi This (HPsh = 2680 psi) is less than the fracture pressure at the same shoe (FPsh) and thus adequate to handle the well kick scenario. HPsh = 2680 psi < FPsh = 0.80 psi/ft x 3800' = 3040 psi. Anna Platform Well #51 Pressure Calculations Hole Section 3 Depth Interval: 3800'- 10900' 12-1/4" hole size 9-5/8" casing to 10900' Mud Weight: Shoe depth (9-5/8"): Est. fracture gradient of 9-5/8" shoe: Depth of next hole section (8-1/2"): BHP gradient: Gas gradient (assume worst case) 9.3 ppg = 0.48 psi/ft. 10900' MD / 9920' TVD 0.85 psi/ft. 12900' MD / 10687' TVD 0.45 psi/ft 0.0 psi/ft. Gas kick situation in the wellbore, assume; 3/4 mud & 1/4 gas. MSP = BHP - Hydrostatic Pressure MSP = BHP - (3/4 mud + 1/4 gas) MSP = (10687' x 0.45 psi/ft) - ((0.75 (10687' x 0.48 psi/ft)) + (0.25 (10687' x 0.0 psi/ft.))) MSP = 962 psi Therefore, the hydrostatic pressure at the 9-5/8" shoe (HPsh) is the greatest when the gas (kick) bubble reaches the 9-5/8" shoe, ifa constant BHP is applied. A conservative estimate would be the MSP plus the hydrostatic pressure at the 9-5/8" casing depth (HPcsg). HPsh = MSP + HPcsg HPsh = 962 + (9920' x 0.48 psi/fi) HPsh = 5724 psi This (HPsh = 5724 psi) is less than the fracture pressure at the same shoe (FPsh) and thus adequate to handle the well kick scenario. HPsh = 5724 psi < FPsh = 0.85 psi/ft x 9920' = 8432 psi. Additionally, HPsh - Pore Pressure at shoe < Internal Yield of the 9-5/8" casing 5724 - (9920' x 0.45 psi/fO < 6870 psi 1260 psi < 6870 psi Filename:AKOGCCV~n5 lcalc, doc Well # Date Baker Platform Ba 28 10-10-93 Ba 30 10-24-93 Ba 30 10-28-93 Ba 28 11-17-93 Ba 29 12-17-94 Ba 29 12-29-93 Ba 30 01-27-94 Ba 28 03-01-94 Grayling Platform G-40 01-24-90 G-40 Monopod Platform A- 1 rd 04-04-91 A-8rd 07-01-89 A-20rd 03-30-90 A-20rd 04-13-90 A-28rd 11-20-89 A-28rd 11-27-89 Granite Point Platform 11-13rd 02-14-92 51 08-07-92 51 07-28-92 51 08-25-92 50 05-27-92 50 06-04-92 50 06-27-92 Dillon Platform Leak Off Test (LOT) Data Cook Inlet, Alaska Revised December 19, 1994 Unocal Energy Resources Alaska Csg Size Shoe Depth (TVD) Frac Grad. (psi/ft.) EMW (PPe) 24" 802' 0.94 18.10 24" 803' 0.83 15.90 18-5/8" 2011' 0.94 18.10 18-5/8" 2135' 0.75 14.50 18-5/8" 2054' 0.76 14.61 13-3/8" 5869' 0.85 16.33 13-3/8" 5467' 0.93 17.96 13-3/8" 3509' 0.75 14.40 16" 1926' 0.96 18.46 13-3/8" 4977' 0.86 16.54 9-5/8" 1132' 1.07 9-5/8" 3760' 1.02 13-3/8" 755' 0.95 9-5/8" 1931' 0.85 20" 240' 0.75 13-3/8" 1140' 0.97 9-5/8" 9966' 0.96 18.40 13-3/8" 3803' 1.00 19.20 18-5/8" 1010' 0.87 16.80 9-5/8" 9592' 1.05 20.20 18-5/8" 982' 0.91 17.50 13-3/8" 4208' 0.84 16.20 9-5/8" 9877' 0.93 17.90 1.12 0.82 NA 1.01 0.83 NA 1.02 0.80 l 6 04-22-94 18-5/8" 1131' 16 06-16-94 13-3/8" 3640' 16 07-04-94 9-5/8" 9469' 17 04-27-94 18-5/8" 1142' 17 05 -01-94 13-3/8" 3560' 17 05- 9-5/8" 9213' 18 07-26-94 18-5/8" 1132' 18 08-01-94 13-3/8" 3988' 20.57 19.61 18.2o 16.30 14.42 18.65 21.72 15.80 14.2 (FIT) 19.47 15.90 16.5 (FIT) 19.63 15.3 Leak Off Test (LOT) Data Page 2 Anna Platfom 11 rd 10-23-94 13-3/8" 2976' 11 rd 11-11-94 9-5/8" 8750' 3rd 12/10/94 9-5/8" 7839' Notes: All fracture gradients reported have been corrected for air and water gaps. (FIT)-Formation Integrity Test 0.89 0.92 0.75 17.2 17.7 (FIT) 14.5 Filename AOGCCXLotdata.doc 'WELL.PERMIT CHECKLIST ~.~.D ~ POO~. ~/ WELL NAIv[g~..~!,,~,.-~ZI~__~',,I~'~ /i:~'~(7/.~.'~IPROGRAM= exp [] dev~ redrll [] ,erv [] ADMINISTRATION ENGINEERING 1. Permit fee attached ................... ~ N 2. Lease number appropriate ............... ~ N 3. Unique well name and number .............. ~ N 4. Well located in a defined pool ............. ~ N 5. Well located proper distance from drlg unit boundary. .~ ~,_~ 6. Well located proper distance from other wells ...... Y ~ 7. Sufficient acreage available in drilling unit ...... Y__~.~.~ 8. If deviated, is wellbore plat included ........ .~Y~ N 9. Operator only affected party .............. ~ N 10. Operator has appropriate bond in force ......... ~ N 11. Permit can be issued without conservation order ..... ~-~3ffi--~ 12. Permit can be issued without administrative approval. . .Y 13. Can permit be approved before 15-day wait ....... ~ N APPR 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 29. Conductor string provided ............... ~ N Surface casing protects all known USDWs ........ ~ N CMT vol adequate to circulate on conductor & surf csg..~ N CMT vol adequate to tie-in long string to surf csg . . . Y CMT will cover all known productive horizons ...... ~ N Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage or reserve pit ............. ~ N If a re-drill, has a 10-403 for abndnmnt been approved.-- Adequate wellbore separation proposed .......... If diverter required, is it adequate .......... Drilling fluid program schematic & equip list adequate .~ N BOPEs adequate .............. ~ ...... [Y~ N BOPE press rating adequate; test to .~6~y~'t> psig.~ N Choke manifold complies w/API RP-53 (May/84) ....... Work will occur without operation shutdown ....... ~ N Is presence of H2S gas probable ............. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y ~ ~ ~/~ 32. Seismic analysis 9f shallow gas zones .......... y N //~.,./~. , 33. Seabed condition survey (if off-shore) ........ ~ N 34. Contact name/phone for weekly progress reports .... /. Y N [exploratory only] /' G EOLOGY~~ E NGI NE ERING: COMMISSION: DWJ 7 TAB Comments/Instructions: · *~l=ORMb-Acheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. G.P. 18742 NO. 51 (ANNA)ST1 .,~'~~ ~ GRANITE POINT KENAI ALASKA LOGGED: 16 JUNE 1995 LIBRARY TAPE L/STING WESTERN ATLAS LOGGING SERVICES Anchorage, Alaska Date .~e 2 is type: ~IS .000 1024 CN WN FN COUN STAT : UNOCAL : GP 18742 ~51 ST1 : GRANITE POINT : KENAI : ALASKA LIS COMMENT RECORD (s): MAIN UP PASS * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units 1 CAL DLL 68 1 IN 2 CHT DLL 68 1 LB 3 GR DLL 68 1 GAPI 4 RD DLL 68 1 OHMM 5 RS DLL 68 1 OHl~4 6 SP DLL 68 1 MV 7 SPD DLL 68 1 F/MN 8 TEMP DLL 68 1 DEGF 9 TTEN DLL 68 1 LB 10 CN 2435 68 1 PU-L 11 CNC 2435 68 1 PU-S 12 CNCF 2435 68 1 PU-S 13 LSN 2435 68 1 CPS 14 SSN 2435 68 1 CPS 15 CORR CDL 68 1 G/C3 16 DEN CDL 68 1 G/C3 17 LSD CDL 68 1 CPS 18 SSD CDL 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 17 280 99 1 4 17 635 99 1 4 17 310 01 1 4 17 220 10 1 4 17 220 09 1 4 17 010 01 1 4 17 636 99 1 4 17 660 99 1 4 17 635 99 1 4 43 890 01 1 4 43 995 99 1 4 43 995 99 1 4 43 334 31 1 4 43 334 30 1 4 45 356 01 1 4 45 350 01 1 4 45 354 02 1 4 45 354 01 1 72 * DATA RECORD (TYPE# 0) Total Data Records: 796 994 BYTES * Tape File Start Depth = 13354.000000 Tape File End Depth = 10770.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: .: 68 !~6404 datums ~ Subfile: 2 801 records... Minimum record length: 62 bytes Maximum record length: 994 bytes ~ile 3 is type: LIS FILE HEADER **** .001 1024 CN WN FN COUN STAT : UNOCAL. : GP 18742 #51 ST1 : GRANITE POINT : KENAI : ALASKA LIS COMMENT RECORD (s): REPEAT DOWN PASS * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 CHT DLL 68 1 LB 2 GR DLL 68 1 GAPI 3 RD DLL 68 1 OHMM 4 RS DLL 68 1 OHMM 5 SP DLL 68 1 MV 6 SPD DLL 68 1 F/MN 7 TEMP DLL 68 1 DEGF 8 TTEN DLL 68 I LB 9 CN 2435 68 1 PU-L 10 CNC 2435 68 1 PU-S 11 CNCF 2435 68 1 PU-S 12 LSN 2435 68 1 CPS 13 SSN 2435 68 1 CPS 14 CORR CDL 68 1 G/C3 15 DEN CDL 68 1 G/C3 16 LSD CDL 68 1 CPS 17 SSD CDL 68 1 CPS 4 17 635 99 1 4 17 310 01 1 4 17 220 10 1 4 17 220 09 1 4 17 010 01 1 4 17 636 99 1 4 17 660 99 1 4 17 635 99 1 4 43 890 01 1 4 43 995 99 1 4 43 995 99 1 4 43 334 31 1 4 43 334 30 1 4 45 356 01 1 4 45 350 01 1 4 45 354 02 1 4 45 354 01 1 68 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 105 Tape File Start Depth = 13315.000000 Tape File End Depth = 12950.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** _~ntation code deco~ing summary: ~de: 68 26299 datums ~pe Subfile: 3 110 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes ~file 4 is type: LIS **** TAPE TRAILER ***~ 95/ 6/26 01 **** REEL TRAILER **** 95/ 6/26 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 26 JUN 95 9:58a Elapsed execution time = 12.74 seconds. SYSTEM RETURN CODE = 0
