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Home My WebLink About196-045Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 10/31/2025 InspectNo:susKPS250909140855 Well Pressures (psi): Date Inspected:9/8/2025 Inspector:Kam StJohn If Verified, How?Other (specify in comments) Suspension Date:8/11/1997 Tubing:0 IA:0 OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Gus Wik Date AOGCC Notified:9/5/2025 Type of Inspection:Subsequent Well Name:GRANITE POINT 52 Permit Number:1960450 Wellhead Condition Well was in good shape no leakes all gauges operational. Surrounding Surface Condition No stain from leaks or any other issues Condition of Cellar Offshore platform; no cellar Comments Location verified from platform well slot schematic Supervisor Comments Photos (2) attached Suspension Approval:Completion Report Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Friday, October 31, 2025            20205-0908_Suspend_GranitePt_GPP_52_photos_ksj Page 1 of 1 Suspended Well Inspection – Granite Pt GPP 52 PTD 19604560 AOGCC Inspection Rpt # susKPS250909140855 Photos by AOGCC Inspector K. StJohn 9/8/2025 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): Granite Point Field / Middle Kenai Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 1,122'N/A Casing Collapse Conductor Conductor Surface 1,950 psi Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Suspended Well Renewal 1,122'580'580'0 psi Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. N/A N/A Daniel E. Marlowe N/A Perforation Depth MD (ft): N/A N/A Tubing Grade:Tubing MD (ft): N/A Perforation Depth TVD (ft): 229' 33" 26" 13-3/8" 294' 1,107' 294' 1,107' 294' 1,107' 229' N/A TVD Burst N/A Tubing Size: MD 3,450 psi 196-045 50-733-20472-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC N/A Granite Point 52 COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018761 Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size N/A 229' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 12:46 pm, Sep 28, 2020 320-403 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.09.28 07:21:30 -08'00' Dan Marlowe (1267) SFD 9/28/2020 DSR-9/28/2020 No form required gls 10/7/20 Suspended Well Renewal Comm. on Required? Yes 10/8/2020 JLC 10/7/2020dts 10/07/2020 RBDMS HEW 11/2/2020 Suspended Well Inspection Data Well: GPP 52 Surface Location: 2428’ FNL, 1298’ FWL, Sec 13, T10N, R12W S.M. Permit to Drill: 196-045 API: 50-733-20472-00-00 AOGCC Inspection Date: 9/10/2020 AOGCC Inspector: Brian Bixby Size Pressure (psi) Tubing N/A Casing 13 3/8” 0 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: x The well was suspended on August 11, 1997. The well had been drilling at a depth of 1,107’ when the decision was made to cease drilling operations and suspend the well at that point. x The well was prepped for a sidetrack on 6/25/2019, cement was milled down to 580’, and the well was circulated out with FIW. Pressure test of 13 3/8” casing completed successfully, 2000psi for 30min. Operations were suspended due to rig timing. x It is proposed that well GP-52 be maintained in a suspended status to be utilized as a sidetrack candidate for future development opportunities. x Condition of Wellhead: Very good and Clean / No Issues. x Condition of Surrounding Surface Location: Good - No Issues Mentioned or Noted. x Follow up Actions needed: No follow up actions required at this time. Attachments: x Current Well Schematic x Picture(s) x Plat - 1/4mile radius of wellbore The well was prepped for a sidetrack on 6/25/2019, cement was milled down to 580’, and the well was circulated out with FIW. Pressure test of 13 3/8” casing completed successfully, 2000psi for 30min. Operations were suspended due to rig timing. Updated by: JLL 09/22/20 Granite Point Field Well Name: GP-52 Completion Date: 8/11/97 PTD:196-045 API: 50-733-20472-00 SCHEMATIC Casing Detail Size Type Wt/ Grade Top Btm CONN /ID Cement/Other 33” Conductor Surface 229’ Driven 26” Conductor Surface 294’ Driven 13-3/8” Surface 68#, K-55 Surface 1,107’ BTC 354bbl 12.9ppg lead, 68bbl 15.8ppg tail PBTD = 1,063’MD (1,063’ TVD) TD = 1,122’MD (1,121 TVD) 26” @ 294’ RKB: 43.44’ 13-3/8” @ 1,107’ Rig Floor to Wellhead: 114.75’ 33” @ 229’ FCO to 580’ 07/2019 9.1 ppg WBM Directional Data: max hole angle = 3.5o @ 591’ Suspended WellInspection Re\ieVDeDQrf !nspec1Mn: sus8DB200911084603 Date Inspected: 9/10/20I0 Inspector: Brian Bixby Type ofInspection: Subsequent - Well Name GRANITE POINT 52 Date A0G[ZNotified: 9/8/2020 ' Permit Number: 1960450 Operator: Hi|corpA|asku' LU[ - Suspension Appnrvak Completion Report' Operator Rep: Jeff Bartlett � Suspension Date: 8/11/1997 ~ Wellbore Diagram Avail? Location Verified? W PhotosTaken? (fVerified, Flow? Other (specify incomments) Offshore? W Well Pressures (psi): Tubinl": 0 Fluid in Cellar? El |A� 0 BPVinstaUed? [� OA� VRP|ug(s)Installed? [] Wellhead Condition � Wellhead look to be in good shape. All valve handles installed and good gauges Condition ofCellar NA ' Surrounding Surface Condition Good ' Comments Location . rified by the Granite Point Platform Well Slot Schematic, There was never any tubing run in the hole so | put the ~ 13 3/8" casing esthe tubing. Supervisor Comments Photos(2)attached � 17_ 2- Zo'Iv Tuesday, September 22, 2020 Al a �Q C/� a 7 HES U b 0 0 N h P. o � C) a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS '`A 2 2 ?nta 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate Pull Tubing Operations shutdownLJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Reinter Susp Well ❑� Other: C/O surface casing for rednll Q 2. Operator 4. Well Class Before Work: 5. Permit to Dnll Number: Name: Hilcorp Alaska, LLC Development ❑✓ Exploratory ❑ Stratigraphic ❑ Service ❑ 196-045 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20472-00-00 7. Property Designation (Lease Number): 8. Well Name and Number. ADL0018761 Granite Point 52 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Granite Point Field / Middle Kenai Oil Pool 11. Present Well Condition Summary: Total Depth measured 1,122 feet Plugs measured N/A feet true vertical 1,122 feet Junk measured N/A feet Effective Depth measured 1,063 feet Packer measured N/A feet true vertical 1,063 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 229' 33" 229' 229' Conductor 294' 26" 294' 294' Surface 1,107' 13-3/8" 1,107' 1,107' 3,450 psi 1,950 psi Intermediate Production Liner Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth) WA Packers and SSSV (type, measured and true vertical depth) N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 0 0 0 129 121 Subsequent to operation: 10 0 0 160 0 14. Attachments (required per 20 AAc 25o70,25.071, &25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑ Development Service ❑ Stratigmphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR p WINJ ❑ WAG ❑ GINJ ❑ SUSP Q SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-271 Authorized Name: Stan W. Golfs Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmanoweCcDhilcom.com 'sL' Authorized Signature: W Date: (:!Z Contact Phone: (907) 283-1329 Q Form 10-404 Revised 4/2017 �' .t 7_,5�, -2 RBS 5S ' �U� 2 3 ZOt9 Submit Original Only le�f Granite Point Field Well Name: GP -52 11 SCHEMATIC Completion Date: 8/11/97 PTD: 196-045 Hilcnro Alaska, LLC. API: 50-733-20472-00 Rig Floor to Wellhead: 114.75' Ea 33" @ 229' 26" @ 264' S, �3/9 131,107 @ EL7r_-7 _ -^L 1,107' PBTD=1,063'MD (1,063' TVD) TD=1,122'MD (1,121 TVD) Directional Data: max hole angle = 3.5° @ 591' Casing Detail Size Type Wt/ Grade Top Btm CONN Cement/Other /ID 33" Conductor Surface 229' Driven 26" Conductor Surface 294' Driven 13-3/8" Surface 68#, K-55 Surface 1,107' BTC 354bbl 12.9ppg lead, 68bb] 15.8ppg tail Updated by: AL 05/24/19 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 52 HAK 404 50-733-20472-00-00 1 196-045 6/25/19 1 6/28/19 Daily Operations: 06/25/19 -Tuesday N/D GP -52 wellhead and remove tree with crane. N/D BOPE from GP -55 and N/U to GP -52. No activity on GP -52 while finishing up activities on GP -55. 06/26/19 - Wednesday Skid rig over well GP -52. Replace all storm clamps. Install stairways. Scope up derrick. Set guy wires and chain stack in place. Rig down skid jacking assembly. Install handrails and secure areas where hand rails had to be removed. Skid rig 6" north. Install rig floor and racking beam. Install stairs to rig floor/dog house. Drain cement water tank and prep equipment for back load. Rig up to test BOPS. Make up test joint and fluid pack stack. Perform shell test to 250 L/2500 H. Had to troubleshoot and repair a couple of leaks. Shell test BOPE 250L/2500H test GOOD. Tally pipe while waiting on Helicopter for State inspector. Test BOPE to 250L/2500H per AOGCC and Hilcorp standards - charted, Test GOOD. Test gas detection system. Cellar H25 detector was not communicating and was replaced with spare sensor on -board -Test GOOD. Test witnessed by AOGCC inspector Austin McCloud. M/U 13-3/8" scraper on 3.5" 12.95# PH -6 work string. R/D Hawklaw, R/U Gill tongs. RIH with 13-3/8" scraper on 3.5" 12.95# PH -6 work string, picking up singles. Worked scraper down to 475Ft and wouldn't work it any further. R/U and circulate well. 06/27/19 - Thursday Attempt to wash in the hole and made down to 545' until no further progress made. Pull out of hole and pick up 12 1/4" mill tooth bit. Unable to torque bit so had weld tack weld to bit sub. RIH to 540' with clean out assembly. Pick up power swivel and rig up power pack hoses. Wash and ream from 545' to 580'. Reverse circulate every 15' to prevent packing off. Getting back large amount of cement. Decision made to suspend drilling cement operations. Rig down power swivel. Transfer 145 bbls of contaminated fluid from pits to ISO's. Clean pits. Continue transferring from Pits to ISOs, clean pits, work boat, R/U to circulate out WBM. Displace well to from 9.1# WBM to FIW, reverse circulating at SBPM 280psi for 94BBL taking returns back to ISO tanks. Monitoring returns until clean FIW came back. R/U and test 13-3/8"-K- 55- 68# casing to 2000psi for 30min, charted - TESTED GOOD. R/D test pressure test equipment. R/U to POOH. POOH laying down 3.5" 12.95# PH -6 work string from 58OFT. R/U HawkJaws and break off 13-3/8" scraper assembly. Clean/clear rig floor, R/D HawkJaw, stairs, beaver slide. Move ISO's. Clean and begin R/D of all rig components. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig�APIberGranite Pt St 52 HAK 403 20471 nn nn , oc Drain stack. Open ram doors and sent VBR's in for redress. Cleaned door seals and buttoned up for transport. R/D rig floor. R/D Koomey lines. Remove stairs. Scope mast down. Finish pumping out pits into tote. General housekeeping. Prepare to lay down mast. Unspool and secure manrider and tuggers. Assist Total Safety and Quadco with rigging down their equipment. Unspool drill line off of drawworks. Cut off 100' of drill line. Rig down mud pump controls and weight indicator. Disconnect brake handle and hydraulic lines. Remove drive shaft to drawworks. Secure lines on hooks in derrick. Clean pits and rig down hoses. Rig down drillers doghouse. Lay down derrick, N/D and clean BOPE stack. Remove raising cylinders from derrick. R/D choke manifold. N/D riser, N/U wellhead and test 1500psi - 30 min Test GOOD. R/D test pump. R/D clean Koomy & hoses. Clean doghouse. Unbolt draw works from carrier. Unbolt clamps from platform beams. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Stan W. Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Point 52 Permit to Drill Number: 196-045 Sundry Number: 319-271 Dear Mr. Golis: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a o g c c. a l a s k a. g o v Enclosed is the approved application for the 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, IPP5�� Daniel T. Seamount, Jr. Commissioner DATED thisZ`J day f May, 2019. — RBDMStL%-' MAY 3 0 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED MAY 2 8 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑� ' Alter Casing ❑ Other: C/O surface casino ❑✓ for redrill 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 196-045 - 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20472-00-00 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 ❑� Granite Point 52 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018761 I 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): 1,122 1,122 1,063 1,063 384 psi N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 229' 33" 229' 229' Conductor 294' 26" 294' 294' Surface 1,107' 13-3/8" 1,107' 1,107' 3,450 psi 1,950 psi Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Exploratory ❑ Strati ra hic g p ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/10/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑� GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe hilcor .Com Contact Phone: (907) 283-1329 5 et Authorized Signature: Date: I Z '{ I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: f``J Plug Integrity ❑ BOP Testis Mechanical Integrity Test ❑ Location Clearance ❑ Other:L RBDMS — MAY 3 0 2019 No Post Initial Injection MIT Req'd? Yes ❑ ❑ � (/ Spacing Exception Required? Yes ❑ No LvJ Subsequent Form Required: ! a — Y d Y APPROVEDBY 11'7 Approved byCOMMISSIONER THE COMMISSION Date: `Zp S(Al � s" ve o�ceR } A submit Form and 10-403 Revlsed 4/2017 Approved appli ti V I G�1r/p_El om the date of approval. � hme sin uplicate sA� iy K HJI.,p Alaska, LLC Well Work Prognosis Well Name: Granite Point 52 API Number: 50-733-20472-00 Current Status: Suspended Leg: Leg #4 Estimated Start Date: lune 10, 2019 Rig: HAK 404 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 196-045 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907) 777-8356 (0) (281) 450-3071 (M) Current Bottom Hole Pressure: 487 psi @ 1,029' TVD 0.473 lbs/ft (9.1 ppg) Maximum Expected BHP: 487 psi @ 1,029' TVD 0.473 lbs/ft (9.1 ppg) Maximum Potential Surface Pressure: 384 psi Using 0.1 psi/ft gradient per 20AAC25.280(b)(4) Brief Well Summary ell GP -52 is a Suspended Development well drilled in 1997. After drilling to 1,122' MD and setting surface casing at 1,107' the program was cancelled. This project will clean out the surface casing in preparation for the jack-up drill well program scheduled for this summer. Last Casing Test: N/A Procedure: Phase I 1. MIRU Rig HAK-404. 2. Monitor well to ensure it is static. FIW will be circulated as necessary to balance well, BOP's will be closed as needed to circulate the well. 3. ND Wellhead. 4. NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 5. Monitor well to ensure it is static. 6. Pickup workstring and RIH with cleanout assembly to +/-1,063' (landing collar). 7. Displace well to clean FIW. 8. Pressure test 13-3/8" to 2,000 psi for 30 minutes, chart test. 9. POOH. 10. ND BOPE and NU dry hole tree and test. 11. Rig down. 12. Suspend operations until drilling rig moves on location. ***Remaining Procedure to be included on the Permit to Drill for the sidetrack*** Phase II General sequence of operations pertaining to drilling procedure: (informational only) 13. Resume operations with drilling rig. 14. MIRU drilling rig. 15. Monitor well to ensure it is static. U fGkorp Alaska, LLC Well Work Prognosis 16. ND Wellhead, NU BOP and test to 250psi low/3,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 17. PU Drilling BHA and RIH to TOC. 18. Swap well to drilling fluid. 19. Drill 20' of new hole. 20. Swap to drilling PTD. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. BOP Drawing — HAK 404 5. Fluid Flow Diagrams —HAK 404 6. RWO Sundry Revision Change Form 0 Hilearo Alaska, LLC Rig Floor to Wellhead:114.75' RKB: 43.44' ji , r 33" @ 229' .:t 26" @ 294' 1- 9.1 ppg WBM IN 13-3/8" I�. i 13-3/8" @. ....•::�71t 1,107, s:i.• PBTD=1,063'MD (1,063' TVD) TD=1,122MD (1,121 TVD) Directional Data: max hole angle = 3.5° @ 591' SCHEMATIC Granite Point Field Well Name: GP -52 Completion Date: 8/11/97 PTD: 196-045 API: 50-733-20472-00 Casing Detail Size Type Wt/ Grade Top Btm CONN Cement/Other /ID 33" Conductor Surface 229' Driven 26" Conductor Surface 294' Driven 13-3/8" Surface 68#, K-55 Surface 1,107' BTC 354bbl 12.9ppg lead, 68bbl 15.8ppg tail Updated by: JLL 05/24/19 Granite Point Field Well Name: GP -52 PROPOSED Completion Date: 8/11/97 PTD: 196-045 Hilcorp AJ4aka, LLC API: 50-733-20472-00 33" @ 229' 26" @ 294' Rig Floor to Wellhead: 114.75' Casing Detail Size Type Wt/ Grade Top Btm CONN Cement/Other /ID 33" Conductor Surface 229' Driven 26" Conductor Surface 294' Driven 13-3/8" Surface 68#, K-55 Surface 1,107' BTC 354bbi 12.9ppg lead, 68bbi 15.8ppq tail 1,197' PBTD = 1,063'MD (1,063' TVD) TD=1,122MD (1,121 TVD) Directional Data: max hole angle = 3.5° @ 591' fly � ekc**'� ON Updated by: JLL 05/24/19 K Hibmrp Ala.4., IAA: Unihead, National SMS, 3 step system, 135/8 SM API Hub top X 13 3/8 BTC casing bottom, w/ 2- 2" IPO, 4- 21/16 SM S5O Granite Point Platform GPP-52 Current 04/30/2019 H M6.m p Aluaku, LIA: BOP Stack HAK 404 5.5 bles Il vahes M Valve Position RIG #404 (0/q 5tantlpipe Pump Manifold 1(PM1) 0 FLUID FLOW DIAGRAM Manifold Pump Manifold 2 HM2) c Pump Manifold 3 (PM3) 0 NORMAL OPERATIONS Pump Manifold 4(PM4) C CIRCULATING DOWN TUBING, UP CASING ANNULAS Pump Manifold 5(PM5) 0 "THE LONG WAY" Mud Kill Llnel o Crass Kill Line2 0 STANDPIPE HCR valve(Choke Line 1) C Choke Line2 0 Choke Choke Manifoltl I(CMI) O Manifold Choke Manifold 2(CM2) C Choke Manifold 3(CM3) 0 Choke Manlfold4(C_4I C Choke Manifold 5(CMS) O Choke Manifold 6(CM6) C PANIC Choke Manifold 7 (CM]) 0 LINE Choke Man,(,MS) C Choke Manifold 9 (CM9) C RIG FLOOR #2 Choke Manifold 10(CM10) 0 lift Super Choke C Manual Choke C SUPER 1!9 RigFloor Safety Valve 0 CHOKE #3 STRIPPER HEAD if #3 #5 #7 #10 #4 #2 MUDBOP #5 PUMP STACK #4 #6 #8 CHOKE C LP `HCR SUCTION VALVE#1 GAS LINE BUSTER FLUID TANK/PIT RIG #404 FLUID FLOW DIAGRAM NORMAL OPERATIONS CIRCULATING DOWN CASING, UP TUBING "REVERSE CIRCULATING" STANDPIPE PANIC LINE RIG FLOOR 2 SUPER #3 CHOKE #3 STRIPPER #3 ,#r0 #7 #10 HEAD )f if if v #4 #2 STOCK #4 #6 #8 #5 T1 #1 MANUAL J R CHOKE LP HC , SUCTION VALVE #� GAS LINE HusTE� FLUID TANK/PIT Valve Position o/c Standpipe Pump Manifold 1(PMlI O Manifold Pump Manifold 2 (PM21 O Pump Manifold 3 (PM31 C Pump Manifold 41PMAI 0 Pump ManifoldSIPM61 C Mud KIII Linel 0 Cross Kill Line2 0 HCR valve (Choke Line l) C Choke Line2 0 Choke Choke Manifoldl(CMl) 0 Manifold Choke Manifold2(CM2) C Choke Manifold 3 (CM3) 0 Choke Manifoltl4(CMVI C Choke Manifold S (CM61 O Choke Manifold 61CM61 C Choke Manifold]ICM7) 0 Choke Manifold8(CMS) C Choke ManNoltl9(CMS) C Choke Manifold 10 (CM1D) 0 Super Choke C Manual Choke C Rig Floor Safety Valve 0 RIG #404 FLUID FLOW DIAGRAM NORMAL OPERATIONS CIRCULATING DOWN CASING, UP TUBING "REVERSE CIRCULATING" STANDPIPE PANIC LINE RIG FLOOR 2 SUPER #3 CHOKE #3 STRIPPER #3 ,#r0 #7 #10 HEAD )f if if v #4 #2 STOCK #4 #6 #8 #5 T1 #1 MANUAL J R CHOKE LP HC , SUCTION VALVE #� GAS LINE HusTE� FLUID TANK/PIT Valve Position o/c Standpipe Pump Manifold 1(PMlI O Manifold Pump Manifold 2 (PM21 O Pump Manifold 3 (PM31 C Pump Manifold 41PMAI 0 Pump ManifoldSIPM61 C Mud KIII Linel 0 Cross Kill Line2 0 HCR valve (Choke Line l) C Choke Line2 0 Choke Choke Manifoldl(CMl) 0 Manifold Choke Manifold2(CM2) C Choke Manifold 3 (CM3) 0 Choke Manifoltl4(CMVI C Choke Manifold S (CM61 O Choke Manifold 61CM61 C Choke Manifold]ICM7) 0 Choke Manifold8(CMS) C Choke ManNoltl9(CMS) C Choke Manifold 10 (CM1D) 0 Super Choke C Manual Choke C Rig Floor Safety Rig 404 BOP Test Procedure H .gAi.rk„,LLC Attachment #1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Rig 404, 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. 3) 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 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.) H H&.1, M.A., LLC Rig 404 BOP Test Procedure Attachment #1 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. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) 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 joint 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- RIH with test plug on joint of tubing. Install a pump -in sub w/ test line plus an open TIW or lower Kelly valve in top of test joint w/ open IBOP. 3) Test BOPE per standard procedure. STANDARD HOPE TEST PROCEDURE (after 2 -way check or test plug is set) 1) Fill stack and all lines with rig pump- install chart recorder on test line connected to pump -in sub below safety valve and IBOP in test joint assembly. 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 (test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1" valve on standpipe manifold, close valves 1, 2, 10 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross, open V valve of standpipe, close valves 3, 4 & 9 on choke manifold, open valves 1 & 2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve / open outside valve on kill side of mud cross, close valves 5 & 6 / open valves 3 & 4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke / open valves 5 & 6 on choke manifold. Pressure up to - 1200 psi and bleed off 200 - 300 #s recording change and stabilization. If passes after 5 minutes, bleed off pressure back to tank. f) Close HCR (outside valve on choke side of mud cross), open manual & super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. n Hilu,q ALA.. LLC Rig 404 BOP Test Procedure Attachment #1 g) Close inside valve / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off- open pipe rams and pull test joint leaving test plug/ 2 -way check in place. Close blind rams and attach test line to valve 10 on choke manifold, close valve 7 & 8 / open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves (TIW or Lower Kelly Valve) and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/ -3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre - charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto', not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) 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. HHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well: Granite Point 52 (PTD 196-045) Sundry M XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call" engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials -HA K Approved By initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: /Asset i earn uperations manager Date first -an uperavons tngmeer Date RECEIVED STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMAION SEP 2 8 2015 ` REPORT OF SUNDRY WELL OPERATIONS AOGGC 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend 0 Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Re-enter Susp Well❑ Other:Suspended Well Inspection ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 196-045 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service El 6.API Number: Anchorage,AK 99503 50-733-20472-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018761 Granite Point 52 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Point Field/Middle Kenai Oil Pool 11.Present Well Condition Summary: Total Depth measured 1,122 feet Plugs measured N/A feet true vertical 1,122 feet Junk measured N/A feet Effective Depth measured 1,030 feet Packer measured N/A feet true vertical 1,030 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 294' 26" 294' 294' Surface 1,107' 13-3/8" 1,107' 1,107' 3,450 psi 1,950 psi Intermediate Production Liner Perforation depth Measured depth N/A feet ' CAkitila1 )P ` 2 0 an G; True Vertical depth N/A feet Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required pet 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development[] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil p Gas El WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSPD SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 310-360 Contact Dan Marlowe Email dmarlowe(DhiIcorp.com Printed Name Da Marlowe Title Operations Engineer / Signature "' Phone (907)283-1329 Date �f J /Js J. to--(3'1 5RBDMS SEP 2 9 2015 Form 10-404 Revised 5/2015 Submit Original Only • • Suspended Well Inspection Data Well: GPP 52 Surface Location: 2428' FNL, 1298' FWL, Sec 13,T10N, R12W S.M. Permit to Drill: 196-045 API: 50-733-20472-00 AOGCC Inspection Date: 9/25/15 AOGCC Inspector: Matt Herrera Size Pressure (psi) Tubing 0/0 Casing IA 0/0 OA 0/0 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • Condition of Wellhead: Good • Condition of Surrounding Surface Location: Good • Follow Up Actions needed: None/ Readings psi Attachments: • Current Well Schematic • Picture(s) • Plat- 1/4mile radius of wellbore • Correspondence/Suspended Well Inspection Report • Granite Point Platform Completion GP-52 Date: 8/11/97 Hilcorp Alaska,LLC Rig Floor to Wellhead:11479 RF4B:43A4 Casing Detail Size Type Wt/Grade Top Btm CONN Cement/Other /ID 26" Conductor Surface 294' Driven 13-3/8" Surface 68#, K-55 Surface 1,107' BTC 354bb1 12.9ppg lead, a;°@294 68bbl 15.8ppg tail 9.1 ppg WBM • rs N. �.H off, 133/8"@ A. 1,107 PBTD=1,030MD(1,020 TVD) 1D=1,122'MD(1,121 TVD) Directional Data: max hole angle=3.5°@ 591' GP-52 Schematic 10-6-10 Updated by CVK 10-6-10 Ts . , ... I. w .s. 4 440 0 .4 a t A r ,, s oil iml . 1 ,.... .. , , i‘ 4 444 44 i 111111.‘ ,14, . , . ii morletts. ot. b. 4 IL I 1 , . , ! '' .,. ' .., . _ ... 1 'II _ 1 1111P. * .t. I 0 , . , _ '''' 14_ * . 11 •41 .,....,;V,,e: a, lir .. - 0 r . , , J , k, r-#.4 .4ofeilitt, —,...,.. 0.4 ' ., •ii° . 4 ' -""44 i 4071. fr I Vt,.., 1 - e .,..,,,...A. r0 ,:;4,-,,,,t'4• "r , *2a: • • '.'-.e,,',, ','":,,i,..r:!0,-,,,,t,'„',-, ""•,, *.,',.,. I ,, i „LEI 0, , ! a tw, ... .1— \ //.... /\ (11 \ 6. l 0 4'1 6 ri r ,.- ci 41C.' 0 em .. . . 0 b \, t___11110, 2 in H ( '- ... i i 0 ....• ...-. . . H 411, ........,, ,o.. . _ ,_▪. g cp 5 ,--, ._V a 0\ N al H ,. g 4r 4 0 , . # \ \ ...... ,....... .„,,,,,, ,. \-, -^I , .0\\ •._44)__ ri ,.71 ,: 4 •il• ----,.....„..., CD ' N ,, a. 0 . \\.. ._____................._________. ra x el r^.? al "It a. 0 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/25/15 Inspector: Matt Herrera Operator: HILCORP Well Name: Granite Pt 52 Oper.Rep: James Madrid PTD No.: 1960450 Oper.Phone: 907-776-6650 Location Verified? Yes Oper.Email: jmadrid@hilcorp.com If Verified,How? LAT/LONG Onshore/Offshore: Offshore • Suspension Date: 08/11/97 Date AOGCC Notified: 09/23/15 Sundry No.: Well Completion Report Type of Inspection: Subsequent " Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes • IA 0 OA 0 s Condition of Wellhead: Good,Gauges operable Condition of Surrounding Surface Location: Good no standing water or oil sheen discoloration around well head or in cellar area Follow Up Actions Needed: Monitor IA and OA pressure and visually inspection by Operator Comments: No SSV Attachments: Photo(1) SCANNED SEP O 120117 REVIEWED BY: Insp.Supry Comm PLB 12/2014 2015-0925_Suspend_GranitePt_State_52 mh..xlsx • • • e , I ;It :: ! :iy.ri. rx * CNJ 14:- swot6.. „ ., tea A777 S - ier • .. '� ilk .w' �, 1 N ... ......-- kn rj t. -c, .� +, i# !OI N rli 1 Fa— ,,. rcal cN i �I 0 $.-, ■ II` ' v_ u� is 11 k: — 16i. • /-- • cn ,--1 S •0 ..... ..... .. t. CA N w • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/25/10 Inspector: Lou Grimaldi Operator: Union Oil Company Well Name: GP -52 Oper. Rep: Jerry Collins PTD No.: 196 -045 Oper. Phone: 776 -6650 Location Verified? Yes Oper. Email: If Verified, How? Other (specify in comments) Onshore / Offshore: Offshore Suspension Date: 08/11/97 Date AOGCC Notified: unknown Sundry No.: Well Completion Report Type of Inspection: Initial Wellbore Diagram Avail.? No Well Pressures (psi): Tubing 0 Photos Taken? Yes IA 0 OA 0/0 Condition of Wellhead: Clean and secure Condition of Surrounding Surface Granite Pt Platform; Wellroom clean and secure Location: Follow Up Actions None Needed: Attachments: Photo REVIEWED BY: Insp. Supry jrg. Comm PLB 09/2010 2010- 0925 _Suspend_Granite_Pt_52_Ig.xls Suspended Well Inspection — Granite Pt 52 (Granite Pt Platform) PTD 1960450 Photo by AOGCC Inspector L. Grimaldi 9/25/2010 • 11; 4.141 V-53 IMP - 1141 z r , 0 r -� *s f 4 $ • • • y • CAlrflOt4 a ,� SEAN PARNELL, GOVERNOR ALASIKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMUSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 1 / FAX (907) 276-7542 Timothy C. Brandenburg st AW&f) Nov 1 8 Zulu Drilling Manager Union Oil Company of California CqJ1 PO Box 196247 Anchorage, AK 99519 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Point 52 Sundry Number: 310-360 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. . gre 0 N an i ione DATED this /�_ day of November, 2 010. Encl. W4� STATE OF ALASKA OCT 2 g 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A1*8011&rj2SC0P2.00 aSion 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Request for Suspended Well ❑� Renewal 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 Exploratory ❑ 196 -045 ' 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20472 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El Granite Point 52 . 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0018761 [Granite Point Platform] Granite PT Field / Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): i 1,122 1,121 1,030 1,029 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 294' 26" 294' 293' Surface 1,107' 13 -3/8" 1,107' 1,106' 3,450 psi 1,950 psi Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A / N/A N/A / N/A 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Service ❑ 14. Estimated Date for N/A 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended Q 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature _i^—� . Phone 276 -7600 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 0 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: Ajo kt APPROVED BY Appr 4 MMISSIONER THE COMMISSION Date: Form 10 -403 Revised 1/2010 f L Submit in Duplicate NA Suspended Well Data Well: GP -52 Surface Location: 2428' FNL, 1298' FWL, Sec 13, T10N, R12W S.M. Permit to Drill: 196 -045 API: 50- 733 - 20472 -00 AOGCC Inspection Date: 9/25/10 AOGCC Inspector: Lou Grimaldi Size Pressure (psi) Tubing N/A N/A Casing 13 -3/8" 0 *Note: Wellhead pressures to be recorded daily. Other Notes: • Inspector's comments: Wellhead excellent, secure. Well room clean. • The well was suspended on August 11, 1997. 'The well had been drilling at a depth of 1,107' when the decision was made to cease drilling operations and suspend the well at that point. • The well is believed to be suspended above any potential hydrocarbon bearing intervals. • The well does not exhibit any wellhead pressure. • Wellhead pressures will continue to be monitored on a daily basis. • It is proposed that well GP -52 be maintained in a suspended status until the Granite Point Platform production is shut -in and the platform abandonment commences. Attachments: • Current Well Schematic • 3 Year TIO Plot evro Granite Point Platform Completion GP -52 Date: 8/11/97 Rig Fl" to Wellhead: 11478 Rte: 43.44 i Casing Detail Size Type Wt/ Grade Top Btm CONN Cement/Other /ID 26" Conductor Surface 294' Driven 13 -3/8" Surface 68 #, K -55 Surface 1,107' BTC 354bb1 12.9ppg lead, 29'@294 68bbl 15.8ppg tail 9.1 ppg VVBM �i Z ,. 1a3rs °@ . 1,107' PBTD = 1,03(Y MD (1,029 TVD) TD= 1, 122'IMD (1,121 TVD) Directional Data: max hole angle = 3.5° @ 591' GP -52 Schematic 10 -6 -10 doc Updated by CVK 10 -6 -10 Pressure N N A O O 0 O N A O OD O O O O O O O O O O O 10/17/07 0 1/17/08 c w � v -- oq 0o - oa - 4/17/08 7/17/08 b O 10/17/08 b C 0 1/17/09 I A� C 4/17/09 y i 7/17/09 r.� b 10/17/09 C11 N 1/17/10 4/17/10 7/17/10 10/17/10 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED · ON OR BEFORE JANUARY 03, 2001 PL M ATE E T H IS IA L U N D M ARK E W E R R C:LORIhMFILM.DOC .... -~. STATE OF ALASKA -~ ALASKA C._ AND GAS CONSERVATION U,.,MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED:X ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Unocal 96-0045 3. Address 8. APt Number P.O. Box 196247 Anchorage, AK 99519 50- 733-20472 4. Location of well at surface ~ 9. Unit or Lease Name 2426' FNL, 1296' FWL, Sec. 13, T10N, R12W, SM ~ Granite Point Field At Top Producing Interval~ 10. Well Number ,~ GP #52 N/A At Total Depth - 11. Field and Pool 2439' FNL, 1307' FWL, Sec. 13, T10N, R12W, SM Granite Point Field/Middle Kenai "C" Sands 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 114.75 RKB (MLLW)I ADL 18761 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 8/8/97 8/9/97I 8/11/97 75 feet MSLI One 17'Tota'Depth(MD+TVD) 18' P'ug Back Depth (MD+TVD' I 19' Direct'°na' Survey 20' Depth where SSSV set I21' ThiCkness of Permafr°st1122/1121 1030'/1030' Yes: X No: N/A feet MD N/A 22. Type Electric or Other Logs Run None 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~. PER FT. G~DE TOP BO~OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 68 K-55 44 1107 17-1/2" N/A 24. Pedorations open to Production (MD+~D of Top and BoAom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A N/A 26. ACID, F~CTURE, CEMENT SQUEEZE, ETC. 0RIGIN L DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production ~ Method of Operation (Flowing, gas lift, etc.) I N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO I TEST PERIOD => Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (corr) Press. 24-HOUR ~TE => 28. CORE DATA Brief description of lithology, porosiW, fractures, apparent dips and presen~ of oil, gas or water. Submit core chips. Interbedded sandstones; conglomerates, claystones and coals. Pay zone is a sandy conglomerate averaging 12% porosiW with an estimated RECEIVED SEP ~ 4 1991 Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/A N/A 31. LIST OF ATTACHMENTS Daily Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Dale A. Haines ~,~ (,~. ~. ~ ~ u,.,- Ddlling Manager Sept. 22, 97 Signed Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space 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 productin 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. Form 10-407 Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cemeR' ~',' C ~ ~ V ~ D lng 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. _~1~_ .0JJ & Gas Cons. 00rnmis~J, Item 28: If no cores taken, indicate "none". GRANITE POINT 52 DAY 1 (8/7/97) LD 3-1/2" DP. CLEAN ALL PITS AND LINES. SKID RIG TO SLOT #3. INSTALL 6" LINERS. OFFLOAD 5" DP. DAY 2-4 (8/8/- 8/11/97) RIH AND TAG BOTTM @ 248'. ClRC HOLE CLEAN. PU BHA AND RIH. DIRECTIONAL DRILL 17-1/2" HOLE TO 1,122'. CBU. RIH WITH 13-3/8" 68 LB/FT K-55 CASING. PUMP 400 SX OF CEMENTmWITH CEMENT RETURNS TO SURFACE. ND RISER. NU WELLHEAD VALVES AND TREE. CLEAN PITS. SKID RIG TO GP 53. UNOCAL Granite Point Platform Cook Inlet, Alaska Leg #4, Slot #3 Well #GP52 Directional & Navigation Drilling Completion Report DDS: T DUNN, D YOUNG Job Numb~'~?~50-87748 · Start Date: 08-Au9-97 . ~ ~J~,~, =w,-- , vr'~,-v,M=,,u-~ = ,v=, r~=,~,,~ I IL--'---i,~ ~VV~'~,Ua ii--i- ~ JobNo. 0450-87748 Sidetrack No. Page 1 · -= [I,r~ -=1 ::(--:'! Company UNOCAL Rig Contractor & No. Nabors Drilling - #156 Field GRANITE POINT FIELD / Well Name & No. GRANITE POINT PLATFORM/GP-52 Survey Section Name Definitive Survey BHI Rep. DUNN, YOUNG, MAPES WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -2421.24 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS[- Target Description Target Coord. ENV Slot Coord. E/W 1302.77 Magn. Declination 22.090 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build\Walk\DL per: 100ft[~ 30mCI 10m~ Vert. Sec. Azim. 155,22 Magn. to Map Corr. 22.090 Map North to: OTHER i i SURVEY DATA -I Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool - Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) __. 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 08-AUG-97 RGSS 90.00 0.36 139.20 90.00 90.00 0.27 -0.21 0.18 0.40 0.40 08-AUG-97 RGSS 180.00 0.46 190.80 90.00 180.00 0.84 -0.78 0.30 0.41 0.11 08-AUG-97 RGSS 264.00 0.24 21.40 84.00 264.00 0.99 -0.95 0.30 0.83 -0.26 , 08-AUG-97 RGSS 382.00 0.31 224.10 118.00 382.00 0.93 -0.95 0.17 0.46 0.06 ' 08-AUG-97 RGSS 443.00 0.65 187.20 61.00 442.99 1.29 -1.41 0.01 0.73 0.56 08-AUG-97 RGSS 531.00 3.25 160.60 88.00 530.94 4.19 -4.26 0.78 3.05 2.95 08-AUG-97 RGSS 591.00 3.55 160.60 60.00 590.83 7.74 -7.62 1.96 0.50 0.50 09-AUG-97 RGSS 668.00 2.15 144.70 77.00 667.73 11.53 -11.04 3.59 2.07 -1.82 09-AUG-97 RGSS 678.00 1.84 137.60 10.00 677.73 11.87 -11.32 3.80 3.96 -3.10 09-AUG-97 RGSS 767.00 0.54 85.30 89.00 766.71 13.37 -12.34 5.19 1.76 -1.46 -- 09-AUG-97 RGSS 887.00 1.38 49.80 120.00 886.69 13.18 -11.36 6.85 0.83 0.70 __ 09-AUG-97 RGSS 1076.00 0.50 143.70 189.00 1075.67 13.39 -10.55 9.08 0.79 -0.47 09-AUG-97 RGSS 1122.00 0.30 145.00 46.00 1121.67 13.70 -10.81 9.27 0.44 -0.43 Projected Data - NO SURVEY -- -- -- · Unocal Corporation .... Agricultural Products 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOr. ALe July 9, 1997 AOGCC Attn: Mr. Robert Crandall 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Crandall: This letter is in reference to UNOCAL's previous requests for a variance from Article 1 20 AAC25.050 Deviation--concerning survey frequency. AOGCC Regulation Article 1 20 AAC25.050 requires surveys to be taken at least 100 ft apart while drilling Granite Point #52 (Permit # 96-0045). Since the well will be vertical down to 1,200 ft (MD), we like to begin surveying at the conductor shoe, 294 ft (MD), and then survey 200 ft apart from 294 ft (MD) to 1,200 t~ (MD). We are then requesting a variance; so that we can survey at least 500 ff apart during the three tangent sections. The first tangent section will start at 1,800 ff (MD) and will end at 3,010 ft (MD). The section tangent section will start ~ 5,000 ft (MD) and will end at 12,309 ft (MD). The third and final tangent section will start ~ 12,875 ft (MD) to 15,503 ft (MD). The proposals listed above are in reference to the Proposed AOGCC Regulations (see page 29 Dated 10/4/96). We thank you for the opportunity to submit this proposal and will be happy to answer any of your questions. Please contact Mitchell Damm ~ 263-7679 if further details are required. Sincerely, Dale Haines Drilling Manager mwd , UL 23 199T Alaska 0il .& Gas Cons. Co.m~SS: gnola0_ra[ta STATE OF ALASKA ALASKA O,,_ AND GAS CONSERVATION UOMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: . Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: x 114.75 RKB (MLLW) feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Granite Point Field 4. Location of well at surface Granite Point Platform, Slot #4, Conductor #3 8. Well number 2428' FNL, 1298' FWL, Sec. 13, T10N, R12W, SM GP #52 At top of productive interval 10,500' 9. Permit number 1900' FNL, 1825' FEL, Sec. 24, TION, R12W, SM ~ ~' At effective depth 10. APl number At total depth 14,672' 11. Field/Pool 600' FSL, 580' FEL, Sec 24, TION, R12W Granite Point Field/Middle Kenai "C" Sands 12. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 247' 26" Driven 294' RKB Surface Intermediate Production Liner Perforation depth: measured OR!OiNAL true vertical Tubing (size, grade, and measured depth) Alaska 0il & Gas Cons, Packers and SSSV (type and measured depth) Change of bottom hole location. Anchorage 13. Attachements Description summary of proposal: x Detailed operations program: BOP sketch: Directional Survey X 14. Estimated date for commencing operation 15. Status of well classification as: August 1, 1997 16. If proposal well verbally approved: Oil: x Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: Dale Haines //,)~ ~.. ¢~1 ~ Title: Drilling Manager Date: 7/15/97 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval No. Plug integrity.__ BOP Test Location clearance~_ /.~ / '1J ~'-¢'"""- / Mechanical Integrity Tes~.e_9~ Subsequent form required 10- ~, 7 ~Z)/,-..~_.¢,-o ~/¢",,",'~7,..~ Approved by order of the Commllssionor Commissioner Datoq - LCorm IO-dOR Rc_v OR/1R/RR SUBMIT IN 1 RIPLI ATE -~-- STATE OF ALASKA ' ' ALASKA Om-AND GAS CONSERVATION L, OMMISSION APPLICATION FOR SUNDRY APPROVALS Unocal has changed the directional program of Granite Point #52. Please see the attachments that shows the new directional In addition, the 9-5/8", 7" & 5" (was changed from 4 1/2") casing measured depths have changed as follows: 9-5/8" Old Measured Depth New Measured Depth Old True Vertical Depth New True Vertical Depth 2,700' 4,500' 2,699' 4,397' 7" Shoe Old Measured Depth New Measured Depth Old True Vertical Depth New True Vertical Depth 11,395' 12,309' 10,165' 10,615' 5" Shoe Old Measured Depth New Measured Depth Old True Vertical Depth New True Vertical Depth 14,357' 15,503' 10,965' 11,515' If you have questions, please call Mitch Damm @ 907-263-7679. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE UNOCALe RKB = 115'; 43.44' Rig Floor to Wellhead Kvaerner SMS Wellhead 6 TOL @ 11,300' 7 8 GRANITE POINT PLATFORM WELL # 52 PROPOSED COMPLETION: CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 33" Outside conductor 47 229 26" Inside Conductor 47 294 13-3/8 68 K-55 BTC 47 1,100 9-5/8 47 L-80 BTC 46 73 9-5/8 53.5 P-110 BTC 73 4,500 7" 29 P-110 TKC-BTC 45 6,000 7" 29 L-80 TKC-BTC 6,000 12,309 5" 15 L-80 SC-KC-BTC 11,900 15,503 Baker 5" HMC liner hanger @ 11,300' 3-1/2" 9.2 L-80 SC BTC 44 11,920 JEWELRY DETAIL NO. ITEM DEPTH Kvaemer Tubing Hanger 44' (AB TC-4S Up X STD VAM DWN) 3.6' STD VAM x Buttress Pup JT HES XXO Safety Valve Landing 300' Nipple (ID = 2.813") McMurry-MACCO SMO-1 Gas Lilt Mandrels with 1-1/2" Valves: HES Seal Assembly with Nitrile/Flourel molded seals HES Packer HES "X" Nipple ID = 2.813" Wireline Muleshoe Re-entry Guide C-5 SAND PERFORATION DATA TOP. BTM ZONE SPF DATE COMMENTS 12,399 15,503 C-5 6 TCP PDTD = 14,590 MAX HOLE ANGLE = 77° @ 12,875' O:~DRILLING\SCHEMATIC\GP\GPP~Gp52 prop 3.doc REVISED: 7/15/97 DRAWN B Y: MWD 1997 GRANI2'2 POINT DRILL, NG PROGR, AM C-5 STRUCTURE MAP Plot Reference is GP52 Version ~8. Coordinates ore in feet reference sial jl4-3, j True Vertical Oepths~ore reference RKB (Rig: ~156). 60O 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 960O 10200 10800 11400 12000 ,L 26 Conductor J,L 13 3/8 Casing Pt Begin O'nl Nudge 1.00 End Anqle Build Beqin Angle Orop 1.00 End D'nl Nudge KOP 2.50 7.50 12.50 17.50 22.50 DLS: 2.50 deg per 100 ft 27.50 32.50 TANGENT ANGLE 37.24 DEG UNOCAL Structure : GRANITE POINT Platform Well : GP52 Field : Granite Point Field Location : Cook Inlet, Alaska UNOCAL ) WELL PROFILE DATA Point MO Inc Oir Tva North Tie on 0.00 0.00 155.47 0.00 0.00 End of Hold 1200.00 0.00 155.47 1200.00 0.00 End of Build 1400.00 2.00 155.47 1399.96 -3.18 End of Hold 1600.00 2.00 155.47 1599.84 -9.52 End of Drop/Turn 1800.00 0.00 0.00 17~9.80 -12.70 KOP 3010.54 0.00 155.47 3010.54 -12.70 End of Build 4500.00 37.24 155.47 4397.14 -457.72 Target GP52 C5 Enter12509.97 37.24 155.47 10615.00 -4736.90 End of Build/Turn 12875.74 76,84 155.67 10916,73 -5160.62 T.D. & Torqe[ 6P52 TO R 15503.54 76.84 155.67 11515.00 -7492.11 East V. Sect Oeg/lO0i 0.00 0.00 0.00 0.00 0.00 0.00 1.45 3.49 1.ooJ 4.35 10.47 o.ool 5.80 13.96 1.ooi 5.80 13.96 0.00I 199.80 481.16 2.50I 2162.15 5207.05 0.00 2554.45 5672.34 7.00 5408.75 8231.11 0.00 East (feet) -> 800 O 800 1600 2400 3200 4000 ,~, ~ L £ :5 1997 Alaska Oil & Gas Cons. 6orm~ Anch0raga 1' i I i i 600 0 6OO EOC - 9 5/8 Casing Pt 155.47 AZIMUTH 8 3i' (TO ***Plane of Proposal*** 800 (~KOP. osing Pt ~- 1600 2400 3200 4000 TARGET / 7 Casing Pt GP52 C5 Entry Rvsd 11--Jun-g7'~'~v., - ~ ;- 4800 F ~- 5600 i 6400 T~ ~\~ ! 72oo GP52 TD Rvsd 11 -Jun-97 F ~- 8000 L 8OO T^,¢~ /7 Cos,ng ~ ~ ,,-e:-~ TARGET ANGLE GP52 C5 Entry Rvsd l i-Jun-97 v ~ ? 6. 8 4 D E G GP52 ~ TO ! i i i i i i i i J Ii i ii i ii , i 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 Verficol Secfion (feel) -> Azimuth 155.47 with reference 0.00 N, 0.00 E from slot //4-,3 7200 7800 8400 Created by jones Date platted : 7-Jul-97 iPlot Reference ;s GP52 Version ~8. ( ) Caardinat ..... in feet ret ....... Iai ~4-3. t )Tr',Je Vertical 0epths ore reference RK8 (Rig: ~156).~ --- Baker Hughes INTEQ --- UNOCA Structure : GRANITE POINT Platform Well : CP52 Field : Granite Paint Field Location : Cook Inlet, Alaska TRUE NORTH 350 1 340 0 )o q?i 2000 170' 1700 500 UNOCAL ) 300 290 ~' 7O 8O 280 soo 270 1~ ~ ' + 90 260 25O 240 ~30 220 140 210 150 1400 2O 1 60 180 0 II 110 lO0 150 Nor~oi Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference We!l Created by jones Dote plotted : 7-dui-g7 Plot Reference [s GP52 Ver31an .~8. Coordinates are ;n feet reference slot {4-3. True Vertical Depths are reference RKB (Rig: i --- Baker Hughes INT£G --- 41 O0 320 UNOCAL Structure : GRANITE POINT Platform Well : GP52 Field : Granite Paint Field Location : Cook Inlet, Alaska % TRUE NORTH 0 10 340 2goo 20 3500 5O 6200 4O UNOCAL ) 300 6O 290 7O 280 27O ~000 2500 8O 9O 260 100 250 110 240 ,- 200( / // ,..,....,'" 220 2000 2OOO 1 50 200 1 60 190 i 170 DO0 140 150 120 Normoi Plone Trovelling Cylinder - Fee[ All depths shown ore Meosured depths on Reference Well Created by jones ,T~a Ve~[c~l 0epths ~re re~erence RKB --- Baker Hughe~ INTEQ ---- r- UNOCAL Structure : GRANITE POINT Platform Well : GP§2 jr e d : Granite Point Field Location : Cook Inlet, Alaska Eosf (feet) -> V UNOCAL~) so~,°, 4~o , ~,o ,_2,o.~ ,,o , ? , ? , ~,o , ~,o, to, ~,o , ~,o, ho, ~,o' ~,o, ,?O~o '~~ ~¢ "~o~~~°° 80 ~ 1500 'X ( 80 .,oJ /, ' '""5,~oo 140 140 50 40 30 20 10 0 10 20 50 40 50 60 7B 80 90 1 OD East (feet) -> 0 Created by jones I Date plotted : 7-Jul-97 P~ot Reference is GP52 Version ~. --- Bcker Hughes iNTEG --- ~ 80 120 160 2oo 240 280 .320 360 440 UNOCAL Structure : GRANITE POINT Platform Well : GP52 Field : Granite Paint Field Location : Cook Inlet, Alaska 0 40 80 120 160 2300 \,,,, ~t700 250O 2900 UNOCAL ) 1700 1900 East (feet) -> 200 240 280 320 360 400 440 480 520 i I i i i ~ i i [ i .i I i i i i i i 80 2300 ~ I 240 300 280 2500 320 2700 3~0 4300 \ 400 ,, 2900 \,,\ ~ 440 ' 5100 2100 I 48o 4 ,/ i 2300 520 ~ 560 i 6OO I 250O 640 ~ 680 720 760 - 8oo 840 - 410 I 3300 4~0 \\ \% 4500 *\\\ ",,\ ",,,, "\·\ 1 O0 \\ ~ 8*0 ' ~ ' '' 120 160 200 2'%0 280 East (feet) -> 320 '~ 4900 · \ i i i 360 400 3300 3500 I i i 480 ? 520 I v , 560 - 68O 720 76O 800 L 840 r Created by jones Dote platted : 7-Ju1-97 J Plot Reference is GP52 Version #8. Coord[no[es are in fee[ reference slot ~4--3. JTrue Vertical Depths are reference RKB (Rig: j~156),J --- Baker Hughes INTI;Q --- J UNOCAL UNOCAL ) 5300 2600 / \ 7400 5600 '~ 7700 28oo- / 5600 I \', ~8ooo~ ~oo \~\ 8ooo 3000 ! \ 5900 200 '\ 6 '~,8300 3200 \ 3200 6200 '~ 8600 3400 " 3~00 3600 ~ 6600 \ ~ 3600 -J '\' "h 9200 3800 7 3800 6800 "",,, I oo 80 'q 9500 4000 ,,, 4000 71 O0 O0 '~,, /883 '~ 9800 4200 4200 q O0 '\, 7400 /~'86 '\' 4400 O0 '~,10100 ~400 \ 4800 / ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 4600 600 400 200 O 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 East (feet) -> 1000 1200 40O 1600 1800 2000 I2200 2400 2600 2800 t ' 3000 East (feet) -> 600 400 200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 i i ii, i i i _i i i i i ~ i i i i i i i f i j i i I ! i i 8oo ,-:7 ; 4'~/]0 / ~ 5000'~ %4700 ~ 9800 ~ ~ / /,~, ~oo~ ~oo ~ , ~ooo / / 5200 I 2600% ', ' / / 3500 / ~ ',,, ~53oo ,oooq ,' / ~ X ~3o~ ~~oo ~1~oo ~oo~ ~ooX ',, ~~oo ~ t ~ ~2ook 5~oo'~~~5oo , oo 4100 59 0 ,~oo 4 ~ ~ .~Z, ~ 8000 ~ooj ~oo .oo:",¢,~oo ~ooo I / ~oo ~oo,, ~/~,, ~oo / 4,00 ,o~~ 6800~ ~ '~ 71 00 2400 1 ~ 7 fi000 \ 6800/ XX 7400 / 5zoo 7100d Structure : GRANITE POINT Platform Well : GP52 Field : Granite Point Field Location : Cook Inlet, Alaska 8C0 UNOCAL GP32~ITE POINT Platform GP52 slot #4-3 Granite Point Field Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : GP52 Version #8 Our ref : prop2064 License : Date printed : 7-Jul-97 Date created : 12-Feb-97 Last revised : 7-Jul-97 Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 57 52.745,w151 20 20.066 Slot location is n60 57 28.902,w151 19 53.682 Slot Grid coordinates are N 2544509.919, E 263335.150 Slot local coordinates are 2421.24 S 1302.77 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North UNOCAL GRANITE POINT Platform, GP52 Granite Point Field, Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : GP52 Version #8 Last revised : 7-Jul-97 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect 0.00 0.00 155.47 0.00 0.00 N 0.00 E 0.00 500.00 0.00 155.47 500.00 0.00 N 0.00 E 0.00 1000.00 0.00 155.47 1000.00 0.00 N 0.00 E 0.00 1200.00 0.00 155.47 1200.00 0.00 N 0.00 E 0.00 1300.00 1.00 155.47 1299.99 0.79 S 0.36 E 1.00 0.00 0.00 0.00 13 3/8" Casing Pt 0.00 Begin D'nl Nudge 0.87 1400.00 2.00 155.47 1399.96 3.18 S 1.45 E 1.00 1500.00 2.00 155.47 1499.90 6.35 S 2.90 E 0.00 1600.00 2.00 155.47 1599.84 9.52 S 4.35 E 0.00 1700.00 1.00 155.47 1699.80 11.91 S 5.43 E 1.00 1800.00 0.00 0.00 1799.80 12.70 S 5.80 E 1.00 3.49 End Angle Build 6.98 10.47 Begin Angle Drop 13.09 13.96 End D'nl Nudge 1900.00 0.00 155.47 1899.80 12.70 S 5.80 E 0.00 2000.00 0.00 155.47 1999.80 12.70 S 5.80 E 0.00 2100.00 0,00 155.47 2099.80 12.70 S 5.80 E 0.00 2200.00 0.00 155.47 2199.80 12.70 S 5.80 E 0.00 2300.00 0.00 155.47 2299.80 12.70 S 5.80 E 0.00 13.96 13.96 13.96 13.96 13.96 2400.00 0.00 155.47 2399.80 12.70 S 5.80 E 0.00 2500.00 0.00 155.47 2499.80 12.70 S 5.80 E 0.00 2600.00 0.00 155.47 2599.80 12.70 S 5.80 E 0.00 2700.00 0.00 155.47 2699.80 12.70 S 5.80 E 0.00 2800.00 0,00 155.47 2799.80 12.70 S 5.80 E 0.00 13.96 13.96 13.96 13.96 13.96 2900.00 0.00 155.47 2899.80 12.70 S 5.80 E 0.00 3000.00 0.00 155.47 2999.80 12.70 S 5.80 E 0.00 3010.54 0.00 155.47 3010.34 12.70 S 5.80 E 0.00 3110.54 2.50 155.47 3110.31 14.68 S 6.70 E 2.50 3210.54 5.00 155.47 3210.08 20,63 S 9.42 E 2.50 13.96 13.96 13.96 KOP 16.14 22.68 3310.54 7.50 155.47 3309.48 30.54 S 13.94 E 2.50 3410.54 10.00 155.47 3408.31 44.37 S 20.25 E 2.50 3510,54 12.50 155.47 3506.38 62.12 S 28.35 E 2.50 3610,54 15.00 155.47 3603.51 83.74 S 38.22 E 2.50 3710.54 17.50 155.47 3699.50 109.20 S 49.84 E 2.50 33.57 48.78 68.29 92.05 120.03 3810.54 20.00 155.47 3794.19 138.44 S 63.19 E 2.50 3910.54 22.50 155.47 3887.38 171.40 S 78.24 E 2.50 4010.54 25.00 155.47 3978.91 208.04 S 94.96 E 2.50 4110.54 27.50 155.47 4068.59 248.27 S 113.32 E 2.50 4210.54 30.00 155.47 4156.25 292.02 S 133.29 E 2.50 152.17 188.42 228.69 272.91 321.01 4310.54 32.50 155.47 4241.74 339.21 S 154.83 E 2.50 4410.54 35,00 155.47 4324.88 389.75 S 177.90 E 2.50 4500.00 37.24 155.47 4397.14 437.72 S 199.80 E 2.50 5000.00 37.24 155.47 4795.21 712.96 S 325.43 E 0.00 5500.00 37.24 155.47 5193.28 988.19 S 451.06 E 0.00 372.88 428.43 481.16 EOC - 9 5/8" Casing Pt 783.72 1086.27 6000.00 37.24 155.47 5591.35 1263.43 S 576.69 E 0.00 1388.82 6500.00 37,24 155.47 5989.43 1538.67 S 702.32 E 0.00 1691.38 7000.00 37.24 155,47 6387.50 1813.90 S 827.95 E 0.00 1993.93 7500.00 37.24 155,47 6785.57 2089.14 S 953.59 E 0.00 2296.48 8000.00 37.24 155.47 7183.64 2364.38 S 1079.22 E 0.00 2599.04 8500.00 37.24 155.47 7581.72 2639.62 S 1204.85 E 0.00 2901.59 9000.00 37.24 155.47 7979.79 2914.85 S 1330.48 E 0.00 3204.14 9500.00 37.24 155.47 8377.86 3190.09 S 1456.11 E 0.00 3506.70 10000.00 37.24 155.47 8775.93 3465.33 S 1581.74 E 0.00 3809.25 10500.00 37.24 155.47 9174.00 3740.56 S 1707.38 E 0.00 4111.80 All data is in feet unless otherwise stated. Coordinates from slot #4-3 and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Bottom hole distance is 8231.11 on azimuth 155.54 degrees from wellhead. Total Dogleg for wellpath is 80.84 degrees. Vertical section is from wellhead on azimuth 155.47 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Platform, GP52 Granite Point Field, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES PROPOSAL LISTING Page 2 Your ref : GP52 Version #8 Last revised : 7-Jul-97 Dogleg Vert Deg/100ft Sect 11000.00 37.24 155.47 9572.08 4015.80 S 1833.01 E 0.00 4414.36 11500.00 37.24 155.47 9970.15 4291.04 S 1958.64 E 0.00 4716.91 12000.00 37.24 155.47 10368.22 4566.27 S 2084.27 E 0.00 5019.47 12309.97 37.24 155.47 10615.00 4736.90 S 2162.15 E 0.00 5207.03 12400.00 43.54 155.51 10683.54 4789.96 S 2186.34 E 7.00 5265.34 GP52 C5 Entry Rvsd 11-Jun-97 12500.00 50.54 155.56 10751.65 4856.53 S 2216.63 E 7.00 5338.47 12600.00 57.54 155.59 10810.34 4930.18 S 2250.07 E 7.00 5419.36 12700.00 64.54 155.62 10858.73 5009.81 S 2286.18 E 7.00 5506.80 12800.00 71.54 155.65 10896.10 5094.25 S 2324.42 E 7.00 5599.49 12875.74 76.84 155.67 10916.73 5160.62 S 2354.45 E 7.00 5672.34 Final EOC 13000.00 76.84 155.67 10945.02 5270.87 S 2404.30 E 0.00 5793.33 13500.00 76.84 155.67 11058.86 5714.49 S 2604.91 E 0.00 6280.20 14000.00 76.84 155.67 11172.69 6158.11 S 2805.51 E 0.00 6767.06 14500.00 76.84 155.67 11286.53 6601.73 S 3006.12 E 0.00 7253.93 15000.00 76.84 155.67 11400.36 7045.35 S 3206.72 E 0.00 7740.80 15500.00 76.84 155.67 11514.19 7488.97 S 3407.33 E 0.00 8227.66 15503.54 76.84 155.67 11515.00 7492.11 S 3408.75 E 0.00 8231.11 GP52 TD Rvsd 11-Jun-97 All data is in feet unless otherwise stated. Coordinates from slot #4-3 and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Bottom hole distance is 8231.11 on azimuth 155.54 degrees from wellhead. Total Dogleg for wellpath is 80.84 degrees. Vertical section is from wellhead on azimuth 155.47 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POIA"r P1atform, GP52 Granite Point Field, Cook Inlet, Alaska PROPOSAL LISTING Page 3 Your ref : GP52 Version #8 Last revised : 7-Jul-97 Comments in wellpath -MD TVD Rectangular Coords. Comment 1000.00 1000.00 0.00 N 0.00 E 13 3/8" Casing Pt 1200.00 1200.00 0.00 N 0.00 E Begin D'nl Nudge 1400.00 1399.96 3.18 S 1.45 E End Angle Build 1600.00 1599.84 9.52 S 4.35 E Begin Angle Drop 1800.00 1799.80 12.70 S 5.80 E End D'nl Nudge 3010.54 3010.34 12.70 S 5.80 E KOP 4500.00 4397.14 437.72 S 199.80 E EOC - 9 5/8" Casing Pt 12309.97 10615.00 4736.90 S 2162.15 E GP52 C5 Entry Rvsd 11-Jun-97 12875.74 10916.73 5160.62 S 2354.45 E Final EOC 15503.54 11515.00 7492.11 S 3408.75 E ~P52 TD Rvsd 11-Jun-97 Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 294.00 294.00 0.00N 0.00E 26" Conductor 0.00 0.00 0.00N 0.00E 1000.00 1000.00 0.00N 0.00E 13 3/8" Casing 0.00 0.00 0.00N 0.00E 4500.00 4397.14 437.72S 199.80E 9 5/8" Casing 0.00 0.00 0.00N 0.00E 12309.97 10615.00 4736.90S 2162.15E 7" Casing 0.00 0.00 0.00N 0.00E 15503.54 11515.00 7492.11S 3408.75E 5 1/2" Casing Targets associated with this wellpath ..... Target name Geographic Location T.V.D. Rectangular Coordinates Revised GP52 C5 Entry Rvsd i 265400.000,2539730.000,0.0000 10615.00 4736.90S 2162.15E 12-Feb-97 GP52 TD Rvsd 11-Jun- 266590.000,2536950.000,0.0000 11515.00 7492.11S 3408.75E 12-Feb-97 UNOCAL GRANITE POINT Platform, GP52 Granite Point Field, Cook I~let, Alaska PROPOSAL LISTING Page 1 Your ref : GP52 Version #8 Last revised : 7-Jul-97 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/100ft Sect 0.00 0.00 155.47 0.00 2421.24 S 1302.77 E 0.00 500.00 0.00 155.47 500.00 2421.24 S 1302.77 E 0.00 1000.00 0.00 155.47 1000.00 2421.24 S 1302.77 E 0.00 1200.00 0.00 155.47 1200.00 2421.24 S 1302.77 E 0.00 1300.00 1.00 155.47 1299.99 2422.03 S 1303.13 E 1.00 0.00 0.00 0.00 13 3/8" Casing Pt 0.00 Begin D'nl Nudge 0.87 1400.00 2.00 155.47 1399.96 2424.42 S 1304.22 E 1.00 1500.00 2.00 155.47 1499.90 2427.59 S 1305.67 E 0.00 1600.00 2.00 155.47 1599.84 2430.76 S 1307.12 E 0.00 1700.00 1.00 155.47 1699.80 2433.15 S 1308.20 E 1.00 1800.00 0.00 0.00 1799.80 2433.94 S 1308.57 E 1.00 3.49 End Angle Build 6.98 10.47 Begin Angle Drop 13.09 13.96 End D'nl Nudge 1900.00 0.00 155.47 1899.80 2433.94 S 1308.57 E 0.00 2000.00 0.00 155.47 1999.80 2433.94 S 1308.57 E 0.00 2100.00 0.00 155.47 2099.80 2433.94 S 1308.57 E 0.00 2200.00 0.00 155.47 2199.80 2433.94 S 1308.57 E 0.00 2300.00 0.00 155.47 2299.80 2433.94 S 1308.57 E 0,00 13.96 13.96 13.96 13.96 13.96 2400.00 0.00 155.47 2399.80 2433.94 S 1308.57 E 0,00 2500.00 0.00 155.47 2499.80 2433.94 S 1308.57 E 0.00 2600.00 0.00 155.47 2599.80 2433.94 S 1308.57 E 0.00 2700.00 0.00 155.47 2699.80 2433.94 S 1308.57 E 0.00 2800.00 0.00 155.47 2799.80 2433.94 S 1308.57 E 0.00 13.96 13.96 13.96 13.96 13.96 2900.00 0.00 155.47 2899.80 2433.94 S 1308.57 E 0.00 3000.00 0.00 155.47 2999.80 2433.94 S 1308.57 E 0.00 3010.54 0.00 155.47 3010.34 2433.94 S 1308.57 E 0.00 3110.54 2.50 155.47 3110.31 2435.92 S 1309.47 E 2.50 3210.54 5.00 155.47 3210.08 2441.87 S 1312.19 E 2.50 13 13 13 16 22 .96 .96 .96 KOP .14 .68 3310.54 7.50 155.47 3309.48 2451.78 S 1316.71 E 2.50 3410.54 10.00 155.47 3408.31 2465.61 S 1323.02 E 2.50 3510.54 12.50 155.47 3506.38 2483.36 S 1331.12 E 2.50 3610.54 15.00 155.47 3603.51 2504.98 S 1340.99 E 2.50 3710.54 17.50 155.47 3699.50 2530.44 S 1352.61 E 2.50 33 48 68 92 120 .57 .78 .29 .05 .03 3810.54 20.00 155.47 3794.19 2559.68 S 1365.96 E 2.50 3910.54 22.50 155.47 3887.38 2592.64 S 1381.01 E 2.50 4010.54 25.00 155.47 3978.91 2629.28 S 1397.73 E 2.50 4110.54 27.50 155.47 4068.59 2669.51 S 1416.09 E 2.50 4210.54 30.00 155.47 4156.25 2713.26 S 1436.06 E 2.50 152.17 188.42 228.69 272.91 321.01 4310.54 32.50 155,47 4241.74 2760.45 S 1457.60 E 4410.54 35.00 155,47 4324.88 2810.99 S 1480.67 E 4500.00 37.24 155.47 4397.14 2858.96 S 1502.57 E 5000.00 37.24 155.47 4795.21 3134.20 S 1628.20 E 5500.00 37.24 155,47 5193.28 3409.43 S 1753.83 E 2.50 372.88 2.50 428.43 2.50 481.16 EOC - 9 5/8" Casing Pt 0.00 783.72 0.00 1086.27 6000.00 37.24 155.47 5591.35 3684.67 S 1879.46 E 0.00 1388.82 6500.00 37.24 155.47 5989.43 3959.91 S 2005.09 E 0.00 1691.38 7000.00 37.24 155.47 6387.50 4235.14 S 2130.72 E 0.00 1993.93 7500.00 37.24 155.47 6785.57 4510.38 S 2256.35 E 0.00 2296.48 8000.00 37.24 155.47 7183.64 4785.62 S 2381.99 E 0.00 2599.04 8500.00 37.24 155.47 7581.72 5060.86 S 2507.62 E 0.00 2901.59 9000.00 37.24 155.47 7979.79 5336.09 S 2633.25 E 0.00 3204.14 9500.00 37.24 155.47 8377.86 5611.33 S 2758.88 E 0.00 3506.70 10000.00 37.24 155.47 8775.93 5886.57 S 2884.51 E 0.00 3809.25 10500.00 37.24 155.47 9174.00 6161.80 S 3010.14 E 0.00 4111.80 All data is in feet unless otherwise stated. Coordinates from NW Corner of Sec. 13, T10N, R12W SM and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Bottom hole distance is 8231.11 on azimuth 155.54 degrees from wellhead. Total Dogleg for wellpath is 80.84 degrees. Vertical section is from wellhead on azimuth 155.47 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Platform, GP52 Granite Point Field, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S PROPOSAL LISTING Page 2 Your ref : GP52 Version #8 Last revised : 7-Jul-97 Dogleg Vert Deg/100ft Sect 11000.00 37.24 155.47 9572.08 6437.04 S 3135.78 E 0.00 4414.36 11500.00 37.24 155.47 9970.15 6712.28 S 3261.41 E 0.00 4716.91 12000.00 37.24 155.47 10368.22 6987.51 S 3387.04 E 0.00 5019.47 12309.97 37.24 155.47 10615.00 7158.14 S 3464.92 E 0.00 5207.03 GP52 C5 Entry Rvsd il-Jun-97 12400.00 43.54 155.51 10683.54 7211.20 S 3489.11 E 7.00 5265.34 12500.00 50.54 155.56 10751.65 7277.77 S 3519.39 E 7.00 5338.47 12600.00 57.54 155.59 10810.34 7351.42 S 3552.84 E 7.00 5419.36 12700.00 64.54 155.62 10858.73 7431.05 S 3588.95 E 7.00 5506.80 12800.00 71.54 155.65 10896.10 7515.49 S 3627.19 E 7.00 5599.49 12875.74 76.84 155.67 10916.73 7581.86 S 3657.22 E 7.00 5672.34 Final EOC 13000.00 76.84 155.67 10945.02 7692.11 S 3707.07 E 0.00 5793.33 13500.00 76.84 155.67 11058.86 8135.73 S 3907.68 E 0.00 6280.20 14000.00 76.84 155.67 11172.69 8579.35 S 4108.28 E 0.00 6767.06 14500.00 76.84 155.67 11286.53 9022.97 S 4308.89 E 0.00 7253.93 15000.00 76.84 155.67 11400.36 9466.59 S 4509.49 E 0.00 7740.80 15500.00 76.84 155.67 11514.19 9910.21 S 4710.10 E 0.00 8227.66 15503.54 76.84 155.67 11515.00 9913.35 S 4711.52 E 0.00 8231.11 GP52 TD Rvsd il-Jun-97 All data is in feet unless otherwise stated. Coordinates from NW Corner of Sec. 13, T10N, R12W SM and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Bottom hole distance is 8231.11 on azimuth 155.54 degrees from wellhead. Total Dogleg for wellpath is 80.84 degrees. Vertical section is from wellhead on azimuth 155.47 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Platform, GP52 Granite Point Field, Cook Inlet, Alaska PROPOSAL LISTING Page 3 Your ref : GP52 Version #8 Last revised : 7-Jul-97 Comments in we11path MD TVD Rectangular Coords. Comment 1000.00 1000.00 2421.24 S 1200.00 1200.00 2421.24 S 1400.00 1399.96 2424.42 S 1600.00 1599.84 2430.76 S 1800.00 1799.80 2433.94 S 3010.54 3010.34 2433.94 S 4500.00 4397.14 2858.96 S 12309.97 10615.00 7158.14 S 12875.74 10916.73 7581.86 S 15503.54 11515.00 9913.35 S 1302.77 E 13 3/8" Casing Pt 1302.77 E Begin D'nl Nudge 1304.22 E End Angle Build 1307.12 E Begin Angle Drop 1308.57 E End D'nl Nudge 1308.57 E KOP 1502.57 E EOC - 9 5/8" Casing Pt 3464.92 E GP52 C5 Entry Rvsd 11-Jun-97 3657.22 E Final EOC 4711.52 E GP52 TD Rvsd 11-Jun-97 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 2421.24S 1302.77E 294.00 294.00 2421.24S 1302.77E 26" Conductor 0.00 0.00 2421.24S 1302.77E 1000.00 1000.00 2421.24S 1302.77E 13 3/8" Casing 0.00 0.00 2421.24S 1302.77E 4500.00 4397.14 2858.96S 1502.57E 9 5/8" Casing 0.00 0.00 2421.24S 1302.77E 12309.97 10615.00 7158.14S 3464.92E 7" Casing 0.00 0.00 2421.24S 1302.77E 15503.54 11515.00 9913.35S 4711.52E 5 1/2" Casing Targets associated with this wellpath Target n~me Geographic Location T.V.D. Rectangular Coordinates Revised GP52 C5 Entry Rvsd I 265400.000,2539730.000,0.0000 10615.00 7158.14S 3464.92E 12-Feb-97 GP52 TD Rvsd 11-Jun- 266590.000,2536950.000,0.0000 11515.00 9913.35S 4711.52E 12-Feb-97 UNOCAL GRANITE POINT P1atform, GP52 Granite Point Field, Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : GP52 Version #8 Last revised : 7-Jul-97 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 00 R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 155.47 0.00 0.00N 0.00E 0.00 0.00 263335.15 2544509.92 500.00 0.00 155.47 500.00 0.00N 0.00E 0.00 0.00 263335.15 2544509.92 1000.00 0.00 155.47 1000.00 0.00N 0.00E 0.00 0.00 263335.15 2544509.92 1200.00 0.00 155.47 1200.00 0.00N 0.00E 0.00 0.00 263335.15 2544509.92 1300.00 1.00 155.47 1299.99 0.79S 0.36E 1.00 0.87 263335.50 2544509.12 1400.00 2.00 155.47' 1399.96 3.18S 1.45E 1.00 3.49 263336.53 2544506.72 1500.00 2.00 155.47 1499.90 6.35S 2.90E 0.00 6.98 263337.92 2544503.51 1600.00 2.00 155.47 1599.84 9.52S 4.35E 0.00 10.47 263339.30 2544500.31 1700.00 1.00 155.47 1699.80 11.91S 5.43E 1.00 13.09 263340.34 2544497.90 1800.00 0.00 0.00 1799.80 12.70S 5.80E 1.00 13.96 263340.69 2544497.10 1900.00 0.00 155.47 1899.80 12.70S 5.80E 0.00 13.96 263340.69 2544497.10 2000.00 0.00 155.47 1999.80 12.70S 5.80E 0.00 13.96 263340.69 2544497.10 2100.00 0.00 155.47 2099.80 12.70S 5.80E 0.00 13.96 263340.69 2544497.10 2200.00 0.00 155.47 2199.80 12.70S 5.80E 0.00 13.96 263340.69 2544497.10 2300.00 0.00 155.47 2299.80 12.70S 5.80E 0.00 13.96 263340.69 2544497.10 2400.00 0.00 155.47 2399.80 12.70S 5.80E 0.00 13.96 263340.69 2544497.10 2500.00 0.00 155.47 2499.80 12.70S 5.80E 0.00 13.96 263340.69 2544497.10 2600.00 0.00 155.47 2599.80 12.70S 5.802 0.00 13.96 263340.69 2544497.10 2700.00 0.00 155.47 2699.80 12.70S 5.80E 0.00 13.96 263340.69 2544497.10 2800.00 0.00 155.47 2799.80 12.70S 5.80E 0.00 13.96 263340.69 2544497.10 2900.00 0.00 155.47 2899.80 12.70S 5.80E 0.00 13.96 263340.69 2544497.10 3000.00 0.00 155.47 2999.80 12.70S 5.80E 0.00 13.96 263340.69 2544497.10 3010.54 0.00 155.47 3010.34 12.70S 5.80E 0.00 13.96 263340.69 2544497.10 3110.54 2.50 155.47 3110.31 14.68S 6.702 2.50 16.14 263341.55 2544495.10 3210.54 ~.00 155.47 3210.08 20.63S 9.42E 2.50 22.68 263344.14 2544489.10 3310.54 7.50 155.47 3309.48 30.54S 13.94E 2.50 33.57 263348.46 2544479.10 3410.54 10.00 155.47 3408.31 44.37S 20.25E 2.50 48.78 263354.49 2544465.14 3510.54 12.50 155.47 3506.38 62.12S 28.35E 2.50 68.29 263362.23 2544447.23 3610.54 15.00 155.47 3603.51 83.74S 38.22E 2.50 92.05 263371.65 2544425.42 3710.54 17.50 155.47 3699.50 109.20S 49.84E 2.50 120o03 263382.75 2544399.73 3810.54 20.00 155.47 3794.19 138.44S 63.19E 2.50 152.17 263395.50 2544370.23 3910.54 22.50 155.47 3887.38 171.40S 78.24E 2.50 188.42 263409.87 2544336.96 4010.54 25.00 155.47 3978.91 208.04S 94.96E 2.50 228.69 263425.84 2544299.99 4110.54 27.50 155.47 4068.59 248.27S 113.32E 2.50 272.91 263443.37 2544259.39 4210.54 30.00 155.47 4156.25 292.02S 133.292 2.50 321.01 263462.45 2544215.24 4310.54 32.50 155.47 4241.74 339.21S 154.83E 2.50 372.88 263483.02 2544167.62 44.10.54 35.00 155.47 4324.88 389.75S 177.90E 2.50 428.43 263505.05 2544116.63 4500.00 37.24 155.47 4397.14 437.72S 199.80E 2.50 481.16 263525.96 2544068.22 5000.00 37.24 155.47 4795.21 712.96S 325.43E 0.00 783.72 263645.93 2543790.49 5500.00 37.24 155.47 5193.28 988.19S 451.06E 0.00 1086.27 263765.91 2543512.75 6000.00 37.24 155.47 5591.35 1263.43S 576.69E 0.00 1388.82 263885.89 2543235.02 6500.00 37.24 155.47 5989.43 1538.67S 702.32E 0.00 1691.38 264005.87 2542957.28 7000.00 37.24 155.47 6387.50 1813.90S 827.95E 0.00 1993.93 264125.84 2542679.54 7500.00 37.24 155.47 6785.57 2089.14S 953.592 0.00 2296.48 264245.82 2542401.81 8000.00 37.24 155.47 7183.64 2364.38S 1079.22E 0.00 2599.04 264365.80 2542124.07 8500.00 37.24 155.47 7581.72 2639.62S 1204.85E 0.00 2901.59 264485.78 2541846.33 9000.00 37.24 155.47 7979.79 2914.85S 1330.48E 0.00 3204.14 264605.76 2541568.60 9500.00 37.24 155.47 8377.86 3190.09S 1456.11E 0.00 3506.70 264725.73 2541290.86 10000.00 37.24 155.47 8775.93 3465.33S 1581.742 0.00 3809.25 264845.71 2541013.12 10500.00 37.24 155.47 9174.00 3740.56S 1707.38E 0.00 4111.80 264965.69 2540735.39 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #4-3 and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Bottom hole distance is 8231.11 on azimuth 155.54 degrees from wellhead. Total Dogleg for wellpath is 80.84 degrees. Vertical section is from wellhead on azimuth 155.47 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Platform, GP52 Granite Point Field, Cook Inlet, Alaska Measured Inclin Azimuth True Vert R E C T A N G Depth Degrees Degrees Depth C O 0 R D I N 11000.00 37.24 155.47 9572.08 4015.80S 11500.00 37.24 155.47 9970.15 4291.04S 12000.00 37.24 155.47 10368.22 4566.27S 12309.97 37.24 155.47 10615.00 4736.90S 12400.00 43.54 155.51 10683.54 4789.96S 12500.00 50.54 155.56 10751.65 4856.53S 12600.00 57.54 155.59 10810.34 4930.18S 12700.00 64,54 155.62 10858.73 5009.81S 12800.00 71.54 155.65 10896.10 5094.25S 12875.74 76.84 155.67 10916.73 5160.62S 13000.00 76.84 155.67 10945.02 5270,87S 13500.00 76.84 155.67 11058.86 5714.49S 14000.00 76.84 155.67 11172.69 6158.11S 14500.00 76.84 155.67 11286.53 6601.73S 15000.00 76.84 155.67 11400.36 7045.35S 15500.00 76.84 155.67 11514.19 7488.97S 15503.54 76.84 155.67 11515.00 7492.11S PROPOSAL LISTING Page 2 Your ref : GP52 Version #8 Last revised : 7-Jul-97 U L A R Dogleg Vert G R I D C O 0 R D S A T E S Deg/100ft Sect Easting Northing 1833.01E 0.00 4414.36 265085.67 2540457.65 1958.64E 0.00 4716.91 265205.64 2540179.92 2084.27E 0.00 5019.47 265325.62 2539902.18 2162.15E 0.00 5207.03 265400.00 2539730.00 2186.34E 7.00 5265.34 265423.10 2539676.47 2216.63E 7.00 5338.47 265452.02 2539609.29 2250.07E 7.00 5419.36 265483.95 2539534.98 2286.18E 7.00 5506.80 265518.42 2539454.62 2324.42E 7.00 5599.49 265554.93 2539369.43 2354.45E 7.00 5672.34 265583.59 2539302.46 2404.30E 0.00 5793.33 265631.18 2539191.22 2604.91E 0.00 6280.20 265822.67 2538743.61 2805.51E 0.00 6767.06 266014.17 2538296.00 3006.12E 0.00 7253.93 266205.66 2537848.39 3206.72E 0.00 7740.80 266397.15 2537400.78 3407.33E 0.00 8227.66 266588.65 2536953.17 3408.75E 0.00 8231.11 266590.00 2536950.00 Alaska Oil & Gas Cons. Anchorage All data in feet unless otherwise stated. Calculation uses minimu~ curvature method. Coordinates from slot #4-3 and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Bottom hole distance is 8231.11 on azimuth 155.54 degrees from wellhead. Total Dogleg for wellpath is 80.84 degrees. Vertical section is from wellhead on azimuth 155.47 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ UNOCA~ GRANITE POINT Platform, GP52 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 3 Your ref : GP52 Version #8 Last revised : 7-Jul-97 Comments in wellpath __ MD TVD Rectangular Coords. Comment 1000.00 1000.00 0.00N 1200.00 1200.00 0.00N 1400.00 1399.96 3.18S 1600.00 1599.84 9.52S 1800.00 1799.80 12.70S 3010.54 3010.34 12.70S 4500.00 4397.14 437.72S 12309.97 10615.00 4736.90S 12875.74 10916.73 5160.62S 15503.54 11515.00 7492.11S 0.00E 13 3/8" Casing Pt 0.00E Begin D'nl Nudge 1.45E End Angle Build 4.35E Begin Angle Drop 5.80E End D'nl Nudge 5.80E KOP 199.80E EOC - 9 5/8" Casing Pt 2162.15E GP52 C5 Entry Rvsd il-Jun-97 2354.45E Final EOC 3408.75E GP52 TD Rvsd 11-Jun-97 Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 294.00 294.00 0.00N 0.00E 26" Conductor 0.00 0.00 0.00N 0.00E 1000.00 1000.00 0.00N 0.00E 13 3/8" Casing 0.00 0.00 0.00N 0.00E 4500.00 4397.14 437.72S 199.80E 9 5/8" Casing 0.00 0.00 0.00N 0.00E 12309.97 10615.00 4736.90S 2162.15E 7" Casing 0.00 0.00 0.00N O.OOE 15503.54 11515.00 7492.11S 3408.75E 5 1/2" Casing Targets associated with this wellpath Target naz~e Geographic Location T.V.D. Rectangular Coordinates Revised GP52 C5 Entry Rvsd i 265400.000,2539730.000,0.0000 10615.00 4736.90S 2162.15E 12-Feb-97 GP52 TD Rvsd 11-Jun- 266590.000,2536950.000,0.0000 11515.00 7492.11S 3408.75B 12-Feb-97 Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7676 UNOr. ALi G. Russell Schmidt Drilling Manager Wednesday, March 06, 1996 Mr. David Johnston AOGCC 3001 Porcupine Drive Anchorage, AK 99519 Dear Mr. Johnston' This letter is concerning the conversation Mitchell Damm had with Blair Wondzell on March 6, 1996. Unocal would like to inform you of the changes we have made in our directional and casing programs for Granite Point 52, 53 & 54. The modications in the directional plans have changed the total depths slightly in each wells. We are also changing the 13-3/8" and 9-518" casings depths in GP #52 slightly. The major change is in which slots the wells will be drilled out of. ORIGINAL PLAN 13-3/8" shoe 9-5/8" shoe 7" shoe TD Slot # GP #52 900' MD 2,700' MD 11,395' MD 14,357' MD 6 GP #53 1100' MD 3,500' MD 12,800' MD 15,700' MD 8 GP #54 1100' MD 3,500' MD 12,684' MD 15,477' MD 9 REVISED PLAN GP #52 1100' MD 3,450' MD 11,400' MD 13,793' MD 4 GP #53 1100' MD 3,500' MD 12,950' MD 15,859' MD 3 GP #54 1100' MD 3,550' MD 12,625' MD 14,508' MD 2 If you require additional information, please contact myself or Mitchell Damm. Sincerely,...,.,, h, G. Russell Schmidt Drilling Manager MWD/leg Memorandum State of Alaska Oil and Gas Conservation Commission TO: Pm: Subj: Commission Staff ;~~J2a,~ Request for Diver[er Variance -- ~" Unocal Granite Pt. Platform Wells 52,53 & 54 Januaw 31,1996 Unocal has requested a waiver of diverter requirements on the subject wells. They propose to drill the 17-1/2" hole through the 26" conductor with a flow nipple to approximately 900', set 13-3/8" surface casing at 900', then drill 12-1/4" hole from +/- 2700' to 3500' using a 13 5/8", 5000 psi. BOPE system. They state in their application letter that the fracture gradient anticipated at the surface and intermediate casing shoes are .90 and .85 psifioot respectively and the rock is competent 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 Cook Inlet area and other Granite Point wells drilled recently. I reviewed 3 wells which offset the subject wells. There were no shallow gas kicks, abnormal pressure or lost circulation noted in the wells reviewed. There were several instances of stuck tools, however, fishing operations were successful and no other complications were noted. 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 similar arguments were the basis of the diverter variances granted on MGS Dillon wells 16 & 17 in April, 1994 and Granite Point Anna Wells ,Sq, 51, and 52 in July, 1994. The proposal to drill the surface hole to 900' 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 900-3500', their permit application shows a 13-5/8" BOP system with a 3000 psi annular preventer. 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 summary, a review of AOGCC well histories on three wells in the vicinity of the 3 proposed wells indicated no shallow gas, kicks or lost circulation zones The section of hole drilled from the structural pipe to the conductor depth of 900' RKB will be done without any means to divert. Hole drilled from 900' RKB to total depth will be accomplished with BOP equipment. Recommendation: Absent shallow gas and other notable drilling problems in the vicinity of the well to be drilled, I recommend approval of the waiver of diverter requirements. If there are other circumstances which the Commission thinks would cause a need for diverter use, Unocal should be allowed to address those circumstances. ALASKA OIL AND GAS CONSERVATION COMMISSION 3anuar~ 6, 1996 TONY KNOWLEg, GOVERNOF~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 G Russell Schmidt Drilling Manager Union Oil Company of California (Unocal) P O Box 196247 Anchorage, AK 99519 ' Re: Granite Point Field 52 ADI.,-18761 Unocal Permit No: Sm'. Loc. 2428'FNL, 1298~VL, Sec. 13, T10N, R12W, SM Btmhole Loc. 1570'FSL, 1829~'~EL, Sec. 24, T10N, R12W, SM Dear Mr. Schmidt: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Your application for a variance to the divener requirements of 20. AAC 25.035 has been approved. Blowout prevention equipment (BOPE) must be tested in accordance with 20.AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. Sincerely, T~uckerman Babcock Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. i. · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 a. Type of work Ddll ~J Redrill 0 Ilb' Type of well. Exploratory E~ Stratigraphic Test E] Re-Entry r-] Deepen E~ Service E] Development Gas E] Single Zone ;,."Name ot L~perator b. Union Oil Company of California (Unocal) 3. Address feet 76.9 P.O. Box 196247, Anchorage, AK 99519 4. Location of well at surface 2,428' FNL, 1298' FWL, Sec 13, T10N, R12W, SM At top of productive interval 10,910' 758' FNL, 2,461' FWL, Sec 24, T10N, R12W At total depth 14,357' 1,570' FSL, 1,829' FEL, Sec 24, T10N, R12W lZ. u~stance to nearest I 1 ;¢. Lhstance to nearest well property line I 2000 feet See Clearance Report 16. TO be completed for deviated wells Kickoff depth 3,500 feet Maximum hole angle Specifications Weight I Gradel Coupling I Length 68 IK-55 I BTCI 853' 29 IL-80 I BTC I 11,348' 12.6 IL-80 I SC-BTC/3162' · I~ednll, Me-entry,'and L)eepen L)perat~ons Uatum blevat~on (IJk or Kid) 4.75 RKB feet Property ues~gnat~on 18. Casing program size Hole ! Casing 17-1/2" 13-3/8" 12-1/4" 9-5~8" 8-1/Z' 7" 6" 4-1/2" lf9. I o De ompleted to Present well condition summary Total depth: measured true vertical ADL 18761 7. Unit or property name Granite Point Field 8. Well number 52 ADL-18761 9. Approximate spud date 2/11/96 14. Number ot acres ~n property 5089 14,357'110,965' 17. Anticipated Pressure (see 20 AA 3 25.035 (e)(2)) ~' T¢ O Maximum surface l$'~ ? psig At total depth (TVD) - ~ Setting Depth Iop uottom Quantity of cement MD ] TVD] MD ] TVD 47 I 47I 9ooI 90o 25ooft3 47 I 47 I 2700 I 2699 3383ft3 47 ] 47 ] 11395'] 10165 500ft3 110015' I 14357I 10965 11195 feet Plugs (measured) feet Development Oil [~] Multiple Zone u. I-~e~a and I~oo~ Granite Point Field Middle Kenai "C" Sands 1 .Type Bond (SEE 20 ACC 25.0 AK Statewide Oil & Gas Bond Number U62 - 9269 Amount $200,000 1 ~. Froposed depth (MU an~ I V feet psig Effective depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 20. Attachments Length Size Cemented Measured depth True vertical depth 294' 26" Driven 294' RKB measured See attached true vertical See attached Filing fee r~ Property plat [~] BOP Sketch JAN 1 6 Alaska Oil & Gas Cons. Commission Diverter Sketch ['-] Ddlling'~l~P~lT~le [~] Drilling fluid program E] Time vs depth plot L-~ Refraction analysis E] Seabed report [~ 20 AAC 25.050 requirements 2:1. I I~ereby c ,eCjty ~,t me tor,,e&o~ng is jl~ue and c~ct to the best ot my knowledge Commission Use Only Permit N~ber ~ _ ~ ._~ APl ~mUer _ _ ~ J ~proval~te2 ~ee leper ~' -'-.-~:L ~' ~1~ 7~ -~ 0 ~ ~ I / ~ ~ ~ ~ ~ cover foro~er requirem~ Cond~o~s ~f'~~i Samples r~uired U Yes ~ No Mud log r~ufr~ ' f Q Yes~ No Hydrogen suede measures ~ Ye~,~_~Dir~onal su~ey required ~ Yes ~ ~o R~uir~ working pre~ure ~r B~Q~ ~[~~ 3M; ~ 5M; ~ 10M; ~15M O~er: ~"~ ~ ~0C~ ~ ~ ~go~ef~BB~O~ by ~e order of Approved by Commissioner ~e ~mmi~ion Da~ Form 10-401 Rev. 12-1 ~5 Subm~ in ~¢li~ Unocal Corporation P.O, Box 196247 Anchorage, Alaska 99519 907-263-7676 UNOCAL G. Russell Schmidt Drilling Manager Thursday, January 11, 1996 Mr. David Johnston Commissioner Alaska O&G Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Johnston: Please find the enclosed Applications for Permit to Drill (Form 10-401) for the Granite Point Platform wells #52, #53, #54. UNOCAL is planning to batch drill all three wells; we will be commence batch drilling operations on GP #52 in mid- February. (See enclosed Granite Pt. Time Line.) These three grass root wells are part of UNOCAL's continued development drilling program on the Granite Point Platform. UNOCAL is requesting that the AOGCC waive the diverter system requirements on the 26" conductor casing strings for all three grass root wells. This waiver is similar to our April & July 1993 request for the Dillon Platform wells #16. #17, and #18 and the Anna Platform wells #50, #51, #52. The AOGCC approved UNOCAL's request to waive the diverter system requirements for both the Anna and Dillon wells. For the Granite Point Platform drilling program, UNOCAL is intending to drill out of the 26" conductor casing to approximately 900' to 1,100' utilizing a flow nipple; run and cement 13-3/8" surface casing; and will then install a 13-5/8" 5,000 psi BOPE stack on the 13-3/8" surface casing. Mr. David Johnston Page 2 January 11, 1996 UNOCAL has selected the casing points of the 13-3/8" ( 900' to 1,100') and 9- 5~8" (2,700' to 3,500' ) to be in competent formation. From offset development wells and log data, no gas bearing zones are evident above the proposed 13- 3/8" casing setting points. The anticipated formation fracture gradients at these shoe depths are 0.9 psi/ft and 0.85 psi/ft respectively. UNOCAL's recent experience in the Granite Point Field and in the Cook Inlet in general has demonstrated that the true fracture gradients range from 0.75 to 0.94 psi/ft; design assumptions are reasonable based on this data (See attached Granite Point Fracture Gradient Data and Graph.) While drilling below the 26' conductor casing, the maximum hydrostatic pressures (during as gas kick scenario) will not exceed the fracture pressures at the individual casing shoes. Since the casing shoes are structurally competent and the setting depths are in competent formations, UNOCAL believes the casing designs and drilling operations are safe and prudent designs. The completion design for Granite Point Platform wells #52, #53, #54 is to set 4- 1/2" slotted liner throughout the Tyonek C-5 sand. All three wells will then be completed with 2-7/8" gas lift completions. An outline and diagram of UNOCAL drilling and completion plans are included in each Application for Permit to Drill. For the Granite Point 53 and Granite Point 54 wells, UNOCAL is requesting an exception to Rule No. 2 of Conservation Order No. 76 and 20 AAC 25.055. Drilling Units and Well Spacing. The open pay section in Granite Point 53 will cross the lease line between ADL 18761 and ADL 374045; and Granite Point 54's pay section will be drilled less than 500 ft from the ADL 18761 lease line. UNOCAL would like to inform the AOGCC that all three wells will be intentionally deviated; and we are aware of the 15 day public comment period. UNOCAL would like to thank Robert P. Crandail for his help and cooperation with the spacing and Conservation Order issues. If any questions arise while the Permit to Drills are being reviewed, please contact the drilling engineer who is assigned to this project--Mitchell Damm (263-7679). Thank you for your time and cooperation. Enclosure /mwd S. ir!~erely¢, G. Russell Schm~d.t..~., Drilling Manager UNOCAL ) RKB= 115' GRANITE POINT PLATFORM WELL # 52 GRASS ROOTS PROPOSED COMPLETION CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 33" Outside conductor 26" Inside Conductor 13-3/8 68 K-55 9-5/8 L-80 7" 29 L-80 4-1/2" 12.6 L-80 BTC BTC BTC SC-BTC NOTE: 4-1/2" = slotted liner 2-7/8" 6.4 N-80 SC BTC 0 229 0 294 0 900 0 2,700 0 11,395 11,195 14,357 0 11,230 JEWELRY DETAIL NO. ITEM 1 SSSV 2 Camco Gas Lii~ Mandrels 3 Sliding Sleeve 4 7" Packer 5 "X" Profile Nipple 6 Wireline Re-entry Guide DEPTH 300 As Required 10,120 11,150 11,200 11,230 TOL ~ 11,195' PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS SLOTFED LINER TYONEK C-5 SAND TD = 14,357' MAX HOLE ANGLE = 76° O:~DRILLING\S CHEMATIC~GI~GPI:SGP52-PRO.DOC REVISED: 11/27/95 DRAWN BY: MWD ,nite Pt. 52 (New Well, South East Tyonek C-5) AFE 761100 ,'imeEst. Cum Time Preliminary Procedure: 0.5 0.5 1 1.5 1 2.5 0.5 3 2 5 1.5 6.5 0.5 7 14 21 I MIRU R156, Leg #.4, Conductor ~., Install 26-30" flow dser. 2 Drill 17-1/2" hole to 13-3/8" csg point of approx. 900'. 3 Run and cement 13-3/8" casing. Install 13-5/8" wellhead system. 4 Batch ddll, skid dg to next well. Install 13-5/8" BOPE. 5 Drill 12-1/4" hole to 9-5/8" csg point of approx. 2700' (ROP 1100'). 6 Run and cement 9-5/8" casing. 7 Batch drill, skid dg to next well. 8 Directionally drill 8-1/2" hole from appmx 2700'-11395' (Top C-5). ROP=640 fpd (all 8-1/2" hole) KOP DLS Angle Range 2700 2.5 0-45 0 21 2 23 12 35 9 No intermediate E-line logs required 10 Run & cement 7" casing. 11 Directionaily ddil 6" hole from 11395'-14357'. ROP=240 fpd (all 6" hole) KOP DLS Angle Range 11395 7 45-77 1.5 36.5 O.75 37.25 1.5 38.75 1.5 40.25 0 4O .25 0 40.25 0 40.25 1.5 41.75 0.5 42.25 0.5 42.75 12 13 14 15 16 17 18 19 2O 21 Run drillpipe conveyed logs; DIL-GR-SP-Sonic. RIH, CCH for 4-1/2" slotted liner Run & install slotted liner from 11195'-14357'. PU 2-7/8" tubing, RIH. Displ well to diesel & wash slotted liner. MU packer assy, 2-7/8" tbg COmpletion, GLM and RIH. Land same. Set BPV. Nipple down BOP's. Install wellhead. Install gas lift system. Release dg. J'AN t 6 Alaska Oil & Gas Cons. Commmsion Anchorage 'Revised 12/19/95 GRVVEST.XLS Page 1 RT 114.75' RKB 62' 33' @ 229' RKB (40' BM£) i 294' RKB · (105' BML) WELLHEAD STARTS HERE PROD DECK TOP OF LEG (75' WATER DEPTH) SEA LEVEL (MI.1.W) Top 2~' @ 17'/' RIG] (only on; Inner conductor) MUD LINE Note: Outer 9 conductors have 26" back to surface Inner 3 s/ots are d/ffemnL See attached plan view. GRANITE POINT WELLBORE CONDUCTOR STATUS UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLI._ File: GPCOND. drw DATE: 07-21-95 2,000 4,000 6,000 8,000 10,000 12,000 14,000 18,000 , GPP 52 Grass Roots Depth VS Days Drill 17-112" OH!(ROP = 900') i ~ Run 13-$/~ CSGWellheadi Drill 12-1/4.-." OH (ROP = 1i00') Run 9-5/8" COG Drill 8-112" OH (ROP = 640') Rub 7" CSG ~Estimated Depth (FT) · Actual Depth (FT) Drill $" OH (RO~ = 240') Run Logs; Cbanout OH; Rur 1/2" Slotted Uner; Run TBG 6O Days GP52DVT.XLS 12/19/95 Granite Pt. Time Line Overall Plan for Granite Pt. Platform Days Start End Req'd Cum Days Date Date Description of work 71 71 7112/95 9/21/95 7 78 9/21195 9/28/95 13 91 9128195 10/11195 11 102 10111195 10122/95 2 104 10/22/95 10/24195 65 169 10124/95 12/28/95 39 208 12/28/95 2/5/96 2 210 2/5/96 2/7/96 4 214 2/7/96 2/11196 3 217 2/11196 2/14196 3.5 220.5 2/14196 2/17196 7 227.5 2/17196 2/24196 3 230.5 2/24196 2/27196 3 233.5 2/27196 311196 2 235.5 311196 313196 38 273.5 3/3196 4110196 39.5 313 4110/96 5/20196 38 351 5120/96 6127196 18 369 6127196 7115/96 Mobilize I Install Rig 156 and Gdnding Package a,t ,G, PP Workover 11-13 Rd P&A 42-23 for reddll P&A 22-13 for reddll Change over mud system from WBM to OBM Reddll 22-13 and complete Reddll 42-23 and complete Remove OBM and clean activelresv system Skid dg from leg #3 to #4 Batch ddll well #52 to 13-318" csg. pt. Batch ddll well #53 to 13-318" csg. pt. (includes dg skid) Batch drill well #54 to both 13-318" & 9-5~8" csg. pt. (includes dg skid) Batch ddll well #53 to 9-518" csg. pt. (includes dg skid) Ddll well #52 to 9-518" csg. pt. Change over mud system from WBM to OBM Ddll to TD & complete well #52 Ddll to TD & complete well #53 Dflll to TD & complete well #54 Demobilize Rig 156 Revised 12/19195 per MWD TIMELINE.XLS Page I * !+ _.,LI t mm mm mm m mm mm m JAN 1 ~ l~J~' J) + Alaska Oil & Gas Cons. Commission ..... -An~of~e I . , , o ] d 0 're on .. 5O0 o 1000 2000 _ 2500 _ 5500 ~ ~ 40~ i V 8000 _ 8500 _ 10000_ 1 O500_ 11000 Begin SE Nudge 1.00 2.00 End Angle Bu;Id Begin Angle Drop 2.00 1.00 End of Nudge i Point ~Fnd of Hold lind of Build IEnd of Hold !End of Drop iEnd of Build nd of Hold orget nd of Build Eorget nd of Droo KOP 2.50 5.OO 7.50 10.00 12.50 15.00 17.50 20.00 22.50 25,00 27.50 30.00 52.50 EOC TARGET ANGLE 76.94 DEG UNOCAL GRANITE POINT Platform Well : GP52 S 17.86 DEG E 6906' (TO TD) **ePeE CF PROPO~*** Fqeld : Granite Paint Field Location : Cook Inlet, Alaska ,L, eated by : jones For: M DAMMJ %.3re plotted : 2-Jon-96 :xot Reference is GP52 Version Coordinates ore in feet reference slot ~4-6. True Vertic01 Depths ore r~ference RKB (Rig: iQ56). WELL PROFILE DATA MD inc Dir TVD NoAh East Deg/10(Y 0 0.00 162.14 0 0 0 0.00 500 0.00 162.14 500 0 0 0.00 8~ 5.00 162.14 800 -7 2 1.00: 1200 5.OO 162.14 1199 -27 9 0.O(Y 1500 0.00 162.14 1499 -55 11 1.00~, 5500 0.00 162.14 ,3499 -55 11 0.00~ 4851 55.79 162.14 4774 -403 150 2.50~ 10991 35.79 162.14 9877 -5655 1177 0.0~, 11365 45.00 162.14 10165 -5879 1249 5.00, i 1822 76.94 161.34 10384 -4255 1575 7.00~ 13730 76.94 161.34 10815 -6014 1968 0.00{ 14327 73.94 161.34 10965 -6562 2153 0.5~ ....... Eas --> 0 500 10OO 1500 2000 2500 __ 0 - __ 500 SURFACE LOCATION: 2428' FNL. 1298' FWL rD SEC. 15, TION, R12W 1000O 1500 _2000 _2500 0(~ _ TARGET #1 LOCATION: _5000 \ 1027' FNL, 2547' FWL \ _ ~'- SEC. 24, TION, R12W '\ _5500 Begin Finol Angle BuBd~ MAXIMUM ANGLE ,~Top4 1/2 Uner I TARGET ii1 - Top 3 3.7 9 DE G T B c-~no, ~oo _4000 ARCET ~2 -o.e I '~ _4500 _ , ~ _5000 k ~ 'J -~)//J~t- Begin Or~ 16000 I . Alaska Oil & (3as Cons, Commismn ~ ~0 _ -6500 i ~'~.~ ~ 1570' eSL 1829' FEL ~~ S¢C. 24, TION, R12W V I I II I I I I I I I I1 II II I I I I II I I I I I I I 0 500 1000 15OO 2000 2500 ~ 5500 4000 4500 5000 5500 6000 6500 7~ Scale 1 · 250.00 Vertical Section on 162.14 azimuth wHh reference 0.00 N, 0.00 E from slot #4-6 TD ANGLE 73.94 DEG UNOCAL GRANITE POINT Platform GP52 slot ~4-6 Granite Point Field Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : GP52 Version #4 Our ref : prop1455 License : Date printed : 2-Jan-96 Date created : 15-Nov-95 Last revised : 2-Jan-96 Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 57 52.745,w151 20 20.066 Slot location is n60 57 28.836,w151 19 53.782 Slot Grid coordinates are N 2544503.295, E 263330.093 Slot local coordinates are 2427.96 S 1297.85 E Reference North is True North UNOCAL GRANITE POINT P[atform,GP52 Granite Point FieLd,Cook InLet, ALaska Measured Depth 0.00 500.00 600.00 700.00 800.00 PROPOSAL LISTING Page 1 Your ref : GP52 Version Last revised : 2-Jan-96 Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 0.00 162.14 0.00 0.00 N 0.00 E 0.00 0.00 0.00 162.14 500.00 0.00 N 0.00 E 0.00 0.00 1.00 162.14 599.99 0.83 S 0.27 E 1.00 0.87 2.00 162.14 699.96 3.32 S 1.07 E 1.00 3.49 3.00 162.14 799.86 7.47 S 2.41 E 1.00 7.85 1000.00 1200.00 1300.00 1400.00 1500.00 3.00 162.14 999.59 17.44 S 5.62 E 0.00 18.32 3.00 162.14 1199.31 27.40 S 8.83 E 0.00 28.79 2.00 162.14 1299.22 31.55 S 10.16 E 1.00 33.15 1.00 162.14 1399.18 34.04 S 10.97 E 1.00 35.77' 0.00 162.14 1499.18 34.87 $ 11.23 E 1.00 36.64 2000.00 2500.00 3000.00 3500.00 3600.00 0.00 162.14 1999.18 34.87 S 11.23 E 0.00 36.64 0.00 162.14 2499.18 34.87 S 11.23 E 0.00 36.64 0.00 162.14 2999.18 34.87 $ 11.23 E 0.00 36.64 0.00 162.14 3499.18 34.87 S 11.23 E 0.00 36.64 2.50 162.14 3599.14 36.95 S 11.90 E 2.50 38.82 3700.00 5.00 3800.O0 7.50 3900.00 10.00 4000.00 12.50 4100.00 15.00 4200.00 17.50 4300.00 20.00 4400.00 22.50 4500.00 25.00 4600.00 27.50 4700.00 30.00 4800.00 32.50 4851.49 33.79 5000.00 33.79 5500.00 33.79 6000.00 33.79 6500.00 33.79 7000.00 33.79 7500.00 33.79 8000.00 33.79 8500.00 33.79 9000.00 33.79 9500.00 33.79 10000.00 33.79 10500.00 33.79 10991.39 33.79 11065.15 36.00 11165.15 39.00 11195.00 39.90 11265.15 42.00 11365.15 45.00 11400.00 47.44 11500.00 54.44 11600.00 61.44 11700.00 68.43 162.14 3698.92 43.18 S 13.91 E 2.50 45.36 162.14 3798.32 53.54 S 17.24 E 2.50 56.24 162.14 3897.15 68.02 $ 21.91 E 2.50 71.46 162.14 3995.22 86.58 S 27.89 E 2.50 90.96 162.14 4092.35 109.20 S 35.18 E 2.50 114.73 162.14 .4188.34 135.84 S 43.76 E 2.50 142.71 162.14 4283.03 166.43 S 53.61 E 2.50 174.85 162.14 4376.22 200.93 S 64.72 E 2.50 211.09 162.14 4467.75 239.26 $ 77.07 E 2.50 251.36 162.14 4557.43 281.35 S 90.63 E 2.50 295.59 162.14 4645.09 327.13 S 105.38 E 2.50 343.68 162.14 4730.58 376.51 S 121.28 E 2.50 395.56 162.14 4773.69 403.30 S 129.92 E 2.50 423.71 162.14 4897.12 481.91 S 155.24 E 0.00 506.30 162.14 5312.67 746.57 S 240.49 E 0.00 784.35 162.14 5728.23 1011.24 S 325.75 E 0.00 1062.41 162.14 6143.78 1275.90 $ 411.01 E 0.00 1340.46 162.14 6559.34 1540.56 S 496.26 E 0.00 1618.52 162.14 6974.89 1805.22 S 581.52 E 0.00 1896.57 162.14 7390.44 2069.88 S 666.77 E 0.00 2174.63 162.14 7806.00 2334.54 S 752.03 E 0.00 2452.68 162.14 8221.55 2599.21 S 837.28 E 0.00 2730.74 162.14 8637.11 2863.87 S 922.54 E 0.00 3008.79 162.14 9052.66 3128.53 S 1007.80 E 0.00 3286.84 162.14 9468.22 3393.19 S 1093.05 E 0.00 3564.90 162.14 9876.62 3653.30 S 1176.84 E 0.00 3838.17 162.14 9937.11 3693.46 S 1189.78 E 3.00 3880.36 162.14 10016.44 3751.39 S 1208.44 E 3.00 3941.23 162.14 10039.49 3769.44 S 1214.26 E 3.00 3960.19 162.14 10092.47 3813.20 S 1228.35 E 3.00 4006.17 162.14 10165.00 3878.72 S 1249.45 E 3.00 4074.99 162.06 10189.11 3902.66 S 1257.19 E 7.00 4100.15 161.85 10252.09 3976.43 S 1281.23 E 7.00 4177.75 161.67 10305.14 4056.87 S 1307.75 E 7.00 4262.44 161.51 10347.48 4142.76 S 1336.34 E 7.00 4352.96 Begin SE Nudge End Angle Build Begin Angle Drop End of Nudge KOP EOC Begin Final Angle Build Top 4 1/2" Liner TARGET #1 - Top C-5 Att data is in feet unless otherwise stated Coordinates from slot ~4-6 and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 162.14 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. CaLculation uses the minimc~ curvature method. Presented by Baker Hughes [NTEQ UNOCAL GRANITE POINT P[atform,GP52 Granite Point Field,Cook Inter, Alaska PROPOSAL LISTING Page 2 Your ref : GP52 Version #4 Last revised : 2-Jan-96 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 11751.85 72.06 161,44 10365.00 4189.02 S 1351.85 E 7.00 11800.00 75.43 161,37 10378.47 4232.83 S 1366.59 E 7.00 11821.54 76,94 161.34 10383.62 4252.65 S 1373.28 E 7.00 12000.00 76.94 161,34 10423.94 4417.35 S 1428.90 E 0.00 12500.00 76.94 161,34 10536.93 4878.82 S 1584.73 E 0.00 4401.75 TARGET #2 - Base C-5 4447.96 4468.88 Final HOC 4642.71 5129.72 13000.00 76.94 161,34 10649.91 5340.28 S 1740.57 E 0.00 13500.00 76.94 161.34 10762.90 5801.75 S 1896.40 E 0.00 13730.58 76.94 161,34 10815.00 6014.55 S 1968.26 E 0.00 13734.43 76.92 161.34 10815.87 6018.11 S 1969.47 E 0.50 13834.43 76.42 161.34 1083~.93 6110.30 S 2000.60 E 0.50 5616.74 6103.76 6328.35 TARGET #3 - O/g Contact - Begin Drop 6332.10 6429.40 13934.43 75.92 161.34 10862.84 6202.29 S 2031.66 E 0.50 6526.49 14034.43 75.41 161,34 108~7.60 6294.09 $ 2062.66 E 0.50 6623.37 14134.43 74.91 161.34 10913.21 6385.67 S 2093.59 E 0.50 6720.02 14234.43 74.41 161.34 10939.66 6477.04 S 2124.45 E 0.50 6816.45 14327.32 73.94 161.34 10965.00 6561.71 S 2153.04 E 0.50 6905.81 TD All data is in feet un[ess otherwise stated Coordinates from slot #4-6 and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Vertical section is from we[Ehead on azimuth 162.14 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Ptatform, GP52 Granite Point Field,Cook Intel, Alaska PROPOSAL LISTING Page 3 Your ref : GP52 Version #4 Last revised : 2-Jan-g6 Comments in wellpath MD TVD Rectangular Coords. Co~ent 500.00 500.00 0.00 N 0.00 E Begin SE Nudge 800.00 799.86 7.47 S 2.41E End Angle Build 1200.00 1199.31 27.40 S 8.83 E Begin Angle Drop 1500.00 1499.18 34.87 S 11.23 E End of Nudge 3500.00 3499.18 34.87 S 11.23 E KOP 4851.49 4773.69 403.30 S 129.92 E EOC 10991.39 9876.62 3653.30 S 1176.84 E Begin Final Angle Build 11195.00 10039.49 3769.44 S 1214.26 E To~4 1/2" Liner 11365.15 10165.00 3878.72 S 1249.45 E TARGET #1 - Top C-5 11751.85 10365.00 4189.02 S 1351.85 E TARGET #2 - Base C-5 11821.54 10383.62 4252.65 S 1373.28 E Final EOC 13730.58 10815.00 6014.55 S 1968.26 E TARGET #5 - O/W Contact - Begin Drop 14327.32 10965.00 6561.71S 2153.04 E TD Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised GP52 O/W 15-Nov-95 265175.000,2538450.000,0.000010815.00 6014.55S 1968.26E 15-Nov-95 GP52 B/C-5 15-Nov-95 264000.000,2540330.000,0.000010365.00 4146.63S 1354.95E 15-Nov-95 GP52 T/ C-5 15-Nov-9 264500.000,2540600.000,0.000010165.00 3878.72S 1249.45E 15-Nov-95 JAN 1 6 ~J~ A/asZa Oil & ~a~ C~, Cornmiss~ All data is in feet unless otherwise stated Coordinates from slot ~4-6 and TVO from RKB (Rig: #156) (115.00 Ft above mean sea level). Bottom hole distance is 6905.91 on azimuth 161.83 degrees from wellhead. Total Dogleg for wellpath is 85.95 degrees. Vertical section is from wellhead on azimuth 162.14 degrees, Declination is 0.00 degrees, Convergence is -1,17 degrees. Calculation uses the minim~n curvature method. Presented by Baker Hughes INTEQ UNOCAL PROPOSAL LISTING Page 1 GRANITE POINT Platform, GP52 Your ref : GP52 Version ~4 Granite Point Field,Cook Inlet, Alaska Last revised : 2-Jan-96 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 0.00 162.14 0.00 2427.97 S 1297.85 E 0.00 500.00 0.00 162.14 500.00 2427.97 S 1297.85 E 0.00 600.00 1.00 162.14 599.99 2428.80 S 1298.12 £ 1.00 700.00 2.00 162.14 699.96 2431.29 S 1298.92 E 1.00 800.00 3.00 162.14 799.86 2435.44 S 1300.26 E 1.00 0.00 0.00 Begin SE Nudge 0.87 3.49 7.85 End Angle Build 1000.00 3.00 162.14 999.59 2445.40 S 1303.46 E 0.00 1200.00 3.00 162.14 1199.31 2455.37 S 1306.67 E 0.00 1300.00 2.00 162.14 1299.22 2459.52 S 1308.01 E 1.00 1400.00 1.00 162.14 1399.18 2462.01 S 1308.81 E 1.00 1500.00 0.00 162.14 1499.18 2462.84 S 1309.08 E 1.00 18.32 28.79 Begin Angle Drop 33.15 35.77 36.64 End of Nudge 2000.00 0.00 162.14 1999.18 2462.84 S 1309.08 E 0.00 36.64 2500.00 0.00 162.14 2499.18 2462.84 S 1309.08 E 0.00 36.64 3000.00 0.00 162.14 2999.18 2462.84 S 1309.08 E 0.00 36.64 3500.00 0.00 162.14 3499.18 2462.84 S 1309.08 E 0.00 36.64 KOP 3600.00 2.50 162.14 3599.14 2464.92 S 1309.75 E 2.50 38.82 3700.00 5.00 162.14 3698.92 2471.14 S 1311.76 E 2.50 45.36 3800.00 7.50 162.14 3798.32 2481.50 S 1315.09 E 2.50 56.24 3900.00 10.00 162.14 3897.15 2495.98 S 1319.76 E 2.50 71.46 4000.00 12.50 162.14 3995.22 2514.55 S 1325.74 E 2.50 90.96 4100.00 15.00 162.14 4092.35 2537.17 S 1333.03 E 2.50 114.73 4200.00 17.50 162.14 4188.34 2563.80 S 1341.60 E 2.50 142.71 4300.00 20.00 162.14 4283.03 2594.40 S 1351.46 E 2.50 174.85 4400.00 22.50 162.14 4376.22 2628.89 S 1362.57 E 2.50 211.09 4500.00 25.00 162.14 4467.75 2667.22 S 1374.92 E 2.50 251.36 4600.00 27.50 162.14 4557.43 2709.32 S 1388.48 E 2.50 295.59 4700.00 30.00 162.14 4645.09 2755.10 S 1403.23 E 2.50 343.68 4800.00 32.50 162.14 4730.58 2804.47 S 1419.13 E 2.50 395.56 4851.49 33.79 162.14 4773.69 2831.26 S 1427.76 E 2.50 423.71 EOC 5000.00 33.79 162.14 4897.12 2909.88 S 1453.09 E 0.00 506.30 5500.00 33.79 162.14 5312.67 3174.54 S 1538.34 E 0.00 784.35 6000.00 33.79 162.14 5728.23 3439.20 S 1623.60 E 0.00 1062.41 6500.00 33.79 162.14 6143.78 3703.86 S 1708.85 E 0.00 1340.46 7000.00 33.79 162.14 6559.34 3968.52 S 1794.11 E 0.00 1618.52 7500.00 33.79 162.14 69?4.89 4233.19 S 1879.36 E 0.00 1896.57 8000.00 33.79 162.14 7390.44 4497.85 S 1964.62 E 0.00 2174.63 8500.00 33.79 162.14 7806.00 4762.51 S 2049.88 E 0.00 2452.68 9000.00 33.79 162.14 8221.55 5027.17 S 2135.13 E 0.00 2730.74 9500.00 33.79 162.14 8637.11 5291.83 S 2220.39 E 0.00 3008.79 10000.00 33.79 162.14 9052.66 5556.50 S 2305.64 E 0.00 3286.84 10500.00 33.79 162.14 9468.22 5821.16 S 2390.90 E 0.00 3564.90 10991.39 33.79 162.14 9876.62 6081.26 S 2474.69 E 0.00 3838.17 Begin Final Angle Build 11065.15 36.00 162.14 9937.11 6121.42 S 2487.62 E 3.00 3880.36 11165.15 39.00 162.14 10016.44 6179.36 S 2506.29 E 3.00 3941.23 11195.00 39.90 162.14 10039.49 6197.41S 2512.10 E 3.00 3960.19 Top 4 1/2" Liner 11265.15 42.00 162.14 10092.47 6241.17 S 2526.20 E 3.00 4006.17 11365.15 45.00 162.14 10165.00 6306.68 S 2547.30 E 3.00 4074.99 TARGET #1 - Top C-5 11400.00 47.44 162.06 10189.11 6330.62 S 2555.03 E 7.00 4100.15 11500.00 54.44 161.85 10252.09 6404.40 S 2579.08 E 7.00 4177.75 11600.00 61.44 161.67 10305.14 6484.84 S 2605.60 E 7.00 4262.44 11700.00 68.43 161.51 10347.48 6570.73 S 2634.19 E 7.00 4352.96 All data is in feet unless otherwise stated Coordinates from NW Corner of Sec. 13, TION, R12W SM and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 162.14 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the mininmm~curvature method. Presented by Baker Hughes INTEQ Grani UNOCAL GRANITE POINT Platform,GPS2 te Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : GP52 Version ~4 Last revised : 2-Jan-96 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 11751.85 72.06 161.44 10365.00 6616.99 S 2649.70 E 7.00 4401.75 11800.00 75.4] 161.37 10378.47 6660.79 S 2664.44 E 7.00 4447.96 11821.54 76.94 161.34 103~3.62 6680.62 S 2671.12 E 7.00 4468.88 12000.00 76.94 161.34 10423.94 6845.32 S 2726.74 E 0.00 4642.71 12500.00 76.94 161.]4 10536.9] 7306.78 S 2882.58 E 0.00 5129.72 TARGET #2 - Base C-5 Final EOC 13000.00 76.94 161.34 10649.91 7768.25 S 3038.41 E 0.00 5616.74 13500.00 76.94 161.34 10762.90 8229.71 S 3194.25 E 0.00 6103.76 13730.58 76.94 161.34 10~15.00 8442.52 S 3266.11 E 0.00 6]28.35 11734.43 76.92 161.]4 10815.87 8446.07 S 3267.31 E 0.50 6312.10 138~4.4] 76.42 161.34 108.~8.93 8518.26 S 3298.45 E 0.50 6429.40 TARGET ~r5 - O/W Contact - Begin Drop 13934.43 75.92 161.34 10862.84 86]0.26 S ]]29.51 E 0.50 6526.49 14014.43 75.41 161.34 10~7.00 8722.05 S 3160.51 E 0.50 662].37 14134.43 74.91 161.34 10913.21 8813.64 S 3391.44 E 0.50 6720.02 14214.43 74.41 161.34 10939.~ 8905.00 S 3422.29 E 0.50 6816.45 14327.32 73.94 161.34 10965.00 8989.68 S 3450.89 E 0.50 6905.81 TD All data is in feet unless otherwise stated Coordinates from NW Corner of Sec. 1], TION, R12~ SM and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 162.14 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minim~ curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT P[atform,GP52 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 3 Your ref : GP52 Version Last revised : 2-Jan-96 Con~nts in wel[path ND TVD RectanguLar Coords. Coe~ent 500.00 500.00 2427.97 S 1297.85 E Begin SE Nudge 800.00 799.86 2435.44 S 1300.26 E End Angle Build 1200.00 1199.31 2455.37 S 1306.67 E Begin Angle Drop 1500.00 1499.18 2462.84 S 1309.08 E End of Nudge 3500.00 3499.18 2462.84 S 1309.08 E KOP 4851.49 4773.69 2831.26 S 1427.76 E EOC 10991.39 9876.62 6081.26 S 2474.69 E Begin Final Angle Build 11195.00 10039.49 6197.41S 2512.10 E Top 4 1/2" Liner 11365.15 10165.00 6306.68 S 2547.30 E TARGET #1 - Top C-5 11751.85 10365.00 6616.99 S 2649.70 E TARGET #2 - Base C-5 11821.54 10383.62 6680.62 S 2671.12 E Final EOC 137'50.58 10815.00 8442.52 $ 3266.11E TARGET ~F5 - O/W Contact - Begin Drop 14327.32 10965.00 8989.68 S 3450.89 E TD Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised GP52 O/W 15-Nov-95 265175.000,2538450.000,0.000010815.00 8442.52S 3206.11E 15-Nov-95 GP52 B/C-5 15-Nov-95 264600.000,2540330.000,0.000010365.00 6574.59S 2652.80E 15-Nov-95 GP52 T! C-5 15-Nov-9 264500.000,2540600.000,0.000010165.00 6306.68S 2547.30E 15-Nov-95 All data is in feet unless otherwise stated Coordinates from NW Corner of Sec. 13, TION, R12W SM and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Bottom hole distance is 6905.91 on azimuth 161.83 degrees from wel[head. Total Dogleg for we[[path is 85.95 degrees. Vertical section is from wellhead on azimuth 162.14 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT PLatform GP52 slot #4-6 Granite Point FieLd Cook InLet, ALaska CLEARANCE REPORT Baker Hughes INTEQ Your ref : GP52 VersionS4 Our ref : prop1455 License : Date printed : 29-Dec-95 Date created : 15-Nov-95 Last revised : 29-Dec-95 FieLd is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 57 52.745,w151 20 20.066 SLot Location is n60 57 28.836,w151 19 53.782 SLot Grid coordinates are N 25/,4503.295, E 263330.093 Stol Local coordinates are 2427.96 S 1297.85 E Reference North is True North Main caLcuLation performed with 3-D Minimu~ Distance method Object weLlpath GMS <O-10572'>,,13-13,GRANITE POINT PLatform PGMS <O-11560'>,,11-13Rd,GRANITE POINT Ptatfor GMS ~4025-11653'>,,11-13,GRANITE POINT Ptatfor PMSS <9437 - 10270'>,,32-13Rd,GRANITE POINT Pt PMSS <8~78 - 1256~'>,,32-13RcI~2,GRANITE POINT PG~IS <0-10200">,,32-13,GRANITE POINT Ptatfor~ GMS <2700 - 11450'>,,33-13,GRANITE POINT Ptatf MSS <86~0-11376,> ,,33-23,GRANITE POINT Ptatfo GMS <0-12000'>,,32-~,GRANITE POINT Ptatfor~ GNS <4~900-11986'>,,32-23Rd,GRANITE POINT Ptatf GMS/NSS <0-11150-15715'>,,MUC I-1,GRANITE POZN GMS <0-118~9'> ,,GP-51,GRANITE POINT Ptatfora PGMS <O-12163'>,,GP-50,GRANITE PO]NT Ptatfo~ GMS <O-108~O'>,,MUC ]-2,GRANITE POINT Ptatfona GNS <O-12200">,~12-24,GRANITE PO%NT Ptatfor~ Gals <O-10560'>,,24-13,GRANITE POINT PLatform GNS <9700-10640'>,,24-13Rd,GRANITE POINT Ptatf GMS <O-11473'>,,33-14,GRANITE POINT PLatform ~ <9200-11&lO'>,,33-14Rd, GRANITE POINT Ptatf GNS <0-11200'>,,31-?.5,GRANITE POINT PLatform GNS/NSS/r.~IS <O-12471'>,,44-11,GRANITE POINt Pt GMS <O-10850'>,,44-14,GRANITE POINT PLatform GMS <O-11800'>,,11-24,GRANITE POINT PLatform GNS <O-10191'>~,31-14Rd#2~GRANITE POINT Ptatfo r.~/NSS <O-8876'>~31-14,GRANITE POINT Ptatfor CalS <O-11011'>,,31-14Rd#1,GRANI?E POINT P[atfo GMS <O-1087~'>,,31-13,GRA#[TE POINT PLatform GMS/NSS/G#S (O-14544'>,,42-2~,C~j~IITE POI#T PI PMSS <11453 - 13821,>,,22-13Rd2,.r. dLANiTE POII~ Closest approach ~ith 3-D minim~m~ distance method Last revised Distance M.D. 11 - Aug- 95 33.2 3500.0 11 -Aug-95 71.5 600.0 11-Aug-95 71.5 600.0 13-Aug-95 88.5 1720.0 13-Aug-95 88.5 1720.0 13-Aug-95 88.5 1720.0 13-Aug-95 88.5 1720.0 11-Aug-95 66.8 260.0 11-Aug-95 66.8 260.0 22-May-91 66.8 260.0 22-May-91 87.9 460.0 11-Aug-95 87.5 600.0 2-0ct-92 78.1 750.0 2~-May-91 92.4 700.0 22-May-91 31.7 840.0 22-May-91 66.3 1040.0 22.-May-91 66.3 1040.0 22-May-91 68.7 360.0 22-May-91 68.7 360.0 22-May-91 75.0 200.0 2Z-May-91 76.7 280.0 22-#ay-91 65.6 100.0 22-#ay-91 17.6 1250.0 22-May-91 76.4 60.0 ?.Z-May-91 76.4 60.0 22-#ay-91 76.4 60.0 22-May-91 87.0 100.0 2Z-May-91 25.] 1350.0 20-Dec-95 89.8 320.0 Diverging from M.D. 3500.0 600.0 600.0 9160.0 9140.0 1~0.0 5360°0 ' 1400.0 1400.0 9840.0 10900.0 3120.0 9180.0 7T80.0 6660.0 10680.0 lOSOO.O JAN 200.0 1~.0 ~.0 ~.0 13~.4 ~0.0 PMSS <6T58 - 12036 ~2-13Rd,GRANITE POINT GCT Gyro <0-7002'>,,cZ-13Rd,GRANITE POINT Plat GP53 Version #4,,GP53,GRANITE POINT Platform GP54 Version #4,,GP54,GRANITE POINT Ptatform 20-Dec-95 4-Dec-95 29-Dec-95 29-Dec-95 .- -, 8.4 11.3 320.0 320.0 500.0 500.0 320.0 320.0 12200.0 350O.O I Hold IEnd of 8uBd iEnd of Hold End of Drop iKOP IEnd of Build !End of Hold target nd of Build arget nd of Drop 40 0 0 ,-. 20 .. -~ 0 2O 40 8O t O I V 180. WELL PROFILE DATA MD Inc Dir 'FVD 0 0.00 162.14 0 500 0.00 162.14 500 800 3.00 162.14 800 1200 5.00 162.14 1199 1500 0.00 162.14 1499 3500 0.00 162.14 3499 4851 55.79 162.14 4774 10991 33.79 162.14 9877 11365 45.00 162.14 10165 11822 76.94 161.34 10384 13730 76.94 161.34 10815 14327 73.94 161.34 10965 Scale 1 ' 10.00 140 120 100 80 60 40 20 1300 1300 1300 1500 1 1201 4300 1700 1900 6100 140 120 100 80 Scale 1 ' 10.00 UNOCAL Structure : GRANITE POINT Platform Well : 0P52 Field : Granite Pain! Field Location : Cook Inlet, Alaska Nodh East Deg/tO0 0 0 0.00 0 0 0.00 -7 2 1.00 -27 9 0.00 -35 11 1.00 -35 11 0.00 -403 130 2.50 -3653 1177 0.00 -3879 1249 3.00 -4253 1373 7.00 -6014 1968 0.00 -6582 2153 0.50 East 0 20 40 1100 13oo 150o 21oo oo 1100 35OO 80 100 120 1100 700 900 1300 1700 1900 310,C 3300 5900 1500 150~ 4100 43OO 13O0 1500 1700 1500 4500 40 20 0 20 East 40 60 80 100 120 > JCreoted by : jor~s Fora M Dote plotted : 2-Jan-96 Plot Reference is C.,P52 Version Coordinates (]re in feet reference slot ~4-6. True Vertical Depths ore reference RKB (Rig: ~156).i 140 160 180 200 2O 2100 20 1900 80 100 120 ~60 ~oo I I V 140 160 180 200 I I ¥ 700 800 900 1000_ -- 1100_ 1200 1300 1400 1500 1600_ _ 1700_ _ !800_ 1900~ 2000t 21001 2200 2500 $coie 1 ' 50.00 500 400 300 2900 4500 33OO 4700 49OO 55OO 57OO MO0 500 400 300 Scale 1 · 50.00 2OO UNOCAL 67O0 20O Structure : GRANITE POINT Platform Well : GP52 Field : Granite Point Field Location : Cook Inlet, Alaska ~300 55OO 57OO East --> ~ O0 0 i OO 200 300 400 500 . 3100 55O0 37C~ 6100 3900 4~00 450O 4700 4900 250( 270C 55OO 5700 5900 6100 3~0C 6300 35~ 3700 6500 3900 ~300 JAN Oil & Ga~ Con~, Commission 670O F iCreoted by : jones For:. M DAMM Dote plotted : 2-Jori-96 IPIot Reference is GP52 Version ~4. Coordino[es ore in feet reference slot ~4-6. ~True Verticol Oepths ore reference RKB (R~: ~1561. 600 700 800 go0 1000 700 ~4500 800 4900 900 5100 5300 1 ~0 5~ 57~ 11 O0 5900 6100 _1200 6~0 { 6500 300 47O0 7100 6OOO 7300 9500, 9500 9700 970O t900 0100 6OO 700 1800 _ _1900 _ _2000 _ _2100 _ _2200 0 0 0 0 I I 49OO 79OO 5100 lO0 0 1 O0 200 300 400 500 600 700 800 900 10(30 East > DE C-- 22-- 95 F R I 10 : 4 ~ M-- I DR I LL I N G ~_K P . 02 UNOCAL GRANITE POINT PLATFORM WELLS #~2, #$3 a~D #§4 DEPTH INTERVAL 0 - ± 900' #52 0 - Z 1100' #53 AND ~54 17-1/2" HOLE 13-3/8" CASING MUD TYPE GENERIC MUD #2 MUD ADDITIVES lt-r GEL/M-I BAR/SODA/ ASH/CAUSTIC/LIME POTENTIAL PROBLEMS HOLE CLZANINO/CRAVEL/ OAS KICK/LOST CIRCULATION TREATMENTS/PROCEDURES i) Build spud mud system with prehydrated bentonit~ in fresh water and filtered inlet water. a) Treat drill water with Soda Ash as required to reduce calcium content to 40 i ppm. b) Pre-hydrate 25 lbs/bbl bentonite and allow to hydrate for 4-6 hours. Just prior to spud add filtered inlet water as required to yield a 50-70 sec/qt spud mud. 2) Drill hole. Drill to ±1100'. Use ail solids control equipment. Rais~ viscosity if gravel sections are encountered. Run 13-3/8 casing. 4) Evaluate quality of mud and if possible save the mud from well #52 and reuse it on well #53 in the 13-3/8" Casing Interval. Build additional volume as required. After the 13-3/8" on #53 reuse mud on the 13-3/8" and 9-5/8" Interval on #54. Then move back to #53 and use the mud in the 9-5/8" Interval. Then use the mud on #52 in the 9-5/8" Interval. DM-184 .WP (12/95) DEC--22--95 FR I 10 : 44 M-- I DR I LL I NG AK P. 0~ Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels Fluid Loss (API) P~ 8.8 - 9.4 ppg 45-100 se¢/qt 10-15 cps 10-30 #/100 ft~ 8-2O NO Control 8.5 - 9.5 Note: DO ~OT EXCEED M.A.C. of products or use products not approved in the discharge Permit. See letter requesting authorization for list of approved products and M.A.C. DM-184 .WP (iZ/95) DEC--22--95 FR I 10 : 44 M-- I DR I LL I NG AK P . 04 MUD TYPE MUD ADDITIVES POTENTIAL PROBLEMS UNOCAL GRANITE POINT PLATFORM ~ELLS %52, #53 ~_~U %54 ±iloo' - i3500' (#53) ~:lloo' ~:3500' (#54) i9oo, - +2700' (#52) 12-1/4" HOLE 9-5/8" CASING GENERIC HUD M-r GEL/M-I BAR/SODA ASH/ POLYPAC/SPERS ENE / XP'- 2 0 / SODIU~ BZCARSONAT~./ CAUSTIC HOLE CLEANING/TIGHT HOLE/BIT GUMBO CLAYS/HOLE ENLARGEMENT/GAS KICKS/ COAL SLOUGHING i) 2) 3) 4) 6) 7) TREATMENT PROCEDURES Use the surface mud from well ~53 to drill the 13-3/8" collar, cement and shoe. Treat this fluid as required to avoid excessive cement contamination. Build additional volume as required with prehydrated bentonite in fresh water and filtered inlet water. Pump viscous sweeps if required by hole conditions. Control density with barite, F.I.W. water, and solids control equipment. Dump all sand traps as required. Report drill solids analysis on mud check sheet. Report hydraulics calculations on mud check sheet. Use Defoam-X if foaming becomes a problem. Prehydrate all bentonite in freshwater. DM-184 .WP (12/95) DEC--22--95 FR I 10 : 44 M-- I ~R ILL I H~ AK P . O5 9) lo) Drill to T.D. If hole conditions warrant, spot a viscous pill on bottom. Run 9-5/8" casing. Evaluate quality of mud and save for reuse on 9-5/8" casing interval on wells ~53 and #§4. ANTICIPATED 9-5[8'~ MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels API Fluid Loss MBT Drilled Solids 9.0-9.6 ppg 40-70 sec/qt 10-15 cps 10-20 #/100ft' 6/12/18 NO CONTROL 8.5 - 11.0 < 30 ppb < 75 ppb Note: This mud program is a guideline only. Bole conditions should dictate actual mud properties. DO NOT EXCEED M.A.C. of products or use products not approved the discharge permit. See letter requesting authorization of list of approved products and M.A.C. DM-184 .WP (12/95) DEC--22--95 FRI 10:45 ~--I ~RILLING ~K P.06 DEPTH INTERVAL MUD TYPE MUD ADDITIVES VERSAWET/ POTENTIAL PROBLEMS CIRCULATION/WATER KICKS/HIGH GELS UNOCAL ORANITE POINT PLAT~OKM WELLS #52, #53 AND #54 #52 2700' - 11395' 8-1/2" 11395' - 14357' 6" ~53 3S00' - 12800' 6" 12800' - 15700' 6" #54 3500' - 12664' 8-1/2" 12664' - 15517' 6" MINEKAL OIL BASE VG-69/M-I Bar/CONOCO LVT2-/LOWATE VERSACOAT/ VERSAHRP/VERSAMOD/ALCO~ R 27%/LINE/CaCI= HOLE CLEANING/LOST TREATMENTS/PROCEDURES 1. Mix mineral oil mud system utilizing the following recommendations: Note: Initial volume from G.P. 22-13 will be approximately 800 bbls. Additional volume should be mixed as follows: a. Premix and store 10.8 ppg calcium chloride brine. b. Place mineral oil in clean mixing tank. c. Add VG-69 and lime slowly through shear pump to minimize balling. Shear for 30 minutes. d. Add primary emulsifier, versacoat. e. Blend for a minimum of 30 minutes. f. Add calcium chloride brine.g. Blend for a minimum of 30 minutes. h. Add Versawet/check theology/add Versamod. i. Add Barite to required mud weight. Anticipated mud weight in the 8-1/2" hole should be approximately 9.5 ppg. DM-184 .WP (12/95) JAN 1 6 1996, Alaska Oil a Gas C.~s, Commission An~rage ~EC--22--95 FR I 18 : 45 M-- I DR ILL I N~ AK P. 07 j. Blend fOr a minimum of 30 minutes. Note: The most important aspect in mixing a mineral oil mud is the amount of mixing energy put into the fluids while the brine is being added. The more shear put into the fluoid the smaller the water droplets become and the more viscous the fluid. The emulsions become more stable as more shear is put into the fluid. 2. Displacement Procedure Note: Use large mesh shaker screens (30 or 40) during displacement and for up to two circulations thereafter. Monitor pump strokes and pump rates continuously during displacement. a, Conduct a rig team meeting discussing all aspects of .displacement. Note: Rig operations should dictate optimum.displacement time. b~ Dilute and lower mud weight ofwater base mud. Pump a 75 bbl brineXCD polymer viscous sweep. Pump a 25 bbl mineral oil viscous sweep pill. Pump mineral oil mud system. c. Displace in turbulent flow if possible. d. Reciprocate and rotate drill pipe. Make sure the bit is on bottom as the spacers and mineral oil mud clear the bit. . Drill the 8-1/2 lateral section. If there are indications that a cuttings bed has been deposited in the wellbore, the most effective method to clean the cuttings bed is with mechanical agitation by rotating and reciprocating the drill string. Maintaining high low shear rate theologies will minimize the formation of a cuttings bed. Low shear rate theologies can be elevated with Versamod, Versa HRP, Al¢omer 274 .and VG-§9. If required, pump low/hi vi~cosity sweeps. · Optimize mixing of "dry jobs" in order to'minimize the number of wet trips. , After reaching TD, condition the hole for logging by rotating and reciprocating the drill string. If required, pump low/hi viscosity sweeps. 6. Run and cement the 7" liner. ~ Clean out 7" liner and drill 6" hole. Mud weights should be kept as low as possible. Centrifuge 8-1/2" hole mud and add Conoco LVT 200 to reduce mud weight. Conduct cost estimate prior to reducing mud weight. DM-184 .WP (~2/~5) DEC-- 22-- 95 F R I .~0 : 46 M-- I DR ILL I N ~ ~_gK P . 08 Maintain low .shear rate values with VG-69, Versamod, Alcomer 274 and Versa HRP. Run and cement 5" liner. · Displace well to diesel after running tubing. displacement procedure.) (See separate 10. Store mineral oil mud for use on next well in sequence. ANTICIPATED MUD PROPERTIES Mud Weight ppg 8.5 9.5 PV i2-20 25-35 YP 15-20 i5-20 Gels 10/25 10/40 o/w ~o/2o 80/20 E.S. 800+ 800+ BTBP @ 225° F 6 ce 6 ce LVT 200 bbl VG-69 ppb Lime ppb Versacoat ppb Versawet ppb Versamod ppb/Versa HRP/Alcomer 274 CaCI~ Barite/Lowate ppb Varies w/MW & OW ratio 5-8 2 4-6 1-2 0-1 34 As Required DM-184 .WP (12/95) FILL-UP KILL LINE ANNULAR BOP 13~s'3000 psi PIPE RAMS 13~/~'5000 psi BI2ND RAMS 13~"5000 psi ~{~~ SPOOL ~ 4" 5000 psi {I I{ 4" ~000 P~E ~S 13~5000 psi FLOW CHOKE LINE psi RISER 13 ~e" 5000 psi COOK INL ET PLATFORMS BOP STACK 13%' 5000 psi 6" - I§0 LB OH RI(; HEADER SECTION FRONT VIEW - 5000,' 5~' BUFFER !ANK FRONT VIEW TOP GAUGE & REI~OIE PANEL TRANSMITT£R IJA~E FLANGE BEHIND lEADER 3 ! 3A i 4, 1 5 2 7 8 I 9 1 10 2 ~ ~ 2 913.6" - 10,000# ~ 11 3 5 '- ,,my NPS f.%~;w bloc~, 4X4X3X3X2 Lee Lo~e~er - Unocal ~/24/95, pg2 11 3 15 17 1 18 8 19 23 JAN 1 6 Aia;k~ 0!1 & Ca~ Casing Design Summary Well: GP 52 Field: Granite Point Date: Casing Mud WT M.S.P. Size (PPG) (psi) 1/8/95 Design by: Mitchell Damm Max. Kick Tolerance (BBLS) 26" 8.8 17 13-3/8" 9 226 9-5/8" 9 694 7" 9 1,579 4-1,'2" 9 NA 146 81 40 316 NA *** Slotted Liner*** Casing Bottom Top Length Wt Size (FEET) (FEET) (FEET) (LB/FT) Grade Thread Connection 26" 329 47 282 TVD 329 47 282 ! 3-3/8" 900 47 853 68 Tx/T) 899 47 852 9-5/8" 2,700 47 2,653 47 TVD 2,699 47 2,652 -7" 11,395 47 11,348 29 'rVD 10,165 47 10,118 4-1/2" 14,357 11,195 3,162 12.6 TVD 10,965 10,015 ,, K-55 L-80 L-80 L-80 Buttress Buttress Buttress SC-Buttress Casing Weight Tension Minimum Size W/O BF Top of Strength TDF Section Tension (LBS) (LBS) (1,000/LBSD 13-3/8" 58,004 58,004 1,069 18.4 'Collapse Pressure #1 ~ Bottom (psi) 257 * Collapse Pressure #2 ~ Bottom (psi) Collapse **Burst Minimum Resist. CDF #1 CDF #2 Pressure Yield Tesnsion Strength (psi) (psi) (psO BDF 9-5/8" 124,691 124,691 1,086 8.7 NA 1,950 7.6 NA 1,350 3,450 2.6 7" 329,092 329,092 772 NA 4,760 6.2 NA 5 286 6,870 1.3 597 1.8 2,907 4,409 7,020 2.4 1.6 5,702 8,160 1.4 NA NA NA NA NA NA 4-1/2" 39,841 39,841 289 7.3 NA NA * Collapse pressures are calculated using two methods (checks). 1) Difference between two cement slurries (i.e. AVG of a 15.8 PPG (tail) & 14.2 PPG (lead) = 15 PPG. Subtract a mud of 9.5 PPG = 5.5 PPG = .286 psi~FT gradient X TVD of the casing string.) 2) Difference between Mud Weight on the outside and gas lift gas (0.0 psi/FT) on the inside. (i.e. Multiply (.052 X MW - 0.0 psi/FT) X the TVD of the Top of Cement. * * Burst pressure is calculated. (BliP ~ the depth of the next casing X TVD next casing) X (0.5 = half of weilbore evacuated. KTGP52.XLS 1/15/96 Maximum Surface Pressure Calculations Well: 52 Casing Size: 26" Depth Interval: 0'-900' Hole Size: 17.50 General Information: Anticipated Mud Wei~t (MW): 8.8 PPG Shoe Depth 0Z~ho~): 294 MD Estimated Fracture Gradient (at the Shoe): Total Depth (Dm): 900 MD Bottom Hole Pressure Gradient (BHPG): Gas Gradient (GG); (assumes worse case): Maximin Gas Column Height in wellbore when top of gas is at the shoe (Ht): 0.4576 psi/FT 294 TVD 0.90 psi/Fr 899 TVD 0.35 psi/FT 0.10 psi/FT 317 Feet anticipated Mud Weight) Maximum Surface Pressure Calculations: The wellbore volume is determined using the height of gas column m wellbore when top of gas bubble is at the shoe- during a gas kick situation. A percentage of the gas column height (Ht), found in the Maximum Kick Tolerance Calculations, is used. Maximum Surface Pressure = Maximum Bottom Hole Pressure - Hydrostatic Pressure (Gas Volume +Mud Volume) MSP = Proem- GG*Ht - .052*MW*(Dm-Ht) MSP = I7 psi Hydrostatic Pressure at the Shoe Calculations: The greatest hydrostatic pressure at the shoe (Pshoe) is when the gas bubble reaches the shoe. Assuming a constant bottom hole pressure is applied while circulating out the gas kick. A conservative estimate would be the maximum surface pressure plus the hydrostatic pressure at the Shoe Depth (Dshoe). Pmo~ = MSP + .052*?,gg*EM,,. Pshoe= 151 psi FP.~oe= 265 psi The pressure at the shoe (Pshoe) is less than the fracture pressure at the same shoe. Therefore the shoe integrity is sufficient to adequately handle a gas kick. Pressure Differential Across the Shoe: Pressure differential across the casing shoe = Pshoe - Maximum pore pressure at shoe DPshoe = Pshoe - Pmax ~ shoe = Pshoe - BHPG * D.ho~ DP shoe = 48 psi The DPshoe is less that the internal yield of the casing. KTGP52.XLS 26" MSP 1/8/96 Maximum Kick Tolerance Calculations Well: GP 52 Casing Shoe: 26" General Information Variables 1 26" Casing Shoe (from RT) 294 Feet (TVD) D,ho, 2 Fracture pressure Gradient 0.90 psi/FI' FPG 3 Fracture pressure at the 26" Shoe 265 psi FP,~,, 4 Proposed TD of the 13-3/8" Casing Shoe (TVD) 899 Feet (TVD) Dm 5 Pore pressure ~xadient 0.350 psi/Fr PpG 6 Maximum anticipated pore pressure ~ TD 315 psi Pm~om 7 Mud Wei~,ht See table PPG MW 8 Gas Gradient 0.10 psi/Er GG 9 Average open hole size 17.50 Inches ODo~ 10 Dfillpipo OD 5.00 Inches OD~ 11 Capacity of open hole by drillpipe 0.2731 BBIdFT CAP 10 Height of gas column in wellbore when top of gas is at the shoe HT Feet (TVD) Ht Assumptions for Granite Point Field: Fracture Pressure Gradient = .9 PSI/IZr. All calculations assume that water based mud is used and does not take into account gas solubility in oil based mud. i Gas bubble height in wellbore (Ht) calculation with gas bubble top at 26" shoe. FPshoe + Pgas bubble + Pmud = Pmax@ TD FP,~o, + GG*Ht + .052*MW*(Eh~Ht) = P~m Gas Volume (GV) calculation at 26" shoe. GV = CAP*Ht Kick Tolerance calculation: Gas volume in weilbore at TD. P1V1 = P2V2. Assume constant temperature. Kick Tolerance * P~,,4~ ~ = GV * Fl:' Mud Weight Gas Bubble Height Gas Volume ~ Shoe Kick Tolerance (PPG) (Feet) (BBLS) (BBLS) 7.0 645 176 148 7.2 643 176 148 7.4 642 175 147 7.6 640 175 147 7.8 639 175 147 8.0 638 174 147 8.2 637 174 146 8.4 636 174 146 8.6 635 173 146 8.8 634 173 146 9.0 633 173 145 9.2 633 173 145 9.4 632 173 145j 9.6 631 172 145 9.8 631 172 145 I0.0 630 172 145 10.2 629 172 145 10.4 629 172 144 10.6 628 172 144 10.8 628 171 144 11.0 627 171 144 ,JAN 1 6 1996 laska Oil & Gas Con~, C~omrnissior~ Anchorage KTGP52.XLS 1/8/96 Maximum Surface Pressure Calculations Well: 52 Casing Size: 13-3/8" Depth Interval: 0'-2,700' Hole Size: 12.25 General Information: Anticipated Mud Weight (MW): 9.0 PPG Shoe Depth (Dao,): 900 MD Estimated Fracture Gradient (at the Shoe): Total Depth (D'm): 2700 MD Bottom Hole Pressure Gradient (BffPG): Gas Gradient (GG); (assumes worse case): Maximum Gas Column Height in wellbore when top of gas is at the shoe (Ht): 0.468 psi/FT 899 TVD 0.85 psi/FT 2699 TVD 0.45 psi/FT 0.10 psiJFT 746 Feet (@ anticipated Mud Weight) Maximum Surface Pressure Calculations: The wellbore volume is determined using the height of gas column in wellbore when top of gas bubble is at the shoe- during a gas kick situation. A percentage of the gas column height (Ht), found in the Maximum Kick Tolerance Calculations, is used. Maximum Surface Pressure = Maximum Bottom Hole Pressure - Hydrostatic Pressure (Gas Volume +Mud Volume) MSP = Pm~gro- GG*Ht - .052*MW*(D'm-Ht) MSP = 226 psi Hydrostatic Pressure at the Shoe Calculations: The greatest hydrostatic pressure at the shoe (Pshoe) is when the gas bubble reaches the shoe. Assuming a constant bottom hole pressure is applied while ch-culating out the gas kick. A conservative estimate would be the maximum surface pressure plus the hydrostatic pressure at the Shoe Depth (Dshoe). P~ho, = MSP + .052*MW*Dao, Pshoe= 647 psi FP,hoe = 764 psi The pressure at the shoe (Pshoe) is less than the fracture pressure at the same shoe. Therefore the shoe integrity is sufficient to adequately handle a gas kick. Pressure Differential Across the Shoe: Pressure differential across the casing shoe = Pshoe - Maximum pore pressure at shoe DPshoe = Pshoe - Pmax ~ shoe = Pshoe - BffPG * Da,, DP shoe= 242 psi The DPshoe is less that the internal yield of the casing. KTGP52.XLS 13-38" MSP 1/15/96 Maximum Kick Tolerance Calculations Well: GP 52 Casing Shoe: 13-3/8" General Information Variables 1 13-3/8" Casing Shoe (from RT)+B6 899 Feet (TVD) 2 Fracture pressure Gradient 0.85 psi/FT FPG 3 Fracture pressure at the 26" Shoe 764 psi FPsho~ 4 Proposed TD of the 9-5/8" Casing Shoe ~,TVD) 2,699 Feet (TVD) Dm 5 Pore pressure gradient 0.450 psi/FT PpG 6 Maximum anticipated pore pressure ~ TD 1,215 psi Pm~m 7 Mud Weight See table PPG MW 8 Gas Gradient 0.10 psi/FT GG 9 Average open hole size 12.25 Inches ODo, 10 Drillpipe OD 5.00 Inches ODDP 11 Capacity of open hole by drillpipe 0.1214 BBL/FT CAP 12 Height of gas column in wellbore when top of gas is at the shoe HT Feet (TVD) Ht Assumptions for Granite Point Field: Fracture Pressure Gradient = .9 PSI/Fr. All calculations assume that water based mud is used and does not take into account gas solubility in oil based mud. Gas bubble height in wellbore (Ht) calculation with gas bubble top at 13-3/8" shoe. FPshoe + Pgas bubble + Proud = Pmax~ TD FPeo~ + GG*Ht + .052*MW*(DrD-~Ht) = Gas Volume (GV) calculation at 13-3/8" shoe. GV = CAP*Ht Kick Tolerance calculation: Gas volume in weilbore at TD. P1V1 = P2V2. Assume constant temperature. Kick Tolerance * Pm~ m = GV * FP ! Mud Weight Gas Bubble Height Gas Volume ~ Shoe Kick Tolerance (PPG) (Feet) (BBLS) (BBLS) 7.0 776 94 59 7.2 815 99 62 7.4 851 103 65 7.6 884 107 68 7.8 915 111 70 8.0 944 115 72 . 8.2 972 118 74 8.4 997 121 76 8.6 1,021 124 78 8.8 1,044 127 80 9.0 1,065 129 81 9.2 1,085 132 83 ., 9.4 1,105 134 84 9.6 1,123 136 86 9.8 1,140 138 87 10.0 1,156 140 88 10.2 1,172 142 90 10.4 1,187 144 91 10.6 1,201 146 9~ 10.8 1,214 147 93 11.0 1,227 149 94 KTGP52.XLS 1/15/96 Maximum Surface Pressure Calculations Well: 52 Casing Size: 9-5/8" Depth Interval: 0'-11,395' Hole Size: 8.50 " General Information: Anticipated Mud Weight (MW): 9.0 PPG Shoe Depth (Dm,: 2700 MD Estimated Fracture Gradient (at the Shoe): Total Depth (Dm): 11,395 MD Bottom Hole Pressure Gradient (BHPG): Gas Gradient (GG); (assumes worse case): Maximum Gas Column Height in wellbore when top of gas is at the shoe (Ht): 0.468 psi/FT 2699 TVD 0.85 psi/FT 10189 TVD 0.50 psi/FY 0.10 psi/Ir 1,000 Feet (@ anticipated Mud Weight) Maximum Surface Pressure Calculations: The wellbore volume is determined using the height of gas column in wellbore when top of gas bubble is at the shoe- during a gas kick situation. A percentage of the gas column height (Ht), found m the Maximum Kick Tolerance Calculations, is used. Maximum Surface Pressure = Maximum Bottom Hole Pressure - Hydrostatic Pressure (Gas Volume +Mud Volume) MSP = P~m- GG*Ht - .052*MW*(Dn>-Ht) MSP= 694 psi Hydrostatic Pressure at the Shoe Calculations: The greatest hydrostatic pressure at the shoe (Pshoe) is when the gas bubble reaches the shoe. Assuming a constant bottom hole pressure is applied while circulating out the gas kick. A conservative estimate would be the maximum surface pressure plus the hydrostatic pressure at the Shoe Depth (Dshoe). P~ho, = MSP + .052*MW*D~o, Pshoe = 1,957 psi FP,aoe = 2,294 psi The pressure at the shoe (Pshoe) is less than the fracture pressure at the same shoe. Therefore the shoe integrity is sufficient to adequately handle a gas kick. Pressure Differential Across the Shoe: Pressure differential across the casing shoe = Pshoe - Maximum pore pressure at shoe DPshoe = Pshoe - Pmax ~ shoe = Pshoe - BHPG * Eh~ DP shoe = 608 psi The DPshoe is less that the internal yield of the casing. KTGP52.XLS 9-58" MSP I/8/96 Maximum Kick Tolerance Calculations Well: GP 52 Casing Shoe: 9-5/8" General Information Variables 1 9-5/8" Casin~ Shoe (from RT) 2,699 Feet (TVD) 2 Fracture pressure Gradient 0.85 psi/FT FPG 3 Fracture pressure at the 9-5/8" Shoe 2,294 psi 4 Proposed TD of the 7" Casing Shoe (TVD) 10,189 Feet (TVD) Dm 5 Pore pressure ~radient 0.50 psi/FT PpG 6 Maximum anticipated pore pressure ~ TD 5,095 psi Pm~Om 7 Mud Wei~,ht See table PPG MW 8 Gas Gradient 0.10 psi/FT GG 9 Average open hole size 8.50 Inches ODo, 10 Ddllpipe OD 5.00 Inches OEk, 11 Capacity of open hole by drillpipe 0.0459 BBL/FT CAP 12 Height of gas column in wellbore when top of gas is at the shoe ItT Feet (TVD) Ht Assumptions for Granite Point Field: Fracture Pressure Gradient = .9 PSI/leT; and Maximum Pore Pressure Gradient = .52 PSI/FT. (GP 13-13; 1967) All calculations assume that water based mud is used and does not take into account gas solubility in oil based mud. Gas bubble height in weilbore (Ht) calculation with gas bubble top at 9-5/8" shoe. FPshoe + Pgas bubble + Pmud = Pmax~ TD FPeo~ + GG*Ht + .052*MW*(Dm-EMo,-Ht) = Pn~ Gas Volume (GV) calculation at 9-5/8" shoe. GV = CAP*Ht Kick Tolerance calculation: Gas volume in wellbore at TD. P1V1 = P2V2. Assume constant temperature. Kick Tolerance * P~O m = GV * FP Mud Weight Gas Bubble Height Gas Volume ~ Shoe Kick Tolerance (PPG) (Feet) (BBLS) (BBLS) 7.0 (280) (13) (6)~ 7.2 14 1 0 7.4 287 13 6 7.6 541 25 11 7.8 777 36 16 8.0 998 46 21 8.2 1,205 55 25 8.4 1,399 64 29 8.6 1,582 73 33 8.8 1,754 80 36 9.0 1,916 88 40 9.2 2,069 95 43 9.4 2,214 102 46 9.6 2,351 108 49 9.8 2,482 114 51 10.0 2,606 120 54 10.2 2,724 125 56 10.4 2,836 130 59 10.6 2,944 135 61 10.8 3,046 140 63 11.0 3,144 144 65 KTGP52.XLS 1/8/96 Maximum Surface Pressure Calculations Well: 52 Casing Size: 7" Depth Interval: 0'-14,357' Hole Size: 6.00 " General Information: Anticipated Mud Weight (MW): 9.0 PPG Shoe Depth (D~o~): 11,395 MD Estimated Fracture Gradient (at the Shoe): Total Depth (Dm): 14,357 MD Bottom Hole Pressure Gradient (BHPG): Gas Gradient (GG); (assumes worse case): Maximum Gas Column Height in wellbore when top of gas is at the shoe (Fit): 0.468 psi/FT 10189 TVD 0.85 psi/FT 10965 TVD 0.52 psi/FT 0.10 psi/FT 2,741 Feet (@ anticipated Mud Weight) Maximum Surface Pressure Calculations: The wellbore volume is determined using the height of gas column in wellbore when top of gas bubble is at the shoe- during a gas kick situation, A lx-rcentage of the gas column height (Ht), found in the Maximum Kick Tolerance Calculations, is used. Maximum Surface Pressure = Maximum Bottom Hole Pressure - Hydrostatic Pressure (Gas Volume +Mud Volume) MSP = Pm~'rD-GG*Ht - .052*MW*(Dm-Ht) . MSP -- 1,579 psi Hydrostatic Pressure at the Shoe Calculations: The greatest hydrostatic pressure at the shoe (Pshoe) is when the gas bubble reaches the shoe. Assuming a constant bottom hole pressure is applied while circulating out the gas kick. A conservative estimate would be the maximum mrface pressure plus the hydrostatic pressure at the Shoe Depth (Dshoe). Pa~ = MSP + .052*MW*D,~o, Pshoe= 6,347 psi FP,~oe= 8661 psi The pressure at the shoe (Pshoe) is less than the fracture pressure at the same shoe. Therefore the shoe integrity is sufficient to adequately handle a gas kick. Pressure Differential Across the Shoe: Pressure differential across the casing shoe = Pshoe - Maximum pore pressure at shoe DPshoe = Pshoe - Pmax ~ shoe = Pshoe - BHPG * DP shoe = 1,049 psi The DPshoe is less that the internal yield of the casing. KTGP52.XLS 7" MSP 1/8/96 Maximum KiCk Tolerance Calculations Well: GP 52 Casing Shoe: 7" General Information Variables 1 7" Casinl~ Shoe (from RT) 10,189 Feet (TVD) 2 Fracture pressure Gradient 0.85 psi/FT FPG 3 Fracture pressure at the 7" Shoe 8,661 psi 4 Proposed TD of the 4-1/2" Casing Shoe (TVD) 10,965 Feet (TVD) Dm 5 Pore pressure ~7~adient 0.52 psi/FT PpG 6 Maximum anticipated pore pressure @ TD 5,702 psi P~u~o 7 Mud Wei~rht See table PPG MW 8 Gas Gradient 0.10 psi/FT . GG 9 Average open hole size 6.00 Inches ODo. 10 DrillpipeOD 3.50 Inches ODr, 11 Capacity ofopan hole by drillpipe 0.0231 BBL/FT CAP 12 Height of gas column in wellbore when top of gas is at the shoe lit Feet (TVD) Ht Assumptions for Granite Point Field: Fracture Pressure Gradient = .9 PSl/Fr; and Maximum Pore Pressure Gradient = .52 PSI/FT. (GP 13-13; 1967) All calculations assume that water based mud is used and does not take into account gas solubility in oil based mud. Gas bubble height in weilbore Cltt) calculation with gas bubble top at 7" shoe. FPshoe + Pgas bubble + Pmud = Pmax@ TI) FP,~o~ + GG*Ht + .052*MW*(Dm-IX~-Ht) = Gas Volume (GV) Calculation at 7" shoe. GV = CAP*Ht Kick Tolerance calculation: Gas volume in wellbore at TD. P1 V1 = P2V2. Assume constant temperature. Kick Tolerance * P~ m = GV * FP Mud Weight Gas Bubble Height Gas Volume ~ Shoe Kick Tolerance (PPG) (Feet) (BBLS) (BBLS) 7.0 12,278 283 430 7.2 11,842 273 415 7.4 11,438 264 401 7.6 11,062 255 387 7.8 10,712 247 375 8.0 10,385 239 364 8.2 10,079 232 353 8.4 9,792 226 343 8.6 9,522 220 333 8.8 9,267 214 325 9.0 9,027 208 316 9.2 8,800 203 308 9.4 8,586 198 301 9.6 8,382 193 294 9.8 8,189 189 287 10.0 8,006 185 280 10.2 7,831 181 274 10.4 7,664 177 268 10.6 7,506 173 263 10.8 7,354 170 ~iZ~l~ 11.0 7,209 166 253 KTGP52.XLS 1/8/96 Fracture Pressure Data Granite Point Field Platform Well Date Casing Frac Csg Shoe EMW Notes Size Gradient Depth PPG Psi/ft. TVD GPP 11-13rd 2/14/92 9-5/8" 0.96 9,966 18.4 GPP 51 8/7/92 13-3/8" 1 3,803 19.2 GPP 51 7/28/92 18-5/8" 0.87 1,010 16.8 GPP 51 8/25/92 9-5/8" 1.05 9,592 20.2 GPP 50 5/27/92 18-5/8" 0.911 982 17.5: GPP 50 6/4/92 13-3/8" 0.84 4,208 16.2 GPP 50 6/27/92 9-5/8" 0.931 9,877 17.9! Anna 1 lrd 10/23/94 13-3/8" 0.89 2,976 17.2 Anna llrd 11/11/94 9-5/8" 0.92 8,750 17.7 * Anna 3rd 12/10/94 9-5/8" 0.75 7,839 14.5 Anna 50 2/8/95 18-5/8" 1.38 1,160 26.6 Anna 50 2/13/95 13-3/8" 1.01 4,251 19.5 Anna 50 3/8/95 9-5/8" 0.86 9,844 16.5 Anna 51 1/29/95 18-5/8" 1.36 1,130 26.2 Anna 51 5/15/95 13-3/8" 0.71 3,796 13.6 Anna 51 6/3/95 9-5/8" 0.88 9,842 17 * Anna 52 2/3/95 18-5/8" 1.41 1,153 27 Anna 52 3/27/95 13-3/8" 0.84 3,940 16.15 Anna 52 4/15/95 9-5/8" 0.91 9,470 17.6 * Anna 7rd2 8/25/95 9-5/8" 0.96 4,439 18.5 Anna 7rd2 9/6/95 7" 0.82 9,589 15.8 Notes: All fracture gradients reported have been corrected for air and water gaps. * Indicates a (FIT)-Formation Integrity Test was achieved, not actual leak off. FRACDATA.XLS 1/4/96 Granite Point Field Fracture Gradient Data 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 0 0.2 0.4 0.6 0.8 1 1.6 Fracture Gradient (PSI/FT) Alaska Oil & Gas Cons, Commission Anchorage FRACDATA. XLS 1/4/96 Unocal Energy Resour 3ivision Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL Alaska January 16, 1995 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 GRANITE POINT #52 PERMIT TO DRILL ADL 18761 Dear Mr. Johnston: Enclosed in triplicate is our application for Permit to Drill Granite Point #52 (form 10- 401) pursuant to 20 AAC 25.005 and our check No. 2000026 in the amount of $100.00 as required under 20 AAC 25.005 (c)(1). If you require additional information, please contact me at (907) 263-7623 or Mitch Damm, Drilling Department at (907) 263-7679. We appreciate your review and trust the enclosed is satisfactory. Very truly yours, Roxanne M. Sinz Enclosures JAPl t 6 Naska Oil & Gas Cons. commission wELL PERMIT CHECKLIST FI -LD OOL GEOL AREA , /~::7T ,/~--~ ,-~h--., PROGRAM: exp [] dev., redrll [] aery [] Z~_C~ UNIT# ~ /~: ON/OFF SHORE__ 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.. N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party ............. - N 10. Operator has appropriate bond in force ........ ' N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ....... N REMARKS 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ....... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed. 23. If diverter required, is it adequate....... · · . 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate .................... 26. BOPE press rating adequate; test to ~~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ...... 29. Is presence of H2S gas probable ............. GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y .N/.__ 31. Data presented on potential overpressure zones ..... Y/( ~ 32 Seismic analysis of shallow gas zones .......... ;/N ~)~ ~. 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . . //. Y N [exploratory only] ~ GEOLOGY: ENGINEERING: COMMI SS ION: Comments/Instructions: .,~ HOW/lib - A:\FORMS~cheklist rev 11/95