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Home My WebLink About195-1131. 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: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12,900 N/A Casing Collapse Structural Conductor 520psi Surface 1,130psi Intermediate 3,090psi Production 7,020psi Liner 7,250psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Eric Dickerman Contact Email:Eric.Dickerman@hilcorp.com Contact Phone:(907) 564-4061 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Repair Tubing 11/10/2025 12,880'2,242' 2-7/8" & 2-3/8" 10,157' See schematic See schematic 10,846' Perforation Depth MD (ft): 4,647' 10,810 - 12,767 10,846' 5" 9,868 - 9,910 9,591'7" 90' 30" 20" 13-3/8" 623' 9-5/8"4,647' 2,040' MD 5,750psi 1,530psi 2,730psi 623' 2,001' 4,421' 623' 2,040' Length Size Proposed Pools: 90' 90' L-80 TVD Burst 10,370 & 10,374 8,160psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018742 195-113 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20012-02-22 Hilcorp Alaska, LLC Granite Pt St 18742 07RD2 AOGCC USE ONLY 8,290psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY N/A Granite Pt Middle Kenai Oil Same 10,162 12,786 10,135 330psi N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:04 am, Oct 27, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.10.27 09:12:12 - 05'00' Dan Marlowe (1267) 325-666 MGR31OCT25 10-404 00 * BOPE test to 2500 psi. 48 hour notice. DSR-10/30/25TS 10/28/25JLC 10/31/2025 10/31/25 Tubing Repair Well: AN-07RD2 Well Name:AN-07RD2 API Number:50-733-20012-02-00 Current Status:Offline, Jet Pump Producer Leg:Leg 1 (N corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:195-113 First Call Engineer:Eric Dickerman (907) 564-4061 (o) Second Call Engineer:Casey Morse (907) 777-8322 (o) Maximum Expected BHP:1,305 psi at 9,750 tvd Static bottomhole pressure survey 5/26/25 0.134 psi/ft, 2.6 ppg EMW Max. Potential Surface Pressure:330 psi 0.1 psi/ft gas gradient to surface Brief Well Summary AN-07RD2 is a dual string jet pump producer completed in the Granite Point Middle Kenai Oil Pool. The RD2 was drilled and completed in September 1995 as a reverse flow jet pump producer (power oil down casing, commingled power oil and formation fluid up tubing). The jet pump became stuck and the well was worked over and converted to a dual string jet pump completion in October 1997. The well has been a steady producer since that time. In Q2 2025 the power fluid rate began to increase down the long string and well was shut in to diagnose a suspected shallow tubing leak. A leak detection log was performed on 6/1/25 and indicated a leak long string leak close to surface pointing towards either a wellhead leak or a shallow tubing leak. On 10/14/25, a TWC was set and the tree passed a pressure test, indicating the leak is most likely at one of the pup joints below the tubing hanger. In researching when the tubing was ran, none of the five hanger pups were made up with power tongs. Objective: Replace the long string tubing hanger pups to restore tubing integrity. Notes on wellbore condition: 08/1995 -09/1995: Drill AN-07RD2 Run 3-1/2 jet pump completion. 7 casing test passed 3,000 psi 9/18/1995. 10/1997: RWO to pull 3-1/2 jet pump completion with stuck jet pump. Replaced with dual string jet pump completion. 03/01/2009: Anna platform shut in for Mt. Redoubt eruption. 07/30/2014: No flow test passed. 04/02/2025: Would not come back online after platform shutdown. 06/01/2025: Leak Detection Log indicated shallow leak in the longstring. 10/14/2025: TWC set and the wellhead and tree passed a 5,000 psi pressure test. Indicates long string tubing leak below hanger. Tubing Repair Well: AN-07RD2 Pre-rig Procedure: 1. MIRU Slickline. 2. Set standing valve in the 3-1/2 R Nipple at 10,545. 3. Pressure test the wellbore to 1,500 psi (CMIT-TxIA). Proposed RWO Procedure: 4. MIRU casing jacks, work platform, and 404 auxillary equipment (pits, pump, choke manifold, etc). 5. Confirm well is dead. Well is a closed system with the standing valve at 10,545. a. Work over fluid will be diesel (6.8ppg) if the fluid is expected to contact formation, otherwise water (8.33 ppg) will be used. 6. Set BPV/TWC, ND tree, NU 13-5/8 BOP stack. b. Top down: annular, Dual Fixed Flex 2-3/8 3-1/2 pipe rams, Blinds, Flow cross. c. Notify AOGCC 48 hours in advance for witness. d. Test to 250 psi Low / 2,500 psi High / 2,500 psi Annular. e. Submit completed 10-424 within 5 days of BOPE Test. f. BOPE will be used as needed to circulate the well. 7. Pull BPV/TWC. 8. MU landing joints or spear. BOLDS. Pull hangers to floor. Expected PUWs are 145k # from running tally. 9. Lay down the 2-7/8 long string hanger pups to the first full tubing joint, and 2-3/8 short string to match. a. Long string tally top down: i. Hanger ii. 1.50 2-7/8 pup joint iii. 5.05 2-7/8 pup joint iv. 5.10 2-7/8 pup joint v. 8.20 2-7/8 pup joint vi. 8.10 2-7/8 pup joint vii. 32.06 2-7/8 full joint b. Short String tally top down: i. Hanger ii. 0.50 2-3/8 pup joint iii. 30.32 2-3/8 full joint 10. RU slickline to the long string. 11. Set a standing valve in the jet pump cavity. 12. Perform a bundle test (MIT-T) to 1,500 psi on a chart. If bundle test fails, plan to re-land hangers, RDMO, then work a different repair option (separate sundry): 13. Pull the standing valve from the jet pump cavity. 14. RD Slickline. 15. Reland the hangers, proceed to step Step 22, to begin the RDMO process. Notify AOGCC 48 hours in advance for witness. Tubing Repair Well: AN-07RD2 If the bundle test passes: 16. Pull the standing valve from the jet pump cavity. 17. RD Slickline. 18. Make up new 2-7/8 and 2-3/8 hanger pup joints and confirm space out. 19. RU eline to the long string. 20. Drift through the seal assembly/PBR area. Log CCL across the seal assembly/PBR area to confirm seals are stung in. 21. RD Eline. 22. Re-land the long string and short string hangers. RILDS. 23. Set BPV/TWC. 24. ND BOPE. 25. NU tree and test. 26. Pull BPV/TWC. 27. RDMO. Operations: 28. Test SVS system within five days of returning well to service. Attachments: 1. Current Wellbore Schematic (schematic will remain the same after operation) 2. Wellhead Diagram 3. BOP Drawing 4. Fluid flow diagram 5. Sundry Change Form _____________________________________________________________________________________ Updated By: JLL 10/23/25 SCHEMATIC Anna Platform Well: An-07RD2 PTD: 195-113 API: 50-733-20012-02-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 30 Structural Surface 90 20 85 & 94 H-40 19.124 Surface 623 13-3/8 54.5 J-55 BTC 12.615 Surface 2,040 9-5/8 40 & 43.5 N-80 & S-95 BTC 8.755 Surface 4,647 7 29 L-80 BTC 6.184 Surface 10,846 5 15 L-80 BTC TKC 4.408 10,638 12,880 TUBING DETAIL 2-7/8 6.4 L-80 BTC SC 2.441 0 10,370 2-3/8 4.6 L-80 BTC SC 1.995 0 10,374 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 50.3 50.3 2.5 7.06 WGPC ERC Dual 2-9/16 Tubing Hanger Half 2 10,370 9,255 2.5 3.22 2-7/8 Buttress Box x 2-7/8, EUE 8 rd Pin Crossover 3 10,371 9,256 2.5 2.87 2-7/8, 6.5#, L-80, EUE 8 rd Pup 4 10,381 9,264 2.25 5.62 Kobe 2-1/2 Type A Single Parallel Cavity 5 10,428 9,299 2.44 2.87 2-7/8, 6.4#, L-80, Perforated Pup 6 10,469 9,330 2.18 3.5 HES R Landing Nipple 7 10,478 9,336 2.44 2.87 2-7/8, 6.4#, L-80, Perforated Pup 8 10,486 9,342 2.99 4.41 Locator, 12.98 Seal Assembly 9 10,482 9,339 4.00 5.45 HES Upper PBR Assembly 10 10,501 9,354 2.99 4.5 HES Seal Anchor 11 10,501 9,354 3.25 5.93 Halliburton HVT Packer 12 10,545' 9,386 2.56 4.25 HES R Nipple 13 10,609 9,432 2.99 4.42 Wireline Entry Guide Short String A 50.3 50.3 2.03 7.06 WGPC ERC Dual 2-1/16 Tubing Hanger Half B 10,374 9,258 1.62 2.7 1-1/4, 10rd Pin x 2-3/8 Buttress Box Crossover C 10,375 9,259 1.37 1.66 1-1/4, 10rd Pup Joint PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status C-5 10,810' 10,871' 9,868 9,606 61' 9/16/1995 Open C-5 10,904' 11,090' 9,625 9,719 186' 9/16/1995 Open C-5 11,123' 11,152' 9,733 9,744 29' 9/16/1995 Open C-5 11,185' 11,215' 9,756 9,766 30' 9/16/1995 Open C-5 11,248' 11,277' 9,778 9,787 29' 9/16/1995 Open C-5 11,310' 11,340' 9,797 9,805 30' 9/16/1995 Open C-5 11,373' 11,402' 9,814 9,822 29' 9/16/1995 Open C-5 11,435' 11,527' 9,831 9,852 92' 9/16/1995 Open C-5 11,561' 12,767' 9,859 9,910 1,206' 9/16/1995 Open PBTD =12,786 TD = 12,900 Max Hole Angle = 80° RKB to TBG Head = 50.3 Rig 428 1 3 5 4 9 7 6 2 8 C5 10 11 A B C 12 13 R R 12/20/05: Tagged up at 11230 w/ 1.90 GR. Anna Platform An-07RD Current 10/14/2025 Casing spool, OCT-22, 21 ¼ 2M X 13 5/8 3M, w/ 2- 2 1/16 5M EFO, 00 bottom prep Casing head, OCT-22, 21 ¼ 2M X SOW, w/ 2- 2 1/16 2M EFO Tubing head, Wood Group TC-60, 11 5M x 7 1/16 5M, w/ 2-2 1/16 5M SSO, w/ BG bottom 20' 13 5/8' Casing Spool, CIW-WF, 13 5/8 3M x 11 5M, w/ 2- 2 1/16 5M SSO, X bottom prep 7' 2 7/8' 9 5/8' BHTA, Dual-CIW pocket 7 1/16 5M FE w/ 2 3/8 8rd top x 2 7/8 8rd top 3 3 35/64 centers 2 3/8' Tubing hanger WGPC-TC60, 7 1/16 x 2 7/8 EUE 8rd bottom x 2 7/8 NU lift, 2 3/8 EUE bottom X 2 3/8 NU lift 3 35/64 centers 2 ½ x 2' CIW BPV preps Anna Platform AN-7 20 x 13 3/8 x 9 5/8 x 7 x 2 7/8 x 2 3/8 7 1/16 5M Composite Block Dual WKM-M tree assy Single master 3 35/64 centers Long string test against Hanger neck good to 5000psi 10/14/25 AN-07RD2 BOP Stack 13 5/8 5M Shaffer 4.67' CIW-U 13 5/8-5000 Blind Rams 3.74' 2.00'13 5/8- 5000 Choke and Kill Valves 2 1/16 5M w/ Unibolt connections for hoses Riser, 13 5/8 5M FE X 13 5/8 5M FE Variable 2 7/8-5 and 2 3/8 rams 2.00' DSA, 13 5/8 5M x 7 1/16 5M Hydril Dual Fixed Flex 2-3/83-1/2 Pipe Rams Choke and Kill line valves 2-1/16 5M 4.54 2.26 2-3/8" - 2-7/8" Pipe Rams - mgr Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: Granite Pt St 18742 07RD2 (PTD 195-113)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC 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 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/18/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250618 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN 07RD2 50733200120200 195113 6/1/2025 AK E-LINE LDL AN 24RD 50733202850100 207170 6/1/2025 AK E-LINE LDL BRU 221-24 50283202020000 225027 5/29/2025 AK E-LINE CBL KALOTSA 10 50133207320000 224147 5/21/2025 AK E-LINE Perf KALOTSA 2 50133206590000 216155 5/25/2025 AK E-LINE Perf PAXTON 11 50133207040000 221114 5/27/2025 AK E-LINE Perf PAXTON 11 50133207040000 221114 5/26/2025 AK E-LINE Perf PBU 06-12C 50029204560300 225022 5/17/2025 HALLIBURTON RBT-COILFLAG PBU 15-32C 50029224620300 217104 5/27/2025 HALLIBURTON RBT PBU D-01B 50029200540200 224155 5/18/2025 BAKER MRPM PBU D-01B 50029200540200 224155 5/18/2025 HALLIBURTON RBT-COILFLAG PBU H-18A 50029208800100 224011 5/14/2025 BAKER MRPM PBU H-18A 50029208800100 224011 5/14/2025 HALLIBURTON RBT-COILFLAG PBU L-109 50029230460000 201201 5/24/2025 HALLIBURTON IPROF PBU L-115 50029230350000 201140 5/19/2025 HALLIBURTON IPROF PBU L-117 50029230390000 201167 5/30/2025 HALLIBURTON IPROF PBU N-07B 50029201370200 223122 6/7/2025 HALLIBURTON RBT PBU S-100A 50029229620100 224083 5/26/2025 HALLIBURTON PPROF-LDL PBU Z-34 50029234690000 212061 5/17/2025 HALLIBURTON IPROF-LDL Please include current contact information if different from above. T40566 T40567 T40568 T40569 T40570 T40571 T40571 T40572 T40573 T40574 T40574 T40575 T40575 T40576 T40577 T40578 T40579 T40580 T40581 AN 07RD2 50733200120200 195113 6/1/2025 AK E-LINE LDL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.18 12:03:53 -08'00' c:CO~i~,lvi.DOC P E F.:~ B'1 1 T D A T A 9 B .... J i ~ ~ '::' 0 G C C ., L.. 4.680--- i 2r,,}(.~0 01/ 'J 2,/'q~6 ! 0 .... .'.:. 0 7 R COkiPl...ETZON [)ATE ~//'~/' DAZL. Y WELl.,. OF'S A r" e d r' y Was i:he wel 1 :~r'~ v,!8'j J d'itch sarnpies r"equ'~r"ed? COt Les-ks r"equ.'~r'ed?.~/es.. n cornp'i'iance Z n 'l' 't ~' a 1 C 0 H H E N T S ~on Unocal Energy Resource., 909 West 9th, P.O. BOX 1 Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 263-7828 UNOr. Debra Childers Clerk DATA TRANSMITTAL 96- 1 Janua~ 11,1996 To: From: Larry Grant Debra Childers 3001 Porcupine 909 W. 9th Avenue Anchorage, AK 99501 Alaska Oil & Gas Anchorage, AK 99519-6247 Unocal Swanson River 242-16 blueline/sepia Thermal decay time log Granite Point 18742-7RD #2 blueline/sepia Mudlog Granite Point 22-13 RD blueline/sepia Phasor Induction/Sonic/GR Granite Point 22-13 RD blueline/sepia Mudlog Granite Point 22-13 RD tape/listing LIS tape RECEIVED JAN 12 1996 Please acknowledge receipt by sig.ning and retuming one copy of this transmittal or FAX to (907) 263-7828. I Received by: Date: ...... ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COwlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well Oil [] Gas [] Suspended [] Abandonment [] Service [] 2. Name of Operator 7. Permit Number UNION OIL COMPANY OF CALIFORNIA (UNOCAL) !~ 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 ~~~. 2,02 4. Location of well at surface Leg 1, Slot 3, Anna Platform ~. 9. Unit or~e/'a~/i(I,~'n~__~.~, 727' FNL, 631' FEL, Sec. 12, T10N, R12W, SM ;'~'cTii .:':- i:'i !.i ;' 'i, Granite Point'l:~l.,¢ At top of productive interval ·,,, ,~..,~.....,..,~' '.-, ,-. ~ 10. Well Number 1039' FSL, 2623' FWL, Sec. 6, T10N, R11W, SM (10796' MD) r--,/7/~-~-~c'-~--Z~_, i 7RD2 At total depth~ .,,_~ VF?.~*-`r:,',, ,,~.~,;¢ 11. Field and Pool 1788' FSL, 808' FEL, Sec. 6, T10N, R11W, SM (12900' MD) ; ---,4"~'-<~ .... 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Granite Point Field 127' KB MSLI ADL 18742 Middle Kenai "C" Sand 12. Date Spudded I 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 8/25/95I 9/13/95[ 9/18/95 77 ft. MSLI 1 17. T°tal Depth (MD + TVD)112900'/10160' 18. 12786'/10133'Plug Back Depth (MD + TVD)I]19' Directional SurveYYes [] No [] 20. Depth where SSSV set I 21.N/A Thickness of Permafrost 22. Type of Electric or Other Logs Run None as per Bob Crandle 23. CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" I 85/94 H-40 0' 623' Existing csg 1285 sx -0- 13-3/8" 54.5 J-55 O' 2044' Existing csg 1200 sx -0- 9-5/8 I 40/43.5/47 I N80/595 0' 4647' Existing csg 3000 sx -0- 7"I 29I LB0 0' 10846' 8-1/2" 546 sx -0- 5" 15 LB0 10638' 12880' 6" 317 sx -0- 24. Perforations open to Production (MD + 'rVD of Top and Bottom and 25. TUBING RECORD interval, size and number) 3 3/8" 6 JSPF Size I Depth Set (MD) t Packer Set (MD) MD ME) TVD TVD 3 1/2" 9.2# 1-80I 0-10505' IHVT PKR (i~ 10505 10810'-10871' 11435'-11527' 9567'-9604' 9829'-9850' I I 10904'-11090' 11561'-12767' 9623'-9717' 9858'-10128' 26. Acid, Fracture, Cement Squeeze, Etc. 11123'-11152' 9732'-9743' Depth Interval (MD) Amount & Kind of Material Used 11185'-11215' 9754'-9765' NONE 11248'-11277' 9776'-9786' 11310'-11340' 9795'-9804' 11373'-11402' 9813'-9821' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 9/20/95 Jet Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE-SIZEI GAS-OIL RATIO 9/29/95 8 TEST PERIOD '-) 97 70 4 -J 733 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 80 80 24-HOUR RATE --) 292 208 12 41 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. 0CT 2 ~ 1995 AtaSk~ Uii & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUTED ON REVERSE SIDE ~29. 30. ~ GEOLOGIC MARKERS FORMATION TEST NAME Include interval tested, pressure data, all fluids recovered and gravity, MI~AS. DEPTH TRUE VERT. DEPTH TM17 Marker 6034 5778 Top GP Sds 9832 8848 Top C-3 Sand 10229 9147 Top C-5 Sand 10747 ~' 9527 31. LIST OF ATTACHMENTS 32. I hereby ce ,rtr~y, thc, t the f,of~g~ng~s truet,~correct to the best of my knowledge Signed G. Russell Schmidt Title Drillin~ Mana~ler Date Oct. 23, 1995 INSTRUCTIONS General: This form is designed for submitting a complete and correct well complete report and log on on all types of lands and leases in Alaska. Item 1' Classificaiton of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5 Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage T Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If not cores taken, indicate "none". ANNA PLATFORM WELL # 7 RD 2 GRANrm POINT (GP) COMPLETION 9/18/95 HYDRAULIC JET PUMP FREE COMPLETION 1) 3-1/2" 9.2# L-80 SCBT ~ 0-10505' 2) Hydraulic jet pump ~ 10390' 3) HES "HVT" 7" Packer @ 10505' 4) "R" Profile Nipple ~ 10545' 5) End of Packer Assembly ~ 10610' RKB = 127' 30" structural Casing ~ 290' RKB (86'BML) 20" 85# & 94# H-40 Surface Casing ~ 623' ~' 13-3/8" 54.5# J-55 Intermediate Casing ~ 2040' 9-5/8" 40# / 43.5# / 47# N80 / S95 BTC Intermediate Casing ~ 4647' TOL ~ 10638' 29# L-80 BTC Production Casing ~ 10846' TYONEK C-5 PERFORATIONS MEASURED 10810'-10871' 10904'-11090' 11123'-11152' 11185'-11215' 11248'-11277' 11310'-11340' 11373'-11402' 11435'-11527' 11561'-12767' TVD 9567'-9604' '9623'-9717' 9732'-9743' 9754'-9765' 9776'-9786' 9795'-9804' 9813'-9821' 9829'-9850' 9858'-10128' 5" 15# L80 BTC Liner 10638' - 12900' DAY 10-12 (08/25-27/95) CLEANOUT CMT F/4185'-4500'. TEST CSG TO 3000 PSI, OK. CLEANOUT CMT F/4500'-4680'. CBU, POH. RIH W/8-1/2" MOTOR ASSBY. DRILL 8-1/2" HOLE F/4680'-4734'. CONDUCT LOT. 17.8 PPG EMW. DRILL 8-1/2" HOLE F/4734'-6079'. POH. TEST BOP. RIH W/8- 1/2" MOTOR ASSBY. DRILL 8-1/2" HOLE F/6079'-6232'. DAY 13 (08/28/95) DRILL 8-1/2" HOLE F/6232'-6977'. HOLE NOT BUILDING ANGLE AS REQUIRED. POH. SET AKO TO 1.25. DAY 14 (08/29~95) RIH W/8-1/2" MOTOR ASSBY. DRILL 8-1/2" HOLE F/6977'-7690'. DAY 15 (08/30/95) DRILL 8-1/2" HOLE F/7690'-8223'. BHP INCREASE. CIRC BTMS UP. POOH, TIGHT @ 7385', 7355' AND 5539'. RUBBER IN FLOAT. M/U BHA #5. RIH W/8-1/2" MOTOR ASSBY. DAY 16 (08/31/95) CONT RIH. REAM THRU TIGHT SPOTS AS REQUIRED. DRILL 8-1/2" HOLE F/8223' 0 9153'. DAY 17-20 (09/01-04/95) DRILL 8-1/2" HOLE F/9153' - 9685'. POH F/BIT. RIH W/8-1/2" MOTOR ASSBY. DRILL 8-1/2" HOLE F/9685'-10868'. MADE WIPER TRIP. IN CORRECT FILL UP. WEIGHTED UP TO 9.8 PPG. POH F/CSG. RIH WI7" CSG. WORK CSG TO 10846'. DAY 21 (09/05/95) CCH F/CMT. CMT 7" CSG W/546 SX CMT. CIP @ 0300. TEST CSG TO 4800 PSI, OK. SET SLIPS. ND BOP, NU TBG SPOOL. NU & TEST BOP. RIH W/6" MOTOR ASSBY. PU 3-1/2" DP. OCT 2 0 !995 Alask~ Oil & Gas Coils. Commission Anchorage DAY 22 (09/06/95) FINISH PU 3-1/2" DP. CLEAN OUT CMT F/10651'-10830'. TEST CSG TO 3000 PSI, OK. CLEANOUT CMT TO 10868'. DRILL 8-1/2" HOLE F/10868'-10878'. CONDUCT FIT. 15.8 PPG EMW. MWD FAILED. POH & CHANGE OUT SAME. RIH WI6" MOTOR ASSBY. DRILL 8-1/2" HOLE F/10878'-11011' DAY 23 (09/07/95) DRILL 6" HOLE Fl11011'-11041'. MOTOR BEGAN STALLING. POH TO CHECK BHA. TIH WI6" MOTOR ASSBY. DRILL 6" HOLE Fl11041'- 11068'. LOST MWD. POH. MWD PLUGGED W/SOLIDS. RIHW/6" MOTOR ASSBY DAY 24-26 (09/08-10/95) FINISH IN HOLE WI6" MOTOR ASSBY. CLEAN PITS WHILE TIH. DRILL 6" HOLE Fl11068'-11512'. POH F/BIT. RIH W/MOTOR ASSBY. DRILL 6" HOLE Fl11512'-11733'. POH F/BIT. RIH W/MOTOR ASSBY. DRILL 6" HOLE Fl11733'-11948'. DAY 27 (09/11/95) POH F/BIT. RIH W/MOTOR ASSBY. DRILL 6" HOLE Fl11946'-12291' POH F/BIT. DAY 28 (09/12/95) RIH W/MOTOR ASSBY. DRILL 6" HOLE F/11946'-12607'. POH F/BIT. RIH. DAY 29 (09/13/95) RIH WI6" MOTOR ASSBY. SET DOWN @ 11671', HUNG UP. JAR LOOSE. CONTINUE IN HOLE. DRILL 6" HOLE F/12607'-12900' TD. ST TO CSG SHOE, TIGHT HOLE AT INTERVALS. RIH TO TD, ClRC CLEAN. POOH. DAY 30 (09/14/95) RU & RIH WI5", 15#, L80 LINER TO 12,880', UNABLE TO REACH TD. M&P 65 BBLS OF 15.8 PPG CMT, BUMPED PLUGS CIP AT 1730 HRS. HANGER SET DURING CMT JOB. REL F/HGR & SET LINER TOP PKR. PU REV OUT 14 BBLS CMT. POOH. DAY 31-33 (09/15-17/95) POOH W/LINER RUNNING TOOL, CHANGE BOP RAMS AND TEST BOP'S. RIH W/TANDEM SCRAPERS AND 4-1/8" MILL TAG CEMENT STRINGER AT 12678' CLEAN OUT LINER TO 12786'. TEST LINER TO 3500 PSI. CHANGE WELL OVER FROM MUD TO DIESEL. POOH LAY DOWN EXCESS DRILL PIPE. RIH W/TUBING CONVEYED PERFORATING ASSEMBLY, SET PACKER. W/2000 PSI HYDROSTATIC PRESSURE ON ZONE. DROP BAR AND PERFORATED THE TYONEK C-5 FROM 10810' TO 12767', GROSS INTERVAL, 1694' NET. FLUID LEVEL DROPPED FROM 4400' TO 4700' AFTER PERFORATING. UNSET PACKER HOLE TAKING + 40 BBLS/HR OF DIESEL. POOH W/GUN ASSY ALL SHOTS FIRED. RIH W/3-1/2" SINGLE COMPLETION. SET PACKER AT 10505'. TEST PACKER TO 3000 PSI. DAY 34 (09/18-95) PULL TUBING FREE OF PACKER SPACE OUT LAND TUBING. TEST ANNULUS TO 3000 PSI. RETRIEVE DUMMY PUMP. N/D BOP. NU TREE. RUN KOBE PUMP AND STANDING VALVE. L/D 3-1/2" D.P. PULL PUMP PLUGGED WITH SCALE FROM TUBING. RAN BACK SAME. SKID RIG FROM WELL 7RD TO 3RD FINAL REPORT. OCT Alaska Uil & Gas Cons. Commissien Anchorage UNOCAL ANNA Platform 7 Rd#2 slot #1-3 Granite Point Field Cook Inlet, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : PMSS <4791 - 12900'> Our ref : svy5031 License : Date printed : 27-Sep-95 Date created : 27-Aug-95 Last revised : 14-Sep-95 Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 58 44.738,w151 18 33.113 Slot location is n60 58 37.569,w151 18 45.900 Slot Grid coordinates are N 2551414.020, E 266820.951 Slot local coordinates are 728.00 S 631.00 W Reference North is True North Gas Cons. Commission Anci~orage UNOCAL ANNA Platform, 7 Rd#2 Granite Point Field,Cook Inlet, Alaska Measured Depth Inc[in. Azimuth True Vert. Degrees Degrees Depth 4700.00 18.75 29.00 4469.68 4791.00 18.92 28.85 4555.81 4886.00 16.88 26.50 4646.21 4977.00 17.26 25.00 4733.20 5074.00 15.56 20.56 4826.25 SURVEY LISTING Page 1 Your ref : PMSS <4791 - 12900'> Last revised : 14-Sep-95 R E C T A N G U L A R Dogleg Vert C 0 0 R D ! N A T E S Deg/100Ft Sect 5166.00 5271.00 5354.00 5447.00 5541.00 13.83 19.81 4915.24 11.77 16.70 5017.62 9.48 15.41 5099.19 7.67 11.81 5191.15 5.40 2.59 5284.54 1042.74 N 696.17 E 1.42 1095.04 1068.46 N 710.38 E 0.19 1119.41 1094.29 N 723.97 E 2.28 1143.28 1118.35 N 735.57 E 0.64 1164.58 1143.58 N 746.22 E 2.18 1185.56 5635.00 5729.00 5820.00 5913.00 6038.00 3.56 0.81 5378.24 2.28 5.68 5472.12 1.25 9.52 5563.08 0.37 266.89 5656.07 1.58 262.26 5781.05 1165.48 N 754.28 E 1.89 1202.72 1187.55 N 761.61 E 2.07 1219.31 1202.25 N 765.86 E 2.77 1229.79 1215.71 N 769.17 E 2.03 1238.87 1226.27 N 770.65 E 2.65 1245.01 1233.60 N 770.89 E 1.96 1248.57 1238.38 N 771.12 E 1.38 1250.95 1241.16 N 771.46 E 1.14 1252.52 1242.15 N 771.33 E 1.48 1252.85 1241.89 N 769.22 E 0.97 1250.86 6101.00 6194.00 6288. O0 6363. O0 6476. O0 2.64 270.47 5844.00 2.48 277.05 5936.91 1.83 286.96 6030.84 1.55 328.83 6105.82 3.26 1.59 6218.72 1241.79 N 766.91 E 1.74 1248.75 1242.05 N 762.77 E 0.36 1245.19 1242.74 N 759.31 E 0.79 1242.43 1243.96 N 757.64 E 1.65 1241.50 1248.48 N 756.94 E 1.88 1242.93 6567.00 6658.00 6753.00 6846.00 6940.00 5.16 25.25 6309.47 7.21 44.47 6399.95 7.90 56.34 6494.13 9.35 73.41 6586.09 11.58 75.87 6678.52 1254.77 N 758.76 E 2.79 1247.42 1262.54 N 764.51 E 3.17 1256.08 1270.42 N 774.12 E 1.79 1268.22 1276.12 N 786.68 E 3.15 1282.00 1280.60 N 803.15 E 2.42 1298.70 7057.00 17.01 67.06 6791.87 7125.00 18.96 66.57 6856.54 7218.00 22.73 67.91 6943.44 7312.00 27.00 71.97 7028.71 7407.00 29.93 74.78 7112.22 1290.15 N 830.32 E 4.99 1327.24 1298.42 N 849.62 E 2.88 1348.18 1311.19 N 880.14 E 4.08 1381.17 1324.63 N 917.28 E 4.89 1420.35 1337.53 N 960.66 E 3.39 1464.85 7500.00 32.09 7594.00 35.76 7686.00 39.55 7779.00 42.02 7875.00 45.16 75.65 7191.93 77.79 7269.92 80.20 7342.74 78.53 7413.16 76.78 7482.68 1349.74 N 1006.99 E 2.37 1511.65 1361.74 N 1058.04 E 4.10 1562.56 1372.42 N 1113.20 E 4.42 1616.52 1383.65 N 1172.90 E 2.90 1674.76 1397.83 N 1237.54 E 3.50 1738.76 7945.00 46.46 8019.00 47.04 8089.00 47.92 8250.00 47.40 8343.00 47.91 8436.00 47.91 8528.00 48.33 8623.00 48.34 8718.00 49.10 8812.00 47.90 8906.00 45.73 8998.00 45.41 9092.00 46.17 9184.00 44.43 9277.00 44.15 76.83 7531.47 78.62 7582.18 81.35 7629.49 82.83 7737.93 81.69 7800.58 81.35 7862.92 80.89 7924.33 81.37 7987.49 81.01 8050.16 80.17 8112.45 1409.28 N 1286.40 E 1.86 1787.47 1420.74 N 1339.07 E 1.93 1839.57 1429.70 N 1389.86 E 3.14 1888.86 1446.08 N 1507.73 E 0.75 2001.24 1455.34 N 1575.84 E 1.06 2066.07 79.82 8176.77 1521.38 N 1989.39 E 2.32 2464.24 79.58 8241.18 1533.13 N 2054.03 E 0.39 2527.13 79.57 8306.72 1545.32 N 2120.29 E 0.81 2591.66 79.53 8371.43 1557.18 N 2184.60 E 1.89 2654.31 79.40 8438.00 1569.05 N 2248.45 E 0.32 2716.54 1465.52 N 1644.10 E 0.27 2131.46 1476.10 N 1711.77 E 0.59 2196.52 ©CT P ..i~ ,7 1487.04 N 1781.89 E 0.38 2263.91 ..... 1497.97 N 1852.44 E 0.85 2331.69 1509.48 N 1921.90 E 1.44 2398.75 Ataska Oi~ & Gas Cons. C0mmJssi0n All data is in feet unless otherwise stated Coordinates from slot #1-3 and TVD from wellhead (127.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 62.87 degrees. Declination is 22.84 degrees, Convergence is -1.14 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL ANNA Platform, 7 Rd#2 Granite Point Field,Cook Inlet, Alaska SURVEY LISTING Page 2 Your ref : PMSS <4791 - 12900'> Last revised : 14-Sep-95 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 9370.00 42.79 79.37 8505.49 1580.84 N 2311.33 E 1.46 2777.88 9464.00 43.79 79.46 8573.92 1592.68 N 2374.69 E 1.06 2839.67 9559.00 42.82 79.27 8643.05 1604.70 N 2438.73 E 1.03 2902.15 9646.00 41.80 81.17 8707.39 1614.66 N 2496.43 E 1.88 2958.04 9729.00 41.31 80.48 8769.50 1623.44 N 2550.78 E 0.81 3010.42 9822.00 41.18 80.42 8839.42 1633.61 N 2611.25 E 0.15 3068.87 9915.00 41.34 80.29 8909.33 1643.88 N 2671.71 E 0.20 3127.37 10007.00 41.04 81.28 8978.57 1653.59 N 2731.52 E 0.78 3185.02 10101.00 41.51 80.21 9049.21 1663.56 N 2792.72 E 0.90 3244.04 10195.00 39.81 79.20 9120.52 1674.50 N 2852.97 E 1.94 3302.65 10286.00 40.22 78.10 9190.22 1686.02 N 2910.34 E 0.90 3358.96 10382.00 41.20 77.48 9262.98 1699.26 N 2971.54 E 1.10 3419.46 10476.00 41.77 77.64 9333.40 1712.68 N 3032.34 E 0.62 3479.70 10569.00 42.63 76.61 9402.30 1726.60 N 3093.24 E 1.19 3540.24 10660.00 46.25 76.54 9467.26 1741.39 N 3155.20 E 3.98 3602.13 10755.00 49.06 75.95 9531.24 1758.09 N 3223.39 E 2.99 3670.44 10796.00 50.49 75.49 9557.72 1765.81 N 3253.73 E 3.59 3700.96 10862.00 51.60 74.80 9599.22 1778.97 N 3303.33 E 1.87 3751.11 10953.00 58.40 72.90 9651.38 1799.74 N 3374.87 E 7.66 3824.25 11046.00 61.50 72.10 9697.95 1823.96 N 3451.64 E 3.42 3903.61 11138.00 66.90 71.87 9737.98 1849.57 N 3530.37 E 5.87 3985.36 11264.00 72.50 68.66 9781.68 1889.50 N 3641.52 E 5.04 4102.50 11355.00 73.90 67.32 9807.98 1922.15 N 3722.28 E 2.09 4189.26 11445.00 75.10 67.57 9832.04 1955.42 N 3802.38 E 1.36 4275.71 11506.00 78.90 68.00 9845.75 1977.88 N 3857.39 E 6.27 4334.92 11598.00 76.00 66.25 9865.74 2012.78 N 3940.12 E 3.66 4424.46 11691.00 75.90 66.00 9888.32 2049.30 N 4022.62 E 0.28 4514.53 11783.00 72.80 65.57 9913.14 2085.62 N 4103.40 E 3.40 4602.99 11875.00 73.60 65.20 9939.73 2122.31 N 4183.47 E 0.95 4690.98 11967.00 79.70 64.98 9960.96 2160.00 N 4264.62 E 6.63 4780.39 12060.00 80.70 65.80 9976.79 2198.16 N 4347.94 E 1.38 4871.94 12154.00 78.70 65.30 9993.60 2236.43 N 4432.13 E 2.19 4964.32 12245.00 78.90 65.50 10011.27 2273.59 N 4513.29 E 0.31 5053.50 12339.00 79.20 66.74 10029.13 2310.95 N 4597.68 E 1.33 5145.64 12433.00 76.60 67.60 10048.83 2346.62 N 4682.38 E 2.91 5237.28 12526.00 76.10 67.90 10070.78 2380.83 N 4766.02 E 0.62 5327.33 12561.00 76.20 68.30 10079.16 2393.51N 4797.55 E 1.14 5361.17 12900.00 76.20 68.30 10160.02 2515.24 N 5103.44 E 0.00 5688.91 Projected Data - NO SURVEY All data is in feet unless otherwise stated Coordinates from slot #1-3 and TVD from wellhead (127.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 62.87 degrees. Declination is 22.84 degrees, Convergence is -1.14 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL ANNA Platform,7 Rd#2 6ranite Point Field,Cook Inlet, Alaska MD TVD Rectangular Coords. SURVEY LISTING Page 3 Your ref : PMSS <4791 - 12900'> Last revised : 14-Sep-95 Comments in wellpath Comment 12900.00 10160.02 2515.24 N 5103.44 E Projected Data - NO SURVEY Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOW 4669.00 4440.36 1033.97N 691.24E 9 5/8" Casing 0.00 0.00 O.OON O.OOW 10846.00 9589.25 1775.71N 3291.25E 7" Casing 0.00 0.00 O.OON 0.00~ 12900.00 10160.02 2515.24N 5103.44E 5" Liner Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised C-5 Exit Rvsd 7-Jul- 272060.000,2553840.000,0.000010227.00 2530.27N 5189.73E 18-May-95 T/C-5 Rvsd 7-Jul-95 270260.000,2553090.000,0.00009627.00 1744.43N 3405.01E 18-May-95 All data is in feet unless otherwise stated Coordinates from slot #1-3 and TVD from wellhead (127.00 Ft above mean sea level). Bottom hole distance is 5689.59 on azimuth 63.76 degrees from wellhead. Vertical section Ts from wellhead on azimuth 62.87 degrees. Dec[inat|on is 22.84 degrees, Conver~eri~e is -1.14 degrees, Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MEMORANDbM TO: David Johns_~, Chairmarr~'~~ :State of Alaska Alaska Oil and Gas Conservation Commission DATE: August 27, 1995 THRU: Blair Wondzell, ~ FILE NO: - P. I. Supervisor g('c_e FROM: Jerry Herring ¢~4~.~ SUBJECT: Petroleum I nCpecto~ ao9khlcd.doc BOPE Test, Pool Rig 428 Granite Point State 7RD2 PTD 95-113 Sunday, August 27, 1995: I traveled to Unocal's Anna Platform and witnessed a BOPE test on Pool Rig 428 completing a redriil on well 7RD2. The BOPE test report is attached for reference. I arrived on the platform at 5:30 PM on the previous day and drilling was underway. A walk-through was complet, ed and I found the rig to be in excellent condition. The BOPE test began at 2:00 PM and lasted for 2-1/2 hours. There were no failures. Tool Pusher John McCoy did an excellent job conducting the test. Summary: I witnessed a BOPE test on Unocal's Anna Platform, Pool Rig 428. The test lasted 2-1/2 hours and there were no failures. Attachment: ao9kh 1 cd.xls C: Don Byrne / Evan Harness- Unocal STATE OF ALASKA OIL .-~ND GAS CONSERVATION COMMIS& BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Pool Arctic Alaska Rig No. Operator: Unocal Well Name: Anna - Granite Point State 7RD2 Casing Size: 9-5/8" Set @ 4669' Test: Initial Weekly X Other 428 PTD # Rep.: Rig Rep.: Location: Sec. 95-113 DATE: Rig Ph.# 8/27/95 776-6627 Don Byrne John McCoy 12 T. 10N R. 12W Meridian SM TEST DATA MISC. INSPECTIONS: Location Gen.: EX. Housekeeping: EX. (Gen) PTD # OK Standing Orders Posted YES BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign NO Drl. Rig EX. Hazard Sec. OK Test Quan. Pressure P/F 1 300 / 3,500 P 1 30015,000 P 1 300~5,000 P 1 300~5,000 P I 30015,000 P 2 300/5,000 P 1 30015,000 P n/a n/a n/a MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Methane Gas Det. OK OK H2S Detectors OK OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. 2 Test Pressure P/F 300 / 5,000 P 300~5,000 300~5,000 300~5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 16 Test Pressure P/F 300 / 5,000 P 48 300~5,000 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2,950 P 1,650 P 0 minutes 30 2 minutes 15 OK Remote: Twelve Bottles 2,200 (AVE.) Psig. sec. sec. OK TEST RESULTS Number of Failures 0 Test Time 2.so Hours Number of valves tested 25 Repair or Replacement of Failed Equipment will be made within n/a days. Notify the Inspector and follow with Written or Faxed verification to :he AOGCC Commission Office at: Fax No. 276-754-2. The AOGCC phone number is 279-1433. REMARKS: Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: (Rev. 8/95) AO9KH1CD.XLS TONY KNOWLE$, GOVERNOR ALAS~ OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 3, 1995 G. Russell Schmidt, Drilling Manager Union Oil Company of California (UNOCAL) P O Box 196247 Anchorage, AK 99519 Re: Granite Pt Field 7RD2 UNOCAL Permit No. 95-113 Surf Loc 727'FNL, 631'FEL, Sec 12, T10N, R12W, SM Btmhole Loc 1803'FSL, 721'FEL, Sec 6, T10N, R11W, SM Dear Mr Schmidt: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. 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. BY ORDER OF THE COMMISSION dlflencI c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALAS ........ OIL AND GAS CONSERVATION Ci -'iMiSSION PERMIT TO DRILL 20 AAC 25.OO5 i la. Type of work Drill ~ Redrill ~ 1 lb. Type of we~. Re-Entry ~] Deepen ~] Service ,,_-- i2. Name ct Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 196247, Anchoraae, AK 99519 4. Lccation et well at surface Leg 1, Slot 3, Anna Platform 727' FNL 631' FEL, Sec. 12, T10N, R12W, SM At top of productive interval 1017' FSL 2506' FEL, Sec 6, T10N, R11W, SM At total deptll 803' FSL 721' FEL, Sec. 6, T10N. R11W, SM 12. Distance to nearest 113. Distance to nearest we4 property line I 5800 feet i 1400 (Anna37) feet 16. To be completed for deviated wells Kickoff depth 5000 feet Maximum hole anqle 87 de.q 18. Casing program Exploratory ~ Stratigraptqic Test I-] Development Oil Development Gas [] Single Zone.l--J Multiple Zone 5. Datum Elevation (DF or KB) 127' KB MSL feet 6. Property Designation ADL 18742 7. Unit or property name Granite Pt Field 8. Well number 7RD2 9. Approximate spud date 8/15/95 14. Number of acres in property 5060 10. Field and Pool Granite Point Field Middle Kenai "C" Sands 11. Type Bond ~SE~ ao~cc2s.~ AK Statewide Oil & Gas Bond Number U62-9269 Amount $200,000 15. Proposed depth ~v~,,~ ~ 12900/10227 feet 4602 pw 17. Anticipated Pressure(,m a~A~C Z~.03.~(~(a) Maximum lurface 844 psi~ At total dep ~h {'f~ Settin,q Depth Bottom MD ! TVD 623 [623' 2040' I 2000' 4647' I 4419' 10828'1 9627' 12900'I 10227' Quantity of cement (include stage data) 1285 sx 1200 sx 3(X)0 sx 600 sx 350 sx ' Hole Casing Weight IGradeiCoupiing Len_mn ', MD D E;dsfing 13-3/8 54.5 ij55 2040' 0 Existinc~ 9-5/8" 40/4,3.5/47N80/S915 4647' 0 8-1/2" 7" 29 LB01 BTC 10828' 0 6' 5" 15 , 1_80I BTC 2300' 10600' J 9457] 19. To be completed for Rec¥ill, Re-entry, and Deepen Operations Present well condition summary Total depth: measure(3 10225' feet Plugs (measured) true vertical 9772' feet Effective depth: measured 10063' feet Junk (measured) true vert~_.al 9612' feet l\\~sV, a 0il & Ancherr Casing Length Size Cemented Measured depth True vertical depth StructLral Co~cluctor 623' 20' 1285 sx 623' 623' Surface 2040' 13-3/8" ]200 sx 2040' 2000' Intermediate 4647' 9-5/8' 3000 sx 4647' 4419' Production 7141' ~. 2050 sx 7141' 6743' Liner 3054' 5" 368 sx' 7141 '- 10195' 6743'-9743' Perforation depth: measured See attached true vertical See attached 20. Attachments Filing fee ~ Property plat ~ BOP Sketch~ Diverter Sketch [~ Drilling program ~: Drilling fluid p(ogr .a~,'"n E~; Time vs,,depth plot i'__X RefraC~on analysis E~ Seabed report E] 20 AAC 25.050 requirements E~ 21. I hereby c~j't~/that the~loree(]mg J~t[u~d ccrrect to the best of my knowledge ;:t 1'..,~,k~t Signed 'G. RUSSELLSCHMIDT T~tle DRILLING MANAGER Date 07/18/95 Com~ssion Use Only Permit Number Conditions of approval Samples required ,,~ Yes ~ No Mud logrequired [-] Yes ~] No Hyclrccjen sulfide measures ~ Yes [-] No DirectionaJ survey required .~ Yes ~ No Rea. uired working pressure for BOPE ~ 2M: [-] 3U; ~ 5M; ~ 10M; [-] 15M O~er:. Original Signed By by the order of ApFoved by David, W. Johnston Commissioner the commission Form 10-401 Rev. 12-1-85 i50-/2'~._~..-,~-. 4:~<:~/2_.-o 2_. At)pr .- See cover letter for other requirements Submit in triplicate 5099 A{} + ~BP f,060 ,~,C ~ PERFORATION DATA SltEET PRIOR TO ABANDONMENT GP 18742 NO. 7RD 6/30/95 MEASURED DEPTH (FEET) 8980-9035 TRUE VERTICAL DEPTH 8532-8587 9040-9070 8592-8622 9085-9115 8636-8667 9123-9135 8675-8687 9211-9270 8763-8821 9286-9375 9593-9610 8837-8926 9145-9162 9655-9715 9206-9266 9790-9845 9340-9395 9855-9885 9405-9435 10045-10060 9595-9609 Anna Well #7 RD2 July 17, 1995 Drillin~ Hazards: Lost circulation zones: None Low pressure zones: None Over pressured zones: None Shallow gas zones: None Tim. e Est. .25 .25 .5 .75 .5 1.25 .25 1.5 .25 1.75 .25 2 .25 2.25 .5 2.75 .25 3 .25 3.25 .25 3.5 .5 4 .5 4.5 11 15.5 1.5 17 11 28 2.25 30.25 2 32.25 3 35.25 .5 35.75 3 38.75 Preliminary Procedure: 1. MIRU, Leg #1, Conductor #3. 2. Establish injection rate and pressure. If rate is above 2 BPM and pressure is below 3000 psi then perform step 2a - 2f, otherwise go to step 3. La. Set BPV. ND well head and NU and test BOP. 2b. PU tubing and remove hanger. 2c. Sting out of packer, circulate well clean and sting back into packer. Re-establish inject/on rate and pressure checking for seal integrity. 2c[ Sting out of packer and spot 100 sx cement to end of tubing. Sting into packer and squeeze cement into peris 9211' - 10060', flushing to 9150'. WOC. 2e. Cut tubing ~ 9120'. 2f. Go to step 6. 3. Set wide range tubing plug in robing ~ 9130'. Pressure test tubing to 3500 psi. RIH with tubing cumer and cut 3-1/2" tubing ~ +/- 9120'. Circulate well with FIW. 4. Set BPV. ND well head and NU and test BOP. 5. PU robing and remove hanger. 6. Lay cement abandonment plug #1 f/9120'-8543' (50 sxs). 7. Lay cement abandonment plug #2 f/7250'-6931' (50 sx), POH LD 3-1/2" tubing. 8. RIH w/6' bit and 7" casing scraper.- Tag plug #2. 9. RIH and set F_,ZSV inside 7" casing ~ 5150'. 10. RU to cut 7" casing. 11. RIH and cut 7' casing ~ 5000'. 12. Pull 5000' ofT' casing from wellbore. 13. Place top cement abandonment plug f/5150'-4450'. Top of plug 100' inside surfac~ casing. Have enough excess cement to squeeze surface casing shoe. Ct-> 14. Directionally drill 8-1/2' hole f/4647'-10828'. 15. Run and cement 7" casing 10828' .... 16. Directionally drill 6' hole f/10828' - 12900' 17. Run and cement 5" liner 10600' - 12900'.. 18. RIH and cleanout 5" liner, change over to completion fluid. 19. RIH w/PBR and single tbg completion. 20. Set BPV. Nipple down BOP's. Install wellhead. 21. RIH w/coiled tbg jet pump. ANNA 7 RD 2 DEPTH VS. DAYS DEPTH '~0 5 !0 !5 20 25 30 35 ,~0 4,5 50 DAYS FLOW ~----~ ANNULAR BOP ~ 27a'3000 psi f , _:IPE RAMS ~ '2~.§"5000 psi ' Y~.b'5000 ~sl · ' DRILLING', !,_~ KILL .,-r-...i~/-'~' SPOOL ~ ~1~/7] LINE ~~> ~.~.2~sooo p~ CHOKE 4" 5000 psi 4" 5000 psi :!PE RAMS 5/8"5000 psi LINE RISER , 5000 . o . · · COOK INLpEET PLATFORMS- BO .. STACK 13 %" 5'000 psi ~FT Ar 40 PSI I0' VENT Bt INI~ IIIIFI '" . ADJ. EIiOKE'- t~ tftJl~ Co~ffiE'CIION UL~ C~$ 5FPF/7~ I !0' IflO lb FI,,4HC, E · · g' I~1~I~ REII/RN lINE COOK cook #JILI PAA RIO Structure : ANNA Platform Well : 7Rd#2 F'ield : Granite Point Field Location : Cook Inlet, Alaska WELL PROFILE DATA Point .... ~O Inc Oir ,",'~ North £cst Deg/I O0! 5000 18,50 28.00 4755 1129 745 0.00! f Drop 5925 O.O0 0.OO 566~ 1259 ~,I 4 2.001 6200 0.00 0.00 5937 1259 514 0.O0l f I~iid 758~ 41.65 79.39 72,3~ 1348 1289 3.001 10828 41.65 79.39 9627 1744 3405 0.00! f l~iid 11369 77.56 64.86 9898 1895 ~7 7.O0l 12900 77.56 64.86 10227 2530 .",gO 0.001 _ Scale 1 · 200.00 la.aorta ~. I[t 4.00 400 800 1200 1600 560O 5950 65OO 755O 5.0O 8.00 9.00 \ ]0150_J 105001 i I 1 I I I i I Easf > 20~O 2400 2800 3200 3500 4000 444X) ~800 5200 5600 I ; i I I I I I I I I I I ~ I I I I I C-5 ~~ ~~-g5 _2800 _2400 - _2000 -- _1600 - _~20o - iC, reoted by :jones IDate I~otted : I 1-Ju1-95 Plot Re/emnc~ is 7 Rd ~2 Version 114. ICoor, inotes are in feet reference stat True Ver~Jcol Depths ore reference weat~eod. = I 700 1050 1400 1750 2100 245-.' 2800 .,t:50 3500 3850 4200 4550 4900 5250 5600 5950 Sccie 1 ' 175.00 Vertical Section on 62.87 azimum wifh reference 0.00 N, 0.00 E from sial #1-$ Anna Platform Well# 7RD 2 Pressure Calculations Anna Platform Well # 7 RD 2 Gmmm Point (GP) July 17, 1995 Hole Section I 4647'-10828' 8-1/2" hole size 9-5/8" casing to 4647' Mud weight: Shoe depth (9-5/8"): Est. framsm gradient of 9-5/8' shoe: Depth of next hole section (8-1/2"): BlIP gradient: Gas gradient (assume worst case): 9.4 pp~.49 psi/it 4647' MD/4419' TVD 0.80 psi/R 10828' MD/9627' TVD 0.45 psi/it 0.0 psi/fl Gas kick situation in wellbore. Assume 3/4 mud & 1/4 gas. MSP=BHP - Hydrostatic Pressure MSP=BHI:' - (3/4 mud + 1/4 gas) MSP---(9627'x.45 psi/fl) - ((.75(9627'x0.49 psi/fl)) + (.25(9627'x0.0 psi/fi))) MSP=- 794 psi Therefore, the hydrostatic pressure at the 9-5/8" shoe (Hpsh) is the greatest when the gas (kick) bubble reache~ the 9-5/8" shoe, if a constant BHP is applied. A conservative estimate would be the MSP plus the hydrostatic pressure at the 9-5/8" casing depth (Htx:sg). Hpsh= MSP + Hpcsg Hpsh= 794 + (4419'x0.49 psi/R) HPsh= 2959 psi This (Hpsh = 2959 psi) is less than the fracture pressure at the same shoe (Fpsh) and thus adequate to handle the well kick scenario. Hpsh = 2959 psi < Fpsh = 0.80 psi/fl x 4419' = 3535 psi. Hole Section 2 Depth Interval: 10828'-12900' 6" hole siz~ 7' casing to 10828' Mud weight: Shoe depth (7"): Est. fracture gradient of 9-5/8" shoe: Dcpth of next bolo section (6"): BlIP gradient: Gas gradient (assume worst case): 9.4 ppg=0.49 psi/~ 10828' MD/9627' TVD 0.80 psi/R 12900' MD/10227' TVD 0.45 psi/fl 0.0 psi/it Anna Platform Well # 7 RD 2 Pressure Calculations Gas kick situation in wellbore. Assume 3/4 mud & 1/4 gas. MSP=BHP - H,vdrostatic Pressure MSP=-BI-IP - (3/4 mud + 1/4 gas) MSP--(10227'x.45 psi/fO - ((.75(10227'x0.49 psi/fO) + (.25(10227'x0.0 psi/fO)) MSP=- 844 psi Therefore, the hydrostatic pressure at the 7" shoe (Hpsh) is the greatest when the gas (kick) bubble reaches the 7" shoe, if a constant BHP is applied. A conservative estimate would be the MSP plus the · hydrostatic pressure at the 7" casing depth (I-Ipcsg). Hpsh-- MSP + Htx~g Hpsh-- 844 + (10227'x0.49 psi/fl) I-IPsh-- 5855 psi This (Hpsh = 5855 psi) is less than the fracture pressure at the same shoe (Fpsh) and thus adequate to handle the well kick scenario. Hpsh = 5855 psi < Fpsh = 0.80 psi/It x 10227' = 8182 psi. Well # Date Baker Platform Ba 28 Ba 30 Ba 30 Ba 28 Ba 29 Ba 29 Ba 30 Ba 28 Leak Off Test (LOT) Data Cook Inlet, Alaska Revised June 3, 1995 Grayling Platform G-40 G-40 Unocal Energy Resources Alaska Monopod Platform Csg Size Sho~ Depth Fra~ 6rad. (TV'D) (psi/ft.) , 10-10-93 24' 802' 0.94 18.10 10-24-93 24' 803' 0.83 15.90 1 0-28-93 18-5/8' 2011' 0.94 18.10 11-17-93 18-5/8' 2135' 0.75 14.50 12-1%94 18-5/8' 2054' 0.76 14.61 12-29-93 13-3/8' 5869' 0.85 16.33 01-27-94 13-3/8' 5467' 0.93 17.96 03-01-94 13-3/8' 3509' 0.75 14.40 01-24-90 A-ltd 04-04-91 A-8rd 07-01-89 A-20rd 03-30-90 A-20rd 04-13-90 A-28rd 11-20-89 A-28rd 11-27-89 Granite Point Platform 11-13rd 02-14-92 51 08-07-92 51 07-28-92 51 08-25-92 50 05-27-92 50 06-04-92 50 06-2%92 16' 1926' 0.96 18.46 13-3/8' - 4977' 0.86 16.54 9-5/8' 1132' 1.07 20.57 9-5/8' 3760' 1.02 19.61 13-3/8' 755' 0.95 18.20 9-5/8' 1931' 0.85 16.30 20' 240' 0.75 14.42 13 -3/8' 1140' 0.97 18.65 9-5/8' 9966' 0.96 18.40 1%3/8' 3803' 1.00 19.20 18-5/8' 1010' 0.87 16.80 9-5/8" 9592' 1.05 20.20 18-5/8' 982' 0.91 17.50 13-3/8' 4208' 0.84 16.20 9-5/8' 9877'. 0.93 17.90 Dill, gn Platform 1.12 0.82 NA 1.01 0.83 1.02 0.80 16 04-22-94 18-5/8' 1131' 16 06-16-94 13-3/8" 3640' 16 07-04-94 9-5/8" 9469' 17 04-27-94 18-5/8' 1142' 17 05-01-94 13-3/8' 3560' 17 05- 9-5/8' 9213' 18 07-26-94 18-5/8" 1132' 18 08-01-94 13-3/8" 3988' 21.72 15.80 14.2 (FIT) 19.47 15.90 16.S (Frr) 19.63 15.3 Leak OffTcst (I~ Data Page 2 Ann~ Platform. 11 rd 10-23-94 13-3/8" 2976' 1 ltd 11-11-94 9-5/8" 8750' 3rd 12~10/94 9-5/8" 7839' 50 2/8/95 18-5/8" 1160' 50 2/13/95 13-3/8" 4251 50 3/8195 9-5/8" 9844' 51 1/29/95 18-5/8" 1130' 51 5/15/95 13-3/8' 3796' 51 6/3195 9-5/8" 9942' 52 2/3/95 18-518' 1153' 52 3/27195 13-3/8" 3 940' 52 4/15/95 9-5/8" 9470' Note~. All fram~ gradients re;xa'~ h~ve beea co~ for air and wm~r gaps. (FrD-Formaam Integn~ Test 0.89 0.92 O.75 1.38 1.01 .86 1.36 .7I .88 1.41 .84 .91 17.2 17.7 (FrD 14.5 26.6 19.5 16.5 26.2 13.6 17.0 (FrD 27.0 16.15 17.6 (m3 WELL: ANNA #7 rd 2 FIELD:. GRANrrE POINT 1. MUD WT. I 9.4 PPG 2. MUD WT. II 9,4 PPG 3. MUD WT. III 0 PPG INTERVAL CASING SIZE p0"l-roM TOP LENG~ W'T. 1 7" 10828 89 1075~ 29 '[VD 9627 6g 2 5" 12~30 10l]00 23O0 15 TVD 10227 9702 CASING DESIGN DATE: 17-Jul-D5 DESIGN BY: P.A. RYAN M.S.P. TENSION MINIMUM WEIGHT TOP OF STRENGTH DESCRIFrlI(~ W/O BF SECTION TENSION GRADI[ THREAD LEiS LBS 1000 LBS L-80 BTC 312011 312011 676 L-80 BTC 34500 34500 350 7~ p~ ~,~ p~ 0 psi 2.17 COLLAPSE COLLAPSE PRESS ~1 RESIST. BOTrOM TENSION 2753 7020 BURST MINIMUM PRESSURE YIELO PSI" PSl 2301 8180 10.14 2925 7250 2.48 2301 8290 3.80 Collapse pre~sure is celculaled; Difference between two cement siurrk~ (i.e. Avg of · 15.8 ppg (tail) & 14.2 ppg (lead) = 15 ppg, subtract · mud of 9.5 ppg 5,5 ppg - .286 psi/It gradient X TVD of the casing ~ripg). Burnt pre~sure is calculated; (BHP i~ depth next csg X TVD next csg) X (0.5 half evacuated). File nam.: 7rd2c~O xl~ UNOCAL ANNA PLATFORM WELL #7 RD 2 DEFrH +/- 10828' CASING S~ZE HOLE SIZE 8-1/2' MUD TYPE FiW./GENERIC MUD #2 (with PHP^) ANTICIPATED MUD PROPERTIES Notes: Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels Fluid Loss AP1 HPHT Fluid Loss Build new PHPA Generic Mud #2. 9.4 - 10.5 ppg 40 - 60 sec/qt 10 - 15 cps 10 - 25 # / 100 ft2 4- 12 8 20 DEPTH +/- 12900' LINER S;7~ 5" HOLE SIzE 6" MUD TYPE F.I.W. / GENERIC MUD #2 (with PHPA) ANTICIPATED MUD PROPERTIES Mud Density 9.4 - 10.5 Funnel Viscosity 45 - 80 sec/qt Plastic Viscosity 10 - 15 cps Yield Point 15 - 30 # / 100 ft2 Gels 6 - 12 AP1 Fluid Loss 5 HPHT Fluid Loss 10 Not~: Treat for cement contamination. Increase yield point anti gels in high angle section Add lubricants for torque and drag. Mud will be carried over from the Anna 28rd2 8-1/2" hole section. 7rd2mucLdoc .. . ~ ,2 ~;,' ,.2 Alaska Oil & Gas C, on,~;..r..ommission Anna 7rd X 20"gS#&94~H-40~623'. Cemamsiw/1285sx X ~3-3/g" 54.5# J-55 (~ 2040'. C~:mmu~wi 1200 ~x Plu~ 1~3 SlS0'-44..q0' (600 sz) I00% wnmogt m open ~ Tq w; dr'iff ~pe. 7"' etslq cut & rt~overed ~ S000' Cemm, ~ ~ 51~0' %5/8" 40# / 43.5# / 47# N80 / Pttt~ #2 7250'-69.31' Tag w/drift pipe. TOL 7141' ,.-" 23///26# $95/NS0 t~ 10312'. C,m:ma~ w/2050 sx Window cut t~ 7464'. Ping #1 9120'..8543' (50 s~) Tubing cut ~ 9120' Tubin~ plu~ @ 9130' 9154' ?a'fa 9040'-9070' 90gF-9115' 91ZI'-913F Pa-ts 9211'-9270' 9286'-9375' 9593'-9610' 96J5'-9715' 9790'-9845' 10045%10060' ETD 10063' TI} I02~' ~. IS#Ng0(~ 18#N80~ 10195'. Ctmm~w/36~s~. ANNA PLATFORM WELL # 7RD 2 GRANITE POINT (GP) PROPOSED COMPLETION CONCENTRIC COMPLETION 1) 4-1/2" 12.6# L-80 SCBT ~ 0-10400' 2) 2" Coiled Tubing ~ 0-10400' 3) Hydraulic Jet Pump ~ 10400' 4) 3-1/4" PBR RKB = 127' 3o" stmctm~ c~s~ @ 290' RrB (86'BML) ~ :20" 85#&94#H-40 Smfs~~@623' 13-3/8"54.5#J-55 Intexmedi~m C,~s, ing @ 2040' ~' 9-5/8" 40# / 43.5# / 47# NS0 / $95 BTC ~ C~sing @ 4647' TOL @ 10600' ~ 7" 29# L-gO BTC Pr~__,~Jon Casing@ 10828' 5" 15# 1,80 BTC ~ 10600' - 12900' ANNA PLATFORM WELL # 7 RD 2 GRANITE ?OINT (G?) ROTARY KELLY BUSHING (RKB) Elcv. 127' DRIIJ. DECK LEVEL Elev. 87' PRODUCTION DECK LEVEL Elev. 69' SEA LEVEL (MLW) Elcv. 0' ,MUD LRqE Elev. -77' 30" $tmcatral Casing@ 290' RKB (86'BML) 20" 85# & 94~ H-40 Surfa~ Ca~iag ~ 623' 13-3~' 54.5# J-55 BTC Intennedia~ Casing (~ 2040' 9-5/8" 40# / 43.5# / 47# NS0 / 895 BTC Intermediat~ Casing @ 4647' TOL ~ 10600' 7'29# L-80 BTC Production Casing@ 10828' X~ 5" 15# LB0 BTC ~ 10600' - 12900' ..,0 I'IUFI 11 'UU FRY, NO, ~Uf~U3'fUU4 1'", U1/Uq UNUCAL - ANCHUNRGE Uneeal No~th American Oil & Ga Division Unocal Co~omlron P.O. Box 190247 Anchorage. Alaska 9951 B-_'_¢47 Telephone {9071 276-76CC for Fa~ ConhrmaUon Fac. almJJ® (~07) 263-?iNt4 UNOCAL., , DATE A,asma Regmn PLEASE DELIVER THIS INFORMATION TO: At the request of: [Sender s Name] If you do not receive Location' pages (including this cover sheet), please call (907) 276-7600 and ask for: [Fax Operator] UNOO~L - ~NCHOR~GE Fi~X NO, 9072637884 P. 02/04 U~OCAL A~NA Platform ?Rd#2 slot #1-3 Granite Point Fiord CLEARANCE REPORT Your ref ~ ? Rd #2 Version Our re~ : propt~8 License : RE(E VED Date printed I 2C-Jul-95 Date created ; l&-Hay-95 Last revised : ll-Ju~-95 Fie~d is centred on r60 59 36.T51,w151 16 33.112 Structure is centred on r60 ~8 44.1r58,~151 18 33.113 Slot Location is n60 58 37,569,w151 18 45.900 Slot Grid coordinates are N ~55141~.020, E 266820.951 Slot [oca~ coordinates are 728.00 S 6~1.00 ~ Reference North is True North Main calculation performed uith ]-D Minimum Distance method Object ~eLLpath PHSS <T859 - 12G11t>,,$ Rd#I,ANNA Platform GeT Gyro <O-?~9'>~,3,ANNA PLatform GM9 <BO00-1311~>~,3,ANNA PLatform MSS <O-9~55~>~$,ANNA PLatform MSS <~020-10000~>,,19,ANNA PLatform PGMS ~O-lO$02'>,~13Rd,ANNA PLatform MSS ~?g&~-IO?OO~>,,~$~ANNA PLatform ReS <O-IO~O0'>~Z5,ANNR P[atfor~ HSS <19~-~>,,A,ANNR PLatform P~SS ~269 - lO856'>~11R~l~A~NA PLatfor~ MSS <0-10~'>,,11,ANflA Ptatform GHS <O-9~'>~27Rd,ANNA Platform MSS <70GS-IOO~>,,2T~AN~A Platform PGHS ~IOO-113~9'>,,$gRd~ANNA Ptatform OHS <0-11387t>~,3g,A~NA Platform MSS ~O-IOGOO'>,~2~AN~A PLatform GMS <O-11065~>,,~C~3,ANNA PLatform ~S <O-lO~O~>~26,ANNA Ptatform ~SS <1136~-11930~>,,55R~,RNNA PLatform MSs <96~-lO~Z'>,,55R~,ANNA PLatform HaS <9565-t~S&F'>,~35Rd~ANNA PLatform PGHS <O-102~,>,,35R~,A~HA PLatform ~SS ~S7~-E938~>,,35,ANNR PLatfOrm GHS <Q-~50~Rd~RNNA PLat~or~ ~SS <3281-10138'>r,E3,ANNA P~a:form ~SS <2015-1O8~%>~5,A~NA PLatform G~S ~-l~80~>~,29,RN~A PLatform PG~S <O-IO5~>~,21,ANNA PLatform CLosest approach ~ith 3-0 minin~z~ distance method Last revised Distance Diverging fromM.D. a-Jan-95 156~.7 5000.0 5000.0 12-~ec-9~ 1568.7 5000.0 5000,0 1G-Nov-94 1568.7 5000.0 5000.0 IS-May-94 1775.9 5000,0 5000.0 1~-Ma¥-9~ 19BA.~ 5000.0 5000.0 13-Hey-94 266~.r 5000.0 10500,0 13-Hay-9~ 2&69.7 5000.0 5925.0 13-~ay-94 2160,1 5000.0 10189.6 13-Hay-94 1225.6 5000.0 6300,0 1?-Jan-95 521.7 5000.0 5000.0 Z4-Oct-94 T57. Z 5000.0 ~000,0 13-May-94 620.~ 5000.0 5000.0 13-May-94 620,4 5000.0 5000.0 1]-May-9~ ~9.6 5866.7 5866.7 13-Hay-9~ 252.9 6225.0 6225.0 1S-May-94 1119,6 5000.0 5000.0 15-May~94 2627,7 5000.0 5925.0 13-Hey-9~ 1562.5 5000.0 5000.0 13-May-gA ~&~29.0 5000.0 5000.0 13-May-94 2~99.0 5000.0 5000.0 13-~ay-~A 2&99.0 5000.0 5000.0 l$-May-9~ ~499.0 5000.0 SO00.O 13-Ma¥-94 2499.0 5000.0 5000.0 13-May-94 ~49~.0 5000.0 5000.0 20'May-94 ~601.B 5000.0 5925.0 13-May-9~ Z640.9 5000.0 10520.0 13-May-9~ ~083.2 5000.0 5925.0 13-May-9~ 1785.8 5000.0 5000.0 l~-May-94 Z~77.2 5000.0 5925.0 .o flUN ll;U~ UNUURL - RNUHUffRU~ N$$ (9180-11~,~51> ,ANNA P[atfor~ NSS <tOD3 - IOGO0,>~ ~gRd~ANN~ P[~tfor~ P~S <O-111~'>,,~6,AN~A Ptatform ~S <O-10674'~,,17.ANNA Platfor~ P~S <0-114~3' >,, ia, ANNA e [atform P~S <O-11741'>r~7,ANNA Platfo~ M~S <1957-1~303~>,,9,ANNA Platfo~ PMSS <1380 - 12~1'>~ ~SO,ANNA PLatform GMS <O-250'>,~50,ANNA PLatform GMS <O-26~,,51,A~NA PLatform PAsS <1507-11385~>,~51~ANNA P[atfo~ PASS <1~ - 1~351'>,,51 St,ANnA Ptatform ~S <O-200'>,,ASZ.ANNA ¢[etfo~ PMSS ~1157 - 121~Z'>,~A52,ANNA PLatform PM$~ <1~5 - 119~'>,,52 S~,ANNA PLatform P~S ~16Z-~1'>,,~8,ANHA PLatform P~$ <0-tO~O'>~,ZSRd,ANN~ PLatform PHSS <56~ - ???~>,,28R~2,ANHA PLatform ~S <O-lO~Z5 ~>, ,~d,ANHA Ptatfo~ MSS <7440 - 105~'>,,7~ANNA ~latfo~ l~R* FlU, ~U/7'UJt'UUq l$-May-9~ 27"J2.~ 5buO.O 5925.0 13-May-94 56~.~ 5000.0 8180.0 13-May-94 523.6 78~0,0 78~0,0 13-May-94 1452.0 5000,0 5000.0 13-May-94 1873.G 5000.0 5000.0 13-May-94 2315.9 5000.0 5000,0 l$-May-g& 1138.~ 5000.0 5000.0 13-May-9~ 1090.6 5000.0 13-May~94 3057.0 5000.0 5925.0 25-Mar-95 1~96.6 5000.0 11520.0 1S-Jan-g5 4703.6 5000.0 $000.0 25-Jan-g5 468].3 ~000.0 500~.0 13-Jut-95 12~1.5 5000.0 5000.0 13-Jut-9~ 1221.6 5000.0 5000,0 ~-Jan-95 &~.O 5000.0 5000.0 8-May-95 1~91.6 5000.0 10-Ju[-95 1491.6 5000.0 125~2.0 13-~-94 11~.8 5000.0 5000.0 11-Jut-95 1180.8 5000.0 1~540.0 2~-du[-95 1100.T 5000.0 5000.0 l~-May-9~ 0.0 5000,0 5000.0 15-~ay-9~ 0.0 5000.0 Y, UJ/UQ RECEIVED UNOCAL - ANCHORAGE FAX NO. YU'f2U2'fUU4 o.oo E a s t 1720_ / 1520~ /6200 1440~ 720 7RO 800 8"-0 880 920 ';)60 '.qO0 1040 1080 1120 1160 1200 124.0 1280 .I I I I ,, I I J..~ I J I I I : I I I l_ ..._[ { ! i i i I ._~l I I i 1400J .!_ - 1280,,.1 ~ - 1240~ I 5200 520O 5100 I 1~o~ 4~00 I 4700 I o4o.J lOOO.J 0 - 960 ..J' .. REEE!VED ,!UL 24 t995 Gas Cons. CommiSsion' ~chorage I-""i I I I ["1 I [ I" I I i I 660 720 780 800 8&O 880 920 East ~cale 1 : 20,00 I I I-'' I J I I 'r'-" ~' ' ~ i I I 1040 1080 1120 1160 l~OO 17,40 [2.80 I 1320 760 _1720 _18~0 _1600 _1860 I ! 1320 Z 0 280 ~ 1160 _1120 _ ~1080 _ 1040 _fOOO - Q 920 0 STATE OF ALASKA _, OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon X_ Suspend __ Alter casing__ Repair well __ Change approved program __ 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 Operations shutdown__ Re-enter suspended well__ Plugging __ Time extension __ Stimulate __ Pull tubing Variance Perforate Other_ _ -- 6. Datum elevation (DF or KB) 4. Location of well at surface Leg #1, Slot 3, Platform Anna 727' FNL, 631' FEL, Sec. 12, R10N, R12W, SM At top of productive interval 1394' FNL, 781' FWL, Sec. 6, T10N, R11W, SM At effective depth 1426' FSL, 741' FWL, Sec. 6, T10N, R11, SM At total depth 1429' FSL, 716' FWL, Sec. 6, T10N, RllW, SM 5. Type of Well: Development X_ Exploratory __ Stmfigraphic __ 105' KB MSL feet 7, Unit or Property name GRANITE POINT ADL 18742 8. Well number 7RD 9. Permit number 10. APl number 50-733-20012-01 11. Field/Pool Granite PT/Middle Kenai "C" Sand 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10225' feet 9772' feet 10063' feet 9612' feet Casing Length Structural Size Plugs (measured) r", I k I ^ L--- i LTl Junk (measured) ~ Cemented Measured depth True vertical depth Conductor 623' 20" 1285 sx 623' 623' Surface 2040' 13-3/8" Intermediate 4647' 9-5/8" Production 7141' 7" 1200 sx 2040' 2000' 3000 sx 4647' 4419' 2050ax 7141' 6743' Uner 3054' 5" 368 sx 7141'-10195' 6743'-9743' Perforation depth: measured See attached true vertical See attached Tubing (size, grade, and measured depth) 3-1/2" 9.2# N-80 0-7105' 2-7/8" 6.4# N-80 7105'-9154' Packers and SSSV (type and measured depth) Baker Model "D" at 9154' .. JUL 07 1995 0il & Gas Cons. Commission ,. 13. Attachments Description summary of proposal _ _ Detailed operations programX__ BOP sketch X 14. Estimated date for commencing operation 7/21/95 Pat Ryan 263-7864 16. If proposal was verbally approved Name of approver Date approved 5. Status of well classification as: Oil X Gas Service Suspended__ 17. I hereby certify that the foregoing i,s,t,~e and correct ~ the. be~,.¢ my knowledge. Signed G. Russell Schmi~le ("l~)!lli~g Manager - '"' ' FOR'COMMISSION USE ONLY Date 7/03/95 Conditions of approval: Notify Commission so representative may witness Plug Integrity ~ BOP Test ,.-- Location clearance Mechanical Integrity Test__ Subsequent form required 10- Approved by the order of the Commission Original Signed Ely David W. Johnston I Approval 4 o"r' Approved Copy F~etur~d ~ Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN'TRIPUCATE WELL PERMIT CHECKLIST WELL NAME~I,~ /~ /x7_~7~_~ ?~_~ROGRAM= exp [] dev [] redrll~ serv [] ON/OFF SHORE ADMINISTRATION ENGINEERING 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ....... :, 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 31. Seismic analysis of shallow gas zones .......... Data presented on potential overpressure zones ..... Y /N .__ 32. 33. Seabed condition survey (if off-shore) ........ /Y N ' - 34. Contact name/phone for weekly progress reports . . ./ . Y N [exploratory only] GEOLOGY: ENGINEERING: ' JDR' ~ COMMISSION: DWJRAD ~~~-' Comments/Instructions: HOW/Jo - A:~FORMS~cheklist rev 03/94