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201-009
STATE OF ALASKA Reviewed 61Y'IiZG OIL AND GAS CONSERVATION COMMISSION P.I. Supry`— BOPE Test Report for: TRADING BAY UNIT K-01RD2 Comm Contractor/Rig No.: Hilcorp 404 " PTD#: 2010090 ' DATE: 11/5/2020 - Inspector Matt Herrera Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: Soule/Mize Rig Rep: Steiner/Castagne Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopMFH2O1106074536 Rams: Annular: Valves: MASP: Type Test: [NIT 320-414 250// — -- - — - 253000 250/3000 250/3000 2355 — Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: Upper Kelly 0 P/F Lower Kelly Visual Alarm Time/Pressure WIT Location Gen.: - P-1 Trip Tank NA NA System Pressure 3000 P Housekeeping: P_ " Pit Level Indicators P P Pressure After Closure 1800 P PTD On Location P Flow Indicator NA NA 200 PSI Attained 20 P Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 87 P Well Sign P H2S Gas Detector P P ' Blind Switch Covers: YES P Drl. Rig _ P MS Misc NA NA Nitgn. Bottles (avg): 4 &_2275 P Hazard Sec. P Check Valve ACC Misc _ 0 NA Misc NA 0 NA FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Upper Kelly 0 NA Lower Kelly 0_ _ NA_ Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 0 NA No. Valves 10 P _ Annular Preventer 1 13 5/8" P- Manual Chokes 1 P #1 Rams 1 2 7/8 x 5" P- Hydraulic Chokes 1 P #2 Rams l Blinds P CH Misc 0 NA #3 Rams 0 NA #4 Rams 0 N_ A_ #5 Rams __ - 0 NA INSIDE REEL VALVES: #6 Rams 0 (Valid for Coil Rigs Only) Choke Ln. Valves 1- 2 1/16" _ _NA_ _ P Quantity P/F HCR Valves 2 ' 2 1/16" P Inside Reel Valves 0 NA Kill Line Valves 2 2 1/16" P Check Valve 0 NA__ BOP Misc 0 NA Number of Failures: 0 ' Test Results Test Time 3.5 Remarks: 2 7/8" Test Joint All Gas Alarms Tested Good. PVT Equipment had only Pit level and G/L all tested good 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,780 feet 13,540 feet true vertical 9,745 feet 13,448 feet Effective Depth measured 13,444 feet N/A feet true vertical 9,479 feet N/A feet Perforation depth Measured depth 11,680 - 13,460 feet True Vertical depth 8,156 - 9,491 feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5 / L-80 10,620 MD 7,445 TVD Packers and SSSV (type, measured and true vertical depth)N/A & N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: TVD measured true vertical Packer Other: Replaced ESP 7" MD 110 2,384 13,779 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 142 Representative Daily Average Production or Injection Data 61335 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-009 50-733-20054-01-00 Plugs ADL0018777 / ADL0017594 Trading Bay Unit K-01RD2 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-414 66 Authorized Signature with date: Authorized Name: 779 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 176 Gas-Mcf 489 N/A Oil-Bbl 41 Water-Bbl Intermediate N/A Junk 5. Permit to Drill Number: 57 McArthur River Field / Hemlock Oil & Middle Kenai G Oil PoolsN/A measured 6,043 Size 65 Production Casing Structural Liner 7,920 Length 110 2,384 Conductor Surface 7,020psi 20" 13-3/8" 9-5/8" 6,043 6,330psi 907 777-8434 109 2,167 4,928 9,743 Collapse Karson Kozub kkozub@hilcorp.com Tubing Pressure 1,540psi 3,810psi 3,090psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,160psi Daniel E. Marlowe Operations Manager Burst Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:49 am, Nov 24, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.11.24 08:37:38 -09'00' Dan Marlowe (1267) RBDMS HEW 11/25/2020 gls 12/8/20 Replaced ESP DSR-12/9/2020 Updated by: JLL 11/18/20 SCHEMATIC King Salmon Platform Well K-01RD2 PTD: 201-009 API: 50-733-20054-01 Last Completed: 11/09/2020 Casing and Tubing Detail Size Type Wt/ Grade TOP BTM CONN / ID Cement / Other 20” Conductor 94/ H40 Surf 110’ Welded/ 19” Driven 13-3/8” Surface 61/ K55 Surf 2,384’ BTC/ 12.515” 2640 “G”/ Surface 9-5/8” Intermediate 47/ N80 Surf 112’ BTC/ 8.681”1321 “G” Surface9-5/8” Intermediate 43.5/ N80 112’ 6,043’ BTC/ 8.755” 7” Liner 29/ L80 5,859’ 13,779’ BTC-KC/ 6.184” 183BBL/ 5859’ Tubing 2-7/8” Tubing 6.5/ L80 Surf 10,620’ EUE 8RD No. Depth (MD) Depth (TVD) ID OD Item 26.4’ 26.4’ Tubing Hanger: OCT-UH-TC-1A-ESP, 13 X 4-1/2 IBT lift and susp, w/ 4" Type H BPV profile, 3/8 cont. control line port 27’ 27’ 2.441” 4.500” X-over: 4-1/2” IBT to 2-7/8” 8RD pin 1 10,620’ 7,445’ N/A 4.000” Discharge, Bolt on, 2-7/8" 8RD, 400X, 416/420SS 10,621’ 7,446’ N/A 4.000” 372 Stg SF-900 Pump (X3) 10,686’ 7,483’ N/A 4.000” Gas Separator, 400X, S/LT,VX#, INC, SS, D-7 & 15 10,689’ 7,485’ N/A 4.000” Tandem Seals – 400 Series BPBSL 10,705’7,494’N/A 4.560” 456 Series Motor, FMS2, 180HP/2952V/43A 10,729’ 7,507’ N/A 4.500” Centralizer/Anode TD =13,780’ PBTD = 13,750’ 13-3/8” @ 2384’ GO-4 GO-6 HB-2 G-5 HB-1/G7 HB-3 HB-6 CIBP Set @ 13,540’ KB-THF: 33.7’ KB HB-7 11-07-20 Fill tagged 13,444’ MD HB-4 HB-5 20” @ 110’ RKB: 100’ AMSL 9-5/8” @ 6043’ 1 TOL: 5859’ G-1 Directional Data: max = 59° at 8,485’ OCTG Rotating Hours 24” Structural Casing 110 Hours 20” Conductor 110 Hours 13-3/8” Surface Pipe 227 Hours 9-5/8” Casing 651 Hours 7” Liner 50 Hours PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date GO-4 11,680' 11,720' 8,156' 8,186' 40' 5/7/01, partial reperf 1/27/05 GO-5 11,732' 11,742' 8,195' 8,202' 10' Opened 5/7/01 GO-6 11,780' 11,810' 8,229' 8,251' 30' Opened 5/7/01 11,820' 11,840' 8,259' 8,273' 20' Opened 5/7/01 11,864' 11,891' 8,291' 8,310' 27' Opened 5/7/01 G-1 12,030' 12,080' 8,413' 8,451' 50' 5/7/01, partial reperf 1/27/05 12,090' 12,120' 8,459' 8,481' 30' Opened 5/7/01 12,142' 12,162' 8,498' 8,513' 20' Opened 5/7/01 G-5 12,659' 12,674' 8,885' 8,896' 15' Opened 5/7/01 12,680' 12,694' 8,901' 8,911' 14' Opened 5/7/01 12,710' 12,790' 8,923' 8,983' 80' 5/7/01, partial reperf 1/27/05 12,800' 12,830' 8,990' 9,012' 30' 5/7/2001 G-7/HB-1 12,950' 13,010' 9,102' 9,147' 60' 7/3/01, partial reperf 1/27/05, partial reperf 8/22/08 HB2 13,075' 13,095' 9,196' 9,211' 20' 8/20/08 HB3 13,120' 13,130' 9,230' 9,238' 10' 8/20/08 HB3 13,190' 13,210' 9,283' 9,298' 20' HB-4 13,228' 13,340' 9,312' 9,397' 112' 5/7/01, partial reperf 1/27/05 HB5 13,405' 13,425' 9,447' 9,463' 20' Opened 1/13/02, reperf 8/20/08 HB5 13,440' 13,460' 9,475' 9,491' 20' Opened 1/13/02 HB6 13,565' 13,580' 9,573' 9,585' 15' Opened 1/13/02, Isolated 2/02 HB7 13,610' 13,650' 9,609' 9,641' 40' Opened 1/13/02, Isolated 2/02 Rig Start Date End Date HAK 404 10/31/20 11/9/20 11/04/20 - Wednesday Cont. Stack up BOPE, torque flanges on same, work on getting he aters rigged up, organize decks & prep backload for boat. Repair crown Beacon. Prep & stand mast, secure lines, scope up mast, secure guy lines. R/u PVT system. Connect controls for BOP remote panel. Position Dog House, connect high pressure mud line from pump to standpipe. Install rig floor. Close in area around BOPE. Connect koomey hoses and function test BOPE. Continue rigging up rig floor, install rig floor wind walls, install ODS stairs from carrier deck to rig floor, install beaver slide and remove packing from pipe stripper. Make up 2-7/8" test joint, RIH and make up to hanger. Mobe crews to Platform, orientate same. PTSM (note: Production pumped 401 bbls FIW to well, got oil returns at 156 bbls, lost returns @ 389bbls). Prep to raise mas t, organize decks & spot Eq. Install drive line, & brake linkage, raise mast. Install tuger & man rider lines. Spool tugger lines. Repair and install air dryer, run and connect mud pump lines to pits. Spool drill line onto drawworks. Lay down mast. Set BPV, Nipple down production lines and prep to remove tree. Remove hub flange clamps. Rig up and remove tree and adapter flange with crane. Clean and inspect hanger threads. Install cap on cable penetrator and cap capillary lines. Install Blanking sub. Install hub by flange adapter spool on bottom of riser. Set adapter flange and riser on well head. Install clamps on hub connection. Set mud cross on riser and install choke and kill line valves on same. Arrive on King. Do orientation, JSA, permit, pre job meeting. Spot equipment. Rig up. P/U LUB, PRESSURE TEST TO 1500 PSI, TEST GOOD. RIH W/ 2 7/8 GS TO 3154'KB W/T POO H W/ AA-STOP. RIH W/ SAME TO 3154'KB W/T POOH W/ 22' PATCH. RIH W/ SAME TO 3177'KB W/T POOH W/ AD-2 STOP. RIH W/ SAME TO 3112'KB W/T POOH W/ AA-STOP. RIH W/ SAME TO 3213'KB W/T POOH W/ 22' PATCH. RIH W/ SAME TO 3235'KB W/T POOH W/ 11' PATCH. RIH W/ SAME TO 3250'KB W/T POOH W/ 11' PATCH. RIH W/ SAME TO 3260'KB W/T POOH W/ 10' PATCH. RIH W/ SAME TO 3270'KB W/T POOH W/ 20' PATCH. RIH W/ SAME TO 3292'KB W/T POOH W/ AD-2 STOP. RDMO. 10/31/20 - Saturday No operations to report 11/03/20 - Tuesday 11/01/20 - Sunday No operations to report 11/02/20 - Monday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name K-01RD2 50-733-20054-01 201-009 Rig Start Date End Date HAK 404 10/31/20 11/9/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name K-01RD2 50-733-20054-01 201-009 Cont. POOH f/9847', t/6227'. L/D 144 jts to splice, pump 2 bbls every 10 joints, (Did find 2 holes in tubing in previously patched area 3153-3290). Change out spools, test cab le, good. Cont. POOH f/6227', t/2760'. L/D 110 jts (254 total) Switch to YT type elevators for beveled collar tubing. Pump 2 bbls every 10 joints. Cont. POOH f/2760', t/178', L/D 84 jts (338 total) to ESP Assembly. P ump 2 bbls every 10 joints. PUW=17K. Rig down flat line and control line sheaves and hose from mast. L/D ESP assembly (Ported Pressure Sub, Discharge, 4 pump sections, 2 Gas separators, Upper and lower tandem seals, Motor, Down hole gauge and Centralizer/Anode = 146.53') Test motor - Good. Recovered 200 C annon Clamps and 3 stainless steel bands. Clear and clean rig floor. 11/07/20 - Saturday R/U W/L. P/U tools w/3" bailer. RIH tag @ 13,444', POOH. R/D W/L. Unload & backload boat, swap pulled completion for new 2 7/8" completion tubing & replacement ESP assy. Rack & strap pipe coming off boat. Cont. unload boat & tally pipe while P/U Motor assy, & lower tandem seal. M/u MLE & service both. Cont. P/U ESP assembly (Cent/Anode, DH Gauge, Motor, Tandem seals, Gas Separator, 3 Pumps, Ported sub, Discharge, 1 jt 2-7/8" tbg = 142.75). Clear and clean floor. RI H f/ 142.75' to 2170' w/ ESP Assembly picking up 2-7/8" EUE 8RD 6.5# L-80 tubing. Testing cable every 1000' (62 jt. tubing / 86 Cannon clamps and 1 splice clamp ran at report time). 11/05/20 - Thursday Work on winterization & heating up BOPE. Install DS carrier stairs & stairs to rig floor. R/u test pump. P/U handling tools & stock rig floor. R/U & blow through BOPE lines, good, fill surface eq. & Shell test 250 low, found leak on mud cross flange. Bleed off & tq. flange, check all connections. Cont. Shell test 250/3000 had leak on L/D pin & grease fitting on CMV #10, repair both, re-te st good. Blow down BOPE and test lines, Organized deck and install side stairs to carrier while waiting on AOGCC Inspector to arrive for BOPE test. Test BOPE with AOGCC Inspector Matt Herrera present to witness same. Test annular, all rams and valves to 250 low and 3000 high. Perform Koomey drawdown test. Test gas alarm and PVT systems. No failures. Blow down BOPE and lines. Rig down test equipment. Pull blanking plug and BPV. Make up landing joint on pipe rack. Rigging up to pull ESP completion. Hang ESP sheaves in mast and string hose from sheave to spooling unit. Rotate heater skid to reroute heater hoses under beaver slide and stairs. Run landing joint in hole and make up to hanger. Back out LDS on well head. Check annulus to verify no trapped pressure under hanger. Pull hanger to rig floor (Pulled 64K to pull hanger off seat, P ulled 86K before seeing weight break back, Pulling @ 78-80K) Remove control lines and penetrator from hanger. Lay down landing joint and hanger. POOH laying down 2-7/8" 6.5# L-80 EUE tubing, EPS control line and flat cable. String cables through Summit sheaves. Continue POOH laying down tubing. Approximately 880' pulled at report time. filling hole with 2X calculated displacement volume every 10 jt." 11/06/20 - Friday pull ESP Rig Start Date End Date HAK 404 10/31/20 11/9/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name K-01RD2 50-733-20054-01 201-009 11/09/20 - Monday Cont. RIH f/8242' t/ 10700' w/ ESP Assembly picking up 2-7/8" EUE 8RD 6.5# L-80 tubing. Testing cable every 1000'. M/U hanger w/ landing joint. Make up penetrator & control line penetrations, test same, good. Land out hanger dn wt 33k, placing assembly tail @ 10729'. Veri fy landed. RILD pins, test cable, good. Pull landing joint, set BPV. Break down landing jt. Clear rig floor windwalls. L/D bales, unpin and remove stairs, disconnect guy lines and disconnect choke and kill lines. R/D f loor, scope down and lay over mast. N/D BOPE. Inspect hanger and penetrators (Good), Lower and land tre e, test ESP penetrator connection (Good). Install and make up hub flange clamp. Test w/ 500 psi for 5 min low / 5000 psi for 15 min high (Good test). N/U wing valves, SSV and choke on tree. Pull BPV and install TWC. Fill tree w/water and test to 5000 psi (Good). Clean up well head room. 11/08/20 - Sunday RIH f/ 2170' to 5435' w/ ESP Assembly picking up 2-7/8" EUE 8RD 6.5# L-80 tubing. Testing cable every 1000'. RIH f/ 5435' to 7523' w/ ESP Assembly picking up 2-7/8" EUE 8RD 6.5# L-80 tubing. Testing cable every 1000', 3' section of plastic sheathing came off of flat w ire. Inspect tubing and verify no damage to same. Encountered sensor signal issue with control cable. Corre cted grounding issue at surface for good signal. RIH f/7523' to 8046' w/ ESP Assembly picking up 2-7/8" EUE 8RD 6.5# L-80 tubing. Testing cable every 1000'. Change out cable spools, make splice and test same . RIH f/8046' to 8242' w/ ESP Assembly picking up 2-7/8" EUE 8RD 6.5# L-80 tubing. Testing cable ev ery 1000'. Total 2-7/8" tbg in hole = 248 jt, Cannon clamp ran on every connection f/ jt 1 - 240 and then eve ry other connection. Total Cannon clamps in hole = 268. Total splice clamps in hole = 4. 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pools 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 13,780'13,448' Casing Collapse Structural Conductor Surface 1,540 psi Intermediate 3,810 psi Production Liner 7,020 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG 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 Authorized Signature: Operations Manager Katherine O'Connor Other: Replace ESP PRESENT WELL CONDITION SUMMARY Length Size 6,330 psi 201-009 COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018777 / ADL0017594 50-733-20054-01-00Anchorage, AK 99503 Hilcorp Alaska, LLC N/A Trading Bay Unit K-01RD2 13,540'9,745' 13,448' 9,480' 2,355 psi 6.5# / L-80 TVD Burst 10,583 MD 3,090 psi 109' 2,167' 4,928' 110' 2,384' 20" 13-3/8" 110' 7,920' 9-5/8"6,043' 2,384' Perforation Depth MD (ft): 6,043' 7" 11,680 - 13,460 N/A & N/A Tubing Grade:Tubing MD (ft): 8,156 - 9,491 Perforation Depth TVD (ft): 8,160 psi Tubing Size: 13,779' 9,743' 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. 10/15/2020 2-7/8" Daniel E. Marlowe N/A & N/A Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:04 am, Oct 05, 2020 320-414 Daniel Marlowe I am approving this document 2020.10.02 15:56:01 -08'00' Daniel Marlowe r: Replace ESP X DLB 10/05/2020 10-404 DSR-10/12/2020 Pull Tubingll Tubing OIL *3000 psi BOPE test (2500 psi annular) X gls 10/12/20 404 Comm. q Yes 10/13/2020 dts 10/12/2020 JLC 10/13/2020 RBDMS HEW 11/3/2020 Well Work Prognosis Well: K-01RD2 Date: 09-25-2020 Well Name:Trading Bay Unit K-01RD2 API Number:50-733-20054-01 Current Status:Oil Producer Leg:Leg #4 NW Corner Estimated Start Date:Oct 15, 2020 Rig:HAK 404 Reg. Approval Req’d?10-403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett 777-8332 Permit to Drill Number:201-009 First Call Engineer:Karson Kozub (907) 777-8434 (O) (907) 570-1801 (M) Second Call Engineer:Katherine O’Connor (907) 777-8376 (O) (907) 214-7400 (M) Current Bottom Hole Pressure:3,300 psi @ 9450’ TVD 0.35 psi/ft (7.3 ppg) ESP Gauge Maximum Expected BHP:3300 psi @ 9,450’ TVD 0.35 psi/ft (8.61 ppg) ESP Gauge Maximum Potential Surface Pressure:**2355 psi Using 0.1 psi/ft gradient per 20AAC 25.280(b)(4) **This is a no flow well 09/17/2014 Brief Well Summary: The K-01RD2 is an ESP completion with a patch. The tubing has lost integrity and is causing fluid swapping and reduced production. This program objective is to recomplete this well with new tubing and a new ESP, like for like. Last Casing Test x 8/5/2017 RIH to 10750’ MD, 7” and 9-5/8” casing test passed to 1900 psi. Procedure: 1. MIRU 404 rig 2. Circulate hydrocarbons off of well. x Work over fluid will be FIW. BOP’s will be closed as needed to circulate the well. 3. Set BPV, ND tree NU BOP 4. BOP and test to 250psi low/3,000psi high. x Note: Notify AOGCC 24 hours in advance of test to allow them to witness test. 5. Monitor well to ensure it is static. 6. Unseat hanger and POOH w/ tubing string and ESP assembly. 7. If needed, drift with SL bailer to TD x Contingent: RIH to with cleanout assembly, circ bottoms up, POOH 8. PU and RIH with new tbg and ESP assembly. See proposed schematic. 9. ND BOP, NU wellhead and test. 10. Turn well over to production. 11. Conduct SVS tests per AOGCC regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current/Proposed (Same) 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form The K-01RD2 is an ESP completion with a patch. The tubing has lost integrity and is causing fluid swapping and reduced production. 3300 psi @9450 ft = 7.0 ppg EMW Updated by: JLL 08/20/20 SCHEMATIC King Salmon Platform Well K-01RD2 PTD: 201-009 API: 50-733-20054-01 Last Completed: 08/09/2017 Casing and Tubing Detail Size Type Wt/ Grade TOP BTM CONN / ID Cement / Other 20” Conductor 94/ H40 Surf 110’ Welded/ 19” Driven 13-3/8” Surface 61/ K55 Surf 2,384’ BTC/ 12.515” 2640 “G”/ Surface 9-5/8” Intermediate 47/ N80 Surf 112’ BTC/ 8.681”1321 “G” Surface9-5/8” Intermediate 43.5/ N80 112’ 6,043’ BTC/ 8.755” 7” Liner 29/ L80 5,859’ 13,779’ BTC-KC/ 6.184” 183BBL/ 5859’ Tubing 2-7/8” Tubing 6.5/ L80 Surf 10,583’ EUE 8RD No. Depth (MD) Depth (TVD) ID OD Item 26.4’ 26.4’ Tubing Hanger: OCT-UH-TC-1A-ESP, 13 X 4-1/2 IBT lift and susp, w/ 4" Type H BPV profile, 3/8 cont. control line port 27’ 27’ 2.441” 4.500” X-over: 4-1/2” IBT to 2-7/8” 8RD pin 1 10,583’ 7,424’ N/A 4.000” Discharge, Bolt-On 10,583’ 7,424’ N/A 4.000” Pump - (3) 400 Series, 125 SF1750 (1) 400 Series 076 SFG2500 10,670’ 7,473’ N/A 4.000” Gas Separator – 400 Series UT & LT 400X Vortex 10,675’ 7,476’ N/A 4.000” Tandem Seals – 400 Series BPBSL 10,692’ 7,485’ N/A 4.000” Motor – 456 Series FMS, 240 HP 10,727’ 7,505’ N/A 4.560” Centralizer/Anode TD =13,780’ PBTD = 13,750’ 13-3/8” @ 2384’ GO-4 GO-6 HB-2 G-5 HB-1/G7 HB-3 HB-6 CIBP Set @ 13,540’ KB-THF: 26.4’ KB HB-7 4-21-2011 Fill tagged 13448’ MD HB-4 HB-5 20” @ 110’ RKB: 100’ AMSL 9-5/8” @ 6043’ 1 Tubing Patch 3,235 - 3,290 KB Tubing Patch 3,153 – 3,177 KB TOL: 5859’ G-1 Directional Data: max = 59° at 8,485’ OCTG Rotating Hours 24” Structural Casing 110 Hours 20” Conductor 110 Hours 13-3/8” Surface Pipe 227 Hours 9-5/8” Casing 651 Hours 7” Liner 50 Hours PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date GO-4 11,680' 11,720' 8,156' 8,186' 40' 5/7/01, partial reperf 1/27/05 GO-5 11,732' 11,742' 8,195' 8,202' 10' Opened 5/7/01 GO-6 11,780' 11,810' 8,229' 8,251' 30' Opened 5/7/01 11,820' 11,840' 8,259' 8,273' 20' Opened 5/7/01 11,864' 11,891' 8,291' 8,310' 27' Opened 5/7/01 G-1 12,030' 12,080' 8,413' 8,451' 50' 5/7/01, partial reperf 1/27/05 12,090' 12,120' 8,459' 8,481' 30' Opened 5/7/01 12,142' 12,162' 8,498' 8,513' 20' Opened 5/7/01 G-5 12,659' 12,674' 8,885' 8,896' 15' Opened 5/7/01 12,680' 12,694' 8,901' 8,911' 14' Opened 5/7/01 12,710' 12,790' 8,923' 8,983' 80' 5/7/01, partial reperf 1/27/05 12,800' 12,830' 8,990' 9,012' 30' 5/7/2001 G-7/HB-1 12,950' 13,010' 9,102' 9,147' 60' 7/3/01, partial reperf 1/27/05, partial reperf 8/22/08 HB2 13,075' 13,095' 9,196' 9,211' 20' 8/20/08 HB3 13,120' 13,130' 9,230' 9,238' 10' 8/20/08 HB3 13,190' 13,210' 9,283' 9,298' 20' HB-4 13,228' 13,340' 9,312' 9,397' 112' 5/7/01, partial reperf 1/27/05 HB5 13,405' 13,425' 9,447' 9,463' 20' Opened 1/13/02, reperf 8/20/08 HB5 13,440' 13,460' 9,475' 9,491' 20' Opened 1/13/02 HB6 13,565' 13,580' 9,573' 9,585' 15' Opened 1/13/02, Isolated 2/02 HB7 13,610' 13,650' 9,609' 9,641' 40' Opened 1/13/02, Isolated 2/02 Updated by: JLL 09/28/20 PROPOSED King Salmon Platform Well K-01RD2 PTD: 201-009 API: 50-733-20054-01 Last Completed: FUTURE Casing and Tubing Detail Size Type Wt/ Grade TOP BTM CONN / ID Cement / Other 20” Conductor 94/ H40 Surf 110’ Welded/ 19” Driven 13-3/8” Surface 61/ K55 Surf 2,384’ BTC/ 12.515” 2640 “G”/ Surface 9-5/8” Intermediate 47/ N80 Surf 112’ BTC/ 8.681”1321 “G” Surface9-5/8” Intermediate 43.5/ N80 112’ 6,043’ BTC/ 8.755” 7” Liner 29/ L80 5,859’ 13,779’ BTC-KC/ 6.184” 183BBL/ 5859’ Tubing 2-7/8” Tubing 6.5/ L80 Surf ±10,580’ EUE 8RD No. Depth (MD) Depth (TVD) ID OD Item 26.4’ 26.4’ Tubing Hanger: OCT-UH-TC-1A-ESP, 13 X 4-1/2 IBT lift and susp, w/ 4" Type H BPV profile, 3/8 cont. control line port 27’ 27’ 2.441” 4.500” X-over: 4-1/2” IBT to 2-7/8” 8RD pin 1 ±10,580’ ±7,423’ N/A Discharge, Bolt-On N/A Pump N/A Gas Separator N/A Tandem Seals N/A Motor ±10,725’ ±7,505’ N/A Centralizer/Anode TD =13,780’ PBTD = 13,750’ 13-3/8” @ 2384’ GO-4 GO-6 HB-2 G-5 HB-1/G7 HB-3 HB-6 CIBP Set @ 13,540’ KB-THF: 26.4’ KB HB-7 4-21-2011 Fill tagged 13448’ MD HB-4 HB-5 20” @ 110’ RKB: 100’ AMSL 9-5/8” @ 6043’ 1 TOL: 5859’ G-1 Directional Data: max = 59° at 8,485’ OCTG Rotating Hours 24” Structural Casing 110 Hours 20” Conductor 110 Hours 13-3/8” Surface Pipe 227 Hours 9-5/8” Casing 651 Hours 7” Liner 50 Hours PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date GO-4 11,680' 11,720' 8,156' 8,186' 40' 5/7/01, partial reperf 1/27/05 GO-5 11,732' 11,742' 8,195' 8,202' 10' Opened 5/7/01 GO-6 11,780' 11,810' 8,229' 8,251' 30' Opened 5/7/01 11,820' 11,840' 8,259' 8,273' 20' Opened 5/7/01 11,864' 11,891' 8,291' 8,310' 27' Opened 5/7/01 G-1 12,030' 12,080' 8,413' 8,451' 50' 5/7/01, partial reperf 1/27/05 12,090' 12,120' 8,459' 8,481' 30' Opened 5/7/01 12,142' 12,162' 8,498' 8,513' 20' Opened 5/7/01 G-5 12,659' 12,674' 8,885' 8,896' 15' Opened 5/7/01 12,680' 12,694' 8,901' 8,911' 14' Opened 5/7/01 12,710' 12,790' 8,923' 8,983' 80' 5/7/01, partial reperf 1/27/05 12,800' 12,830' 8,990' 9,012' 30' 5/7/2001 G-7/HB-1 12,950' 13,010' 9,102' 9,147' 60' 7/3/01, partial reperf 1/27/05, partial reperf 8/22/08 HB2 13,075' 13,095' 9,196' 9,211' 20' 8/20/08 HB3 13,120' 13,130' 9,230' 9,238' 10' 8/20/08 HB3 13,190' 13,210' 9,283' 9,298' 20' HB-4 13,228' 13,340' 9,312' 9,397' 112' 5/7/01, partial reperf 1/27/05 HB5 13,405' 13,425' 9,447' 9,463' 20' Opened 1/13/02, reperf 8/20/08 HB5 13,440' 13,460' 9,475' 9,491' 20' Opened 1/13/02 HB6 13,565' 13,580' 9,573' 9,585' 15' Opened 1/13/02, Isolated 2/02 HB7 13,610' 13,650' 9,609' 9,641' 40' Opened 1/13/02, Isolated 2/02 King Salmon Platform K-01RD2 Current 12/29/2016 King Salmon Platform BOP Stack Valve Position(O/C)Standpipe PumpManifold1(PM1) OManifold PumpManifold2(PM2) OPumpManifold3(PM3) CPumpManifold4(PM4) OPumpManifold5(PM5) CMud KillLine1OCross KillLine2OHCRvalve(ChokeLine1) CChokeLine2OChoke ChokeManifold1(CM1) OManifold ChokeManifold2(CM2) CChokeManifold3(CM3) OChokeManifold4(CM4) CChokeManifold5(CM5) OChokeManifold6(CM6) CChokeManifold7(CM7) OChokeManifold8(CM8) CChokeManifold9(CM9) CChokeManifold10(CM10) OSuperChoke CManualChoke CRigFloor SafetyValve O Valve Position(O/C)Standpipe PumpManifold1(PM1) OManifold PumpManifold2(PM2) CPumpManifold3(PM3) OPumpManifold4(PM4) CPumpManifold5(PM5) OMud KillLine1OCross KillLine2OHCRvalve(ChokeLine1) CChokeLine2OChoke ChokeManifold1(CM1) OManifold ChokeManifold2(CM2) CChokeManifold3(CM3) OChokeManifold4(CM4) CChokeManifold5(CM5) OChokeManifold6(CM6) CChokeManifold7(CM7) OChokeManifold8(CM8) CChokeManifold9(CM9) CChokeManifold10(CM10) OSuperChoke CManualChoke CRigFloor SafetyValve O Rig 404 BOP Test Procedure Attachment #1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Rig 404, WO Program – Oil Producers, Gas 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. x 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.) 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 BOPE 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 st 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 xxx psi (see sundry) 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 1st 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 xxx psi (see sundry) 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 xxx psi (see sundry) 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 xxx psi (see sundry) 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 xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. 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 xxx psi (see sundry) 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 xxx psi (see sundry) 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 2 nd 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. Document both the rolling test and the follow up tests. Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well K-01RD2 (PTD 201-009)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 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,780 feet 13,540 feet true vertical 9,745 feet N/A feet Effective Depth measured 13,448 feet N/A feet true vertical 9,480 feet N/A feet Perforation depth Measured depth 11,680 - 13,460 feet True Vertical depth 8,156 - 9,491 feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5 / L-80 10,583 MD 7,424 TVD Packers and SSSV (type, measured and true vertical depth)N/A & N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: TVD measured true vertical Packer 7" MD 110 2,384 13,779 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 2360 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-009 50-733-20054-01-00 Plugs ADL0018777 / ADL0017594 Trading Bay Unit K-01RD2 Other: Tubing Patch 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-254 58 Authorized Signature with date: Authorized Name: 440 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 108 Gas-Mcf 235 N/A Oil-Bbl 0 Water-Bbl Intermediate N/A Junk 5. Permit to Drill Number: 36 McArthur River Field / Hemlock Oil & Middle Kenai G Oil PoolsN/A measured 6,043 Size 452 Production Casing Structural Liner 7,920 Length 110 2,384 Conductor Surface 7,020psi 20" 13-3/8" 9-5/8" 6,043 6,330psi 907 777-8384 109 2,167 4,928 9,743 Collapse Karson Kozub kkozub@hilcorp.com Tubing Pressure 1,540psi 3,810psi 3,090psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,160psi Daniel E. Marlowe Operations Manager Burst PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 2:55 pm, Aug 20, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.08.20 12:12:03 -08'00' Dan Marlowe (1267) Tubing Patch 108 RBDMS HEW 8/20/2020 SFD 8/28/2020gls 9 /28/20 DSR-8/20/2020 Updated by: JLL 08/20/20 SCHEMATIC King Salmon Platform Well K-01RD2 PTD: 201-009 API: 50-733-20054-01 Last Completed: 08/09/2017 Casing and Tubing Detail Size Type Wt/ Grade TOP BTM CONN / ID Cement / Other 20” Conductor 94/ H40 Surf 110’ Welded/ 19” Driven 13-3/8” Surface 61/ K55 Surf 2,384’ BTC/ 12.515” 2640 “G”/ Surface 9-5/8” Intermediate 47/ N80 Surf 112’ BTC/ 8.681”1321 “G” Surface9-5/8” Intermediate 43.5/ N80 112’ 6,043’ BTC/ 8.755” 7” Liner 29/ L80 5,859’ 13,779’ BTC-KC/ 6.184” 183BBL/ 5859’ Tubing 2-7/8” Tubing 6.5/ L80 Surf 10,583’ EUE 8RD No. Depth (MD) Depth (TVD) ID OD Item 26.4’ 26.4’ Tubing Hanger: OCT-UH-TC-1A-ESP, 13 X 4-1/2 IBT lift and susp, w/ 4" Type H BPV profile, 3/8 cont. control line port 27’ 27’ 2.441” 4.500” X-over: 4-1/2” IBT to 2-7/8” 8RD pin 1 10,583’ 7,424’ N/A 4.000” Discharge, Bolt-On 10,583’ 7,424’ N/A 4.000” Pump - (3) 400 Series, 125 SF1750 (1) 400 Series 076 SFG2500 10,670’ 7,473’ N/A 4.000” Gas Separator – 400 Series UT & LT 400X Vortex 10,675’ 7,476’ N/A 4.000” Tandem Seals – 400 Series BPBSL 10,692’ 7,485’ N/A 4.000” Motor – 456 Series FMS, 240 HP 10,727’ 7,505’ N/A 4.560” Centralizer/Anode TD =13,780’ PBTD = 13,750’ 13-3/8” @ 2384’ GO-4 GO-6 HB-2 G-5 HB-1/G7 HB-3 HB-6 CIBP Set @ 13,540’ KB-THF: 26.4’ KB HB-7 4-21-2011 Fill tagged 13448’ MD HB-4 HB-5 20” @ 110’ RKB: 100’ AMSL 9-5/8” @ 6043’ 1 Tubing Patch 3,235 - 3,290 KB Tubing Patch 3,153 – 3,177 KB TOL: 5859’ G-1 Directional Data: max = 59° at 8,485’ OCTG Rotating Hours 24” Structural Casing 110 Hours 20” Conductor 110 Hours 13-3/8” Surface Pipe 227 Hours 9-5/8” Casing 651 Hours 7” Liner 50 Hours PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date GO-4 11,680' 11,720' 8,156' 8,186' 40' 5/7/01, partial reperf 1/27/05 GO-5 11,732' 11,742' 8,195' 8,202' 10' Opened 5/7/01 GO-6 11,780' 11,810' 8,229' 8,251' 30' Opened 5/7/01 11,820' 11,840' 8,259' 8,273' 20' Opened 5/7/01 11,864' 11,891' 8,291' 8,310' 27' Opened 5/7/01 G-1 12,030' 12,080' 8,413' 8,451' 50' 5/7/01, partial reperf 1/27/05 12,090' 12,120' 8,459' 8,481' 30' Opened 5/7/01 12,142' 12,162' 8,498' 8,513' 20' Opened 5/7/01 G-5 12,659' 12,674' 8,885' 8,896' 15' Opened 5/7/01 12,680' 12,694' 8,901' 8,911' 14' Opened 5/7/01 12,710' 12,790' 8,923' 8,983' 80' 5/7/01, partial reperf 1/27/05 12,800' 12,830' 8,990' 9,012' 30' 5/7/2001 G-7/HB-1 12,950' 13,010' 9,102' 9,147' 60' 7/3/01, partial reperf 1/27/05, partial reperf 8/22/08 HB2 13,075' 13,095' 9,196' 9,211' 20' 8/20/08 HB3 13,120' 13,130' 9,230' 9,238' 10' 8/20/08 HB3 13,190' 13,210' 9,283' 9,298' 20' HB-4 13,228' 13,340' 9,312' 9,397' 112' 5/7/01, partial reperf 1/27/05 HB5 13,405' 13,425' 9,447' 9,463' 20' Opened 1/13/02, reperf 8/20/08 HB5 13,440' 13,460' 9,475' 9,491' 20' Opened 1/13/02 HB6 13,565' 13,580' 9,573' 9,585' 15' Opened 1/13/02, Isolated 2/02 HB7 13,610' 13,650' 9,609' 9,641' 40' Opened 1/13/02, Isolated 2/02 Rig Start Date End Date Slickline 7/21/20 7/27/20 Morning safety meeting, talk w/ company rep, sign permits, TGSM. R/U Slickline unit. Pressure test lubricator to 250psi / 2,500psi - Test Good. Rih w/ 2" RB w/ 2 7/8 DD Hole finder to 3221' kb, set hole finder, pressure up, cannot pressure up, pooh. Rih w/ same to 3203' kb, set hole finder, pressure up, hole finder goes down hole under pressure to 3221'kb. Pull up to 3211' kb, PT-fail, pull up to 3192' kb, (could not get to set between 3194-3210) Pt- Fail. Pull up to 3142' kb, Fail, pul l up to 2942' kb, pass. Pooh. Rih w/ 2" SB w/ 2 7/8 DD Hole Finder to 3221' kb, set Hole finder, pooh. Rih w/ Pony tail hole finder to 2920' kb, pressure up at 30 GPM, fall slow to 3167' kb, hang up several times at that spot. Tubing pressures up to 700 PSI and holds. Bleed pressure off and make several more passes. Still seeing spot @ 3167' kb. Talk w/ town, decide to rig down for the night. 07/26/20 - Sunday Arrive @ OSK. Flgiht departs OSK for King Salmon Platform. Talk w/ company rep, sign permits, Wireline Checklist meeting. Rig up on well. Pressure test lubricator to 2500 PSI. Rih w/ 2 7/8 GS to 3213' kb, latch AA stop pooh, ooh w/ stop. Rih w/ same to 3214' kb, latch patch pooh, ooh w/ patch. Rih w/ same to 3236' kb, latch patch pooh, ooh w/ patch. Patch missing 2 O-rings. Rih w/ same to 3247' kb, latch patch pooh, ooh w/ patch. Patch missing 2 O-rings. Rih w/ same to 3259' kb, latch stop, pooh, ooh w/ patch. Rih w/ same to 3282' kb, latch bottom stop, pooh, ooh w/ stop. Rih w/ 2 7/8 Gs w/ Ad-2 stop to 3290' kb, set stop pooh. Ooh no Stop. Rih w/ 2 7/8 Gs w/ 22' patch w/ Packoff on bottom to 3290' kb (zeroed on bottom). Pooh. Rih w/ 2 7/8 Gs w/ 11' patch to 3257 kb, (zeroed @ GS) set patch pooh, ooh no patch. Rih w/ same to 3245' kb, set patch pooh, ooh no patch. Rih w/ same w/ 22' Patch to 3222' kb, (zeroed @ GS), set patch, pooh, ooh no patch. Rih w/ 2 7/8 Gs w/ AA- Stop to 3221' kb, set stop pooh. Ooh no stop. Rig down off well. Fly slickline crew to beach. End ticket. 07/21/20 - Tuesday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name K-01RD2 50-733-20054-01 201-009 Still seeing spot @ 3167' kb. Rig Start Date End Date Slickline 7/21/20 7/27/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name K-01RD2 50-733-20054-01 201-009 07/27/20 - Monday Morning safety meeting, talk w/ company rep, sign permits. Wait on Helicopter with tools. Rih w/ 2 7/8 BLB to 3100-3200' brush up and down, seeing same spot @ 3167 that w e were seeing the day before. Pooh. Production attempts to pressure up tubing but tubing will not hold. Fluid level had also dropped overnight to 2300' kb. Ooh w/ brush w/ large strand of Pony tail. Rih w/ Pony tail hole finder, have production pump at 30 gpm rate, see same spot @ 3167' kb, pooh. Talk w/ town. Decide to extend existing patch up 10' and add another 20' patch over spot @ 3167' kb. Rih w/ 2" JDC to 3221' kb, latch DD hole finder, pooh, ooh w/ hole finder. Rih w/ 2 7/8 Gs to 3222' kb, latch AA- stop, pooh, ooh no stop. Rih w/ same to 3224' kb, latch 22' patch pooh, ooh w/ patch. Rih w/ same w/ 11' Patch to 3235' kb, (zeroed @ GS) set patch pooh, ooh no patch. Rih w/ same w/ 22' Patch w/ Packoff on top to 3212' kb, attempt to set patch, tool will not shear, pooh. Ooh w/ 22' patch w/ 11' patch stuck on the bottom. GS is not completely sheared. Redress Packoff. Rih w/ 2 7/8 Gs w/ 11' patch to 3235' kb, set patch, pooh. Ooh no patch. Rih w/ same w/ 22' Patch w/ packoff on top to 3212' kb, set patch pooh, ooh no patch. Rih w/ same w/ AA- stop to 3212' kb, set stop, pooh, ooh no stop. Rih w/ same w/ AD-2 stop to 3177' kb, set stop, pooh, ooh no stop. Rih w/ 22' Patch w/ packoff on top and bottom to 3154' kb, set patch, pooh, ooh no patch. Rih w/ same w/ AA-stop to 3153' kb, set stop, pooh, ooh no stop. Ooh w/ tools, rig down off well. Job complete 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pools 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 13,780'13,448' Casing Collapse Structural Conductor Surface 1,540 psi Intermediate 3,810 psi Production Liner 7,020 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:mmckinley@hilcorp.com Contact Phone: (907) 777-8387 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 13,779' 9,743' 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. 6/25/2020 2-7/8" Daniel E. Marlowe N/A & N/A 11,680 - 13,650 N/A & N/A Tubing Grade:Tubing MD (ft): 8,156 - 9,641 Perforation Depth TVD (ft): 8,160 psi Tubing Size: 7,920' 9-5/8"6,043' 2,384' Perforation Depth MD (ft): 6,043' 7" 109' 2,167' 4,928' 110' 2,384' 20" 13-3/8" 110' 6.5# / L-80 TVD Burst 10,583 MD 3,090 psi 50-733-20054-01-00Anchorage, AK 99503 Hilcorp Alaska, LLC N/A Trading Bay Unit K-01RD2 13,540'9,745' 13,448' 9,480' 2,026 psi COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018777 Authorized Signature: Operations Manager Mark McKinley Other: Tubing Patch PRESENT WELL CONDITION SUMMARY Length Size 6,330 psi 201-009 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 5:21 pm, Jun 12, 2020 320-254 Daniel Marlowe I am approving this document 2020.06.12 09:55:28 -08'00' Daniel Marlowe Tubing Patch ADL0017594 SFD 6/15/2020 10-404 SFD 6/15/2020 DSR-6/12/2020gls 6/15/20 Comm. on Required? Yes 6/16/2020 dts 6/15/2020 JLC 6/15/2020 RBDMS HEW 6/18/2020 Well Work Prognosis Well: K-01RD2 Well Name:King Salmon K-01RD2 API Number:50-733-20054-01 Current Status:Oil Producer Leg:Leg #4 NW Corner Estimated Start Date:June 25, 2020 Rig:Slick Line Reg. Approval Req’d?10-403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett 777-8332 Permit to Drill Number:201-009 First Call Engineer:Mark McKinley (907) 777-8387 (O) (907) 953-2685 (M) Second Call Engineer:Dan Marlowe (907) 283-1329 (O) (907) 398-9904 (M) Current Bottom Hole Pressure:2,489 psi @ 7,505’ TVD 0.37 psi/ft (7.2 ppg) ESP Gauge Maximum Expected BHP:2,777 psi @ 7,505’ TVD 0.37 psi/ft (7.2 ppg) ESP Gauge Maximum Potential Surface Pressure:**2,026 psi Using 0.1 psi/ft gradient per 20AAC 25.280(b)(4) **This is a no flow well 10/18/2017 Brief Well Summary: The K-01RD2 ESP had a tubing leak and a patch was installed from 3,282’-3,213’ on 5/17/2020. On 6/9/2020 it appears the patch has failed or there is another tubing leak. Diagnostic Slickline work is being performed, the original patch will be assessed and additional patches will be run if needed. 1. Rig up slick line and pressure test to 2,500 psi. 2. Run diagnostic tools to locate tubing leak. 3. Install tubing patch(s) across hole(s) estimated to be between ±3,000’-±3,600’ (actual depth TBD) 4. Tubing cannot be pressure tested due to ID restrictions of the tubing patch. Patch effectiveness will be determined by running the ESP and monitoring flow and pressures. 5. Rig down slick line and lubricator. 6. Turn well over to production. Attachments: 1. Wellbore Schematic Current 2. Wellbore Schematic Proposed (no packer) Updated by: JLL 06/02/20 SCHEMATIC King Salmon Platform Well K-01RD2 PTD: 201-009 API: 50-733-20054-01 Last Completed: 08/09/2017 Casing and Tubing Detail Size Type Wt/ Grade TOP BTM CONN / ID Cement / Other 20” Conductor 94/ H40 Surf 110’ Welded/ 19” Driven 13-3/8” Surface 61/ K55 Surf 2,384’ BTC/ 12.515” 2640 “G”/ Surface 9-5/8” Intermediate 47/ N80 Surf 112’ BTC/ 8.681”1321 “G” Surface9-5/8” Intermediate 43.5/ N80 112’ 6,043’ BTC/ 8.755” 7” Liner 29/ L80 5,859’ 13,779’ BTC-KC/ 6.184” 183BBL/ 5859’ Tubing 2-7/8” Tubing 6.5/ L80 Surf 10,583’ EUE 8RD No. Depth (MD) Depth (TVD) ID OD Item 26.4’ 26.4’ Tubing Hanger: OCT-UH-TC-1A-ESP, 13 X 4-1/2 IBT lift and susp, w/ 4" Type H BPV profile, 3/8 cont. control line port 27’ 27’ 2.441” 4.500” X-over: 4-1/2” IBT to 2-7/8” 8RD pin 1 10,583’ 7,424’ N/A 4.000” Discharge, Bolt-On 10,583’ 7,424’ N/A 4.000” Pump - (3) 400 Series, 125 SF1750 (1) 400 Series 076 SFG2500 10,670’ 7,473’ N/A 4.000” Gas Separator – 400 Series UT & LT 400X Vortex 10,675’ 7,476’ N/A 4.000” Tandem Seals – 400 Series BPBSL 10,692’ 7,485’ N/A 4.000” Motor – 456 Series FMS, 240 HP 10,727’ 7,505’ N/A 4.560” Centralizer/Anode TD =13,780’ PBTD = 13,750’ 13-3/8” @ 2384’ GO-4 GO-6 HB-2 G-5 HB-1/G7 HB-3 HB-6 CIBP Set @ 13,540’ KB-THF: 26.4’ KB HB-7 4-21-2011 Fill tagged 13448’ MD HB-4 HB-5 20” @ 110’ RKB: 100’ AMSL 9-5/8” @ 6043’ 1 Tubing Patch 3,213’ -3,282’ ID – 0.875” TOL: 5859’ G-1 Directional Data: max = 59° at 8,485’ OCTG Rotating Hours 24” Structural Casing 110 Hours 20” Conductor 110 Hours 13-3/8” Surface Pipe 227 Hours 9-5/8” Casing 651 Hours 7” Liner 50 Hours PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date GO-4 11,680' 11,720' 8,156' 8,186' 40' 5/7/01, partial reperf 1/27/05 GO-5 11,732' 11,742' 8,195' 8,202' 10' Opened 5/7/01 GO-6 11,780' 11,810' 8,229' 8,251' 30' Opened 5/7/01 11,820' 11,840' 8,259' 8,273' 20' Opened 5/7/01 11,864' 11,891' 8,291' 8,310' 27' Opened 5/7/01 G-1 12,030' 12,080' 8,413' 8,451' 50' 5/7/01, partial reperf 1/27/05 12,090' 12,120' 8,459' 8,481' 30' Opened 5/7/01 12,142' 12,162' 8,498' 8,513' 20' Opened 5/7/01 G-5 12,659' 12,674' 8,885' 8,896' 15' Opened 5/7/01 12,680' 12,694' 8,901' 8,911' 14' Opened 5/7/01 12,710' 12,790' 8,923' 8,983' 80' 5/7/01, partial reperf 1/27/05 12,800' 12,830' 8,990' 9,012' 30' 5/7/2001 G-7/HB-1 12,950' 13,010' 9,102' 9,147' 60' 7/3/01, partial reperf 1/27/05, partial reperf 8/22/08 HB2 13,075' 13,095' 9,196' 9,211' 20' 8/20/08 HB3 13,120' 13,130' 9,230' 9,238' 10' 8/20/08 HB3 13,190' 13,210' 9,283' 9,298' 20' HB-4 13,228' 13,340' 9,312' 9,397' 112' 5/7/01, partial reperf 1/27/05 HB5 13,405' 13,425' 9,447' 9,463' 20' Opened 1/13/02, reperf 8/20/08 HB5 13,440' 13,460' 9,475' 9,491' 20' Opened 1/13/02 HB6 13,565' 13,580' 9,573' 9,585' 15' Opened 1/13/02, Isolated 2/02 HB7 13,610' 13,650' 9,609' 9,641' 40' Opened 1/13/02, Isolated 2/02 Updated by: JLL 06/11/20 PROPOSED King Salmon Platform Well K-01RD2 PTD: 201-009 API: 50-733-20054-01 Last Completed: 08/09/2017 Casing and Tubing Detail Size Type Wt/ Grade TOP BTM CONN / ID Cement / Other 20” Conductor 94/ H40 Surf 110’ Welded/ 19” Driven 13-3/8” Surface 61/ K55 Surf 2,384’ BTC/ 12.515” 2640 “G”/ Surface 9-5/8” Intermediate 47/ N80 Surf 112’ BTC/ 8.681”1321 “G” Surface9-5/8” Intermediate 43.5/ N80 112’ 6,043’ BTC/ 8.755” 7” Liner 29/ L80 5,859’ 13,779’ BTC-KC/ 6.184” 183BBL/ 5859’ Tubing 2-7/8” Tubing 6.5/ L80 Surf 10,583’ EUE 8RD No. Depth (MD) Depth (TVD) ID OD Item 26.4’ 26.4’ Tubing Hanger: OCT-UH-TC-1A-ESP, 13 X 4-1/2 IBT lift and susp, w/ 4" Type H BPV profile, 3/8 cont. control line port 27’ 27’ 2.441” 4.500” X-over: 4-1/2” IBT to 2-7/8” 8RD pin 1 10,583’ 7,424’ N/A 4.000” Discharge, Bolt-On 10,583’ 7,424’ N/A 4.000” Pump - (3) 400 Series, 125 SF1750 (1) 400 Series 076 SFG2500 10,670’ 7,473’ N/A 4.000” Gas Separator – 400 Series UT & LT 400X Vortex 10,675’ 7,476’ N/A 4.000” Tandem Seals – 400 Series BPBSL 10,692’ 7,485’ N/A 4.000” Motor – 456 Series FMS, 240 HP 10,727’ 7,505’ N/A 4.560” Centralizer/Anode TD =13,780’ PBTD = 13,750’ 13-3/8” @ 2384’ GO-4 GO-6 HB-2 G-5 HB-1/G7 HB-3 HB-6 CIBP Set @ 13,540’ KB-THF: 26.4’ KB HB-7 4-21-2011 Fill tagged 13448’ MD HB-4 HB-5 20” @ 110’ RKB: 100’ AMSL 9-5/8” @ 6043’ 1 Tubing Patch Estimated between ±3,000’ - ±3,600’ ID –0.875” TOL: 5859’ G-1 Directional Data: max = 59° at 8,485’ OCTG Rotating Hours 24” Structural Casing 110 Hours 20” Conductor 110 Hours 13-3/8” Surface Pipe 227 Hours 9-5/8” Casing 651 Hours 7” Liner 50 Hours PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date GO-4 11,680' 11,720' 8,156' 8,186' 40' 5/7/01, partial reperf 1/27/05 GO-5 11,732' 11,742' 8,195' 8,202' 10' Opened 5/7/01 GO-6 11,780' 11,810' 8,229' 8,251' 30' Opened 5/7/01 11,820' 11,840' 8,259' 8,273' 20' Opened 5/7/01 11,864' 11,891' 8,291' 8,310' 27' Opened 5/7/01 G-1 12,030' 12,080' 8,413' 8,451' 50' 5/7/01, partial reperf 1/27/05 12,090' 12,120' 8,459' 8,481' 30' Opened 5/7/01 12,142' 12,162' 8,498' 8,513' 20' Opened 5/7/01 G-5 12,659' 12,674' 8,885' 8,896' 15' Opened 5/7/01 12,680' 12,694' 8,901' 8,911' 14' Opened 5/7/01 12,710' 12,790' 8,923' 8,983' 80' 5/7/01, partial reperf 1/27/05 12,800' 12,830' 8,990' 9,012' 30' 5/7/2001 G-7/HB-1 12,950' 13,010' 9,102' 9,147' 60' 7/3/01, partial reperf 1/27/05, partial reperf 8/22/08 HB2 13,075' 13,095' 9,196' 9,211' 20' 8/20/08 HB3 13,120' 13,130' 9,230' 9,238' 10' 8/20/08 HB3 13,190' 13,210' 9,283' 9,298' 20' HB-4 13,228' 13,340' 9,312' 9,397' 112' 5/7/01, partial reperf 1/27/05 HB5 13,405' 13,425' 9,447' 9,463' 20' Opened 1/13/02, reperf 8/20/08 HB5 13,440' 13,460' 9,475' 9,491' 20' Opened 1/13/02 HB6 13,565' 13,580' 9,573' 9,585' 15' Opened 1/13/02, Isolated 2/02 HB7 13,610' 13,650' 9,609' 9,641' 40' Opened 1/13/02, Isolated 2/02 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,780 feet 13,540 feet true vertical 9,745 feet 13,448 feet Effective Depth measured 13,448 feet N/A feet true vertical 9,480 feet N/A feet Perforation depth Measured depth 11,680 - 13,650 feet True Vertical depth 8,156 - 9,641 feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5 / L-80 10,583 MD 7,424 TVD Packers and SSSV (type, measured and true vertical depth)N/A & N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,160psi Daniel E. Marlowe Operations Manager Burst Collapse Mark McKinley mmckinley@hilcorp.com Tubing Pressure 1,540psi 3,810psi 3,090psi 6,330psi 907 777-8387 109 2,167 4,928 9,743 110 2,384 Conductor Surface 7,020psi 20" 13-3/8" 9-5/8" 6,043 Size 56 Production Casing Structural Liner 7,920 Length Intermediate N/A Junk 5. Permit to Drill Number: 52 McArthur River Field / Hemlock Oil & Middle Kenai G Oil PoolsN/A measured 6,043 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 142 Gas-Mcf 57 N/A Oil-Bbl 58 Water-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-177 57 Authorized Signature with date: Authorized Name: 690 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-009 50-733-20054-01-00 Plugs ADL0018777 Trading Bay Unit K-01RD2 Other: Tubing Patch measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 197 Representative Daily Average Production or Injection Data 54428 Casing Pressure 7" MD 110 2,384 13,779 TVD measured true vertical Packer PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:23 am, Jun 03, 2020 Daniel Marlowe I am approving this document 2020.06.03 09:47:16 -08'00' Daniel Marlowe DSR-6/3/2020 RBDMS HEW 6/3/2020 gls 6/4/20 Tubing Patch Updated by: JLL 06/02/20 SCHEMATIC King Salmon Platform Well K-01RD2 PTD: 201-009 API: 50-733-20054-01 Last Completed: 08/09/2017 Casing and Tubing Detail Size Type Wt/ Grade TOP BTM CONN / ID Cement / Other 20” Conductor 94/ H40 Surf 110’ Welded/ 19” Driven 13-3/8” Surface 61/ K55 Surf 2,384’ BTC/ 12.515” 2640 “G”/ Surface 9-5/8” Intermediate 47/ N80 Surf 112’ BTC/ 8.681”1321 “G” Surface9-5/8” Intermediate 43.5/ N80 112’ 6,043’ BTC/ 8.755” 7” Liner 29/ L80 5,859’ 13,779’ BTC-KC/ 6.184” 183BBL/ 5859’ Tubing 2-7/8” Tubing 6.5/ L80 Surf 10,583’ EUE 8RD No. Depth (MD) Depth (TVD) ID OD Item 26.4’ 26.4’ Tubing Hanger: OCT-UH-TC-1A-ESP, 13 X 4-1/2 IBT lift and susp, w/ 4" Type H BPV profile, 3/8 cont. control line port 27’ 27’ 2.441” 4.500” X-over: 4-1/2” IBT to 2-7/8” 8RD pin 1 10,583’ 7,424’ N/A 4.000” Discharge, Bolt-On 10,583’ 7,424’ N/A 4.000” Pump - (3) 400 Series, 125 SF1750 (1) 400 Series 076 SFG2500 10,670’ 7,473’ N/A 4.000” Gas Separator – 400 Series UT & LT 400X Vortex 10,675’ 7,476’ N/A 4.000” Tandem Seals – 400 Series BPBSL 10,692’ 7,485’ N/A 4.000” Motor – 456 Series FMS, 240 HP 10,727’ 7,505’ N/A 4.560” Centralizer/Anode TD =13,780’ PBTD = 13,750’ 13-3/8” @ 2384’ GO-4 GO-6 HB-2 G-5 HB-1/G7 HB-3 HB-6 CIBP Set @ 13,540’ KB-THF: 26.4’ KB HB-7 4-21-2011 Fill tagged 13448’ MD HB-4 HB-5 20” @ 110’ RKB: 100’ AMSL 9-5/8” @ 6043’ 1 Tubing Patch 3,213’ -3,282’ ID – 0.875” TOL: 5859’ G-1 Directional Data: max = 59° at 8,485’ OCTG Rotating Hours 24” Structural Casing 110 Hours 20” Conductor 110 Hours 13-3/8” Surface Pipe 227 Hours 9-5/8” Casing 651 Hours 7” Liner 50 Hours PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date GO-4 11,680' 11,720' 8,156' 8,186' 40' 5/7/01, partial reperf 1/27/05 GO-5 11,732' 11,742' 8,195' 8,202' 10' Opened 5/7/01 GO-6 11,780' 11,810' 8,229' 8,251' 30' Opened 5/7/01 11,820' 11,840' 8,259' 8,273' 20' Opened 5/7/01 11,864' 11,891' 8,291' 8,310' 27' Opened 5/7/01 G-1 12,030' 12,080' 8,413' 8,451' 50' 5/7/01, partial reperf 1/27/05 12,090' 12,120' 8,459' 8,481' 30' Opened 5/7/01 12,142' 12,162' 8,498' 8,513' 20' Opened 5/7/01 G-5 12,659' 12,674' 8,885' 8,896' 15' Opened 5/7/01 12,680' 12,694' 8,901' 8,911' 14' Opened 5/7/01 12,710' 12,790' 8,923' 8,983' 80' 5/7/01, partial reperf 1/27/05 12,800' 12,830' 8,990' 9,012' 30' 5/7/2001 G-7/HB-1 12,950' 13,010' 9,102' 9,147' 60' 7/3/01, partial reperf 1/27/05, partial reperf 8/22/08 HB2 13,075' 13,095' 9,196' 9,211' 20' 8/20/08 HB3 13,120' 13,130' 9,230' 9,238' 10' 8/20/08 HB3 13,190' 13,210' 9,283' 9,298' 20' HB-4 13,228' 13,340' 9,312' 9,397' 112' 5/7/01, partial reperf 1/27/05 HB5 13,405' 13,425' 9,447' 9,463' 20' Opened 1/13/02, reperf 8/20/08 HB5 13,440' 13,460' 9,475' 9,491' 20' Opened 1/13/02 HB6 13,565' 13,580' 9,573' 9,585' 15' Opened 1/13/02, Isolated 2/02 HB7 13,610' 13,650' 9,609' 9,641' 40' Opened 1/13/02, Isolated 2/02 Tubing Patchg 3,213’ -3,282’ Rig Start Date End Date Slickline 4/24/20 5/17/20 PJSM and PTW. RIH w/ 2 7/8 GS, tag fluid @ 2120' kb - POOH. RIH w/ 2 " JDC w/ 2 7/8 DD Hole finder to 2222' KB, PT 500psi- Pass - POOH. Re-dress DD. RIH w/ same to 3069' KB, PT 500psi- Pass - POOH. RIH w/ DD Hole finder to 3115 ' KB. Top sheave spun up, fix top sheave. PT 500 PSI- pass, looks like something went wrong with previous nights PT. Talk w/ town decide to pull patch and move down. RIH w/ 2 1/2 JDC, top sheave spins up trying to get in the hole. Decide to lay down and switch to a staff sheave and re-head. RIH w/ 2 1/2 JDC to 3115' KB, latch A-stop, POOH, OOH w/ stop. RIH w/ 2 7/8 GS to 3115' KB, latch patch, POOH. OOH w/ patch, both packoffs seem to be in good shape. RIH w/ same to 3129' KB, latch AD-2 stop POOH. OOH w/ stop. Stop has .87 min ID. RIH w/ 2 7/8 GS w/ AD-2 stop to 3154' KB, (zeroed at top of fishing neck) set stop POOH. OOH no stop. Begin to RIH w/ patch, realize KB was not added on previous run. RIH w/ 2 7/8 GS and drag Ad-2 stop up hole to 3141' KB, set stop POOH. OOH no stop. RIH w/ 2 7/8 GS w/ 13' patch w/ packoff on bottom, element is 1' from bottom of patch, zeroed at the element. POOH. RIH to 3139' KB, set patch POOH. Patch has 1.9 OD w/ 1.55 ID. RIH w/ 2 7/8 GS w/ 10' Patch w/ stinger on Bottom, zero at bottom of patch. RIH to 3127' KB, set patch POOH. Patch has 1.66 OD w/ 1.25 ID. RIH w/ 2 7/8 GS w/ 12' Patch w/ packoff on top and stinger on bottom. Zero at packoff element. RIH w/ Patch to 3105' kb, set patch, POOH. RIH w/ 2 7/8 GS w/ AA-stop to 3104' KB, set stop, POOH, OOH no stop. Ooh w/ tools, rig down secure well for the night. Have production flow well overnight. No operations to report 04/25/2020 - Saturday K-01RD2 tubing patch held, but a second hole developed at 1:00AM on 4/27/2020. Slickline mobilized at 8:00AM, flight to the King Salmon at 11:00AM. PJSM and PTW. R/U SL. Pressure test lubricator to 2500psi - Test good. RIH w/ 2" JDC & 2 7/8 DD hole finder to 3115' kb, (zeroed at DD element). PT tubing, can't get tubing to pressure up - POOH. Fluid level @ 2100' kb. Pressure test to 500psi @ 1833' kb. Well takes 15 min to pressure up and held. Tubing hole is somewhere below 1833' kb and above existing patch. Secure well and SDFN. 04/28/2020 - Tuesday 04/26/2020 - Sunday No operations to report 04/27/2020 - Monday 04/24/2020 - Friday PJSM and PTW. Pressure test lubricator to 2500psi - Test Good. RIH w/ D&D hole finder w/ JDC to 3360' set JDC - Leak above 3360' - POOH. RIH w/ pony tail hole finder and detect hole at 3,110' - POOH. RIH w/ JDC to 3,359' - latch- POOH. RIH w/ Grapple to 10,581' - POOH - no element found. RIH w/pump bailer to 10,581' - POOH - element pieces recovered. RIH w/ AD2 Stop w/ GS to 3,117' - W/T- Set Stop - POOH. RIH w/ Patch W/ GS to 3103' - W/T - Set Patch - POOH. RIH w/ A-Stop W/ GS to 3103'- W/T - Set Stop - POOH. R/D Slickline and turn well over to production. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name K-01RD2 50-733-20054-01 201-009 Rig Start Date End Date Slickline 4/24/20 5/17/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name K-01RD2 50-733-20054-01 201-009 04/29/2020 - Wednesday PJSM and PTW. ESP was ran overnight and a hole in the tubing still exists. Decide to pull tubing patch and run a caliper log. R/U and test lubricator to 2500psi - Test Good. RIH w/ 2 7/8 GS to 3104' KB, pull A-stop, POOH, OOH w/ stop. RIH w/ same to 3105' KB, latch top section of patch, POOH. OOH w/ patch. RIH w/ same to 3115' KB, latch middle section of patch, POOH, OOH w/ patch. RIH w/ same to 3127'KB, latch bottom section of patch, POOH, OOH w/ patch. RIH w/ same to 3140' KB, latch Ad-2 stop, POOH, OOH w/ stop. R/D, Secure well. 04/30/2020- Thursday No operations to report 05/01/2020 - Friday No operations to report 05/02/2020 - Saturday No operations to report 05/03/2020 - Sunday No operations to report 05/04/2020 - Monday No operations to report 05/05/2020 - Tuesday ARRIVE ONBOARD PLATFORM, SIGN-IN/PERMIT/JSA/PRE-WIRELINE SAFETY MEETING W/PROD. CHECK EQUIPMENT. RU SLICKLINE, PT LUBRICATOR TO 2500 PSI, - PASS. RIH W/2" DD BAILER TO 10594KB, TAG TOP OF PUMP, POOH. OOH. REMOVE BAILER AND RU CALIPER TOOLS. RIH W/CALIPER TOOLS TO 10594KB @ 175 FPM. BEGIN LOGGING UP HOLE @ 50 FPM,OOH. REMOVE CALIPER AND STANDBY FOR DATA DOWNLOAD. RD SLICKLINE. 05/06/2020 - Wednesday No operations to report. 05/07/2020- Thursday No operations to report. 05/08/2020 - Friday No operations to report. 05/09/2020 - Saturday No operations to report. 05/10/2020 - Sunday No operations to report. 05/11/2020 - Monday No operations to report. Rig Start Date End Date Slickline 4/24/20 5/17/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name K-01RD2 50-733-20054-01 201-009 05/12/2020 - Tuesday ARRIVE @ OSK. ARRIVE ONBOARD. SIGN-IN/PERMIT/JSA/WIRELINE SAFETY MEETING. SPOT UNIT, RU SLICKLINE. STAB ON RISER AND STAND UP LUBRICATOR AND SHEAVE. STANDBY FOR PRODUCTION. PT LUBRICATOR TO2500 PSI, CHANGE O-RING, RE-TEST, GOOD. RIH W/BRAIDED LINE BRUSH TO 9624KB, SET DOWN AND W/T EXTREMELY HARD TO BOTTOM AT 10588KB, POOH. RIH W/AD-2 STOP TO 1150KB, TOOL SHEARED, POOH W/STOP, RE-PIN. RIH W/SAME TO 10593KB, W/T, SHEAR OFF, POOH. RIH W/DD-PACKOFF TO 10591KB, W/T TO SHEAR GS, UNABLE TO SHEAR, ELEMENT APPEARS TO BE EXPANDED BUT GS NOT SHEARED. POOH, OOH W/ELEMENT MISSING ON 05/13/2020 - Wednesday MORNING SAFETY MEETING, PERMIT/JSA. DISCUSS DAYS OPERATIONS, DISCUSS SIM-OPS W/CRANE OPERATOR. RIH W/BRAIDED LINE BRUSH TO 10591KB, W/T TO FISH PACKOFF ELEMENT. POOH W/EXTRA PICKUP WEIGHT, GRABBED AD-2 STOP AND CANNOT SHAKE FREE, POOH AND AD-2 STOP COMES OFF AT 3668KB. CONT OOH, NO ELEMENT ON BRUSH. RIH W/2.5" GS TO 3668KB, LATCH AD-2 STOP, POOH WITH HALF OF PACKOFF ELEMENT IN FISH NECK. RIH W/2.5" GS AND AD-2 STOP TO 9625KB, CANNOT SHEAR AD-2 STOP. RUN DOWN TO TOP OF PUMP, SHEAR STOP WHILE SPANGING UP, PULL UP TO 9625KB, SET STOP AND HAVE POOR SPANG ACTION TRYING TO SHEAR GS PULLING TOOL, EVENTUALLY SHEAR PIN AND POOH, ADD 5FT WEIGHT BAR. RIH W/2.5" GS AND D&D PACKOFF TO 6573KB, SET DOWN, PICK UP AND WORK TOOL DOWNHOLE SLOWLY, TO 9622KB. WORK TOOL FOR 1HR AND CANNOT SHEAR GS PULLING TOOL, POOH W/PLUG SLOWLY. REDRESS ON SURFACE, RIH W/SAME W/ALUMINUM PIN IN 2.5" GS TO 9622KB, SET PACKOFF PLUG, POOH, PLUG SET. RIH W/5FT OF 1.5" WEIGHT BAR-KJ-OJ-LSSJ W/PONYTAIL TO 3115KB, HAVE PRODUCTION BEGIN PUMPING DOWN TUBING AND BRING PRESSURE UP TO 250 PSI AND MONITOR FLOW RATE. PUMPED 16 BBLS AND PRESSURE BUILT TO 400. TALK TO TOWN AND DECIDE TO PRESSURE UP TO 1000 PSI, TUBING HOLD @ 1000# FOR 2HRS. TALK W/TOWN AGAIN AND FORMULATE PLAN FORWARD FOR TOMORROW. BLEED DOWN WELL FOR NIGHT. SECURE WELL FOR NIGHT, FINISH PAPERWORK. 05/14/2020- Thursday MORNING SAFETY MEETING, PERMIT/JSA. START EQUIPMENT, CHECK WORK AREA. RIH W/ EQUILIZING PRONG TO 9622KB, BREAK KOBE AND WELL GOES ON VACUUM. RIH W/2.5" GS TO SAME ( FLUID LVL @ 1415KB ) LATCH PLUG AND SPANG FREE, LET ELEMENT RELAX FOR 20 MINS. POOH SLOWLY W/PACKOFF PLUG. ELEMENT CAME OFF AROUND 8200KB. RIH W/SAME TO SAME, LATCH AD-2 STOP, POOH. RIH W/2-7/8" D&D HOLE FINDER TO10,590' KB, W/T - FAIL PT, POOH TO 10,459' KB, W/T FAIL. POOH TO 10357KB-FAIL. POOH TO 10,255' KB, W/T POOH TO 10,153' KB, PT- FAIL. POOH TO 10,055' KB, PT- FAIL. POOH TO 9953' KB, PT- FAIL. POOH TO 9849' KB, PT- FAIL. POOH TO 9760' KB, PT- FAIL. POOH TO 9696' KB, PT- FAIL. POOH TO 9639' KB, PT-FAIL TO 9629' KB, PT- FAIL. POOH TO 9619KB, PT - FAIL. POOH TO 9608KB, PT - FAIL. POOH TO 9598KB, PT - FAIL. POOH, TESTING FINISHED. OOH, INSPECT HOLE FINDER, ALL SEAL SURFACES ARE GOOD. CALL TOWN AND DISCUSS PLAN FORWARD FOR NEXT DAY, LAY DOWN FOR NIGHT. Rig Start Date End Date Slickline 4/24/20 5/17/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name K-01RD2 50-733-20054-01 201-009 MORNING SAFETY MEETING. TALK W/ COMPANY REPS, SIGN PERMITS. RIH W/ PONY TAIL HOLE FINDER TO 9300' KB, BEGIN PUMING @ APPROX 32 GPM, AND 940 PSI. RIH @ 30FPM TO 10,583' KB, DO NOT SEE HOLE, PULL UP SLOWLY TO 9400' KB. POOH TO 4000' KB, POOH SLOW, CONTINUE TO PUMP. HANG UP @ 3262' KB, TEST PUMP PRESSURE, IMMEDIETLY SPIKES, PULL UP, GO BACK DOWN HOLE AND SIT DOWN IN SAME SPOT. OOH W/ TOOLS, TALK W/ TOWN, DECIDE TO RUN DD HOLE FINDER. LAY DOWN LUB, RE-HEAD, CUT 30' OF WIRE AND TEST. RIH W/ 2" JUC TO 3283' KB, SET HOLE FINDER, BEGIN PT. FAIL PULL UP TO 3274' KB, PT- FAIL, POOH TO 3270' KB, PT- FAIL- PULL UP TO 3265' KB, PT- FAIL, PULL UP TO 3260' KB, PT- FAIL, PULL UP TO 3254' KB, PT- FAIL, RATE DROPPED FROM 24 GPM IN PREVIOUS TEST TO 12 GPM THIS TEST. PULL UP TO 3248' KB FAIL W/ SAME RESULT. PULL UP HOLE TO 3243' KB, FAIL- BUT RATE DROPS TO 6GPM. PULL UP HOLE TO 3238'KB, PT- FAIL SAME. PULL UP TO 3228' KB, PT- FAIL, RATE CLIMBS BACK UP TO 24GPM. POOH AND RE-DRESS TOOL. RIH W/ SAME TO 3240' KB, PT- FAIL, PULL UP TO 3228' KB, PT- FAIL, PULL UP TO 3213' KB PT 700 PSI- PASS. POOH. LAY DOWN FOR THE NIGHT. OOH W/ TOOLS, SECURE WELL FOR THE NIGHT. END TICKET. 05/15/2020 - Friday MORNING SAFETY MEETING, PERMIT/JSA. START EQUIPMENT, CHECK WORKSITE, PREP TOOLS. RIH W/ 2 7/8 GS W/ 2 7/8 DD PACKOFF TO 10,593' KB, W/T, SHEAR OFF POOH. OOH PT- FAIL, JUDGING BY DISCHARGE PRESSURE ON ESP, IT APEARS THE PACKOFF PLUG IS NOT HOLDING. RIH W/ EQUILZING PRONG TO 10,593' KB, EQUILIZE, POOH. Rih W/ 2 7/8 GS TO BOTTOM, LATCH PLUG, PULL UP 20', ALLOW ELEMENT TO RELAX, POOH VERY SLOWLY. OOH W/ PACKOFF, ELEMENT STILL ATTATCHED. RIH W/ 2 7/8 BLB TO 10,593' KB, WORK BRUSH BETWEEN BOTTOM AND 9,600' KB 5X, POOH. RIH W/ 2 7/8 GS W/ 2 7/8 AD-2 STOP TO 10,593' KB, W/T, SHEAR GS PIN BEFORE AD-2 STOP, POOH. RIH W/ 2 7/8 GS TO 10,593' KB, LATCH STOP, POOH TO 10,580' KB, W/T POOH, OOH NO STOP. BREAK FOR DINNER. RIH W/ 2 7/8 GS W/ WEATHERFORD PACKOFF PLUG TO 10,579' KB, SET PACKOFF POOH. PT- FAIL, DISCHARGE PRESSURE ON ESP INDICATES THAT PACKOFF IS HOLDING AND THAT THERE IS A HOLE IN THE TUBING. OOH W/ TOOLS, LAY DOWN FOR THE NIGHT. 05/16/2020 - Saturday Rig Start Date End Date Slickline 4/24/20 5/17/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name K-01RD2 50-733-20054-01 201-009 05/17/2020 - Sunday Morning Safety meeting. Talk w/ company rep, sign permits. TGSM. Rih w/ 2 7/8 DD Hole finder to 3242' kb, pt- fail. Pull up to 3232' kb, pt- pass @ 700 PSI. Bleed off, let sit for 10 min, pt again. Pass. Pull up to 3219' kb, pt- pass. Pooh. Rih w/ ponytail hole finder set down @ 3237' kb, shut off pump, set down @ 3239' kb, repeat, set down 3244' kb, repeat, 3252' kb, repeat, 3257' kb, turn pump off run down to 3300' kb, turn pump back on, pooh, hang up @ 3257' kb. Shut off pump, pooh to 3200' kb, turn pump on, rih and set down @ 3237' kb. Pooh. Rih w/ same while injecting to bottom, try to see if there are any more holes, don’t see anything, pooh. Rih w/ 2 7/8 BLB to 3200-3300 and brush 10X, pooh. Rih w/ 2 7/8 GS to 10,582' kb, latch ad-2 stop, pooh to 3350' kb, shear off stop, pooh, re-zero. Rih w/ same to 3350' kb, latch stop, pull up to 3282' kb, shear off pooh. Rih w/ 22' of 2" pipe w/ packoff on bottom to 3282 (zeroed @ packoff), shear off pooh. Rih w/ 11' of 1 3/4 pipe to 3249' kb (zeroed @ GS), set patch, pooh. Rih w/ 11' of 1 3/4 pipe to 3236' kb, (zeroed @ GS), set patch, pooh. Rih w/ 22' of 2" pipe w/ packoff on top to 3214' kb, (zeroed @ gs), set top of patch, pooh. Rih w/ 2 7/8 Gs w/ AA-stop to 3213' kb, set stop, pooh. Ooh w/ tools. Begin rig down. Flight home. End ticket. R ih w/ 11' of 1 3/4 pipe to 3249' kb (zeroed @ GS), set patch, pooh. Rih w/ 11' of 1 3/4 pipe to 3236' kb, (zeroed @ GS), set patch, pooh. Rih w/ 22' of 2" pipe w/ packoff on top to 3214' kb, (zeroed @ gs), set top of patch, pooh. Ri h w/ 2 7/8 Gs w/ AA-stop to 3213' kb, set stop, pooh. Ooh w/ tools. Begin rig down. Flight home. End ticket. Rih w/ 2 7/8 DD Hole finder to 3242' kb, set patch 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pools 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,780'13,448' Casing Collapse Structural Conductor Surface 1,540 psi Intermediate 3,810 psi Production Liner 7,020 psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:mmckinley@hilcorp.com Contact Phone: (907) 777-8387 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 Authorized Signature: Operations Manager Mark McKinley Other: Tubing Patch PRESENT WELL CONDITION SUMMARY Length Size 6,330 psi COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018777 201-009 50-733-20054-01-00Anchorage, AK 99503 Hilcorp Alaska, LLC N/A Trading Bay Unit K-01RD2 13,540' 6.5# / L-80 TVD Burst 10,583 MD 3,090 psi 109' 2,167' 4,928' 110' 2,384' 20" 13-3/8" 110' 9-5/8"6,043' 2,384' Perforation Depth MD (ft): 6,043' 11,680 - 13,650 N/A & N/A Tubing Grade: Tubing MD (ft): 8,156 - 9,641 Perforation Depth TVD (ft): 8,160 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. 5/8/2020 2-7/8" Daniel E. Marlowe N/A & N/A Tubing Size: 9,745' 13,448' 9,480' 2,026 psi 7,920' 7" 13,779' 9,743' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Daniel Marlowe I am approving this document 2020.04.23 15:54:53 -08'00' Daniel Marlowe By Samantha Carlisle at 8:22 am, Apr 24, 2020 320-175320-177 SFD 4/24/2020 Guy Schwartz 10-404 gls 4/27/20 4/24/20 DSR-4/27/2020Comm. 4/28/2020 dts 4/27/2020 JLC 4/28/2020 Well Work Prognosis Well: K-01RD2 4 /23/20 Well Name:King Salmon K-01RD2 API Number:50-733-20054-01 Current Status:Oil Producer Leg:Leg #4 NW Corner Estimated Start Date:May 8, 2020 Rig:Slick Line Reg. Approval Req’d?10-403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett 777-8332 Permit to Drill Number:201-009 First Call Engineer:Mark McKinley (907) 777-8387 (O) (907) 953-2685 (M) Second Call Engineer:Dan Marlowe (907) 283-1329 (O) (907) 398-9904 (M) Current Bottom Hole Pressure:2,489 psi @ 7,505’ TVD 0.37 psi/ft (7.2 ppg) ESP Gauge Maximum Expected BHP:2,777 psi @ 7,505’ TVD 0.37 psi/ft (7.2 ppg) ESP Gauge Maximum Potential Surface Pressure:**2,026 psi Using 0.1 psi/ft gradient per 20AAC 25.280(b)(4) **This is a no flow well 10/18/2017 Brief Well Summary: The K-01RD2 ESP began to show signs of a tubing leak above the ESP. Diagnostic Slickline work is being performed and if a leak is identified a patch will be installed 1. Rig up slick line and pressure test to 2,500 psi. 2. Cleanout tubing to full drift. 3. Run diagnostic tools to locate tubing leak. 4. Install tubing patch across hole estimated to be between ±3,000’-±3,600’ (actual depth TBD) 5. Tubing cannot be pressure tested due to ID restrictions of the tubing patch. Patch effectiveness will be determined by running the ESP and monitoring flow and pressures. 6. Rig down slick line and lubricator. 7. Turn well over to production. Attachments: 1. Wellbore Schematic Current 2. Wellbore Schematic Proposed Updated by: JLL 09/05/17 SCHEMATIC King Salmon Platform Well K-01RD2 PTD: 201-009 API: 50-733-20054-01 Last Completed: 08/09/2017 Casing and Tubing Detail Size Type Wt/ Grade TOP BTM CONN / ID Cement / Other 20” Conductor 94/ H40 Surf 110’ Welded/ 19” Driven 13-3/8” Surface 61/ K55 Surf 2,384’ BTC/ 12.515” 2640 “G”/ Surface 9-5/8” Intermediate 47/ N80 Surf 112’ BTC/ 8.681”1321 “G” Surface9-5/8” Intermediate 43.5/ N80 112’ 6,043’ BTC/ 8.755” 7” Liner 29/ L80 5,859’ 13,779’ BTC-KC/ 6.184” 183BBL/ 5859’ Tubing 2-7/8” Tubing 6.5/ L80 Surf 10,583’ EUE 8RD No. Depth (MD) Depth (TVD) ID OD Item 26.4’ 26.4’ Tubing Hanger: OCT-UH-TC-1A-ESP, 13 X 4-1/2 IBT lift and susp, w/ 4" Type H BPV profile, 3/8 cont. control line port 27’ 27’ 2.441” 4.500” X-over: 4-1/2” IBT to 2-7/8” 8RD pin 1 10,583’ 7,424’ N/A 4.000” Discharge, Bolt-On 10,583’ 7,424’ N/A 4.000” Pump - (3) 400 Series, 125 SF1750 (1) 400 Series 076 SFG2500 10,670’ 7,473’ N/A 4.000” Gas Separator – 400 Series UT & LT 400X Vortex 10,675’ 7,476’ N/A 4.000” Tandem Seals – 400 Series BPBSL 10,692’ 7,485’ N/A 4.000” Motor – 456 Series FMS, 240 HP 10,727’ 7,505’ N/A 4.560” Centralizer/Anode TD =13,780’ PBTD = 13,750’ 13-3/8” @ 2384’ GO-4 GO-6 HB-2 G-5 HB-1/G7 HB-3 HB-6 CIBP Set @ 13,540’ KB-THF: 26.4’ KB HB-7 4-21-2011 Fill tagged 13448’ MD HB-4 HB-5 20” @ 110’ RKB: 100’ AMSL 9-5/8” @ 6043’ 1 TOL: 5859’ G-1 Directional Data: max = 59° at 8,485’ OCTG Rotating Hours 24” Structural Casing 110 Hours 20” Conductor 110 Hours 13-3/8” Surface Pipe 227 Hours 9-5/8” Casing 651 Hours 7” Liner 50 Hours PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date GO-4 11,680' 11,720' 8,156' 8,186' 40' 5/7/01, partial reperf 1/27/05 GO-5 11,732' 11,742' 8,195' 8,202' 10' Opened 5/7/01 GO-6 11,780' 11,810' 8,229' 8,251' 30' Opened 5/7/01 11,820' 11,840' 8,259' 8,273' 20' Opened 5/7/01 11,864' 11,891' 8,291' 8,310' 27' Opened 5/7/01 G-1 12,030' 12,080' 8,413' 8,451' 50' 5/7/01, partial reperf 1/27/05 12,090' 12,120' 8,459' 8,481' 30' Opened 5/7/01 12,142' 12,162' 8,498' 8,513' 20' Opened 5/7/01 G-5 12,659' 12,674' 8,885' 8,896' 15' Opened 5/7/01 12,680' 12,694' 8,901' 8,911' 14' Opened 5/7/01 12,710' 12,790' 8,923' 8,983' 80' 5/7/01, partial reperf 1/27/05 12,800' 12,830' 8,990' 9,012' 30' 5/7/2001 G-7/HB-1 12,950' 13,010' 9,102' 9,147' 60' 7/3/01, partial reperf 1/27/05, partial reperf 8/22/08 HB2 13,075' 13,095' 9,196' 9,211' 20' 8/20/08 HB3 13,120' 13,130' 9,230' 9,238' 10' 8/20/08 HB3 13,190' 13,210' 9,283' 9,298' 20' HB-4 13,228' 13,340' 9,312' 9,397' 112' 5/7/01, partial reperf 1/27/05 HB5 13,405' 13,425' 9,447' 9,463' 20' Opened 1/13/02, reperf 8/20/08 HB5 13,440' 13,460' 9,475' 9,491' 20' Opened 1/13/02 HB6 13,565' 13,580' 9,573' 9,585' 15' Opened 1/13/02, Isolated 2/02 HB7 13,610' 13,650' 9,609' 9,641' 40' Opened 1/13/02, Isolated 2/02 Updated by: KK 04/23/20 PROPOSED King Salmon Platform Well K-01RD2 PTD: 201-009 API: 50-733-20054-01 Last Completed: 08/09/2017 Casing and Tubing Detail Size Type Wt/ Grade TOP BTM CONN / ID Cement / Other 20” Conductor 94/ H40 Surf 110’ Welded/ 19” Driven 13-3/8” Surface 61/ K55 Surf 2,384’ BTC/ 12.515” 2640 “G”/ Surface 9-5/8” Intermediate 47/ N80 Surf 112’ BTC/ 8.681”1321 “G” Surface9-5/8” Intermediate 43.5/ N80 112’ 6,043’ BTC/ 8.755” 7” Liner 29/ L80 5,859’ 13,779’ BTC-KC/ 6.184” 183BBL/ 5859’ Tubing 2-7/8” Tubing 6.5/ L80 Surf 10,583’ EUE 8RD No. Depth (MD) Depth (TVD) ID OD Item 26.4’ 26.4’ Tubing Hanger: OCT-UH-TC-1A-ESP, 13 X 4-1/2 IBT lift and susp, w/ 4" Type H BPV profile, 3/8 cont. control line port 27’ 27’ 2.441” 4.500” X-over: 4-1/2” IBT to 2-7/8” 8RD pin 1 10,583’ 7,424’ N/A 4.000” Discharge, Bolt-On 10,583’ 7,424’ N/A 4.000” Pump - (3) 400 Series, 125 SF1750 (1) 400 Series 076 SFG2500 10,670’ 7,473’ N/A 4.000” Gas Separator – 400 Series UT & LT 400X Vortex 10,675’ 7,476’ N/A 4.000” Tandem Seals – 400 Series BPBSL 10,692’ 7,485’ N/A 4.000” Motor – 456 Series FMS, 240 HP 10,727’ 7,505’ N/A 4.560” Centralizer/Anode TD =13,780’ PBTD = 13,750’ 13-3/8” @ 2384’ GO-4 GO-6 HB-2 G-5 HB-1/G7 HB-3 HB-6 CIBP Set @ 13,540’ KB-THF: 26.4’ KB HB-7 4-21-2011 Fill tagged 13448’ MD HB-4 HB-5 20” @ 110’ RKB: 100’ AMSL 9-5/8” @ 6043’ 1 Tubing Patch ±3,XXX’- ±3,6XX’ ID – ±2.0” TOL: 5859’ G-1 Directional Data: max = 59° at 8,485’ OCTG Rotating Hours 24” Structural Casing 110 Hours 20” Conductor 110 Hours 13-3/8” Surface Pipe 227 Hours 9-5/8” Casing 651 Hours 7” Liner 50 Hours PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date GO-4 11,680' 11,720' 8,156' 8,186' 40' 5/7/01, partial reperf 1/27/05 GO-5 11,732' 11,742' 8,195' 8,202' 10' Opened 5/7/01 GO-6 11,780' 11,810' 8,229' 8,251' 30' Opened 5/7/01 11,820' 11,840' 8,259' 8,273' 20' Opened 5/7/01 11,864' 11,891' 8,291' 8,310' 27' Opened 5/7/01 G-1 12,030' 12,080' 8,413' 8,451' 50' 5/7/01, partial reperf 1/27/05 12,090' 12,120' 8,459' 8,481' 30' Opened 5/7/01 12,142' 12,162' 8,498' 8,513' 20' Opened 5/7/01 G-5 12,659' 12,674' 8,885' 8,896' 15' Opened 5/7/01 12,680' 12,694' 8,901' 8,911' 14' Opened 5/7/01 12,710' 12,790' 8,923' 8,983' 80' 5/7/01, partial reperf 1/27/05 12,800' 12,830' 8,990' 9,012' 30' 5/7/2001 G-7/HB-1 12,950' 13,010' 9,102' 9,147' 60' 7/3/01, partial reperf 1/27/05, partial reperf 8/22/08 HB2 13,075' 13,095' 9,196' 9,211' 20' 8/20/08 HB3 13,120' 13,130' 9,230' 9,238' 10' 8/20/08 HB3 13,190' 13,210' 9,283' 9,298' 20' HB-4 13,228' 13,340' 9,312' 9,397' 112' 5/7/01, partial reperf 1/27/05 HB5 13,405' 13,425' 9,447' 9,463' 20' Opened 1/13/02, reperf 8/20/08 HB5 13,440' 13,460' 9,475' 9,491' 20' Opened 1/13/02 HB6 13,565' 13,580' 9,573' 9,585' 15' Opened 1/13/02, Isolated 2/02 HB7 13,610' 13,650' 9,609' 9,641' 40' Opened 1/13/02, Isolated 2/02 1 Carlisle, Samantha J (CED) From:Schwartz, Guy L (CED) Sent:Thursday, April 23, 2020 5:05 PM To:Dan Marlowe Cc:Juanita Lovett; Mark McKinley Subject:Re: K-01RD2 PTD 201-009 sundry application Dan, Youhaveverbalapprovaltosetpatchasproposedinthesundryapplication. Ensurecopyofthisemailispostedonlocation. Regards, GuySchwartz AOGCC SentfrommyiPhone OnApr23,2020,at4:01PM,DanMarlowe<dmarlowe@hilcorp.com>wrote: Guy ThisSundrywillbeelectronicallysubmittedthisafternoon Perourdiscussionoverthephone,Hilcorprequestsverbalauthorizationtoproceedwithimmediate patchinstallationassoonaswecanpinpointtheleak Thanks Dan Marlowe Hilcorp Alaska, LLC Area Operations Manager - CIO Office 907-283-1329 Cell 907-398-9904 Email DMarlowe@hilcorp.com Hilcorp A Company Built on Energy <10Ͳ403ͲKͲ01RD2PTD201Ͳ0092020Ͳ04Ͳ23.pdf> OF TjJ • • //7:. THE STATE Alaska Oil and Gas N � of Conservation Commission __ ALASKA _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF �, Main: 907.279.1433 4LAS' Fax: 907.276.7542 www.aogcc.alaska.gov November 20, 2017 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska,LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit K-01RD2 SCANNEV ` PTD 2010090 Dear Mr. Golis: On October 18, 2017 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow retest of Trading Bay Unit K-01RD2 located on the King Salmon Platform in Cook Inlet. A previous no-flow test on August 25, 2017 was deemed inconclusive by letter dated October 9,2017. The well is operated by Hilcorp Alaska,LLC(Hilcorp). A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The AOGCC Inspector confirmed that the proper test equipment—as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up to Trading Bay Unit K-01 RD2. The no-flow test consisted of a series of flow and shut in periods. During the flow monitoring periods, no liquid production was observed, and the maximum gas flow rate measured was 400 standard cubic feet per hour. Tubing and tubing-casing annulus pressures remained at less than 1 psi. The test results meet AOGCC acceptance criteria for a passing no-flow test. The subsurface safety valve must be returned to service if Trading Bay Unit K-01 RD2 demonstrates an ability to flow unassisted to surface at rates exceeding the no-flow test acceptance criteria. Any cleanout, perforating or other stimulation work in this well will necessitate a new no-flow test. Please retain a copy of this letter on the King Salmon Platform. Sincerely, sioatt4O7- , James B. Regg f\e?? Petroleum Inspection Supervisor 1111 Mr. Stan Golis November 20,2017 Page 2 of 2 cc: P. Brooks AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1((o!l7 DATE: 10/19/2017 P. I. Supervisor FROM: Matt Herrera SUBJECT: No Flow Test Petroleum Inspector TBU K-01 RD2 � � *",`' 09 '.';�' Hilcorp PTD 2010090 10/18/2017: I flew out to the Trading Bay Unit King Salmon platform to witness a no- flow retest. Previous attempt on 8/25/17 was deemed inconclusive by letter to Hilcorp dated 10/9/17. On arrival I contacted Hilcorp Lead Operator Sandra Reynolds. We went over the no-flow test set up on well K-01 RD2. The IA was tied into a crosshead on the production tree with a 2-inch line to a small bleed tank outside the well room. Valve , alignment was verified for the tubing and IA. Pressure gauge and flow meter had current calibrations. The well was open to bleed and was being manned/monitored. The flow meter showed 0 SCFH and the digital gauge showed 0 psi. The well was then shut in - and pressure readings were taken at 30-minute intervals. After being shut in for 1 hour, well was opened to bleed tank and flow and pressure monitored on the flow meter and digital pressure gauge. The well pressure bled to 0 psi and there was no noticeable flow into the bleed tank. The well was again shut in with pressure readings taken at 30- minute intervals. After being shut in for 2 hours, the well was opened to bleed tank and flow and pressure monitored. The following table shows test details: Time Pressures' Flow Rate2 Remarks (psi) Gas - scf/hr Liquid - gal/hr 11:15 0/0/405 - 0 0 Initial bleed and readings 11:45 0.5/0.5/405 ' Readings only 12:15 0.5/0.5/405 - <100 - 0 - Pressure bled to zero 1 min. 12:45 0.5/0.5/405 - Readings only 13:15 0.5/0.5/405 . Readings only 13:45 0.75/0.75/405 Readings only 14:15 0.8/0.8/405 400 0 Pressure bled to zero 5 min. 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr TBU K-01 RD2 meets the requirements for producing without a SSSV. ✓ Attachments: Test Equipment Calibration Records f 2017-1018_No-Flow_TBU_K-01 RD2_mh.docx Page 1 of 1 • • tilliicor p Alaska, LLC HILCORP CALIBRATION CERTIFICATE Pressure Standards Referenced to NIST File TN822-256610-96, TN838-256609-96,P-8523 Gauge type: SSI Technologies Pressure range: 30 psi S/N number: 1506240074 Date: 09/08/ 2017 UOCD-4534 TEST PRESSURE INDICATION 0.00 0.00 - 7.50 7.49 If 15.00 15.04 - 22.50 22.50 30.00 30.01 Calibrated by: jki\ \kNi•)1\ Test equipment SIN: 9484040 This certificate expires in 1 year on September 8, 2018. J For recertification, contact Gina Bogart 776-6825 or Cathy Marshall 283-1384. , • _A" . .. • • , - •___ , a, o ) 6 1 tr ;HHtiIi N ° -1• 0 D3 g. 0 as � � CO . iDo_ " 9Ss ® o0 � :3 ? tkitil rt 4 2 P N r Q D w 5 5 N c C 3 -it �" Cort i 0a, 'i0v"11 c . cn -' r'• o • •• d n: • il I 1 1 I y i qp Al 33 li t 1 Q1.. •• ii. 1 + STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMI SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Performed: Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Replace ESP 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development I] Exploratory 0 201-009 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service 0 6.API Number: Anchorage,AK 99503 50-733-20054-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018777 Trading Bay Unit K-01 RD2 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil,Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 13,780 feet Plugs measured 13,540 RECEIVED true vertical 9,745 feet Junk measured 13,448 feet SEP 0 5 2017 Effective Depth measured 13,448 feet Packer measured N/A feet true vertical 9,480 feet true vertical N/A feet AOC Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 109' Surface 2,384' 13-3/8" 2,384' 2,167' 3,090 psi 1,540 psi Intermediate 6,043' 9-5/8" 6,043' 4,928' 6,330 psi 3,810 psi Production Liner 7,920' 7" 13,779' 9,743' 8,160 psi 7,030 psi Perforation depth Measured depth 11,680-13,650 feet True Vertical depth 8,156-9,641 feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 10,583(MD) 7,424(TVD) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED NU V I el,-%t"? N/A Treatment descriptions including volumes used and final pressure: j 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 0 299 304 Subsequent to operation: 140 71 1135 69 66 14.Attachments(required per 20 AAc 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development9 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 9 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 3USP0 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: 317-003 Authorized Name: Stan W.Golis Contact Name: Joe Kaiser Authorized Title: Operations Manager Contact Email: jkaiser@hilcorp.com Authorized Signature: • Date: el / S f I Contact Phone: (907)777-8393 11/17 d % /h Form 10-404 Revised 4/2017 �sa� s w a - 6 26 17 Submit Original Only • • King Salmon Platform • Well K-01RD2 SCHEMATIC PTD: 201-009 1 11 API: 50-733-20054-01 Hhlcorp Alaska,LLC Last Completed: 08/09/2017 RKB:100'AMSL Casing and Tubing Detail KB-THF:26.4'KB zi. , N 7" sSize Type Wt/Grade TOP BTM CONN/ID Cement/Other - 'ik, 20" Conductor 94/H40 Surf 110' Welded/19" Driven 20"@ 110' 13-3/8" Surface 61/K55 Surf 2,384' BTC/12.515" 2640"G"/Surface rr 9-5/8" Intermediate 47/N80 Surf 112' BTC/8.681" 1321"G"Surface 9-5/8" Intermediate 43.5/N80 112' 6,043' BTC/8.755" ;0 7" Liner 29/L80 5,859' 13,779' BTC-KC/6.184" 183BBL/5859' :�IN 10 Tubing " - 2-7/8" Tubing 6.5/L80 Surf 10,583' EUE 8RD 13-318"@ 2384' '1" .' S A . No. Depth(MD) Depth(TVD) ID OD Item Tubing Hanger:OCT-UH-TC-1A-ESP,13 X 4-1/2 26.4' 26.4' IBT lift and susp,w/4"Type H BPV profile,3/8 cont.control line port 27' 27' 2.441" 4.500" X-over:4-1/2"IBT to 2-7/8"8RD pin 10,583' 7,424' N/A 4.000" Discharge,Bolt-On TOL:5859' �, Pump -(3)400 Series,125 SF1750(1)400 9-5/8'@ 604344f 10,583' 7,424' N/A 4.000" Series 076 SFG2500 .' 1 10,670' 7,473' N/A 4.000" Gas Separator-400 Series UT< 400X Vortex 10,675' 7,476' N/A 4.000" Tandem Seals-400 Series BPBSL 10,692' 7,485' N/A 4.000" Motor-456 Series FMS,240 HP ' 10,727' 7,505' N/A 4.560" Centralizer/Anode !t.‘:t, J PPERFORATION DETAIL t Zone Top(MD) Btm(MD) Top(ND) Btm FT Date "_'" (TVD) • 1 U GO-4 11,680' 11,720' 8,156' 8,186' 40' 5/7/01,partial reperf 1/27/05 GO-5 11,732' 11,742' 8,195' 8,202' 10' Opened 5/7/01 GO-6 11,780' 11,810' 8,229' 8,251' 30' Opened 5/7/01 GO-4 11,820' 11,840' 8,259' 8,273' 20' Opened 5/7/01 Go-6 11,864' 11,891' 8,291' 8,310' 27' Opened 5/7/01 G-1 G-1 12,030' 12,080' 8,413' 8,451' 50' 5/7/01,partial reperf 1/27/05 G-5 12,090' 12,120' 8,459' 8,481' 30' Opened 5/7/01 iK HB-1/G7 12,142' 12,162' 8,498' 8,513' 20' Opened 5/7/01 ' HB-2 G-5 12,659' 12,674' 8,885' 8,896' 15' Opened 5/7/01 . HB-3 12,680' 12,694' 8,901' 8,911' 14' Opened 5/7/01 4-21-2011 Fm HB-4 12,710' 12,790' 8,923' 8,983' 80' 5/7/01,partial reperf 1/27/05 tagged 13448'MD HB-5 12,800' 12,830' 8,990' 9,012' 30' 5/7/2001 r CIBP Set @73,540' ,. 7/3/01,partial reperf 1/27/05, `HB-6 G-7/HB-1 12,950' 13,010' 9,102' 9,147' 60' partial reperf 8/22/08 HB-7 : *;ag r HB2 13,075' 13,095' 9,196' 9,211' 20' 8/20/08 TD=13,780' PBTD=13,750' HB3 13,120' 13,130' 9,230' 9,238' 10' 8/20/08 HB3 13,190' 13,210' 9,283' 9,298' 20' Directional Data: HB-4 13,228' 13,340' 9,312' 9,397' 112' 5/7/01,partial reperf 1/27/05 max=59°at 8,485' HB5 13,405' 13,425' 9,447' 9,463' 20' Opened 1/13/02,reperf 8/20/08 HB5 13,440' 13,460' 9,475' 9,491' 20' Opened 1/13/02 OCTG Rotating Hours HB6 13,565' 13,580' 9,573' 9,585' 15' Opened 1/13/02,Isolated 2/02 HB7 13,610' 13,650' 9,609' 9,641' 40' Opened 1/13/02,Isolated 2/02 24"Structural Casing 110 Hours 20"Conductor 110 Hours 13-3/8"Surface Pipe 227 Hours 9-5/8"Casing 651 Hours 7"Liner 50 Hours Updated by: _ILL 09/05/17 • • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-01RD2 Moncla 404 50-733-20054-01 201-009 7/31/17 8/9/17 Da I O erations i 07/31/2017 Monday Moved equipment from skid path. Rigged up jacks and skidded Moncla 404 South then East over K-01RD2 well. Reposition Koomey unit, choke house and test pump as needed for well work. Checked well- NOS rep set BPV. N/D production tree and N/U 13 5/8" 5M BOPE stack. Hooked up all choke, kill and koomey lines. Set racking mat beam in place. Raised and scoped out derrick securing all guy lines. Mounted rig floor w/supports. Moved driller's shack in place and set stairway. 08/01/2017-Tuesday Loaded floor with handling tools and McCoy tongs. Moncla mechanic onboard. Changed oil on carrier motor. Prod electrician trouble shot on-off switch on tong hyd unit. Welder modified stairs to carrier walkway. Slipped & cut 80' of 1" drill line. M/U 3 1/2" test jt w/ pumpin, SV & IBOP on top, LH x-over on btm to blanked & ported sub-screwed into hanger. Filled system and attempted to shell test to 3500 psi-failed to stop leak at unihead connection. Pulled test jt. Stack drained thru BPV. R/U on stack w/404 block and unbolted clamp. Raised BOP and riser. Changed out BX160 steel ring to rubber coated ring. Lowered riser and bolted up clamp. Attempt to pretest BOP 250/3500 PSI- v� r worked thru minor leaks at flanged connections and electrical issue with the test pump. Production electrician ri; assisted w/problem.Tested all BOPE 250 psi low 3500 psi high as per Sundry in accordance with Hilcorp and AOGCC requirements.Tested w/3 1/2" & 2 7/8" tb- performed successful koomey draw-down test. AOGCC witness waived by Mr. Regg 9:42 AM 8/1/17 by email. Began B/D and clearing floor of test equipment. 08/02/2017-Wednesday NOS rep pulled BPV. M/U 3 1/2" PH-6 landing jt w/4 1/2" IBT x-over. Screwed into hanger. Backed out all but 4 hold downs. Began bleeding 50#s of pressure off annulus. Decision was made to circ well. Lined up to flush well w/FIW sending,returns toprod pipeline. Sent & received NPFT form. Pumped 265 bbls FIW at 1.4 BPM 2540 psi- no returns. 1230 hrs shutdown pump and allowed annulus to settle to zero. Backed out HD pins and unseated hanger at 110k, pulled hanger to surface (traveling at 120k)-filled annulus w/ 18 bbls FIW. NOS &Summit worked hanger- R/U Summit pulling equipment. POH laying down 3 1/2" x 2 7/8" Hyd 563 SCC production string w/ ESP/SPM assy from 10,730'. 15:30 hrs worked M/V Titan receiving Tripoint test pkrs and 404 beam extensions. POH to 5820'. Cut power cable and changed out spooler. Changed out handling tools &SV to 2 7/8" (196 jts of 3 1/2" Hyd 563 tb & 3- SPMs laid down). Continued POH laying down 2 7/8" Hyd 563 SCC production string w/ ESP/SPM assy from 5820'. 20 jts of 2 7/8" laid down at report time= EOT at 5,177'. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-01RD2 Moncla 404 50-733-20054-01 201-009 7/31/17 8/9/17 Daily Operations:, 08/03/2017-Thursday Finished POH w/2 7/8" ESP/SPM production string from 5,177' laying down all 2 7/8" tbg. Continue laying down ESP motors, pumps assembly. Found broken shaft in bottom pump. Cleared and cleaned rig floor. Fill hole with 74 BBL M' FIW. Work M/V Titan -offload groceries. RU Pollard ELU. MU Toolstring= RS (1.0' x 1.44" OD, 1" FN), GR/CCL(5.38' x 3-1/8" OD), XO pin(0.33' X 1.44" OD) +Gauge Ring/Junk Basket(6.67' X 5-1/4" OD)TL= 13.3', CCL-BTS= 11.58'. ELU RIH with 5.25" gauge ring, set down 3 times at 5,859' (Top of Liner), worked past liner top. Continue TIH to 11,200' RKB without further set down. Pumped 20 BBL FIW every hour, on the hour. POOH, LD toolstring, 2 small pieces of rubber and 1 small piece of metal in junk basket. RD ELU. MU 6" Bit/7" Scraper BHA.TIH with 6" Bit/7" Scraper BHA on 3-1/2"PH-6 work string, picking up single joints, MUT= 7K.Tally and rabbit all joints. @ report 3500'. Pump 20 BBL FIW every hour, on the hour. 08/04/2017- Friday TIH with 6" Bit/7" Scraper BHA on 3-1/2"PH 6 work strip ,picking up single joints, MUT= 7K. PU 9-5/8" scraper on Jt. 167, 5200'.Tally and rabbit all joints. @ report 3500'. Pump 10 BBL FIW every hour, on the hour. 255 joints in hole- 7,931'. Working M/V Titan. Continue TIH with 6" Bit/7" & 9-5/8" Scraper BHA on 3-1/2"PH-6 work string, picking up single joints, MUT= 7K.Tally and rabbit all joints. Pump 10 BBL FIW every hour, on the hour. 354 joints total - 11,002'TD. Pump FIW to loads hole- 68 BBL. Reverse circulate 3 bottoms up at 2.50 BPM, 0 psi -242 BBL(6800 stks). RD McCoy tongs, RU Gill tongs. POOH standing back 3-1/2", PH-6 workstring in derrick T/7400'. Pump 10 BBL FIW every 20 stands. 08/05/2017-Saturday POOH standing back 3-1/2", PH-6 workstring in derrick and lay down 9 5/8" and 7" Scraper. Pump 10 BBL FIW every 20 stands. Clean up Floor and M/U tri-point 7" RTTS test pkr w/tri-point hand. RIH w/pkr on 3 1/2" ph-6 `7,0-1, work-string T/ 10,761' (packer element= 10,750'). Load hole with 24 BBL FIW. PUH to string weight, PUW=144K. Rotate string 3 revolutions with tongs to set RTTS packer. Slack off, setting string weight on packer, SOW= 38K, setJ2,5 slips. Pressure test 7" liner and 9-5/8" production casing to 1900 psi, chart test. Chase and eliminate surface leaks �1 Re-Test to 1900 psi -GOOD TEST. Work M/V Titan, offload ESP completion tubing and chemical totes, backload iel0fr Pollard ELU, Summit spools, 1 overpack, 2 dumpsters and drill collars. Lay out production tubing on pipe deck. PUH to release RTTS packer. Pump FIW to load hole -25 BBL. POOH laying down 3-1/2", PH-6 work string. @ 8500'. Pump 10 BBL FIW every hour on the hour. 08/06/2017-Sunday POOH laying down 3-1/2", PH-6 work string. L/D 7" RTTS. Pump 10 BBL FIW every hour on the hour. Clean up Floor and power wash floor and BOP stack.Tally and strap 2 7/8" EUE 6.5# L-80 production string. RD Gill tongs, RU McCoy tongs. Dress tongs, slips and handling equipment for 2-7/8" tubing. Working M/V Titan. Offload jore flat, dumpsters and mud box. Load and secure production tank on jore flat. Backload production tank/jore flat and 3- 1/2", PH-6 work string. Pump 20 BBL FIW.TIH with 2-7/8", 8RD EUE tubing, open ended, MUT= 2250 ft/lb @ 5700'. Tally 2-7/8"joints while TIH. Pump 10 BBL FIW every hour on the hour. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-01RD2 Moncla 404 50-733-20054-01 201-009 7/31/17 8/9/17 Daily Operations ` 08/07/2017- Monday TIH with 2-7/8", 8RD EUE tubing, open ended, MUT= 2250 ft/lb.Tally 2-7/8"joints while TIH.T/ 10550'. Pump 10 BBL FIW every hour on the hour.Total 2-7/8" stands in hole = 169 (10,548'). Monitor well 15 mins POOH Stand back in derrick w/2 7/8" EUE 8 RD Tubing. Pump 10 bbl FIW every hour on the hour. Rabbit each stand out of derrick. 84 stands in derrick. Load hole with FIW- 64 BBL. Continue POOH standing back 2-7/8", 6.5#, L-80 EUE 8RD tubing. Pump 10 bbl FlWevery hour on the hour. Rabbit each stand out of derrick. Pump 15 BBL FIW down tubing to clean inside of tubing. Pump 11 BBL FIW down tubing to clean inside of tubing. Continue POOH standing back 2- 7/8", 6.5#, L-80 EUE 8RD tubing. Pump 10 bbl FIW every hour on the hour. Rabbit each stand out of derrick. Work M/V Resolution -offload cannon clamps. Finish standing back 2-7/8", 6.5#, L-80 EUE 8RD tubing in derrick (169 stands total). Load hole with 53 BBL FIW. Clean and clear rig floor, prep floor to PU ESP assembly. RU Summit running equipment. Pump 10 BBL FIW every hour on the hour. PU motor with gauge and lower in hole, fill motor with oil. Pull motor out of hole and attach anode and flat pack. Lower in hole and MU lower and upper seal sections and connect motor lead. MU 4 pump sections, discharge/pressure sub bucked up to joint of 2-7/8", 6.5#, L-80 EUE 8RD tubing. Perform all checks on cable and leads. Pump 10 BBL FIW every hour on the hour. 08/08/2017-Tuesday Continue T/ MU 4 pump sections, discharge/pressure sub bucked up to joint of 2-7/8", 6.5#, L-80 EUE 8RD tubing. Perform all checks on cable and leads. Pump 10 BBL FIW every hour on the hour. Continue RIH w/ESP Assy on 2 7/8" EUE 8RD 6.5# L-80 Tubing f/derrick. Perform checks on cable every 1000'. Pump 10 BBL FIW every hour on the hour. Rabbit each stand out of derrick. Continue RIH w/ESP Assy on 2 7/8" EUE 8RD 6.5# L-80 Tubing f/derrick T/ 6009'.Test insulation every 1000'. Rabbit each stand out of derrick. C/O ESP Reel/and make a splice. Perform checks on cable. Pump 10 BBL FIW every hour on the hour. Continue RIH with Summit single 240 HP motor ESP assy on 2 7/8" EUE 8RD, 6.5# L-80 Tubing from 6,009' to 8,977'. Test insulation every 1000'. Rabbit each stand out of derrick. Pump 10 BBL FIW every hour on the hour. Finished RIH with Summit single 240 HP motor ESP assy from 8,977' on 2 7/8" EUE 8RD, 6.5# L-80 Tubing to 10,695'.Test insulation every 1000'. Rabbit each stand out of derrick. Pump 10 BBL FIW every hour on the hour. MU tubing hanger and landing joint, assisted by NOS rep. Summit reps plumb power cable and control lines thru hanger. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-01RD2 Moncla 404 50-733-20054-01 201-009 7/31/17 8/9/17 Daily Operations; j' 08/09/2017-Wednesday MU tubing hanger and landing joint, assisted by NOS rep. Summit reps plumb power cable and control lines thru hanger. Land hanger. RILDS test esp cable all good set BPV. R/D and remove rig floor, guy wires, scope derrick and lay over Derrick. N/D BOP. Pull VBR and Annular T/be shipped to town to be redress. Continue N/D BOP and N/U production tree W/NOS hands. Pressure test hanger void -500 psi (5 min)/5000 psi (15 min) -GOOD TEST. RU flow lines and SSV. Pull BPV, Set 2-way check. Work M/V Resolution -Offload Hydril, 3 Summit spoolers, Summit tool box and connex and Knight tool basket. RD rig pump and move to pipe deck, drain rig tank to production, disconnect koomey lines, pull VBR from dual gate BOP and rig down test pump. Pressure Test WHA- 5000 psi (5 mins) -GOOD TEST. Pull 2-way check. Work M/V Titan -offload Summit pumps and 1 bundle 2-7/8" tubing. Continue to rig down and move rig package to Well# K-17.Turn well over to Production. • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission 'Fa TO: Jim Regg 1 DATE: August 28, 2017 lL51 I P. I. Supervisor FROM: Adam Earl SUBJECT: No Flow Test Petroleum Inspector TBU K-01 RD2 Hilcorp Alaska LLC PTD 2010090 8/25/2017: I traveled to the King Salmon Platform to witness a no-flow test on TBU K- 01 RD2. Tim Iverson (Hilcorp) was the operator handling the job. I looked over the rig-up and the wellhead, it was set up and ready to test. This is an ESP well so the tubing and the I/A were tied together at surface with a 2-inch jumper line. A 1/2-inch line was used to bleed the well when opened to flow. The test method to be used was to bleed through a SCFH meter on the hour, three times to complete the three-hour test. I was advised that the well had been bleed to zero and been open for the last 12 hours. All there was left to do was shut it in and start the test. SCANNED 0 101 The following table shows test details: Time Pressures' Flow Rate2 Remarks (psi) Gas - scf/hr Liquid - gal/hr 10:12 0/0/400 shut in to monitor 10:42 .48/.48/400 monitor pressure buildup 11:12 .82/.82/400 1600 0 3min bleed to 700 scfh; shut in well at 0.32 psi 11:42 .78/.78/400 _ monitor pressure buildup 12:12 1.12/1.12/400 1700 0 3min bleed to 800 scfh; shut in well at 0.39 psi 12:42 .88/.88/400 monitor pressure buildup 12:12 1.23/1.23/400 1800 0 3min bleed to 900 scfh; shut in well at 0.32 psi 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr There was no liquid to surface during the no-flow test. Results are inconclusive. Attachments: Test Equipment Calibration Reports (Flow Meter; Pressure Gauge) Equipment Photos (2) 2017-0825 No-Flow TBU K-01RD2 ae.docx Page 1 of 3 • • • ON +. 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I 4 `' / 0. �, d E --',Co. .xfr • • yOFTB ,,,,i„,�• THE STATE Alaska Oil and Gas� � of Conservation Commission 7IMALASI�:Af7iti'l333 West Seventh Avenue 1. c GOVERNOR BILL WALKER Anchorage, Alaska Main: 99501- 509.3572 OF ALABlj'' Fax: 907.276.7542 www.aogcc.alaska.gov scow MAT 2 9/A+ Stan Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU K-01 RD2 Permit to Drill Number: 201-009 Sundry Number: 317-003 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, d_ -.6, P-A-L,,v .- Cathy P Foerster Chair '/4-- DATED this (Z day of January, 2017. RBDMS UL JAI 2 6 2017 • • RECEIVED• . STATE OF ALASKA JAN 0 5 2017 . ALASKA OIL AND GAS CONSERVATION COMMISSION OT'S Iv tai 1 APPLICATION FOR SUNDRY APPROVALSAOGGNO 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing C], Change Approved Program Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. Replace ESP b (] 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory ❑ Development C]• 201-009' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20054-01 w 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 0 No 0 / Trading Bay Unit/K-01RD2• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018777 w McArthur River Field/Hemlock Oil,Middle Kenai G Oil Pools • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 13,780 • 9,745 • 13,448 s 9,480 • 2,626 psi 13,540 13,448 Casing Length Size MD ND Burst Collapse Structural Conductor 110' 20" 110' 109' Surface 2,384' 13-3/8" 2,384' 2,167' 3,090 psi 1,540 psi Intermediate 6,043' 9-5/8" 6,043' 4,928' 6,330 psi 3,810 psi Production Liner 7,920' 7" 13,779' 9,743' 8,160 psi 7,030 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11,680-13,650 • 8,156-9,641 3-1/2"&2-7/8" 9.2#L-80&6.4#L-80 5,821 &10,552 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A N/A w 12.Attachments: Proposal Summary Q Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch (] Exploratory ❑ Stratigraphic❑ Development CI' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 1/20/2017 Commencing Operations: OIL ID w WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown El Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed NameStan W.Golis Title Operations Manager Signature 3 L._.- L3 \.,r1:, Phone (907)777-8356 Date . /3 ( 2-ot-t COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 5 _ i- 0-3Plug Integrity ❑ BOP Test Mechanical Integrity Test CI Location Location Clearance Other: 4 3.Ov Lis . lt0 c.,1- r -S-r/ti "f.�s f" +� Z1t-tf Post Initial Injection MIT Req'd? Yes 0 No ❑ RB DMS L --,l; i 1 6 2017 Spacing Exception Required? Yes ❑ Nod Subsequent Form� Required:/a�. L/0 y f APPROVED BY Approved by: 1COMMISSIONER THE COMMISSION Date: /*/2_—1 7 -4. 1571 *4,— p I_ /—/c).-jT Submit Form and Form 10-403 Revised 11/2015 Approved application Is a o 1i tls r L of a royal. Attachments in Duplicate • S Well Work Prognosis Well: K-01RD2 Date: 12/29/16 Hileorp Alaska.LLC Well Name: King Salmon K-01RD2 API Number: 50-733-20054-01 Current Status: Oil Producer Leg: Leg#4 NW Corner Estimated Start Date: January 20, 2017 Rig: Kuukpik#5 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 201-009 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907)777-8356 (0) .04(LI Current Bottom Hole Pressure: 3,571 psi @ 9,450'TVD 0.38 psi/ft(7.3 ppg)ESP Gauge ---7 3 PPa. Maximum Expected BHP: 3,571 psi @ 9,450'TVD 0.38 psi/ft{mpg)ESP Gauge Maximum Potential Surface Pressure: **2,626 psi v'' Using 0.1 psi/ft gradient per 20AAC 25.280(b)(4) **This is a no flow well 09/17/2014 Brief Well Summary: The K-01RD2 ESP failed on 12/28/16 due to a suspected parted shaft.The purpose of this work over is to replace the failed ESP equipment. ✓ r / (70i3 s Procedure: 1. MIRU Kuukpik Rig#5. 2. Circulate hydrocarbon off of well.Work over fluid will be FIW. BOP's will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/3,500psi high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. 5. POOH ESP. 6. PU, RIH W/casing scraper to 11,000'. Circ hole clean, POOH with Same. 7. PU, RIH W/test packer to 10,750'. Set pkr and pressure test casing to 1,900psi on chart for 30 minutes. Bleed down pressure, unset packer and POOH with same. 8. PU and RIH with new ESP assembly. 9. ND BOP, NU wellhead and test. 10. Turn well over to production. 11. Conduct SVS per AOGCC regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current/Proposed (Same) 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form r el King Salmon Platform Well K-01RD2 • SCHEMATIC Last Completed 6/17/2011 Updated 6/20/2011 Hilcorp Alaska,LLC RKB:100'AMSL Casing and Tubing Detail KB-THF:33.7'KB Size Type Wt/Grade TOP BTM CONN/ID Cement/Other 20" Conductor 94/H40 _ Surf 110' Welded/19" Driven 20"@ 110' 13-3/8" Surface 61/K55 _ Surf 2,384' BTC/12.515" 2640"G"/Surface ' ` 9-5/8" Intermediate 47/N80 Surf 112' BTC/8.681" '+ 1321"G"Surface 9-5/8" Intermediate 43.5/N80 112' 6,043' BTC/8.755" 7" Liner 29/L80 5,859' 13,779' BTC-KC/6.184" 183BBL/5859' • • Tubing 3-1/2 _ Tubing 9.2/L80 Surf 5,821' HYD 563 SCC 1.5'_For x-Over Z. -. 2-7/8" Tubing 6.4/L80 5,821' 10,552' HYD 563 SCC 3-3/8"i 2384' 1 0 Jewelry Detail 2 0 No. Depth(MD) Depth(TVD) Length ID OD Item ' 33.7' 33.7' ±1' Hanger(4-1/2"HYD or TCII) 36.7' 36.7' 1.90' 2.992" 4.500" X-over:4-1/2"IBT to 3-1/2"HYD 563/503 3 1 2,770' 2,452' 8.68' 4.125" 5.313" 3-1/2"#1 SFO-1 GL Mandrel • 2 4,512' 3,781' 8.70' 4.125" 5.313" 3-1/2"#2 SFO-1 GL Mandrel TOL 5859' 3 5,671' 4,646' 8.70' 4.125" 5.313" 3-1/2"#3 SFO-1 GL Mandrel 9-5/8'©6043' 4 ° 5,820' 4,758' 1.50 2.310" 3.500 X-over:3-1/2"Hydril 563-2-7/8"Hydril 563 2.347" 2.875" 2-7/8"Tubing Hydril 563/503 6 1 4 6,805' 5,393' 7.35' 2.347" 4.750" 2-7/8"#4 SFO-1 GL Mandrel 5 7,896' 5,976' 7.34' 2.347" 4.750" 2-7/8"#5 SFO-1 GL Mandrel .., 6 6 8,867' 6,495' 7.35' 2.347" 4.750" 2-7/8"#6 SFO-1 GL Mandrel 7 9,900' 7,048' 7.34' 2.347" 4.750" 2-7/8"#7 SFO-1 GL Mandrel ° ., 8 10,467' 7,359' 4.57' 2.313" 2.875 2-7/8"Sliding Sleeve;SSD,2.313 9CR,H2S ', 9 10,514' 7,385' 2.23' 2.205" 2.875" 2-7/8""XN"Profile Nipple(No-Go:2.205") a 5 XN • r 10,552' 7,406' 2.310" 2.875" X-over to pump 10 10,568' 7,415' ND ND ESP:Motor,Pump and Assembly k,,' m, ' 10,642' 7,457' ND ND ESP Pump Intake 1o! 10,730' 7,507' ND ND Phoenix Assembly •, -GG-4 PERFORATION DETAIL • =Go-6 Zone Top(MD) Btm(MD) Top(ND) Btm FT Date (TVD) G-1 GO-4 11,680' 11,720' 8,156' 8,186' 40' 5/7/01,partial reperf 1/27/05 G-s GO-5 11,732' 11,742' 8,195' 8,202' 10' Opened 5/7/01 ' HB-1/G7 GO-6 11,780' 11,810' 8,229' 8,251' 30' Opened 5/7/01 6-HB-2 11,820' 11,840' 8,259' 8,273' 20' Opened 5/7/01 yHB-3 11,864' 11,891' 8,291' 8,310' 27' Opened 5/7/01 4-21-2011 Fm =---HB-4 G-1 12,030' 12,080' 8,413' 8,451' 50' 5/7/01,partial reperf 1/27/05 tagged 13448'MD HB-5 IBP Set 13,540' �+ 12,090' 12,120' 8,459' 8,481' 30' Opened 5/7/01 SHB-6 12,142' 12,162' 8,498' 8,513' 20' Opened 5/7/01 HB-7 G-5 12,659' 12,674' 8,885' 8,896' 15' Opened 5/7/01 12,680' 12,694' 8,901' 8,911' 14' Opened 5/7/01 TD=13,780' PBTD=13,750' 12,710' 12,790' 8,923' 8,983' 80' 5/7/01,partial reperf 1/27/05 Directional Data: 12,800' 12,830' 8,990' 9,012' 30' 5/7/2001 max=59° at 8,485' 9,102' 9,147' 60' 7/3/01,partial reperf 1/27/05,partial G-7/HB-1 12,950' 13,010' reperf 8/22/08 OCTG Rotating Hours HB2 13,075' 13,095' 9,196' 9,211' 20' 8/20/08 HB3 13,120' 13,130' 9,230' 9,238' 10' 8/20/08 24"Structural Casing 110 Hours HB3 13,190' 13,210' 9,283' 9,298' 20' 20"Conductor 110 Hours HB-4 13,228' 13,340' 9,312' 9,397' 112' 5/7/01,partial reperf 1/27/05 13-3/8"Surface Pipe 227 Hours HB5 13,405' 13,425' 9,447' 9,463' 20' Opened 1/13/02,reperf 8/20/08 9-5/8"Casing 651 Hours HB5 13,440' 13,460' 9,475' 9,491' 20' Opened 1/13/02 7"Liner 50 Hours HB6 13,565' 13,580' 9,573' 9,585' 15' Opened 1/13/02,Isolated 2/02 HB7 13,610' 13,650' 9,609' 9,641' 40' Opened 1/13/02,Isolated 2/02 Updated by: JLL 12/29/16 • • King Salmon Platform Well K-01RD2 • 14 PROPOSED Last Completed: Future Hilcorp Alaska,LLC RKB:100'AMSL Casing and Tubing Detail KB-THF:33.7'KB j e if -7:. ,1 Size Type Wt/Grade TOP BTM CONN/ID Cement/Other 20" Conductor 94/H40 Surf 110' Welded/19" Driven 20"@ 110' • :, V, 13-3/8" Surface 61 K55 Surf 2 384' BTC 12.515" 2 4 " / / 6 0 G"/Surface 9-5/8" Intermediate 47/N80 Surf 112' BTC/8.681" 1 9-5/8" Intermediate 43.5/N80 112' 6,043' BTC/8.755" 1321"G"Surface a. y'Q 7" Liner 29/L80 5,859' 13,779' BTC-KC/6.184" 183BBL/5859' Tubing ' y 3-1/2 Tubing 9.2/L80 Surf ±5,821' HYD 563 SCC 1.5'-For x-Over A ...... 2-7/8" Tubing 6.4/L80 ±5,821' ±10,552' HYD 563 SCC 3-3/8"fa 2384' ee i1 44 Jewelry Detail s: .$ No. Depth(MD) Depth(ND) Length ID OD Item 1 ±33.7' ±33.7' ±1' Hanger(4-1/2"HYD or TCII) '. six ±36.7' ±36.7' 1.90' 2.992" 4.500" X-over:4-1/2"IBT to 3-1/2"HYD 563/503 ±5,820' ±4,758' 1.50 2.310" 3.500 X-over:3-1/2"Hydril 563-2-7/8"Hydril 563 2.347" 2.875" 2-7/8"Tubing Hydril 563/503 TOL 5659' it ±10,552' ±7,406' 2.310" 2.875" X-over to pump 9-5/8"@ 6043'�`+' 1 ±10,730' ±7,507' Bottom of ESP i PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) (Np) FT Date r si. GO-4 11,680' 11,720' 8,156' 8,186' 40' 5/7/01,partial reperf 1/27/05 GO-5 11,732' 11,742' 8,195' 8,202' 10' Opened 5/7/01 o---4/ '' GO-6 11,780' 11,810' 8,229' 8,251' 30' Opened 5/7/01 11,820' 11,840' 8,259' 8,273' 20' Opened 5/7/01 1 11,864' 11,891' 8,291' 8,310' 27' Opened 5/7/01 ;"" G-1 12,030' 12,080' 8,413' 8,451' 50' 5/7/01,partial reperf 1/27/05 GO-4 12,090' 12,120' 8,459' 8,481' 30' Opened 5/7/01 Gob 12,142' 12,162' 8,498' 8,513' 20' Opened 5/7/01 iiG-1 G-5 12,659' 12,674' 8,885' 8,896' 15' Opened 5/7/01 ;HB-1/G7 12,680' 12,694' 8,901' 8,911' 14' Opened 5/7/01 12,710' 12,790' 8,923' 8,983' 80' 5/7/01,partial reperf 1/27/05 HB-2 12,800' 12,830' 8,990' 9,012' 30' 5/7/2001 --HB-3 9,102' 9,147' 60' 7/3/01,partial reperf 1/27/05,partial G-7/HB-1 12,950' 13,010' reperf 8/22/08 4-21-2011 Fill HB-4 tagged 13448'MD HB-6 HB2 13,075' 13,095' 9,196' 9,211' 20' 8/20/08 MP Set 5f5.13,540' *� HB3 13,120' 13,130' 9,230' 9,238' 10' 8/20/08 Her HB3 13,190' 13,210' 9,283' 9,298' 20' rstiHB-7 HB 4 13,228' 13,340' 9,312' 9,397' 112' 5/7/01,partial reperf 1/27/05 TD=13,780' PBTD=13,750' HB5 13,405' 13,425' 9,447' 9,463' 20' Opened 1/13/02,reperf 8/20/08 H85 13,440' 13,460' 9,475' 9,491' 20' Opened 1/13/02 Directional Data: HB6 13,565' 13,580' 9,573' 9,585' 15' Opened 1/13/02,Isolated 2/02 max=59°at 8,485' HB7 13,610' 13,650' 9,609' 9,641' 40' Opened 1/13/02,Isolated 2/02 OCTG Rotating Hours 24"Structural Casing 110 Hours 20"Conductor 110 Hours 13-3/8"Surface Pipe 227 Hours 9-5/8"Casing 651 Hours 7"Liner 50 Hours Updated by: JLL 12/30/16 • • ., . ii King Salmon Platform K-01RD2 Current 12/29/2016 Hilrarp.tlarka.lit King Salmon BHTA, B-11-A0, 4 1/16 5M FE Tbg hanger, OCT-UH-TC- K-01 1A-ESP, 13 X 4 % BTC lift 24X133/8X95/8X3 '/ I R 1 andsusp, w/4" TypeH un1.11.1 BPV profile, 3/8 cont imisi control line port III 1.1 mal Valve, Swab, WKM-M, 4 1/16 5M FE, HWO, EE trim o -. • Valve, Wing, 4 1/16 5M FE, U U Moil w/Axelson AM oper, EE trim 1.iiix_1 Valve, Wing, VG-M, 2 1/16 5M FE, HWO, AA trim 'fir — /.11. .11.1 1.11.1 1.11.1 — Valve, Master, WKM-M, 4 1/16 hl 5M FE, HWO, EE trim p. 1■11■ �� • o -- fel I ) 1.111 Valve, Wing, WKM-M, 4 1/16 5M ' „, FE, HWO, EE trim !�i A3i Adapter, OCT-A5-ESP, 13 5/8 5M Q — 0 API hub X 4 1/16 5M stdd top, w/2- _ %control line exits, prepped w/OCT 1= 1► I lilt 400-4 pocket :I I_1 e id CJI,.. 'fI s ,.1..i All unihead annular valves, Unihead, OCT type 3, 13 5/8 5M ,. . _ = 2 1/16 5M FE OCT-20, API hub top X 13 3/8 BTC casing g ® HWO t bottom, w/ 1-2 1/16 5M SSO on [-' ��� � , (��'���'� ����, lower section, 1-2 1/16 5M SSO —1.. on middle section, 3-2 1/16 5M _ .' _ t. SSO on upper section , IP 1 1 internal lockpin asst' , l ;,•'y La,.1`i 7A/ = Valve, OCT 20, 3 1/8 2M Starting head, OCT, 21 y4 2M 11 Irotot FE, HWO FE X 24" SOW, w/ 1-3 1/8 2M • '' t� EFO, full set of lockpins 4.111 _ 111 _ 11124„ _13 3/8" 9 5/8" 4 %" i King Salmon Platform 2016 BOP Stack(Kuukpik) 06/22/2016 Hilrnrp Rig Floor 16" Pipe I I 1 F{l_1J-lll}it 1 tl • v I�lllil''mlil 111 Iil 111 1l1 III 3.74' Shaffer 13 5/8 5M 121 lii iii iii1110k7 it Shaffer SL - ® �`� — 2 7/8-5.5 Variables 2.83' - 13 5/8 5M — Blind 2 1/16 5M manual and HCR valve 2 1/16 5M manual and HCR valve r� 1111✓ti IU 111 If1 oorio 1.76 f iF I i 1(. 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G ©c c LI k 2 / c @ 2 0 — a) o • 0 a a_ & as � as « Ca � 0 ■ a. 2 x as o as E 0 , m Q ■ x 2 » ■ ■ o m : 0 X .§ e $ 2 0a. W / 2 LE / _ . . n9 0 0 / k :3 U a k >(-9 a 2 / m « « m < o_ • • Kuukpik 5 BOP Test Procedure Hileorp Alaska,LLCAttachment#1 Attachment #1 Hilcorp Alaska LLC. Rolling BOP Test Procedure: Kuukpik 5 — Oil/Gas Producers, Water/Gas Injectors Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile&lift threads were deemed good, but still unable to get good tests 1) 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), Guy Schwartz (AOGCC-guy.schwartz@alaska.gov),Jim Regg (AOGCC-jim.regg@alaska.gov) and Michael Quick (AOGCC—Michael.quick@alaska.gov)via email explaining the wellhead situation prior to performing the rolling test. If on Federal land contact BLM representative Amanda Eagle (aeagle@blm.com) and Mutasim Elganzoory(melganzoory@blm.com). AOGCC and BLM may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: 2) With stack out of the test path, test choke manifold per standard procedure 3) 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.) Kill and choke line valve will also be tested during this time. 4) During these tests the test chart needs to be set to 60 min instead of 12 hours so chart shows a better graph. Need to station hands in cellar going over all connections on the BOPs looking for the slightest leak. Also need a man looking down the hole to confirm that the BOPs are not leaking. Test if 1= Annular, HCR Choke, and HCR Kill. Test#2=Upper Pipe Rams, HCR Choke, and HCR Kill. Test#3=Upper Pipe Rams, Manual Choke, and Manual Kill. Test#4=Lower Pipe Rams. 5) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. 6) 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.) 7) 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. 8) Pull hanger to surface. (Making tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid and sweep off any oil cap that may be present. 9) 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 as per Kuukpik's standard test procedure. Or POOH laying down all the tubing and use the normal test plug to finish the tests that were not completed as per regulatory approval. Kuukpik 5 BOP Test Procedure • Hilcorp Alaskn,1.1AAttachment#1 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 and test. May have to tap out if scaled up or paraffined up if well is not dead may have to be done w/pressure lubricator (diesel or acid could help) 2) If unsuccessful, or BPV profile is eroded and well is dead. Best practice is to have two barriers a. Fluid column b. Set wire line plug or tag fluid level with slick line to establish static fluid level or shoot fluid level with an echo meter gun. 3) Shoot off tubing very shallow ( 300-500' most likely just under SSSV if applicable) 4) Spear hanger w/upside down cup provided by fishing company 5) Proceed to get best test we can achieve against cup and confirm no visual leaks on all flanges of BOPE 6) Notify Hilcorp Anchorage Operations Engineer and AOGCC of situation 7) Pull hanger and cut off stub 8) P/U test plug and set same. 9) Perform complete BOPE test as per Kuukpik's standard procedure Imagi ~roject Well History File Cover ~, ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~,-~-'00? Well History File ldentifier Organizing/,~o.~t [] RESCAN ~ Color items: [] Orayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA ~/' Diskettes, No. [] Other, No/Type OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner '~$1ZED (Non-Scannable) ~ Logs of various kinds BY: BEVERLY ROBIN VINCENT SHERYL ~INDY Project Proofing BY; BEVERLY ROBIN VINCENT SHERYL~~WINDY i Scanning Preparation I x 30 = ~ O BY: BEVERLY ROBIN VINCENT SHERYL~WINDY [] Other Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: Stage 2 BY; PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES IF NO IN STAGE t7 PAGE(S) DISCREPANCIES WERE FOUND: ~ YES II I I NO NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DuE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) RESCANNED B~'~ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked 12110/02Rev3NOTScanned.wpd • • Par 1 ff ALi SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM ISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 August 30, 2011 Mr. Chris Myers Field Superintendent Union Oil Company of California PO Box 196247 Anchorage, Alaska 99519 • RE: No -Flow Verification Trading Bay Unit K -01 RD2 McArthur River Field PTD 2010090 Dear Mr. Myers: On July 6, 2011 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a "no flow test" of Trading Bay Unit K -01RD2 located on the King Salmon Platform in Cook Inlet. The well is operated by Union Oil Company of California (Union). A subsurface safety valve is not required to be installed in this well based on the no -flow test result. A fail -safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. Union recently completed a workover on Trading Bay Unit K -01 RD2 to replace the downhole electric submersible pump. The AOGCC Inspector confirmed that Union verified no obstruction exists in the wellbore. Trading Bay Unit K -01RD2 was monitored 3 hours for flow by opening it to atmosphere through flow measurement equipment with suitable range and accuracy. During the flow monitoring period, the maximum gas flow rate measured on the calibrated flow meter was 400 standard cubic feet per hour. Total liquid production was less than 1 gallon. The subsurface safety valve must be returned to service if Trading Bay Unit K -01RD2 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the King Salmon Platform. Sincerely, ft4440 TR James B. Regg ( / Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission I TO: Jim Regg I l� 1 7 //( DATE: July 6, 2011 P.I. Supervisor FROM: Jeff Jones SUBJECT: No -Flow Test Petroleum Inspector Unocal / King Salmon PLT #,, '.'i` K -01RD2 PTD- 2010090 Trading Bay Unit July 6, 2011: I traveled to Unocal's King Salmon Platform in Cook Inlet to witness a No -Flow Test on well K -01 RD2. On my arrival on the platform I met with Unocal Lead Operator Wayne Johnson and we discussed the operational details of the test. Mr. Johnson indicated that the well pressure had been bled down and the wellbore was open to the tree cap with no plugs or restrictions. Unocal representative Greg McGahan performed the test today in a safe and proficient manner. Well K -01RD2 has an electric submersible pump (ESP) installed and was lined up from the tree top swab valve through an Armor -Flow model # 3461 -03T0 flow meter (180 SCFH to 1800 SCFH span) to a 1" hose which terminated in an open top drum. The flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas and liquid flow from the well did not exceed 900 SCF or 6.3 gals. hourly flow rate during the test. Well K -01 RD2 meets the AOGCC requirements for a No -Flow status determination. Summary: I witnessed a successful No -Flow Test on Unocal's Trading Bay Unit well K -01 RD2 on the King Salmon Platform. - Well No -Flow Test Data Operator: Union Oil Co. Operator Rep: Greg McGahan/Wayne Johnson AOGCC Rep: Jeff Jones Field /Unit/Pad TBU / King Salmon PLT Well: K -01RD2 Time Well Flow Comments Gas Liquid 11:00 400 scfh < 1 cup Start Test 11:30 380 scfh < 1 cup 12:00 350 scfh < 1 cup 12:30 350 scfh < 1 cup 1:00 350 scfh < 1 cup 1:30 360 scfh < 1 cup 2:00 360 scfh < 1 gallon during entire test End Test Produced to open top container through a new Armor -Flow meter model #3461- 03T0 -13 ser. # 112377 Total liquid produced: less than 1 gallon. This well has an ESP (electric submersible pump) installed. Attachments: none RJF 09/19/02 Page 1 of 1 2011- 0706_No- Flow_TBU_K- 01RD2_jj.xls $JG h • STATE OF ALASKA 06 / ; • ALASKA', AND GAS CONSERVATION COMMISSIW REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon (J Repair Well U Plug Perforations U Stimulate U Other U ESP Conversion % Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development igi Exploratory ❑ 201 -009 ■ 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic Service ❑ 6. API Number: 50- 733 - 20054 -01 --00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018777 (King Salmon Platform) TRADING BAY UNIT K -01RD2 9. Field /Pool(s): .. McArthur River Field/ Middle Kenai G Oil and Hemlock Oil Pools 10. Present Well Condition Summary: Total Depth measured 13,780 feet Plugs measured 13,540 feet true vertical 9,743 feet Junk measured 13,448 (Fill) feet Effective Depth measured 13,448 feet Packer measured N/A feet true vertical 9,480 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 109' Surface 2,384' 13 -3/8" 2,384' 2,167' 3,090psi 1,540psi Intermediate Production 6,043' 9 -5/8" 6,043' 4,928' 6,330psi 3,810psi Liner 7,920' 7" 13,780' 9,743' 8,160psi 7,030psi 11680- 11720, 11732- 11742, 11780 - 11810, 11820 - 11840,11864- 11891, 12030 - 12080, 12090 - 12120, 12142- 12162, 12659- 126 126 1 2790, Perforation depth Measured depth 12800 - 12830, 12950- 13010, 13075- 13096, 13120-13130, 13190 - 13210, 13228 - 13340, 13405 - 13425, 13440 - 13460, 13556 - 13580, 13610 -13650 8156 - 8185,8194- 8201, 8229 - 8251,8258 -8273, 8290 - 8310,8413 -8450, 8458 - 8480,8497- 8512, 8885 - 8896,8900- 8911, - 8 9012 -9146, True Vertical depth 9195 -9211, 9229 -9237, 9282 -9298, 9312 -9396, 9447 -9462, 9474 -9490, 9566- 9585, 9609 -9648 3 -1/2" 9.2 #/ L80 Surface - 5,822' Surface- 4,760' Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.4#/180 5,822'- 10,533' 4,760'- 7,395' Packers and SSSV (type, measured and true vertical depth) N/A y pp N / /A A N/A N/A 11. Stimulation or cement squeeze summa0t.,.. Nh1) JUN 0 201 i " � Intervals treated (measured): 1 I } : Ili' N/A Treatment descriptions including volumes used and final pressure: �` f6tnuss10fi N/A Aias a fa & oA Liim. ._, 1 12. Representative Daily Ave rriti rrdd etion or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 N/A Subsequent to operation: 320 63 683 65 60 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development 0 ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations Y 15. Well Status after work: Oil ' la Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. 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: 311 -159 Contact Jack Newell Phone 263 -7832 Printed Name Timothy C. Brandenburg a Title Drilling Manager Signature e'''' ' "� e C " Phone 276 -7600 Date 6/27/2011 a - __,.;c -- RDMS JUN 3 0 2011 '' Form 10-404 Revised 10/2010 Submit Original Only r hevrO King Salmon Platform K-� 1 RD2 Well K -1 RD2 � o''o ' As -Built Wellbore Schematic east completed 6/17/2011 Updated 6/23/2011 RKB: 100' AMSL KB -THF: 33.7' KB — — A ' . ' L Casing and Tubing Detail o° @ 110' Size Type Wt/ Grade TOP BTM CONN / ID Cement / Other 20" Conductor 94/ H40 Surf 110' Welded/ 19" Driven 13 -3/8" Surface 61/ K55 Surf 2384' BTC/ 12.515" 2640 "G "/ Surface 9 -5/8" Intermediate 47/ N80 Surf 112 BTC/ 8.681" 1321 "G" Surface j 1 9 -5/8" Intermediate 43.5/ N80 112 6043 BTC/ 8.755" k 7" Liner 29/ L80 5859 13,780' BTC -KC/ 6.184" 183BBL/ 5859' T ubing -310" @ 2384' 3-1/2 Tubing 9.2/ L80 34.7' 5821.7 HYD 563 SCC 1.5'_For x -Over 2 -7/8" Tubing 6.4/ L80 5821.7' 10552.6' HYD 563 SCC Production String Jewelry Detail # Depth (RKB) Length ID OD Item 33.7' ±1' Hanger (4 -1/2" HYD or TCII) 36.7' 1.90' 2.992" 4.500" X -over: 4 -1/2" IBT to 3 -1/2" HYD 563/503 2770' 8.68' 4.125" 5.313" 3 -1/2" #1 SFO -1 GL Mandrel ToL: ssss 4512' 8.70' 4.125" 5.313" 3 -1/2" #2 SFO -1 GL Mandrel iv s- s/e °(a 6043' 5671' 8.70' 4.125" 5.313" 3 -1/2" #3 SFO -1 GL Mandrel 5820.2' 1.50 2.310" 3.500 X -over: 3 -1/2" Hydril 563 — 2 -7/8" Hydril 563 2.347" 2.875" 2 -7/8" Tubing Hydril 563/ 503 6805' 7.35' 2.347" 4.750" 2 -7/8" #4 SFO -1 GL Mandrel 7896' 7.34' 2.347" 4.750" 2 -7/8" #5 SFO -1 GL Mandrel 8867' 7.35' 2.347" 4.750" 2 -7/8" #6 SFO -1 GL Mandrel '' 9900' 7.34' 2.347" 4.750" 2 -7/8" #7 SFO -1 GL Mandrel i 10467' 4.57' 2.313" 2.875 2 -7/8" Sliding Sleeve; SSD,2.313 9CR,H2S ' 10514' 2.23' 2.205" 2.875" 2 -7/8" "XN" Profile Nipple (No -Go: 2.205 ") 10552.6' 2.310" 2.875" X -over to pump T f 10568' ND ND ESP: Motor, Pump and Assembly 10642' ND ND ESP Pump Intake 10730' ND ND Phoenix Assembly "GO -4 Zone Top Btm Amount Condition lile GO-6 GO -4 11680 11720 40 5/7101, partial reperf 1/27/05 G -1 00-5 11732 11742 10 Opened 5/7101 G-5 GO -6 11,780: 11,810' 30 Opened 5/7101 HB -1/G7 11,820' 11,840' 20 Opened 5/7/01 HB-2 11,864' 11,891' 27 Opened 5/7/01 FHB -3 G -1 12,030' 12,080' 50 5/7/01, partial reperf 1 /27/05 4- 21 -2 °d 13" 448' M F '' D + HB-4 12,090' 12,120' 30 Opened 5/7/01 tagge HB 5 BP Set 0,13,54 12,142' 12,162' 20 Opened 5/7101 - =,HB-s G -5 12,659' 12,674' 15 Opened 5/7/01 HB -7 12,680' 12,694' 14 Opened 5/7/01 PBTD = 13,750' TD = 13,780' 12,710' 12,790' 80 5/7/01, partial reperf 1/27/05 12,800' 12,830' 30 5/7/2001 G- 7 /HB -1 12,950' 13,010' 60 7/3/01, partial reperf 1/27/05, partial reperf 8122/08 Deviation: max = 59° at 8485' MD H62 13,075' 13,095' 20 8/20/08 OCTG Rotating Hours HB3 13,120' 13,130' 10 8/20/08 HB3 13,190' 13,210' 20 24" Structural Casing 110 Hours HB -4 13,228' 13,340' 112 Opened 6/ /1501 & 7/3/01, partial reperf 8 /22/08 20" Conductor 110 Hours HB5 13,405' t3,425' 20 Opened 1/13/02, reperf 8/20/08 13 -3/8" Surface Pipe 227 Hours HB5 13,440' 13,460' 20 Opened 1/13/02 9 -5/8" Casing 651 Hours HB6 13,565' 13,580' 15 Opened 1/13/02, Isolated 2/02 7" Liner 50 Hours HB7 13,610' 13,650' 40 Opened 1/13/02, Isolated 2/02 WBD K -01 RD2 06- 23- 2011.docx Updated by TDF 6 -23 -2011 •Chevron • ■00 Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) K-01RD2 TRADING BAY UNIT K -01 RD2 2010090 5073320054 AR4258 100.00 .10s Primary Job Type Job Category Objective Actual Start Date Actual End Date Pump Repair Major Rig 6/7/2011 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number K -01RD2 507332005401 1670650 Daily Operations 6/7/2011 00:00 - 6/8/2011 00:00 Operations Summary RU to well K -01 RD2, Notify AOGCC of upcoming BOP test on 6/6/2011, witness waived by Jim Regg. 6/8/2011 00:00 - 6/9/2011 00:00 Operations Summary Finish rigging up equipment, ND tree - NU BOP, Test BOPE to 250PSI Low/ 3,000 PSI high, test annular to 250 PSI Low/ 1,500 PSI high, required tests performed using a 2 -7/8 ", 3 -1/2" and 4" test joint. Monitor losses. 6/9/2011 00:00 - 6/10/2011 00:00 Operations Summary Test closing unit function times, after closure - 1,600 PSI, To attain 200 PSI 24 seconds, full recharge 99 seconds. PU, RIH w/ 7" valve retrieving tool - monitor losses. 6/10/2011 00:00 - 6/11/2011 00:00 Operations Summary Continue to RIH with 7" valve removal assembly BHA, circulate well w/ 3% KCL w/ biocide before releasing valve - monitor losses. 6/11/2011 00:00 - 6/12/2011 00:00 Operations Summary SD Pump, RIH w/ retrieving tool, latch packer @ 9,800 DPM, PU to release packer, POH with packer - observe well losses, close annular observe for flow - continue to POH with packer, LD same - Test Annular w/ 4" DP to 200PSI Low/ 1,500PSI High, closure reported to AOGCC 6/12/2011 00:00 - 6/13/2011 00:00 Operations Summary RU slickline RIH w 6" gauge ring and junk basket to 10,750' MD, POH RD slickline, RU to run 2,400 BPD ESP equipment, monitor fluid losses. 6/13/2011 00:00 - 6/14/2011 00:00 Operations Summary PU 2,400 BPD ESP assembly, RIH on 2 -7/8" tubing, monitor fluid losses. 6/14/2011 00:00 - 6/15/2011 00:00 Operations Summary Continue to RIH 2,400 BPD ESP equipment on 2 -7/8" x 3 -1/2: tapered production string - monitor fluid losses. 6/15/2011 00:00 - 6/16/2011 00:00 Operations Summary Finish RIH with 3 -1/2" 9.2# L -80 x 2 -7/8" 6.4# L -80 ESP gaslift completion to 10,730', pump intake at 10,642', land hanger, test same, ND BOPE, NU Tree and test same. 6/16/2011 00:00 - 6/17/2011 00:00 Operations Summary RD ESP running equipment, RD pump and equipment. 6/17/2011 00:00 - 6/18/2011 00:00 — Operations Summary Release rig to next well - K -25. • • Page 1 of 1 Regg, James B (DOA) From: LaFleur, Keith [Swift Technical Services] [KeithLaFleur ©chevron.com Sent: Sunday, June 12, 2011 9:58 AM fi lvti°(It To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: Annular Test Zir) --00 Attachments: Cudd 136 6 -11 -2011 Annular.xls Mr. Regg Attached is a document reflecting the annular test performed after a closure. Please let me know if you require any further information. Thanks, Keith LaFleur Drill Slte Manager MidContinent/Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 King Salmon DSM Office 907 - 776 -6698 Cell 337 - 304 -6140 40 sl01'4 1 4 2U 1 6/13/2011 • • Page 1 of 2 Regg, James B (DOA) PT6 2 01-00 , i From: Hammons Jr, Darrell James [hammodj @chevron.com] Sent: Saturday, June 11, 2011 11:58 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Brandenburg, Tim C; LaFleur, Keith [Swift Technical Services]; Johnston, Ray E (rayj); Bonnett, Nigel (Nigel.Bonnett) Subject: FW: AOGCC BOP Closure notification Mr. Regg, We shut the Annular in on the King Salmon K -01 RD2 last night. Please see the form below if you have any question's Please contact me on my cell or the DSM on the King. Thanks Date: June 11, 2011 Time of BOPE Use: 2030 Hours Well /Location /PTD number: Trading Bay Unit K -01 RD2 /King Platform /201 -009 ' Rig Name: CUDD #136 Operator Contact: Ray Johnston, Drill Site Manager Office: 907 - 776 -6698 Darrell Hammons, Drilling Superintendent Office 907 - 263 -7632 Cell 907 - 382 -4225 Operations Summary including events leading up to BOPE use: While circulating bottoms at 4 BPM for the first time on this well we received an LEL gas detection of 15% LEL. We slowed our pump rate down to 2 BPM and continued to circulate. After a couple more BBLS the High LEL alarm sounding with LEL 84% at the mud pit. We shut down the pump, and closed the Annular preventer. There was a general platform muster. The gas level at the pits was checked an 0 gas and 0 H2S was detected. The muster was called off. We found both casing and DP pressure at 0 (zero) PSI. As a precaution we swapped valves and broke circulation to the production header pumping a total of 75 bbls 3% KCL. Samples revealed no oil in any sample. We shut down and swapped valves then proceeded to circulate to the rig pits with no additional alarms. BOPE Used: 6/13/2011 • Page 2 of 2 Annular and Full Opening Safety Valve. Reason for BOPE use: High LEL alarm at the mud pit while circulating Bottoms up: Actions Taken I To be taken (including the date used BOPE was tested) After circulating to the production header and seeing no oil in samples the well had no flow and was losing fluid. We swapped over and continued to circulate bottoms up to the mud pit. Last BOP test date was 06 -09 -11 at 1230 hours. We plan to test the Annular once we get out of the hole. If you have any questions Please let me know. Thanks. Darrell Hammons I I Drilling Superintendent hammodj ca,chevron.com Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Drive Anchorage, AK 99503 -5826 Tel 907 263 7632 Fax 907 263 7884 Mobile 907 382 4225 6/13/2011 0 • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 4'13, BOPE Test Report / Submit to: iim.rega( alaska.gov doa .aoacc.Prudhoe.bavaalaska.gov phoebe. brooksaa.alaska.gov Contractor: CUDD Rig No.: 136 DATE: 6/11/11 Rig Rep.: Regan /Jasper Rig Phone: 776 -6698 Rig Fax: Operator: Chevron Op. Phone: 776 -6699 Op. Fax: Rep.: LaFleur /Johnston E -Mail klmw @chevron.com Well Name: K -1 RD2 PTD # 2010090 Operation: Drig: Workover: X Explor.: Test: Initial: Weekly: Bi- Weekly Test Pressure: Rams: Annular: 250/1500 % Valves: MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: NA Well Sign NA Upper Kelly 0 NA Housekeeping: NA Drl. Rig NA Lower Kelly 0 NA PTD On Location NA Hazard Sec. NA Ball Type 0 NA Standing Order Posted NA Misc NA Inside BOP 0 NA FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P NA Annular Preventer 1 13 5/8" P - Pit Level Indicators P NA #1 Rams 1 2 7/8 x 5 var. NA Flow Indicator P NA #2 Rams 1 Blind /Shears NA Meth Gas Detector P NA #3 Rams 1 2 7/8 x 5 var. NA H2S Gas Detector P NA #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 2 2 1/16" NA Inside Reel valves 0 NA HCR Valves 2 2 1/16" NA Kill Line Valves 1 2 1/16" NA Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time /Pressure Test Result System Pressure 2950 NA CHOKE MANIFOLD: Pressure After Closure 1600 NA Quantity Test Result 200 psi Attained 24 NA No. Valves 14 NA Full Pressure Attained 99 NA Manual Chokes 1 NA Blind Switch Covers: All stations Yes Hydraulic Chokes 1 NA Nitgn. Bottles (avg): 6 @ 2433 CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 1.0 Hours Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659 -3607, follow with written confirmation to Supervisor at: iim.reggna.alaska.qov Remarks: Annular was tested with 4" pipe. This was an off schedule test due to closing the annular while iz experiencing gas which registered 84% LEL. 24 HOUR NOTICE GIVEN YES NO X Waived By Jim Regg Date Time Witness Test start ,-11 -11 22:00 Finish 6 -11 -11 23:00 Form 10 -424 (Revised 06/2010) Cudd 136 6 -11 -2011 Annular.xls • • sir r [ ALAsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg © 0 �( Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, TBU K -01RD2 Sundry Number: 311 -159 011 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ✓, Daniel T. Seamount, Jr. Chair DATED this) 4 —day of May, 2011. Encl. L: ENEE • 1 ;01' 10.1604. W es`^ �.'�'`'� �€ STATE OF ALASKA ..f 05 / N 2.611 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS '' ` "r'if))iaaior ' 20 AAC 25.280 A tinkles 41 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: Esp Conversion 0 2. Operator Name: Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Development Ei . Exploratory ❑ 201 -009 • 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic ❑ Service ❑ 6. API Number: 50- 733 - 20054 -01 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 CI No El TRADING BAY UNIT K -01RD2 9. Property Designation (Lease Number): 10. Field /Pool(s): . ADL0018777 (King Salmon Platform) McArthur River Field/ Middle Kenai G Oil and Hemlock Oil Pools • 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): 13,780' 9,743' • 13,540' 9554' 13,540' (CIBP) N/A Casing Length Size MD / ND Burst Collapse Structural Conductor 110' 20" 110' 109' Surface 2,384' 13 -3/8" 2,384' 2,167' 3,090 PSI 1,540 PSI Production 6,043' 9 -5/8" 6,043' 4,928' 6,330 PSI 3,810 PSI Liner 7920' 7" 13,779' 9,742' 8,160 PSI 7,020 PSI Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11680 - 11720, 11732 - 11742, 11780. 8156 -8185, 8194 -8201, 8229- N/A N/A N/A 11810, 11820 - 11840, 11864-11891, 8251, 8258 -8273, 8290 -8310, 8413. 12030 - 12080,12090- 12120,12142- 8450,8458- 8480,8497 -8512, 12162, 12659 - 12674, 12680 - 12694, 8885 -8896, 8900 -8911, 8923- 12710- 12790, 12800 - 12830, 12950- 8982, 8990 -9012, 9101 -9146, 13010, 13075- 13096, 13120- 13130, 9195 -9211, 9229 -9237, 9282- 13190- 13210, 13228 - 13340, 13405- 9298, 9312 - 9396, 9447 -9462, 13425, 13440 - 13460, 1156 -135 0k. 9474-9490, 9566 -9585, 9609 - 14R1n -1 QRdR Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Reservoir Isolation Tool / N/A 9,750' MD (6,969' TVD) / N/A 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch U Exploratory ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 6- Jun -11 Commencing Operations: Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WI NJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jack Newell 263 -7832 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature _ Phone 276 -7600 Date 6- May -11 COMMISSION USE ONLY '° 6ii 1 59 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test d Mechanical Integrity Test ❑ Location Clearance ❑ Other: T e s t ram $0 PE f o 3000 t o t - . 1 • ) fectawtti.wtaq I O PE +0 15 1' . Subsequent Form Required: i 0 ^ L C 0, I di" 'G `T . APPROVED BY I Approved by: / OMMISSIONER THE COMMISSION Date: 5/124 ( Form 10-41 Revised 1/24 a" D MAY .12 i R I G I N A L , Submit in Duplicate (C> C t /' r • • Chevron Trading Bay Unit %NO K -01 RD2 %OS 5 -6 -2011 Objective: • Remove reservoir isolation valve, cleanout well to ±10,600' MD, RIH ESP completion with Gas lift mandrels, return well to production. Current BHP: 3358 PSI @ 8889' ND 7.3 PPG EMW Max BHP: 3358 PSI @ 8889' ND 7.3 PPG EMW (Estimated from survey: 8 -2008) Current water cut � 96%. MASP:_0 -ps (Based on actual reservoir conditions and water cut of 96% (0.436psi /ft) with added Safety Factor of 1000' ND of oil cap) Procedure Summary: 1. MIRU HWO unit. 2. Lubricate and bleed well with 3% KCL -FIW (filtered inlet water). Verify well static. 3. ND tree/ NU and test BOPE. Pressure test 250psi Low/ 3000psi High, Annular 250psi Low/ 1500psi High. — 4. PU reservoir isolation valve assembly packer retrieving tool. 5. RIH and retrieve reservoir isolation valve assembly packer @ 9750' MD. 6. Circulate wellbore with 3% KCL -FIW (filtered inlet water). 7. Spot salt bridging pill for loss control as necessary. 8. POH with reservoir isolation valve packer assembly. 9. PU and RIH to ±10,800 with scraper assembly — POH and LD 10. PU and RIH 3 -1/2" x 2 -7/8" L -80 tubing w/ ESP and gas lift mandrels; pump intake set at depth +/- 10,620'. 11. ND BOPE. NU and test tree. 250psi Low/ 5000psi High. 12. Secure and turn well over to production. 13. Rig down and release HWO unit (rig). 05 -06 -2011 JRN • • r evro King K -01RD2 d ing Bay unit ....\-.• 11 K -1 RD2 C urrent Well Schematic I RKB to TBG Head = 33.7' Tree connection: Size Type WT Grade CONK [� Top BTM Hole Cement CMT Size 20" Conductor 94 H40 Weld 19 Surf 110' Driven Sacks Top 2,384' 13 -3/8 Sur Pipe 61 K55 BTC 12.515 Surf 2384 18" 2640 "G" Surf 9 -5/8 Sur CSG 47 N80 BTC 8.681 Surf 112 12.25 1321 "G" Surf 9 -5/8 Sur CSG 43.5 N80 BTC 8.755 112 6043 12.5 7 Liner 29 L80 BTC -KC 6.184 5859 13,779 8.5 183 bbl 585 # Depth ID Jewelry Description 1 9,750 Reservoir Isolation Tool (closed) PERFORATION DATA are Tqp I3rn MTart Qxddai 5,859' 0304 11657 1174 40 5701, pa ha it of 727706 %� 7< C 35 1 11742 10 08 157/01 4 a Q)6 11,7E0 11,810 30 Crarod57/01 11,827 11,847 23 Q 57/01 High DL 11,E64 11,831 27 Cre Seventy @ Window G1 12000 12037 50 5701, rata raze 1/27/06 ant a a n5'1' . . 12060 12'0 37 Q ErEcl57/01 12142 121152 2) Cpatai 57/01 G5 123J 12674 15 Q ETECI 001 12637 1291 14 ()maid 57/01 Rese var 12713 12733 8) 5701, pai epsf 1/D /C6 Isdation 12823 1283) 3) 57/23)1 _ 11[4 V Pkr alve sBau G7/I -B1 12933 13010 6) 7/ 301, rata aTef'1/D/CE paid aTe1822'CB A i 373 1-P2 1 13033 2) 8X008 1-B3 13127 13137 10 82008 DL Severity = 304 H33 -Qv 13,2u 23 . 10,455' –10,477' — 10,826'- 11,110' — C(3-5 I-B4 1378 13343 112 QJero1&1571 &7/301, rate rtEpaf872C8 11,365'- 11,829' 3,06 FE6 13433 13425 23 QJa6d1/13(P,rezaf8'X7C8 3-1 1 13447 13437 23 Q33ied 1 , 13( a F-B 13533 13533 15 Qferod 1/13E Isdae:12tP = FIN 13610 VIEW 40 Qsrod 1/13'CP Isd#ed2C2 • 9-71 HB-1 iB -2 H3-3 " 421 -2011 Fill I-13-4 — _.. -. _. _. __ _ Tagged 1344B MD T H,e OCTG Rotating Hours , aBPSet @13,540 - - 6 24" Structural Casing 110 Hours lsohted Perrorati ons = HB -7 20" Conductor 110 Hours "'T if ' 13 -3/8" Surface Pipe 227 Hours PBTD = 13750' 1D= 13780' 9 -5/8" Casing 651 Hours MAX HOLE ANGLE =59° @8485' 7" Liner 50 Hours NOTE: Tagged CIBP @ 13, 545' 6/24/08 K -01RD2 Schematic 11 -24 -09 Revised by JHM 8 -9 -10 evro: .�.. . K-� i RD2 Well K -1 RD2 - '' Proposed Wellbore Schematic Last completed XXX RKB: 100' AMSL KB -THF: 33.7' KB Casing and Tubing Detail Size Type _ Wt/ Grade TOP BTM CONN / ID Cement / Other 20" @ 110' ' . 20" Conductor 94/ H40 Surf 110' Welded/ 19" Driven 13 -3/8" Surface 61/ K55 Surf 2384' BTC/ 12.515" 2640 "G "/ Surface 9 -5/8" Intermediate 47/ N80 Surf 112 _ BTC/ 8.681" 1321 "G" Surface • 9 -5/8" Intermediate 43.5/ N80 112 6043 BTC/ 8.755" . 7" Liner 29/ L80 5859 13,799' BTC -KC/ 6.184" 183BBL/ 5859' . • Tubing 411. ,3 -31a° z3aa - HYD563/503/ X -over 3 -1/2" HYD - 2 -7/8" 3 -1/2 Tubing 9.2/ L80 Surf ±5825 2.992" HYD ( Length: 5800') 2 -7/8" Tubing 6.4/ L80 5825' 10700' HYD 563/503 Length: 4800' Production String Jewelry Detail 0 # Depth (RKB) Length ID OD Item ' 33 7' `1 Hanger (4 -1/2" HYD or TCII) ±1' 2.992" 4.500" X -over: 4 -1/2" to 3 -1/2" HYD 563/503 1 2.992" 3.500" 3 -1/2" Tubing, Hydril 563/503 ' ±2770' ±7' 4.125" 5.313" 3 -1/2" SFO -1 GL Mandrel Toy 5859' ±4535' - 7 4.125" 5.313" 3-1/2" SFO -1 GL Mandrel 9 -5/8' a 6043' A A ±5743' 4.125" 5.313" 3 -1/2" SFO -1 GL Mandrel ±5825' 2.347" 3.500 X -over: 3 -1/2" Hydril 563 - 2 -7/8" Hydril 563 J. 2.347" 2.875" 2 -7/8" Tubing Hydril 563/ 503 ±6818' ±7' 2.347" 4.750" 2 -7/8" SFO -1 GL Mandrel ±7848' ±7' 2.347" 4.750" 2 -7/8" SFO -1 GL Mandrel ±8876' ±7' 2.347" 4.750" 2 -7/8" SFO -1 GL Mandrel ±9903' ±7' 2.347" _ 4.750" 2 -7/8" SFO -1 GL Mandrel ±10473' ±8' 2.313" 2 -7/8" Sliding Sleeve; SSD,2.313 9CR,H2S ±10545' ±1.5' 2.313" 2.875" 2 -7/8" "XN" Profile Nipple (No -Go: 2.205 ") 1 ±10553' 2.875" X -over to pump ±10568' ±51' ND ND ESP: Motor, Pump and Assembly ±10620 ±55 ND ND ESP Pump Intake ±10675' ND ND Phoenix Assembly _ are Tcp Mrart (brciliai - -a_GO-4 (3)4 11 ) 11 /d) 43 57,01, pEdid rEpef 1rD/C6 GOB C3D5 1173 117 10 Creeed57/01 0-1 (3D6 11,783 11,810 33 Q.B ed 57/01 G-5 11,837 11,843 2) Q.1e e157/01 HB-1/07 11,834 11,81 27 QBDi 57/01 • HB-2 G1 12000 12083 5) TM, patid reef 127/C6 HB3 12060 12120 33 Q:e•ai57 /01 4-21-2011 F II HBO tagged �{`; '{ (y� tagged 13448 MD HB-5 12� 1 ' 2) C 5/01 CIBP Set @ 13,540' G5 12659 12674 15 4ErE � " 12600 . v 2 �1 14 QB'Ed57 /01 H &7 12710 127) 83 &x1, IBM mice l/27 /C6 TD = 13,750' PBTD = 13,780' 112 12830 33 57/201 Directional Data: G7/I -61 12930 13010 CO 7/301, !maid reef1//Q paid reicefF2403 max = 59° at 8485' H32 13075 13 23 8218 ____, FE3 13120 13130 10 82308 OCTG Rotating Hours I-B3 13193 13,210 23 I-B4 13228 13313 112 Quaid /1E01 &7/301, patid r p3f8'22C8 24" Structural Casing 110 Hours FE6 13433 13E03 2) ()BEd 1/13C repef82303 20" Conductor 110 Hours Q �� vp � 13 -3/8" Surface Pipe 227 Hours FE5 134e0 13433 23 9 -5/8 " Casing 651 Hours H33 13633 130321 15 Qaai'V13GIstted2(2 7" Liner 50 Hours F® 13610 1O 43 Q1aai'V1 tg Isdeted2'Q WBD K -01 RD2 03 -11 -2011 Proposed.docx Updated by JRN 3 -11 -2011 0 g King Salmon Platform BOP Stackup 03/14/2011 King Salmon 2011 ESP Workovers BOP Drawing K -1, K -13, K -30 BOP based on Cudd rental 4.54' Hydril stack drawing 13 5/8" 5000 lit: tit tit iii 0. MB itt 111 III I11 11I 4.6T Cl6U ` 1,, • 1 VI al lit 1 ' 111'�t lit All choke and kill line valves 2 1/16 5Mjw/ 111 tor . 2.00'1� �; I?,� :;�� ,�� unibolt end connections ��� °II -4.N, � I I i l lil . • •� 1.1 111 111 111 111 2.83' - - �' iii lii lit lil lil .70' III tal 13.70' Drill deck Riser 13 5/8 5M FE X 13 5/8 5M API Hub 12.98' c jilisin . I■ II J � l ` % 5.70' . r � '! I . ..� - I ek 7 IA ■ci;J. . ill II STATE OF ALASKA RECEIVED ALAS IL AND GAS CONSERVATION COMMISSO NOV V 6 2009 REPORT OF SUNDRY WELL OPERATIONS A1aka Q'I 1 Gas Cons. Commission 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate her Lj Pull Tubing 0 Pe rforate New Pool ❑Anchorage Performed: Alter Casing g Waiver Time Extension Change Approved Program Operat. Shutdowr, Perforate Q' Wok Re -e\ er Suspended Well 2. Operator Union Oil Company of California 4. Well Class Before Work: I Permit to Drill Number: Name: Development El Exploratory 2 1 -009 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphi Service API Number: 50- 733 20054 -01 Property Designation (Lease Number): Well Name and Number: ADL0018777 [King Salmon Platform] Trading Bay Unit K -01 RD2 Field /Pool(s): Mr"Arthur River Field Hemlock Oil, Middle Kenai G Oil Pool 11. Present Well Condition Summary: Total Depth meal 13,780 feet Plugs (measured) 13,540 feet true vertia• 9,743 feet Junk (measured) N/A feet Effective Depth measured 13,600 feet Packer (measured) 9,750 feet true vertical 9,601 feet (true vertical) 6,969 feet Casing Length Size MD TVD u .Burst Collapse Structural 110' 20" 110' Conductor 2,349' 13 -3/8" 2,384' 3,090 psi 1,540 psi Surface 6,008' 9 -5/8" 6,043' 6,330 psi 3,810 psi Intermediate Production Liner 7,920' 7" 13,779 NO4 2 r 2 009 8,160 psi 7,020 psi Perforation depth: Measured depth: See attached schematic True Vertical depth: See attached schematic Tubing (size, grade, measured and true vertical depth): N/A N /A N/A N/A Halliburton Reservoir 9,750'MD Packers and SSSV (type, measured and true vertical depth): Isolation Packer 6,969'TVD 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 0 740 psi 180 psi Subsequent to operation: 0 0 0 10 psi 30 psi 14. Attachments: Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Developments Service Daily Report of Well Operations X Well Status after work: Oil El Gas WDSPL GSTOR WAG GINJ WI NJ 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: 308 -111 308 -219 Contact Marcus Barbee 263 -7605 Printed Name Timothy C. Brandenburg Title Drilling Manager j Signature 1 r Phone 276 -7600 Date 11/24/09 PDfrLS 9 1t( Form 10 -404 Revised 7/2009 Submit Original Only Chevron 1 10 Chevron Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) K -01RD2 TRADING BAY UNIT K -01RD2 2010090 5073320054 AR4258 100.00 Jobs Primary Job Type Job Category Objective Actual Start Date Actual End Date Pump Repair Major Rig To pull a failed ESP and replace it with an ESP on coiled tubing. 6/19/2008 10/28/2009 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number K -01RD2 507332005401 1670650 Daily Operations 6/19/2008 00:00 6/20/2008 00:00 Operations Summary MOBE pump 250 bbls 3% KCL to circ. hydrocarbons out of well. Pump 5 bbl saturated salt, 85 bbl sized salt 10 bbl saturated salt squeeze same to formation AOGCC waived witness of BOP test. 6/20/2008 00:00 6/21/2008 00:00 Operations Summary ND tree NU BOP. Test same to 250 low, 3000 psi high. 6/21/2008 00:00 6/22/2008 00:00 Operations Summary Finalize BOP Test. Pull Hangar. Well U tubing. Mixed pumped 22 bbls of 6% KCL. POOH w /ESP spooling cable, and racking back) 4 1/2" tbg. 6/22/2008 00:00 6/23/2008 00:00 Operations Summary Continue POOH, tailing 4 1/2 pipe, (RB) retrieving clamps SS bands. Pull 20' piece of 3/8" chem inj. line fish from previous workover. POOH w/ 3 1/2" tbg laying down pull ESP BHA to window. 6/23/2008 00:00 6/24/2008 00:00 Operations Summary POOH ESP to deck. PU /MU cleanout assembly. Reassess cleanout BHA, change configuration to include reverse baskets for ESP jewelry fish lost from this run in addition to the past. PU /MU new BHA w /reverse basket and RIH on 4" DP. 6/24/2008 00:00 6/25/2008 00:00 Operations Summary TIH to top of liner circulate. Continue in hole. Tag CIBP 13,545. POOH w /reverse circ. basket BHA. 6/25/2008 00:00 6/26/2008 00:00 Operations Summary Complete pulling out with clean out BHA. LD same. Secure well. Prep for running kill string. 6/26/2008 00:00 6/27/2008 00:00 Operations Summary RIH with 2471' of 4 -1/2" 12.6# L80 tubing as kill string. PU wgt of 331K, Slack off 29K. Land hanger, set BPV test to 3100 psi, 30 min, good. ND BOP NU tree. Test tree to 3000psi for 30 mins, good. Demobe off well. 8/15/2008 00:00 8/16/2008 00:00 Operations Summary Mobe rig onto K -01 RD2. AOGCC was contacted yesterday and waived witness of BOP test. Start BOP test. 8/16/2008 00:00 8/17/2008 00:00 Operations Summary Continue BOP testing. 250 psi low and 3000 psi high. All tests good. Circulate well down killstring. Pull tbg hanger break out in window. POOH w/ killstring LD same. PU 6" Junk mill w/ 7" csg scrapper. RIH. 8/17/2008 00:00 8/18/2008 00:00 Operations Summary Cont. RIH w /csg scrapper BHA to 9800' (approximate location of packer setting depth). Scrape and mill over interval multiple times. POOH w /BHA. LD same. PUMU 4 -5/8" millenium TCP guns. 8/18/2008 00:00 8/19/2008 00:00 Operations Summary RIH w/TCP guns on 4" DP. Guns stacked out 10' shallow of depth. 8/19/2008 00:00 8/20/2008 00:00 Operations Summary RU eline. Tie in TCP guns. Confirm 10' shallow of perf depths. POOH w/ drill pipe. Stand back DP. 8/20/2008 00:00 8/21/2008 00:00 Operations Summary Finish POOH w/ TCP guns and LD same. MU and RIH w/ 3- 1/2 "x5' eline conveyed perf guns correlate. Unable to work to total depth for perfs, able to perf 5' (of desired 15'). Perf 13,445' 13,440' w/ POOH. MU 20' gun. RIH correlate. Perf 13,425' 13,405' w/ 6 spf @72 deg phasing guns. RD eline. 8/21/2008 00:00 8/22/2008 00:00 Operations Summary PUMU TCP guns. RIH to 13,285'. RIH w/ eline correlation logging tools. 8/22/2008 00:00 8/23/2008 00:00 Operations Summary Correlate TCP guns on depth. POOH w /eline. Drop dart and fire guns. 4 -5/8" TCP Millenium guns perfd 13,268' 13,228' (40'), 13,130' 13,120' (10), 13,095' 13,075' (20') 12,975' 12,955' (20'). POOH. LD drillpipe. Chevron Chevron Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface WI ChevNo Original RKB (ft) Water Depth ft 9 S U 9 O th pO K -01RD2 TRADING BAY UNIT K -01RD2 2010090 5073320054 AR4258 100.00 Daily Operations 8/23/2008 00:00 8/24/2008 00:00 Operations Summary Cont. POOH w/ TCP guns, all shots fired. LD guns. PUMU 7" VTA packer and IB4 ball assembly RIH to 9750' (setting depth at top of packer). Drop ball and set packer. 8/24/2008 00:00 8/25/2008 00:00 Operations Summary Pressure up drillpipe. Test csg to 1100psi, 15 mins good. Pressure DP to 3100 psi shear out of pkr. Pressure test ball valve to 1000psi. Good. Valve in closed position. POOH LD drill pipe. 8/25/2008 00:00 8/26/2008 00:00 Operations Summary ND BOP. NU dry hole tree. 8/26/2008 00:00 8/27/2008 00:00 Operations Summary Demobe. 8/28/2008 00:00 8/29/2008 00:00 Operations Summary Demobe. 10/6/2009 00:00 10/712009 00:00 Operations Summary Mobe equipment rig up. 10/7/2009 00:00 10/8/2009 00:00 Operations Summary Winds 25 -30 Knots boat could not get into the dock to load for King Salmon 10/8/2009 00:00 10/9/2009 00:00 Operations Summary Weather hold 10/9/2009 00:00 10/10/2009 00:00 Operations Summary Weather hold 10/10/2009 00:00 10/11/2009 00:00 Operations Summary Weather hold 10/11/2009 00:00 10/12/2009 00:00 Operations Summary Unloaded boat/nipplle up /R/U 10/12/2009 00:00 10/13/2009 00:00 Operations Summary Rigging up Schlumberger Coiled tubing 10/13/2009 00:00 10/14/2009 00:00 Operations Summary Contacted the north slope pager of the AOGCC and Lou Gramaldi instucted to call Jim Regg left message 1400 hrs 10/13/09 for upcoming BOP test.Continue to rig up Schlumberger coiled tubing. 10/14/2009 00:00 10/15/2009 00:00 Operations Summary Continue rigging up 10/15/2009 00:00 10/16/2009 00:00 Operations Summary Continue rigging up prepare to test BOPE 10/16/2009 00:00 10/17/2009 00:00 Operations Summary Test BOPE to 250psi low /4000 psi high, MU BHA prepare to RIH 10/17/2009 00:00 10/18/2009 00:00 Operations Summary RIH with reservoir isolation valve shifting tool and attempt to shift valve open. Unable to open valve, POOH for drill collars. 10/18/2009 00:00 10119/2009 00:00 Operations Summary MU (5) 4 -3/4" drill collars and Reservoir Isolation Valve (RIV) shifting tool. RIH and attempt to open RIV with out success. POOH for clean out nozzle 10/19/2009 00:00.10/2012009 00:00 Operations Summary POOH. Drill collars left in hole. Waiting on fishing tools. RIH. Attempt to latch fish unsuccessful. POOH. 10/20/2009 00:00 10121/2009 00:00 Operations Summary RIH with 5 7/8" overshot. Could not work through liner top. POOH. RIH with 4 3/4" overshot. 10/21/2009 00:00 10/22/2009 00:00 Operations Summary Recover drill collar fish. POOH. MU shifting tool, drill collars, swivel. RIH and attempt to open valve without success. 'Chevron 4 10 Chevron Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) K -01 RD2 TRADING BAY UNIT K -01 RD2 2010090 5073320054 AR4258 100.00 Daily Operations 10122/2009 00:00 10123/2009 00:00 Operations Summary Attempt to open reservoir isolation valve without success. Circulate bottoms up and wait on boat. Jim Regg waived the BOPE Test due to operational suspension. 10/23/2009 00:00 10/24/2009 00:00 Operations Summary No activity, wait on boat. 10/24/2009 00:00 10/25/2009 00:00 Operations Summary Circulate inhibited sea water from 9,680' to surface. POOH. ND BOPE, rig down CTU prepare to de -mob from platform. 10/25/2009 00:00 10126/2009 00:00 Operations Summary Continue ND BOP. NU tree, test tree and casing to 250psi low /2500psi high. Rig down equipment and prep to demobe from platform. 10/26/2009 00:00 10/27/2009 00:00 Operations Summary Demobe equipment from platform. 10/27/2009 00:00 10/28/2009 00:00 Operations Summary Demobe equipment from platform. 10/28/2009 00:00 10/29/2009 00:00 Operations Summary Demobe equipment from platform. evro King Salmon Platform King K-01RD2 Trading Bay Unit Well K -1 RD2 Current Well Schematic Current as of 11/28/0 I RKB to TBG Head 33.7' Tree connection: Ai Size Type WT Grade CONN ID Top BTM Hole Cement CMT Size Sacks Top 20" Conductor 94 H40 Weld 19 Surf 110' Driven 384' 13 -3/8 Sur Pipe 61 K55 BTC 12.515 35 2384 18" 2640 "G" Surf 9 -5/8 Sur CSG 47 N80 BTC 8.681 35 112 12.25 1321 "G" Surf 9 -5/8 Sur CSG 43.5 N80 BTC 8.755 112 6043 12.5 7 Liner 29 L80 BTC -KC 6.184 5859 13,779 8.5 183 bbl 585 2 -3/8" CT 4.6 HS90 1.89 35 9,590 IN CASED HOLE Wire 1 /OSOLBC 5KV 90FB 185 Gal w/ (2) .375 SS Surf -9700 Flat pack 2 Chemical Inj lines Depth ID Jewelry Description 5,859' 1 9,750 Reservoir Isolation Tool (closed) 4 7 High DL Severity Window 6019' -6053' PERFORATION DATA Zone Top Btrn Amount Corxfition I Tbg 10662 10656 6 23 shots .41 dia CP phase CO-4 11680 11720 40 57/01, partial reperf 1/27/05 W-5 11732 11742 10 Cpened 5/7/01 030-6 11,780 11,810 30 Cpened 5/7/01 Reservor 11,820 11,840 20 Cpened 5x7/01 Isolation 11,864' 11,891' 27 Cpened 5/7/01 Pkr Ball Valve G-1 12,030 12,080 50 511/01, partial reperf 1/27/05 i i 12,090 12,120' 30 Opened 5/7/01 12,142 12,162 20 Cpened 5/7/01 DL Severity G04 G-5 12,65g 12,674' 15 Cpened 5/7/01 10,455' 10,477' 12,680 12,694' 14 Opened 57/01 10,826' 11,110' G05 12,710 12,790 80 5/1/01, partial reperf 1/27/05 11,385 11,829' G0.6 12,800' 12,830 30 57/2001 G -1 G 7/I 12,950 13,010' 60 7/3/01, partial reperf 1/27/05 1163 13,190' 13,210 20 G-6 I 13,230 13,340 110 Opened 61/1501 &7/3/01 G-7/ Hal 1165 13,405' 13,425' 20 Opened 1/13/02 1165 13,445' 13,460 15 Opened 1/13/02 HB-3 H66 13,565' 13,580 15 Cpened 1/13/02, Isolated 2/02 HB-4 1167 13,610 13,650 40 Cpened 1/13/02, Isolated 2/02 HB5 CIBP Set 13540' H86 OCTG Rotating Hours Isolated Perforations Ha7 Gl 24" Structural Casing 110 Hours PBTO= 13750' TD= 13780' 20" Conductor 110 Hours MAX HOLE ANGLE =59° @8485' 13 -3/8" Surface Pipe 227 Hours 9 -5/8" Casing 651 Hours NOTE: Tagged CI BP 7" Liner 50 Hours 13,545' 6/24/08 1 K -O 1 RD2 Schematic 11 -24 -09 Revised by CVK 11-24-09 ZO/ - OOg Page 1 of 1 Aubert, Winton G (DOA) _ __ _ __ __ _ _ _ . _ __ _ __ _ _ _ _ ___ _ From: Aubert, V~inton G (DOA) Sent: Thursday, Odober Q8, 2009 5:11 AM To: 'Barbee, Marcus [Consultant]' Cc: DOA AOGCC Prudhoe Bay Subject: RE: King Salmon K-01RD2 CT ESP Completion i1~~E . ~arcee. AC?GCG ;~e~~e~y ~p~r~+,re~ continuinc~ o~erati~~s on;~vel~ r S3~ K-01~~2 ~~T~ 2C1-GU9}, previ~usly ~ppr~~t~d ~+.n~e; 5und3} ~3a. 3~J8-2'~9 and ~esc~i~e~ be!e~~~. ~on~;i~;o~s o~ appro~.ral are (1; zest BvPE to 3~0~ ;~si, ~2} ~r,~vi~~ ~°o~rf~issi~n G~~i;th ~4 ~?~ur ^oti~e ~ricr to B~P~ test, and ;3~1 reoc~rt o~er~iors on a subse~~.;~r~i `:_~~; m ' ~-4{~4. Per 20 ~C 25.~8~ ~h), a)ternate S~PE is approved. },~fntun Aaber~ A~GCC 793-"~%3 i ~'~+r"r~~~~~ ~i?~ +.~ ~ ~ ~o~~ From: Barbee, Marcus [Consultarrt] [mailto:Marcus.Barbee@chevron.com] Sent: Wednesday, October 07, 2009 3:13 PM To: Aubert, ~nton G (DOA) Cc: ICanyer, Chrisb~pher V; Farrell, Robert [APRS) Subject: King Saimon K-O1RD2 CT ESP Completion Mr. Aubert, As per our phone conversation, Chevron is prepared to complete K-01RD2 with a Coil Tubing ESP completion which will finish the approved 10-403 sundry # 30&219. We will provide the State with a minimum of 24 Hours notice prior to our BOPE test for witness of said test. A 10-404 sundry wiff be filed with the State once operations have been completed to finalize 10-403 sundries # 308-111 & 308-219. In addition, according to 20 AAC 25.285 (h) Chevron requests a variance to utilize 2" 1502 hard line from the BOPE to the choke manifold in lieu of flanged or hubbed connections, based on the fact that the well will not flow to sur-face, there is a reservoir isolation valve in place and there is kill weight fluid to surface. Please let me know if you require any additional information, as I have taken the project over for Chantal Walsh. Thank you, ~~'~~~~~~ ;~:~~~~;~ Wellbore Maintenance Team Chevron, Alaska 1-907-263-7605 Offrce 1-907-250-1163 Cetl 1-907-745-2386 Home This trazismission may contain infocmation tl~at is privileged, confidential and / or eicempt finm disclosure under applicable law. If you are not the intended recipient, you are hereby notified that any disclosure, copying, distribution, or use of the infomiation contained herein (including any reliance therein) is STRICTLY PROHIBITED. If you received this transmission in etror, please immediately contact Ihe sender and destroy the material in its entirety, whether in elechonic or hazd copy foimat Thank You. 1 ~~g~20~9 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 13, 2008 10:11 AM To: 'Walsh, Chantal [Petrotechnical]' Cc: Hammons, Darrell; Tyler, Steve L Subject: RE: King Salmon K-01RD2 20( 1-00~ 308-111 and 308-219 Chantal, Thanks for the notice. This complies with the requirement of sundry 308-219. As usual, please provide notice of the BOP test. t will place a copy of this message in the file. Tom Maunder, PE AOGCC From: Walsh, Chantal [Petrotechnical] [mailto:WalshC@chevron.com] Sent: Wednesday, August 13, 2008 9:44 AM To; Maunder, Thomas E (DOA) Cc: Hammons, Darrell; Tyler, Steve L Subject: King Salmon K-O1RD2 308-111 Tom, Chevron intends to resume operations on K-01 RD2 (Sundry #308-111) later this week. We will pull the 2000'+ killlstring, reperf the well with TCP guns, run the reservoir isolation tool and prep the well for the final phase of completion with a Coil Tubing ESP. Please contact me if you have any questions or need further information. Chantal Chantal Walsh PRA Contract Engineer, P.E. walshc~a chev__ron.co_ Chevron North America Exploration and Production Midcontinent/Alaska SBU i~c AEG .~ ~~~$ 909 W. 9th Avenue Anchorage, AK 99501-3322 Te1 907 263 7627 Fax 1 907 263 7884 Mobile 907 227 0952 Mail Confidential Footer Privileged/ConFdential information maybe contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263-7892. 8/13/2008 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Walsh, Chantal [Petrotechnical] [WalshC@chevron.com] Sent: Thursday, June 26, 2008 8:47 AM To: Maunder, Thomas E (DOA) Cc: Tyler, Steve L Subject: K-01 RD b~. bbq ~-~a~ Tom, The Operational Shutdown 10-403 request for the King Salmon Platform well K-~D (currently being worked on under sundry #308-111) is being requested due to operations moving quicker than anticipated and the delivery delay of the mechanical reservoir isolation tool, integral to the coil tubing deployed ESP completion. We anticipate returning to the well after the completion of the K-12RD redrill around 08/14/08. Please contact me if you have further questions. Chantal Walsh PRA Contract Engineer, P.E. walsl~c~ch_e_vron.c_ _o_m Chevron North America Exploration and Production ~~eNE®~U~ ~ ~ 2~0~ Midcontinent/Alaska SBU 909 W. 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7627 Fax 1 907 263 7884 Mobile 907 227 0952 Mail Confidential Footer Privileged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263-7892. 6/26/2008 • ~ ~ ~;~. a ~ y ~ , ~~ ~ a,-3 ~ '~ (-,>` _ ~^° s.. _ _ s 1 ~ ~ ~ i '^ ~ f ~ SARAH PAL/N GOVERNOR ~~~ ~~ ~ ~ /~ 333 W. 7th AVENUE, SUITE 100 COI~TSL'`RQATIOI~T COl-IlrII5SIOl1T ~/ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage AK 99519 ~d ~ ~ ~~ Re: McArthur River Field, Hemlock/G Oil Pool, King Salmon Platform K-O1RD2 Sundry Number: 308-219 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for Rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED thi~~ day of June, 2008 Encl. x >. ~' ~ °.~ " '~JD' STATE OF ALASKA 6~g ~c`~``J J`~ -~~~-t t~-~ ` 'v~"-1~ d ~ ~~" ALA OIL AND GAS CONSERVATION COMMON -~ . ~~ ~ ~ ~ 200 APPLICATION FOR SUNDRY APPROVALS ~~ ~ `r~ ~ 1 T e Request COnS. ~LAbandorr^ Suspend ^ Operational shutdown ^ ~ Perforate ^ Waiver ^ ~' Other^ ~~~ ~ Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Run kill string /~ (~p~ypp~~ f ~'..:Lr~V1 iA~~.. a Ch nge app oved program^ Pull Tubing^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ ~ Exploratory ^ 201-009 ; 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, Alaska 99519 50-733-20054-01 ~ 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 ~ Kin Salmon Platform, K-01 RD2 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL001877f #01 RD2, Cook Inlet Basin, Offshore 33.7' RKB to tb h McArthur River Field /Hemlock & G Zone 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,780' ^ 9745' 13600' 9633' 13540' aren't sure Casing Length Size MD TVD Burst Collapse Structural 75' 20" 110' 110' Conductor 2349' 13-3/8", 61# 2384' 2302 3090 1540 Surface 77" 9-5/8", 47#, N80 112' 6870 4750 5931' 9-5/8", 43.5#, N80 6043' 4908' 6330 3810 Intermediate - Production - Liner 7920' 7", 29#, L80 5859' - 13,779' 9743' 8,160 7,020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Reference Attachment Reference Attachment 4-1 /2" 12.6# & 3-1/2" 9.2# L80, BTC 10,676' Packers and SSSV Type: Packer-less Completion Packers and SSSV MD (ft): Packer-less Completion No flow potential No SSSV 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for Currently on the well. 16. Well Status after proposed work: Commencing Operations: Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chantal Walsh - 263-7627 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Cy Phone 6-7600 Date 20-Jun COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .- Plug Inte gr ity ^ BOP Test ^ Mechanica ) Integrity Test ^ Location Clearance ^ l ~ ~ Other. 'N~~~ ~a~~.:i`~.~~~f:~'~`'•4 ~:\C_~~'CC;<oit...V"~Al, C3~` : c~ ~ 8\1 ~ll `~ Vv ~ v"~~> `l ~ '~ C~~rC Subsequent Form Required: ~ ~ ~L ~" ~t . ~~~~~ ~.~ .~. ~~ ~ ~ ti,,~~ G y. ) ~ , APPROVED BY A roved b : COMMISSIONER ISSION Dater ~ pp y , Form 10-403 R ised 06/2006 ~ ~ ~ ~ A 1 Submit in Duplicate ` r~,P Chevron ~ . K-O1RD2 OperationalShutdown ESP Change Out Revision #1: 06/20/2008 OBJECTIVE: OPERATIONAL SHUTDOWN REQUEST AS PER 20 AAC 25.072 • Change out of the K-01 RD ESP completion, re-run new ESP completion on coil and return to production operations as an ESP artificially lifted well. PROCEDURE SUMMARY: • Mobilize rig onto K-01 RD2 • Set BPV, ND tree, NU BOPE, Test same • Remove BPV. PUMU Landing Joint. BO LDS. PU tbg hanger. • POOH LD 4-1/2" & 3-1/2" tubing • PUMU 9-5/8" Scrapper/CO assy. RIH on 4" DP to TOL @5859'. CBU • POOH. LD Scrapper CO Assy. • PUMU 6" Mill with boot (or reverse basket) with ciresub. RIH and Cleanout 7" liner to top of CIBP at 13,500'. • POOH. LD Mill and boot basket Assy. LD drill pipe. • PU RIH kill string to +/- 5500' - PT hanger seals. • ND BOP NU TREE - PT Tree. • Operational shut down. Waiting on delivery of mechanical isolation tool. • Mobilize rig onto K-01 RD2 • Set BPV, ND tree, NU BOPE, Test same • Remove BPV. PUMU Landing Joint. BO LDS. PU tbg hanger. • MU guns. RIH Perforate 125'. POOH. (Contingency to perf prior to moving back onto the well with the rig). • PUMU mechanical isolation devise. RIH and set in 7" liner below ESP setting depth. • Fill wellbore with 6% KCL FIW. Pressure test to 1500 psi. • PUMU killstring. RIH to 2000'. Stab hanger, set BPV, ND BOP, put on CT spool. PUMU tbg hng. Land tbg • ND BOPE, NU Kill Tree, Test same. • Demobe rig • Utilize crane to set BPV, ND tree, NU 7" CT BOPE, Test same. • Remove BPV. PUMU Landing Joint. BO LDS. PU tbg hanger. • POOH with kill string. • RU Coil Tubing Unit • PUMU Coil tubing ESP completion (2-3/8" coil) • RIH with completion • Manipulate isolation device • Space out and land tubing • Demobe coil unit. Turn well over to production. K-O1RD2 Operational Shutdown Recomplete Objective and Procedure Summary.doc RVSD BY: CRW 06/20/08 RKB to TBG Head = 33.7' 384' High DL Sev ty Window 3019'-6053' DL Severity 10,455' -10,477' ' ' GO-0 10,826 -11,110 11,385' - 11,829' ' GO-5 , GO.6 G-1 ~. ' :•;11.1 3.7 / H&1 HBJ HB-0 HBS ~, -1 Isdated Perforations ~ ,~ H&7 PBTD_=13750' TD = 13780' MAX HOLE ANGLE = 59° @8485' _ King K-O1RD2 Operational Shut Down Well Schematic Salmon Plai ing Bay Unit K-1 RD2 Size Type WT Grade CONN ID Top BTM Hole Cement CMT Size Sacks To 20" Conductor 94 H40 Weld 19 Surf 110' Driven 13-3/8 Sur Pipe 61 K55 BTC 12.515 35 2384 18" 2640 Surf 9-5/8 Sur CSG 47 N80 BTC 8.681 35 112 12.25 1321 9-5/8 Sur CSG 43.5 N80 BTC 8.755 112 6043 12.5 „G„ Surf 7 Liner 29 L80 BTC-KC 6.184 5859 13,779 8.5 183 bbl 5850' -_ OCTG Rotating Hours 24" Structural Casing 110 Hours 20" Conductor 110 Hours 13-3/8" Surface Pipe 227 Hours 9-5/8" Casing 651 Hours 7" Liner 50 Hours _--- Fish In Hole from ESP Removal 4 of the flat guards that were 6' long missing along with 16 each SS Bands from them. One of the two ': 20' 3/8" chemical injection lines with chemical check valve was missing as it pulled lose at the connection at top of the first pump section. ~ T Bm pfrait GS'<itim l6g 103,12 'IOfi~ 6 23~.41da0'fft» OJ4 1'I~ 1'1741 ~ 5'701, f~ rglaf 1/D~C6 OJ5 1T/32 11742 10 Cpat3d57p1 G'~ 11,7H1 11,810 ~ C~asd5101 11,831 11,890 ~ QBied5'7p1 11,834 11,831 27 Cpaed57ro1 G1 '12[80 120 ~ 5'701, patid r~af 1YDiC6 12030 121e"0 3) C}sa157A11 12'142 12162 ~ Cpaed5'7~01 GS 12~ 12614 15 Cpasi57R1 12eeo 12eat 14 Cpat3d5'7/01 j 12710 12790 8) 57p1, fetid rQsf Y71~C6 ~ 12870 12830 3) 5'7Id1D1 i G71f81 12960 1x010 8) 7/381, fatidr~afv711C6 ~ H33 1$190 1x210 ~ ~ H34 1~ 1x340 110 ~aed6'/1571&7/301 H~ 1~ 1x48 ~ Cpasdvl3CP H33 k3,449 1x437 15 ~ v1302 H~ 1x58 1ayfl7 15 ~aBiv1'13CtZ Isd1ed202 H3' 1x610 1a6~0 40 Qasd'V113C)? Isided2CP L' Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 29, 2008 11:43 AM To: 'Buster, Larry W Cc: Alexander, Steve [TWT]; Walsh, Chantal [Petrotechnical]; Hammons, Darrell Subject: RE: - - r~ ~~ `~ V~~ i1, ~lia~l, Tfihi ~ ~... `~ T ialk~uimd~r; I~ From: Buster, Larry W [mailto:LBuster@chevron.com] Sent: Thursday, May 29, 2008 11:38 AM To: Maunder, Thomas E (DOA) Cc: Alexander, Steve [TWT]; Walsh, Chantal [Petrotechnical]; Hammons, Darrell Subject: RE: K-12RD (178-057) Ti`s;. T~ ~ iii Swim ~, m~r;!r>~i=ng~ 2 Tt~'° ~-11!2t' ~3t?II' irr t1}I~ its a idii~rrds'e~s ii:r its l~.ctrr~? c~rcdiznu##d~ c~ it Larry W. Buster Drilling Engineering Manager ~~~~~ ~~~ ~ ~: Z~d~ MidContinent/Alaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel: (907) 263-7853 Cell: (907) 250-0374 Fax: (907) 263-7884 (buster@chevron.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 28, 2008 5:04 PM To: Buster, Larry W Cc: Alexander, Steve ['T'VVT]; Walsh, Chantal [Petrotechnical]; Hammons, Darrell Subject: RE: K-12RD (178-057) ~', ~~1, TlTftt~t:it~ ~ firnr ~~+.. Tfltn~te i~ ~ m~f tlm~ :iizrmritt ttt~ Ali:. V~he~n i~ iii ~,nm~4., t>ftne lii ccfl~ ~oxilll ~>~iiit~nti. itm ttm~ ~ ~ iiirtTmrmnaiti~im lii i~ iiicmnm NK-11~L. H{-'t1~,. ~ ~h~iir ~, iit i~ iimq~tfi~ tYID Ike ttt~ ivmui~tik~ ~i~tti~ ~~ 1$iD ~»X~Ilitr min a ~ i ~iiTrtm. ~A*~i il~tlffi~rrn~~~it rrii~,~=ir;ix~rcir~iDi irtx¢tt~9u~li~ ~ . i~ i~ €pr`~i i1~tt>m~ s tu~frrt¢~tt iif C • • Page 2 of 3 <urntt of s ~i~ m~ ~uui~ its ltnei ~.. I ism;„ a~ yya~ e~ll~djirt~ '~' till ~ , vcoUiit~n ~ i II v~,iial ~~ if~n ti~~ ~ ~ yy~urr ~ arm inftne I i ~i~. 11-c~rr ~ierr.. lid ~tC From: Buster, Larry W [maiito:LBuster@chevron.com] Sent: Wednesday, May 28, 2008 4:51 PM To: Maunder, Thomas E (DOA) Cc: Alexander, Steve [TWf]; Walsh, Chantal [Petrotechnical]; Hammons, Darrell Subject: RE: K-12RD (178-057) _~ ~ ~_ ~ ~ ilfe ai~~~ v~ ~ t !lam 1 ~ tlfr~ G~~ ~ ~;r~i ~~~ ¢rrr ~ 5~~ II~~fi~=trr_ ~I a~t~ i~ 1~ tre=su!I~r~ri i1}' ~?'o~~ I~r f 1tlt fit's ism, s~. r-;`~`.~t~ ~ 1~~1; tf~ ~~+~ Ili 1;~~11 ~,, a i-~,~ ttr ~ {dii~ ~ ~nrr~~-j~ ~°r ~9= Dili Il~irrg S~'r~a~t:r i i itl't~ C~~ ~ ~rti. ~~ ~ ILa ~ ID~i ~~ ~,~ ~~~~~i;~ ~~~ M` ~~~~ ~usine~ U~i~ err li~~ ~rnx~rii~ IElioitiiotm ~ li~~itiiort i ~~er~~ Tt'e t~~~~ ~~~-~~~ is °< :: 1~7~)3 ~~~-T From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 28, 2008 3:37 PM To: Walsh, Chantal [Petrotechnical] Subject: K-12RD (178-057) Chantal, Would you please forward to Steve Alexander. I don't have his email. Steve, I left you a message. The Commission has received the sundry application to plug this well. Will this work be done using the Cudd HWO unit presently on the platform? If so, then the plan should state this. tt is also noted in your letter that you will submit the proposed redrill for sundry approval. The redrill will require a new permit to drill. • Page 3 of 3 Also, a question for both of you. Which BOP stack arrangement is being used on King? This latest sundry has a 2 ram stack with annular which does meet the 3K requirements. I checked back on the 3 sundries recently approved for other wells and 2 have 3 ram stacks (K-22RD and K-01 RD2) and 1 the 2 ram stack (K-19). I probably should have caught the difference when they came through, but as I remember they got split up due to questions. Thanks in advance. Tom Maunder, PE AOGCC • . f 1 tt ~~ COI~TSER~A A~'IO1~T C ~ Ip~ Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: McArthur River Wield, Hemlock/G Oil Pool, King Salmon Platform K-O1 RD2 Sundry Number: 308-111 APR ~ ~ 208 ~~~~ 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day ff the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair DATED this ~;dr day of April, 2008 Encl. QQ _ "D d ~ STATE OF ALASKA ~ A R R 0 1 ~(~,~ ~ ALA OIL AND GAS CONSERVATION COM~ION ~~-~ iY° APPLICATION FOR SUNDRY APPROVALSiaska Oii ~ Gas Cons. 'scion 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other^ Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ RE-Run ESP Change approved program^ Pull Tubing Q Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Chevron/ Union Oil Company of California Development ^ Exploratory ^ 201-009 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, Alaska 99519 50-733-20054-01 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^ ~ Kln Salmon Platform, K-01 RD2 ` 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL0018777 #01 RD2, Cook Inlet Basin, Offshore 33.7' RKB to tb h McArthur River Field /Hemlock & G Zone 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,780' ~ 9745' 13600' 9633' 13540' aren't sure Casing Length Size MD TVD Burst Collapse Structural 75' 20" 110' 110' Conductor 2349' 13-3/8", 61# 2384' 2302 3090 1540 Surface 77" 9-5/8", 47#, N80 112' 6870 4750 5931' 9-5/8", 43.5#, N80 6043' 4908' 6330 3810 Intermediate - Production - Liner 7920' 7", 29#, L80 5859' - 13,779' 9743' 8,160 7,020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Reference Attachment Reference Attachment 4-1/2" 12.6# & 3-1/2" 9.2# L80, BTC 10,676' Packers and SSSV Type: Packer-less Completion Packers and SSSV MD (ft): Packer-less Completion No flow potential No SSSV 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch Q Exploratory ^ Development ~ Service ^ 15. Estimated Date for May-08 16. Well Status after proposed work: ° Commencing Operations: Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chantal Walsh - 263-7627 Printed Name Timothy C. Brandenburg Title Drilling Manager Ph Signature ~ ,_.._-- 263-7657 Date 19-Mar ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ - ( l Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~ ~?S ~ ~~ ~ ~ S T ~+ e~ ~~I. ~FF'~ % ~ 2~Oii Subsequent Form Required: ~O~ APPROVED BY Approved by: C MMISSIONER THE COMMISSION Date: Form 10-403 wised 06/2006 U ~' ~' ~ V ~ ~,,,,, S~pmit in Du licate RKB to TBG Head = 33.7' High DL - - __. NOTE: Last tag in 2002 when CIP set Size Type WT Grade CONN ID Top BTM Hole Cement CMT Size Sacks To 20" Conductor 94 H40 Weld 19 Surf 110' Driven 13-3/8 Sur Pipe 61 K55 BTC 12.515 35 2384 18" 2640 Surf 9-5/8 Sur CSG 47 N80 BTC 8.681 35 112 12.25 1321 9-5/8 Sur CSG 43.5 N80 BTC 8.755 112 6043 12.5 „G„ Surf 7 Liner 29 L80 BTC-KC 6.184 5859 13,779 8.5 183 bbl 5850' 4.5 3.5 P-Tubing P-Tubing 12.6 9.2 L80 L80 BTC BTC 3.958 2.992 34 5698 5557 10,676 IN CASED HOLE IN CASED HOLE Wire 1/OSOLBC 5KV 90FB 185 Gal w/ (2) .375 SS Surf 10668 1.611" x 2.361" Tubes -Gal - R 33.7 3.958 Tbg Hanger, 12" x 4-1/2" FMC 1 2,603 3.833 GLM #1 [4-1/2" SFO-2 (7.063" OD)] 2 4,236 3.833 GLM #2 [4-1/2" SFO-2 (7.063" OD)] 3 5,444 3.833 GLM #3 [4-1/2" SFO-2 (7.063" OD)] 4 5,558 2.992 Crossover, 4-1/2" x 3-1/2" 5 6,102 2.867 GLM #4 [3-1/2" GLMAX-1.0 (5.968" OD)] 6 6,957 2.867 GLM #5 [3-1l2" GLMAX-1.0 (5.968" OD)] 7 7,816 2.867 GLM #6 [3-1/2" GLMAX-1.0 (5.968" OD)] 8 8,675 2.867 GLM #7 [3-1/2" GLMAX-1.0 (5.968" OD)] 9 9,539 2.867 GLM #8 [3-1/2" GLMAX-1.0 (5.968" OD)] 10 Centrilift ESP Assy (Gas separator, 19 stage GC8200 / 151 stage GC1700 10,677 pump, GS63D6 seals, 171 hp KMH motor) MS-1 Phoenix gauge 11 10,740 OCTG Rotating Hours i 24" Structural Casing 110 Hours 20" Conductor 110 Hours '; 13-3/8" Surtace Pipe 227 Hours 9-5/8" Casing 651 Hours 7" Liner 50 Hours Fish In Hole from ESP Removal 4 of the flat guards that were 6' long missing along with 16 each SS Bands from them. One of the two 20' 3/8" chemical injection lines with chemical check valve was missing as it pulled lose at the connection at top of the first pump section. Zone Top Btm Arraurt Condition Tbg 10662 10656 6 23 shots .41 dia 0° phase GOd 11680 11720 40 5!7/01, partial reperf 1/27/05 GO.5 11732 11742 10 Opened 5x//01 GQ6 11,780' 11,8117 3o Opened 5/7/01 11,820' 11,840' 20 Opened Y//01 11,864' 11,891' 27 Opened 5x//01 G-1 12,030' 12,080' S0 5/7/01, partial reperf 1/27/05 12,090' 12,120' 30 Opened 57/01 12,147 12,167 20 Opened 57/01 GS 12,659' 12,674' 15 Opened 57/01 12,680' 12,694' 14 Opened 57/01 12,710' 12,790' 80 57/01, partial reperf 1/27/05 12,800' 12,830' 30 5/7/2001 G7/HB-1 12,950' 13,010' 60 7/3/01, partial reperf 1/27/05 HB3 13,190' 13,210' 20 HBO 13,230' 13,340' 110 Gpened6//1501 &7/301 HB5 13,405' 13,425' 20 Opened 1/13/02 HBS 13,445' 13,460' 15 Opened 1/13/02 F®6 13,565' 13,580' 15 Opened 1/13/02, Isdated 2/02 HB7 13,610' 13,6517 40 Opened 1/13x02, Isdated 2102 MAX HOLE ANGLE = 59° @8485' Chevron ~ • Trading Bay Unit K-O1RD2 ESP Change Out Revision #0: 03/21!2008 OBJECTIVE: • Change out of the K-01 RD ESP completion, re-run new ESP completion on coil and return to production operations as an ESP artificially lifted well. PROCEDURE SUMMARY: • Mobilize rig onto K-01 RD2 • Set BPV, ND tree, NU BOPE, Test same • Remove BPV. PUMU Landing Joint. BO LDS. PU tbg hanger. • POOH LD 4-1/2" & 3-1/2" tubing • PUMU 9-5/8" Scrapper/CO assy. RIH on 4" DP to TOL @5859'. CBU • POOH. LD Scrapper CO Assy. • PUMU 6" Mill with boot (or reverse basket) with ciresub. RIH and Cleanout 7" liner to top of CIBP at 13,500'. • POOH. LD Mil1 and boot basket Assy. LD drill pipe. • RU eline. Perforate 125'. RD eline • PUMU mechanical isolation devise. RIH and set in 7" liner @ 10,500' Fill wellbore with 6% KCL FIW. Pressure test to 1500 psi. PUMU killstring. RIH to 2000'. Stab hanger, set BPV, ND BOP, put on CT spool. PUMU tbg hng. Land tbg. ND BOPE, NU Kill Tree, Test same. Demobe rig Utilize crane to set BPV, ND tree, NU 7" CT BOPE, Test same. Remove BPV. PUMU Landing Joint. BO LDS. PU tbg hanger. -~? ~'~~i~`r`t ~~ `P~S~~` POOH with kill string. RU Coil Tubing Unit PUMU Coil tubing ESP completion (2-3/8" coil) RIH with completion • Manipulate isolation device • Space out and land tubing • Demobe coil unit. Turn well over to production. 0~~~~~E~.-~`1~~g ~ K-19 Recomplete Objective and Procedure Summary.doc RVSD BY: CRW 03/21/08 RKB to TBG Head = 33.7' High DL King K-O1RD2 Proposed Well Schematic Reservdr Isdation Pkr 8 i~l Valve 3-7I H&1 H63 NOTE: Last tag in 2002 when CIP set ding Bay Unit II K-1 RD2 Completed Jan Size Type WT Grade CONN ID Top BTM Hole Cement CMT Size Sacks To 20" Conductor 94 H40 Weld 19 Surf 110' Driven 13-3/8 Sur Pipe 61 K55 BTC 12.515 35 2384 18" 2640 Surf 9-5/8 Sur CSG 47 N80 BTC 8.681 35 112 12.25 1321 9-5/8 Sur CSG 43.5 N80 BTC 8.755 112 6043 12.5 „G„ Surf 7 Liner 29 L80 BTC-KC 6.184 5859 13,779 8.5 183 bbl 5850' 2-3/8" CT 4.6 HS90 1.89 35 10590 IN CASED HOLE Wire 1/OSOLBC 5KV 90F6 185 Gal w/ (2) .375 SS Surf 10680 Flat pack 2 Chemical Inj lines 33.7 3.958 Tbg Hanger, 12" x 4-1/2" FMC 1 10,590 2-3/8" Sliding Sleeve 2 10,600 Schlumberger Coil Tubing conveyed ESP Assy MS-1 Phoenix gauge 3 10.740 OCTG Rotating Hours 24" Structural Casing 110 Hours 20" Conductor 110 Hours 13-3/8" Surface Pipe 227 Hours 9-5/8" Casing 651 Hours 7" Liner 50 Hours __ __ Fish In Hole from ESP Removal 4 of the flat guards that were 6' long missing along with 16 each SS Bands from them. One of the two 20' 3/8" chemical injection lines with chemical check valve was missing as it pulled lose at the connection at top of the first pump section. Zane Top Btm Amount Condition Tbg 10662 10656 6 23 shots .41 da 0° phase GOd 11680 11720 40 5x7/01, partial reperf 1/27/05 G0~5 11732 11742 10 Opened 517/01 Gos 11,760' 11,a1a 30 opened 5x7ro1 11,820' 11,840' 20 Opened 517/01 11,864' 11,891' 27 Opened 5/7/01 G-1 12,030' 12,080' S0 5x7/01, partial reperf 1/27/05 12,090' 12,120' 30 Opened5J7/01 12,147 12,167 20 Opened 5x//01 G•5 12,659' 12,674' 15 Opened 5x-//01 12,680' 12,694' 14 Opened SJ7/01 12,710' 12,790' 80 5r//01, partial reperf 1/27/05 12,800' 12,830' 30 5/7/2001 G-7M&1 12,950' 13,010' 60 7/3/01, partial reperf 1/27/05 HB3 13,190' 13,210' 20 FIB-4 13,230' 13,340' 110 Opened 6x/150187/3x01 H65 13,405' 13,425 20 Opened 1/13J02 HBS 13,445' 13,460' 15 Opened 1/13x02 H66 13,565' 13,580' 15 Opened 1/13/02, Isdated 2102 HB7 13,610' 13,650' 40 Opened 1/13/02, Isdated 2/02 MAX HOLE ANGLE = 59° @8485' • • K-1 rd BOP Stack Leg # 4 King Salmon Platform: RU Drawing • Maunder, Thomas E (DOA) From: Walsh, Chantal [Petrotechnical] [WalshC@chevron.com] Sent: Friday, April 25, 2008 11:51 AM To: Maunder, Thomas E (DOA} Cc: Tyler, Steve L; Hammons, Darrell Subject: RE: King Salmon Platform: RU Drawing ~~ l Attachments: MechlsolationTool2.pdf; MechlsolationTooi.pdf q O'ff' a Tom, Page 1 of 2 The work on the K-0 i RD2 well is in two parts. Initially the well will be pulled apart with the hydraulic pulling unit (Cudd Rig), and the final completion of the well will be done with a coil tubing unit. Following are answers to your requests: 1. The IB4 isolation valve provides a means to isolate well bore fluids from the reservoir. The valve is run in (Ball Open) below the packer as an integral part of the assembly. The wash pipe, located on the bottom of the packer running tool, is extended through the valve. A Collet Shifting Tool is attached to the end of the wash pipe. After dropping a ball and setting the Packer, the running tool is picked up until the Collet Shifting Tool engages the Shifting profile. Continued upward pull closes the ball, isolating the formation and allowing positive pressure testing. The ball holds pressure in both the above and below direction (SOOOpsi). The reservoir is isolated by the closed ball in the IB4 which permits the safe installation of the upper production completion. The upper ESP completion is run in and the ball is shifted open by the Collet Shifting Tool, which is made up an a stinger below the ESP assembly. The Collet Shifting Tool is spaced out below the Shifting profile to allow calculated tubing movement. in the event of ESP failure, the upper completion is picked up and the valve is closed by the Collet Shifting Tooi to provide isolation from the reservoir. (Isolation tool attached drawings) 2. Yes, the 7" CT BOP will be rippled up on the 13-5/8" stack. The stack will be dressed with the 2- 3/8" rams for the coil 3. The kill string will be pulled with the platform crane prior to the coil tubing operation. 4. The tubing hanger passes through the 7" BOP. Thank you for meeting with us this week to review the operations for the K-0l RD2 workover. Let me know if you need further information. Chantal Walsh Chevron Project Manager {907) 263-7627 From'. er, Thomas E {DOA) [mailtoaom.maunder@aiaska.gov] Sent: Thursday, 2008 9:3f AM To: Walsh, Chantal [Petrotec Cc: Hammons, Darrell; Tyler, Steve L Subject: RE: King Salmon Platform: R mg Chantal, °~~.~ am re_vi~ar' a proposed work for K-01 RD2. It appears that this work is in 2 parts, Lea couple of requests. 4/28/2008 ~ ~ ~ ~ RECEIVED APR 2 5 2008 Alaska Oil & Gas Cons. Commission Anchorage HALL~9uiiTON ~ ~ ;~~~~~ ~.,~r~ a,., ~~~p -~ ~ O I I I I ~„{~ ~ ~ _ SrAGEi S.gGEf a CgM[TMNS~kun,vKY[a Srw~ii[BGrtiRtvFn e5~tlv.~[i9~nMifNa£9 M.m59.rRl3RIMFpIM IOLiASg1WpPEl Ixl.wLH. ~ srerta srAGE. 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Subject: RE: King Salmon Platform: RU Drawing ~( ~/ Chantal, I am reviewing the proposed work for K-01 RD2. It appears that this work is in 2 parts, HWO and CT. I have a couple of requests. 1. Could you provide some details on the "mechanical isolation device"? 2. Will the 7" CT BOP be NU on the 13-5/8" stack? 3. How will the kill string be pulled? 4. Will the tubing hanger pass through the 7" BOP or is a window employed? Additional drawingslsketches would be appreciated. Call or message with any questions. Tom Maunder, PE AOGCC Page 1 of 1 From: Walsh, Chantal [Petrotechnical] [mailto:WalshC@chevron.com] Sent: Wednesday, April 16, 2008 6:01 PM To: Maunder, Thomas E (DOA) Cc: Hammons, Darrell; Tyler, Steve L Subject: King Salmon Platform: RU Drawing ~~~~~~~~ APR ~ 9 20Q$ Tom, Please find attached the rig up diagrams for the Cudd Unit we will be utilizing on the upcoming King campaign. Please contact me if you have further questions or require more information. We are looking at an early May start date for the work. Chantal Walsh Chevron Project Manager (907) 263-7627 4/17/2008 King Salmon Platform: RU D~wing • Page 1 of 1 Maunder, Thomas E (DOA) From: Walsh, Chantal [Petrotechnical] [WalshC@chevron.com] Sent: Wednesday, April 16, 2008 6:01 PM To: Maunder, Thomas E (DOA) Cc: Hammons, Darrell; Tyler, Steve L ~ ~r Subject: King Salmon Platform: RU Drawing Attachments: circdrawing two mud pumps ks-19.jpg; ks k-19 deck skid layout.jpg; ru ks well-ks-19.jpg Tom, Please find attached the rig up diagrams for the Cudd Unit we will be utilizing on the upcoming King campaign. Please contact me if you have further questions or require more information. We are looking at an early May start date for the work. Chantal Walsh Chevron Projeet Manager (907) 263-7627 4/17/2008 :" i rd'1T ~snun Kewy 'HiNU: ?- r'hi,iieun rr~r~ ~" 4~'ti Wct~u Piq+ tYtl t .ww. A4.~nA YNY q iar. 'P:.1~1r.d {,,TM finliRt 1h_•Jr, J ,.. ~ "+. 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W^-` TMwl> .~.: Cr i~ ~. ~ __ _ "tl~ _ ~. _~ r ( ~ ~~ ~ ~~ ~ F[ ~a. ~ ~,. ~ ~ ter- ~ ~_ . tt ,~. ,- ~ ~----y --...~ ., G ~ -~ _ - _.. . ~ ~{ .' e~/y v ~...~ e ~ rTM ~~ y.-~~ ~ - _ - _ ~ ~ .ter ~~ -~~ - - Prat~uctenn1 F~al+dirr~ $ ~~~ ~i • • Maunder, Thomas E tDOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 15, 2008 8:10 AM To: 'Walsh, Chantal (Petrotechnical]' Cc: Tyler, Steve L Subject: RE: Cudd UAit Drawings for upcoming King Salmon work Hi Chantal, Any news on the drawing(s)? Tom -----Original Message----- From: Walsh, Chantal [Petrotechnical] [mailto:WalshC@chevron.com] Sent: Friday, April 11, 2008 2:47 PM To: Maunder, Thomas E (DOA) Cc: Tyler, Steve L Subject: Cudd Unit Drawings for upcoming King Salmon work Tom, D~ ~0~. b Chevron will be using the Cudd Unit for the upcoming work on the King Salmon Platform. The updated rigup illustration has been requested and I will get it to you next week. Have a great weekend. Chantal (907)227-0952 -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 09, 2008 10:09 AM To: Walsh, Chantal [Petrotechnical] Subject: FW: [Fwd: BOPE Proposal] -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, December 16, 2004 7:51 AM To: Jim Regg Subject: [Fwd: BOPE Proposal] Here are the equipment drawings. -------- Original Message -------- Subject: BOPE Proposal Date: Tue, 14 Dec 2004 08:26:28 -0900 From: Buster, Larry W <lbuster@unocal.com> To: tom_maunder@admin.state.ak.us CC: Harness, Evan <eharness@unocal.com> Tom, We have worked up a proposed BOPS diagram for the CUDD HWO on the King Salmon Platform. I have attached the diagram for your review. As you can see, the proposal eliminates chicksan hard line in the critical flow paths and uses rotary and circulating hoses. Also, the Choke Manifold in the system is a unocal owned skid mounted unit. I have attached a diagram of this manifold. «unocal king salmon circdrawing one mud pumps revl.jpg» «KS manifold.xls» 1 e e ç~'1¡¡!-...... . ~, "- " ''i..:"", " MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFiche\CvrPgs_ Inscrts\Microfilm _ Marker. doc 1. Operations Abandon U Repair Well U 6~ Plug Perforations Performed: Alter Casing 0 Pull Tubing [Jl1 Perforate New Pool Change Approved Program 0 Operat. Shutdown 0 Perforate 2. Operator Union Oil Company of California 4. Current Well Class: Name: Development 0 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic 0 STATE OF ALASKA' RECEIV .. '" ALA~. )OILAND GAS CONSERVATION COMMa-..JION ED REPORT OF SUNDRY WELL OPERATIONS MAR 2.,1 2005 U o o Stimulate U Alaska, Oil 8fmftf·tl.R~tr~OO1ESP Waiver 0 Time ExteRiÏRQ Re-enter Suspendeð'1Wft . oe 5. Permit to Drill Number: Exploratory 0 201-009 Service 0 6. API Number: 50-733-20054-02 9. Well Name and Number: K-01 RD2 10. Field/Pool(s): TBU/Hemlock Pool 7. KB Elevation (ft): 100' AMSL 8. Property Designation: King Salmon Platform 11. Present Well Condition Summary: Total Depth measured 13,780' feet true vertical 9,743' feet Effective Depth measured 13,540' feet true vertical 9,553' feet Casing Length Size MD Structural Conductor 75' 20" 110' Surface 2,349' 13 3/8" 61 ppf 2,384' Intermediate Production 5,982' 95/8" 47/43.5 ppf 6,017' Liner 7,952' 7" 29 ppf 13,780' Plugs (measured) 13,540' Junk (measured) nla TVD Burst Collapse 109' NIA NIA 2,167' 3090 psi 1540 psi 4,908' 6330 psi 3810 psi 9,743' 8160 psi 7020 psi Perforation depth: Measured depth: 11,680 to 13,650' True Vertical depth: 8,156 to 9,640' Tubing: (size, grade, and measured depth) 4-112", 12.6 ppf and 3-1/2", 9.2 ppf; L-80 IBTC @1 0,676' Packers and SSSV (type and measured depth) nla 12. Stimulation or cement squeeze summary: Intervals treated (measured): nla Treatment descriptions including volumes used and final pressure: SCF\NNED MAR 2 0\: '!.In!;··~ 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl· Casing Pressure 16 301 600 314 451 67 15. Well Class after proposed work: Exploratory n Development r7l 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl Tubing Pressure 105 68 Prior to well operation: 462 Subsequent to operation: 341 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service n x GINJ 0 WINJ 0 WDSPL 0 Sundry Number or NIA if C.O. Exempt: 304-467 Contact Larry Buster 263-7853 Printed Name Timothy C. Brandenburg __ Signature ;7 :ff Cð ¿i? Title Drilling Manager Phone 907-276-7600 Date 3/15/2005 OH\GINAL RBDMS 8Ft ~<AR 2 2 2005 CONADENTIAl Submit Original Only Form 10-404 Revised 04/2004 1/11/05 ) ) Unload boat. Spot equipment. 1/12/05 Spot equipment. BPV in well. Start breaking down tree. 1/13/05 Start to stack up BOPE. Install top variable rams 2 7/8" - 5". Button up stack and install 1 jt. 4 1/2" tubing with 4 1/2 full opening valve closed. Hook up top rams and power Koomey. Pressure test Koomey, close rams. 1/14/05 Finish building scaffolding to hydrillevel. Function test HCR and hydril. Tested hydril to 250/2500 psi. Tested variable rams. Completed testing of HCR and inside manual valve to 250/3000 psi. 1/15/05 Prep to mix 3% KCL. Mixed saturated salt for LCM pill spacer in pill pit. Finish batching up 740 bbl, 3% KCL. 1/16/05 Operations meeting with Cudd, Nabors, Unocal Production and Unocal Drilling. Prep decks for first Cudd load - receive and offload same. 1/17/05 PJSM. RU Cudd equipment. 1/18/05 Connect hydraulic skid jacks and move sub base to allow pinning of window to rotary beams. Work boat and offload CUDD equipment. 1/19/05 PJSM. RU Cudd unit. 1/20/05 Build saturated salt spacer in rig pill pit. PJSM and JSA with all hands. Scope out gin pole in position for racking back pipe. RU tarps and trip tank pump. Finish working boat. 1/21/05 Function tested Weatherford tubing tongs. Prepared to pressure test lines and pump well. Commissioned Cudd rig. Performed Simops inspection with Production Foreman. Held pre-tour safety and operations meeting. Held spud meeting with all hands and Anchorage Drilling. Displaced well with 3% KCL water, returns to Production. Pumped 936 bbls at 4.75 bbls a minute. 1/22/05 Pumped 177 bbls 3% KCL brine at 4.75 bbl/min. Pumped16 bbls saturated salt spacer followed by 96 bbls sized salt pill, chase with 23 bbls saturated salt spacer. Shut in annulus and bullhead 106 bbls, 3% KCL brine at 2 bpm and 900 psi, final pressure 2500 at :25 bbl/min. SO, pressure bled down 250 psi in 10 minutes. Bleed off tubing and annulus. Back out 4-1/2" landing joint, pull BPV and inspect. Make up 3-1/2" landing joint. Run and screw into hanger. Test BOPs. K-01 RD2 (AFE 162223) morning report summary, CONFIDENTIAL: last revised 3/16/2005, Page 1 ) ) 1/23/05 Test of stack and valves on mud cross. Test hydril250 and 2500 psi. Test rams and related equipment to 250 and 3000 psi. Test, PVTs, high-Low alarms and flow sensor. Lay down test joint pull two way check. H2s alarm and abandon platform drill. 1/24/05 PJSM to discuss unlanding hanger and well control procedures for shut in on pipe w. ESP cable. Walk thru drill hydraulic cutter. Make up landing joint to hanger, back out lockdowns on hanger, pull hangar to work window. Mix and pump dry job. Lay down hanger. POOH with 4 1/2 tubing, strip ESP cable thru sheave. POOH. 1/25/05 POOH standing back 4 1/2" tubing doubles. Continue POOH with 4-1/2". 1/26/05 POOH tubing standing back doubles. LD ESP. pump and motor. Install 7" pipe rams in BOPs. Shell test BOPs. Pick up 7" riser with dog knot and land on blind shear rams. Close pipe rams on 7" lubricator. 1/27/05 PU guns and RIH. RIH and perforate HB-1, 12,980' to 13,000'. LD old gun all shots fired, PU new gun. RIH and perforate G-5, 12,730-12,750. RIH and perforate G-1, 12,040' - 12,060'. RIH and perforate, 11,785' - 11,805'. RIH and perforate, 11690' to 11710'. No fluid losses associated with any of the perforations. RD Schlumberger. LD 7" riser. 1/28/05 RU strapping mandrels, ESP, BHA and tubing. PU ESP motor put anode and centralizer on at window. Hang motor off clamp at basket. Fill motor with oil. RIH double stands of 3-1/2" buttress and gaslift mandrels. 1/29/05 RIH with ESP to 4-1/2" tubing. Change dies in slip bowl. RIH with 4-1/2", 12.6#, L-80, IBTC. Change spools, prep and splice ESP cable. Continue to RIH with tubing after splice. Land and test hanger. 1/30/05 Pull riser and hang off on trolleys in rig sub base. Lower tree into well room. Make up clamp. Test seals (Void) to 5K for 20 minutes. Hook up production lines. Test Tree to 5K for 20 minutes. Pulled 2-way check and gave wellhead to production. K-01 RD2 (AFE 162223) morning report summary, CONFIDENTIAL: last revised 3/16/2005, Page 2 "- UNOCAL. RKB to TBG Head = 33.7' Tree connection: 2,384'~ ) SIZE 13-3/8" 9-5/8 9-5/8" 7" Liner Liner hanger ZXP packer Tieback Assembly ~ Tubing: 4-1/2" 3-1/2" ESP Cable I/OSOLBC 1.611" X 2.361" 2 ) Trading Bay 'Unit Well # K-IRD#2 As Completed 1/30/05 CAS.lNG AND TtJBlNG nET AIL WI' GRADE CONN lD TOP BI'M. 61.0 K-55 12.515 35' 2,384' 47 N-80 BTC 8.681 35' 112' 43.5 N-80 BTC 8.755 112' 6,043' 29 L-80 BTC-KC 6.184 5859' 13,779' 6.25 5850 5859 6.31 5847 5850 7.375 5828 5847 12.6 L-80 BTC 3.958 34 5,557.87' 9.2 L-80 BTC 2.992 5,698.79' 10,676.25 3.37 5KV 90 FB 185 GAL wI (2) 0.375" SS SURF 10,667.12 TUBES-GAL-R No. Deoth 33.7 1. 2602.77 2. 4235.58 3. 5444.41 4. 5557.87 5. 6101.53 .. !II 6. 6957.05 ..:....., ~ ~ 7. 7815.78 8. 8674.54 9. 9538.57 10. 10,676.75 CIBP Set c!! 13,540' W" PERFORA nON DATA Top Btm Amount Condition 11680 11720 40 5/7/01, partial reperf 1/27/05 11732 11742 10 Opened 5/7/01 11 ,780' 11,810' 30 Opened 5/7/01 11,820' 11,840' 20 Opened 5/7/01 11,864' 11,891' 27 Opened 5/7/01 12,030' 12,080' 50 5/7/01, partial reperf 1/27/05 12,090' 12,120' 30 Opened 5/7/01 12,142' 12,162' 20 Opened 5/7/01 12,659' 12,674' 15 Opened 5/7/01 12,680' 12,694' 14 Opened 5/7/01 12,710' 12,790' 80 5/7/01, partial reperf 1/27/05 12,800' 12,830' 30 5/7/01, partial reperf 1/27/05 12,950' 13,010' 60 7/3/01, partial reperf 1/27/05 13,190' 13,210' 20 13,230' 13,370' 140 Opened 6//1501 & 7/3/01 13,405' 13,425' 20 Opened 1/13/02 13,445' 13,460' 15 Opened 1/13/02 13,565' 13,580' 15 Opened 1/13/02 13,610' 13,650' 40 Opened 1/13/02 10 = GO-4 == GO-5 GO-6 == G-1 =G-5 == G-7 I HB-1 == HB-3 == HB-4 = HB-5 === HB-6 == HB-7 otIIIIf"1' PBTD = 13750' TD = 13780' MAX HOLE ANGLE = 59° @ 8485' CONFIDENTIAL Jewelry Detail 10 Item. pesçription 3,958 12" x 4-1/2" FMC 8rd Tbg Hngr 3.833 4-1/2" GLM #1 SFO-2 (7.063" aD) 3.833 4-1/2" GLM #2 SFa-2 (7.063" OD) 3.833 4-1/2" GLM #3 SFO-2 (7.063" aD) 2.992 Crossover 4-1/2" x 3-1/2" 2.867 3-1/2" GLM #4 GLMAX-1.0 (5.968" OD) 2.867 3-1/2" GLM #5 GLMAX-1.0 (5.968" OD) 2.867 3-1/2" GLM #6 GLMAX-1.0 (5.968" OD) 2.867 3-1/2" GLM #7 GLMAX-1.0 (5.968" aD) 2.867 3-1/2" GLM #8 GLMAX-1.0 (5.968" aD) Centrilift ESP Pump & Motor BHA. Length=67.75' Re: BOPE Proposal ') '} Vi' ')\t \) ~, \&C\~E)~5ì ~ \ ~. '<- \) \ \ ~ -0 S( C;x¿"e. ~ \ ç.:., \ <c \i w'() Su bject: Re: BOPE Proposal From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 16 Dee 2004 07:50:09 -0900 To: "Buster, Larry W" <lbuster@unoeal.eom> CC: "Harness, Evan" <eharness@unoeal.eom>, Jim Regg <jim_regg@admin.state.ak.us> Larry, Sorry I did not get back to you sooner with regard to the proposed diagram for the HWO rig up on King. Your proposal does greatly reduce the number of connections and potential leak spots. I had done some research on workovers with HWO done in late 2002 and the proposed rig up is similar. 20 AAC 25.285(e) (6) stipulates that kill and choke lines be assembled without hammer unions. (h) of that regulation allows the commission to approve a variance if an equally effective means of well control is provided. The wells proposed for workover are artificially lifted and KIRD2 has been determined to be "no flow". Well pressures that the equipment would likely see should be low and prior to work being performed the equipment will be function pressure tested according to the regulations. Your proposed equipment is acceptable. Please advise how the schedule is looking. The initial BOP test will likely be witnessed, so please have your Company Rep stay in touch with the Inspectors (907-659-2714) . Tom Maunder" PE AOGCC Buster, Larry W wrote: Tom, We have worked up a proposed BOPE diagram for the CUDD HWO on the King Salmon Platform. I have attached the diagram for your review. As you can see, the proposal eliminates chicksan hard line in the critical flow paths and uses rotary and circulating hoses. Also, the Choke Manifold in the system is a unocal owned skid mounted unit. I have attached a diagram of this manifold. «unocal king salmon circdrawing one mud pumps revl.jpg» «KS manifold. xIs» Regards, Larry Buster Drilling Engineer Unocal Alaska SCANNED DEG 1 5 2004 1 of 1 12/16/20047:51 AM unocal king salmon circdrawing one mud pumps rev1.jpg (JPEG Image, 1001x747 pixels) ~ -"-:IUIf !...~'. ~~"'~. '<",~ ~.CÐt~~.($ . .r.1 SOl WDnfL, ""'.... '''''''''-.. r IS[)~ \\(1IlOO ~ Ak,. r)".,... Or V8.OJlllnH~ " 0'.....- \ TrlDl.fJur.N' Pomp Mo.ilmtl 111M: t1dc \ld\~ :;¿~ QN4Il.-m. HMI , i".ì5~:r WØin: '~~~ 1 of 1 , KtngSalmon.Circdr8Wing: Cudd: PreHure 'Controllnc~. .. '" "" '., ". , . Proposed 'Rlgùp 118ustråtlon With Flångea"l. Clrc.' H'o.., 01;Dec.w a4Rev#1 ' , JevOt no.scal9 . ~; . l -~ ,-</~= '~ ¡zt~'mw 'l",1~2W~ ""',~-.._~ ~c~:m. ' i~ "&flJ!~ '\ ~" ,~~~;;; \.14' t'£'IJ ¡ri~: W.,. .~~.\' \~. ,!""'--- '--. :\ÞJl."oIWYl;cUy Circ¡¡.d.4.!1:: HlliII! f1¡mp1 ~~ ~ '1 ,. ,~.". ."f . ,./ '. +1¡t"'"'5~~~'44it~-SÌ')\ XJ¡¡'~~;"' ~. 12/16/20047:52 AM ) ) <- L Porta anifold Drilling Flow Pa~ .. ~ Drain w/1502 Bull plug A,B,C,D,& E. 4"SM National Ball Valves The rest of valves are 3" SM National Ball Valves 'L ... . ...", 2" HPHose w~ 41/16" 5M Flange, ~~,,/ A~ . ., ~ . ,,',.., ,'.. ,,", ", ,," "" ...' ..', ',,' Z'1502 2" 1502 Hook up to RIG GAS BUSTER E ~ ~!~r~~. 0 Well Control Flow Paths + Hyd CHOKE &t~:~¡r~f.'~~~~~~, ... ' ~~,. -~. . r" """I::,~<I(!,'" :~pt :;.-';:'. '~e ;~(:l-luJ: ;""... ," ., æ" i' - ft II! . "", ~ -,~ II jiP~";, , ! ~ .1: " 'I Îii'i\ . ~""~ '1 c hO RE: K-1RD2 WO with HWOU Unit ) Subject: RE: K-1RD2 WO with HWOU Unit From: "Buster, Larry WIt <lbuster@unoeal.eom> Date: Mon, 29 Nov 2004 05 :49:07 -0900 To: Thomas Maunder <tom_maunder@admin.state.akus>, Tim Brandenburg <brandenburgt@unoeal.eom>, Jerry Bowen <jbowen@unoeal.eom>, Larry Buster <lbuster@unoeal.eom>, Evan Harness <eharness@unoea1.eom> CC: Jim Regg <jim_regg@admin.state.ak.us>, AOGCC North Slope Office <aD gee -prudhoe - bay@admin.state.akus> Tom, I can speak to your question. We have met with representatives from our HWOU Contractor (CUDD) and have discussed proposed CL, KL and manifolding for the upcoming work. Keeping regulatory requirements and past lessons learned in mind, we will have a schematic of the proposed rig-up later this week. I will forward to you ASAP. Reg ards , Larry Buster UNOCAL Alaska -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admìn.state.ak.us] Sent: Saturday, November 27, 2004 1:37PM To: Tim Brandenburg; Jerry Bowen; Larry Buster; Evan Harness Cc: Jim Regg; AOGCC North Slope Office Subject: K-1RD2 WO with HWOU Unit Tim, et al: I have received the application to pull tubing to replace the ESP on the K-lRD2. Unocal proposes to employ a hydraulic workover unit (snubbing unit) to move the tubulars. Unocal' has previously employed a HWOU on other platforms and wells in Cook Inlet including King Salmon. The application provided a "stack up" drawing, however there was no detail provided regarding the choke line, kill line or choke manifold. We would appreciate your sending this information. Please be advised, that Unocal should do everything possible to minimize the number of connections that might be proposed in either line and that "lines" assembled of chicksan are not acceptable. As the beginning of operations gets closer, please have your Drilling Supervisor(s} make contact with the Inspectors to make arrangements to inspect the equipment rig up. Please call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 12/16/20047:58 AM ) $71Æ~!:J fÆ:fÆ~~~1Æ AI,ASIiA OIL AlO) GAS CONSERVATION COlWlISSION Tim Brandenburg Drilling. Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 ' Re: King Salmon K-IRD2 Sundry Number: 304-467 Dear Mr. Brandenburg: ) FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 :kot-o°o/ 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ~ Daniel T. Seamount, Jr. Commission DATED thi~7 day of November, 2004 Encl. SCANNED DEC 0 1 2004 1. Type of Req uest: , STATE OF ALASKA \ ALA~.:} OIL AND GAS CONSERVATION COMrvl._~ION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: 4,\6\ Development Stratigraphic 0 0 PerforateL:J Waiver U Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 replace failed ESP 5. Permit to Drill Number: Exploratory 0 201-009 V 0 6. API Number: 50-733-20054-02 V Other 2] Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 100' AMSL Suspend U Repair well D Pull Tubing 0 Service 8. Property Designation: Trading Bay Unit 9. Well Name and Number: King Salmon K-1 RD2 10. Field/Pools(s): McArthur River I Hemlock Pool ece'VED '.lJ""I.) '...J , , ,; \ V e, """f1\ A l' ..,,"t 11. PRESENT WELL CONDITION SUMMARY A\:\8~3 011 & ~ Gon8. eommh1lion Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): PlugS"(ñleasured)Anch_nk (measured): 13,780 9,745 13,540 9,553 13,540 ' Length Size MD TVD Burst NIA Casing Structural Collapse Conductor 75' 20" 110' 109' NIA NIA Surface 2,349' 13 3/8" 61 ppf 2,384' 2,167' 3090 psi 1540 psi I ntermed iate Production 5,982' 95/8" 47/43.5 ppf 6,017' 4,908' 6330 psi 3810 psi Liner 7,952' 7" 29 ppf 13,780' 9,743' 8160 psi 7020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): (see attached) (see attached) 41/2" 12.6 ppf & 3/12" 9.2 ppf L-80 IBTC 10,662' Packers and SSSV Type: None - ESP artificallift wi live annulus, No- Packers and SSSV MD (ft): NIA Flow status approved 2/8/2002 12. Attachments: Wellbore Schematic Description Summary of Proposal L:J 0 BOP Sketch 0 Dec. 21, 2004 (approximate date) Date: 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil 0 Gas D Plugged WAG D GINJ D WINJ 0 Service D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: D D Abandoned WDSPL 0 D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Tim Brandenburg r-1 Title Drilling Manager Signature -Z - ~ 7 Phone 90:~:~:~ON USE ONLY Date Contact Jerry Bowen 12-Nov-04 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ Ö '-\ - '-\ lo \ Plug Integrity 0 BOP Test .~ Mechanical Integrity Test D Location Clearance D RBDMS BFL NOV 3 0 1004 Other ~CJaà~c;l. '<>Ö\>-\es-\ - ~O\? ~">\ \r-.\~"-.I() \ L- '\ ~'-I ~, (ct'\\-~ ~-\- r:1'''''\,~L~' -\c,-- ~Ht\\-\~~\-\-..~ \0 ~,<;'\'C(,L~ ({'\,\J>\>~~J-ç\ \"'\\ ~ ~; Subsequent Form Required: ~O '-'''<L\U.\\Q''~ ~ ~~ ~~~~CJ \~ ",'-"OJ) -.¡ í \J\,~~\ E.~ 'Ç> .~~,~C:t~~,. ~~C§:.~~~~ . COMMISSIONER ~:::~~~~;. 10.,. J~, ~,. t'.,.,",. Ãe / / /21/1- INSTRUCTIONS ON REVERSE 0 K t G u I ~ I Submit in Duplicate Approved b : Form 10-403 Revised 12/2003 ') ) King Salmon Platform Well K-IRD2, AFE 162223 ESP Repair t UNOCAL8 OBJECTIVE: Replace the failed ESP & re-perforate certain O-Zone & Hemlock intervals in well K-IRD2. PROCEDURE SUMMARY: 1. Mobilize Cudd HWOU & Unocal13 5/8" 3k BOPE to platform. 2. Shut off gas lift gas. Bleed down SIWHP slowly to avoid damaging ESP cable. Turn off cathodic protection system. 3. Perforate tbg above ESP. 4. Load well wi 3% KCl. Circ oil out of annulus. 5. Spot sized salt pill, if necessary, to manage losses and keep hole full while POH or RIH wi tbg & ESP cable. ,/ 6. Set BPV. ND tree. NU & test 13 5/8" 3k double BOP & annular to 250/3000 psi (refer to attached diagram). 7. RU 13 5/8" bore x 340k (winterized) HWOU. 8. Verify well dead and FL can be maintained at surface. Circ well clean to verify no oil has entered tbg or annulus. 9. POH wi tbg, cable & failed ESP. Visually inspect tbg & LID singles while POH. Send un- usable OLVs, primary ESP equipment & damaged/corroded tbg to shore. 10. RU E-line unit. Re-perforate the following intervals with 4 'lj" HSD (5 SPF): . . 00-4 00-6 0-1 0-5 HB-l 11680'-11710' 11780'-11810' 12035' -12065' 12720' -12750' 12970' -13000' 30' 30' 30' 30' 30' 10. RIH wi replacement ESP assembly as per attached diagram & 4 1/2" completion string. 11. Install BPV. RID HWOU. ND BOPE. NU & test tree. 12. Install flowline and surface facilities & turn well over to Production. Turn platform cathodic protection back on. 13. Startup ESP as per separate startup procedure and confirm that ESP is functioning properly. 14. Release HWOU from well. AOGCC K-1 RD2 ESP W orkover Summary 1 of 1 November 12,2004 UNOCAL8 ) -- 4. 2 ) Trading Bay Unit Well # K-IRD#2 As Completed 2/26/02 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-318" 61.0 K-55 12.515 35' 2,384' 9-5/8 47 N-80 BTC 8.681 35' 112' 9-5/8" 43.5 N-80 BTC 8.755 112' 6,043' 7" Liner 29 L-80 BTC-KC 6.184 5859' 13,779' Liner hanger 6.25 5850 5859 ZXP packer 6.31 5847 5850 Tieback Assembly 7.375 5828 5847 ~ Tubing: 4-1/2" 12.6 L-80 BTC 3.958 34 5,698.79' 3-1/2" 9.2 L-80 BTC 2.992 5,698.79' 10,662.8 7' ESP Cable 1/0S0LBC 3.37 5KV 90 FB 185 GAL wi (2) 0.375" SS SURF 10,714.5 1.611" X 2.361" TUBES-GAL-R 2 JEWELRY DETAIL NO. Depth ID Item 33.7 3.958 12" x 4-1/2" FMC 8rd Tbg Hngr 1. 2533.67 3.833 4-1/2" GLM #1 SFO-2 (7.063" OD) 2. 4371.49 3.833 4-1/2" GLM #2 SFO-2 (7.063" OD) 3. 5378.89 3.833 4-1/2" GLM #3 SFO-2 (7.063" OD) 4. 5698.79 2.992 crossover 4-1/2" x 3-1/2" 5. 6186.55 2.867 3-1/2" GLM #4 GLMAX-1.0 (5.968" OD) 6. 6845.99 2.867 3-1/2" GLM #5 GLMAX-1.0 (5.968" OD) 7. 7591.10 2.867 3-1/2" GLM #6 GLMAX-1.0 (5.968" OD) 8. 8347.06 2.867 3-1/2" GLM #7 GLMAX-1.0 (5.968" 00) 9. 10,622.14 2.66 "XN" Profile Nipple, 2.813 10. 10,662.87 Centrilift ESP Pump & Motor BHA. Length=94. 73' RKB to TBG Head = 33.7' Tree connection: 2,384,4: :~ 7 8 PERFORATION DATA Zone Top Btm Amount Condition 10 GO-4 11680 11720 V 40 Opened 5/7/01 GO-5 11732 11742 10 Opened 5/7/01 GO-6 11,780' 11,810'\1" 30 Opened 5/7/01 11,820' 11,840' 20 Opened 5/7/01 = GO-4 11,864' 11,891' 27 Opened 5/7/01 == GO-5 G-1 12,030' 12,080' V 50 Opened 5/7/01 GO-6 12,090' 12,120' 30 Opened 5/7/01 12,142' 12,162' 20 Opened 5/7/01 ==G-1 G-5 12,659' 12,674' 15 Opened 5/7/01 =G-5 12,680' 12,694' 14 Opened 5/7/01 = G-7 I HB-1 12,710' 12,790'''/ 80 Opened 5/7/01 12,800' 12,830' 30 Opened 5/7/01 == HB-3 G-7/HB-1 12,950' 13,010'..,/' 60 Opened 7/3/01 = HB-4 HB3 13,190' 13,210' 20 = HB-5 HB-4 13,230' 13,370' 140 Opened 6//1501 & 7/3/01 CIBP Set@ 13,540' HB5 13,405' 13,425' 20 Opened 1/13/02 = HB-6 HB5 13,445' 13,460' 15 Opened 1/13/02 = HB-7 HB6 13,565' 13,580' 15 Opened 1/13/02 .., - PBTD = 13750' TD = 13780' HB7 13,610' 13,650' 40 Opened 1/13/02 MAX HOLE ANGLE = 59° @ 8485' K-IRD2 Actual 02-26-02.doc REVISED2/26/02 -t:IIDD- .1'IÐ".Wa'_"""T_-- 340k Jack Unit Lift Cap:340,000 Snub Cap: 170,000 Rotary Cap: 9,700 ftJIbs 11" Bore ^ ^ ^ 288" Snub Unit & Work Basket Eleva" ion 755.30"(62.94') Elevation 601.30" (50.10') (534.80") 44.56' Lubricator for ElL Work Window 130.8" 29" 4" Flow Line to Mud Pits with Gas Detector & Flow Meter 23.5" 55" v 34" 27" v 14" ^ 10" Top Deck 72" Elevation 153" (12.8') 72" V V .' ..' .' .,.l'" ) ) .J~~ Unocal Alaska King Salmon Well # K-1 RD2 Rev #1 RRU1 BOP Cudd Pressure Control, Inc. J Proposed Rigup Illustration 11_.. " Il ...--, I --- 8, April,2004 rev 0, no scale ~~~ ~ :> WellHead \............. 340k Jack Unit :> CraneHeight Over Well 120' Snub Unit Height 50,10' Crane Height Above Snub Unit 69.90' 7" 29# S-951 L-80 BTC 6.184 J.D. 4-1/2" 12.6# N-80 BTC 3.958 J.D. 3-1/2" 9.2# N-80 BTC 2.992 J.D. 13-5/8" 5M BOP STACK SHAFFER B.O.P.S .,.,.,',....., 2" ÙQ-1. Weco Fill Line Swivel Spool 13-518" 5M Drilling Spool 13-5/8" 5M Annular BOP, 13-518" 5M 2-7/8" to 5-1/2" VBR Ram, 13-5/8" 5M Blind/Shear Ram, 13-5/8" 5M Flow Cross, 11" 5M Top Deck 4' Spool, 13-518" 5M 6' Spool, 13-5/8" 5M 6' Spool, 13-518" 5M ') ) King Salmon K1 RD2 BOP Stack HWOU 13 S/8" Hydril SM 3.9' Test Pressure: 250/3000 psi I.i.".'.,.. ~ 3 1/16"SM x 4 1/16"SM DSA A 41/16" SM Foster HCR Valve B 41/16" SM Manual gate valve C 3 1/16" SM Manual gate Kill line D 3 1/16" SM Manual gate Kill line Graylock Hub ... 55" W â 34" w ... 27" w à 14" Top Deck w - a Top of FMC Type CBS Tubing Head Adapter ... 10.90' 12.67' - ~ UNOCAL8 K-01 RD2 Survey Report - Geodetic Survey I DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Report Date: 24-Jan-2002 Client: Unocal Field: Trading Bay Unit Structure I Slot: King Salmon 1 K.01 (slot 26) Well: K-01 Borehole: K-01 RD2 UWIIAPI#: 507332005402 Survey Name I Date: K-01 RD21 October 9, 2001 Tort I AHD I DDII ERD ratio: 224.338° 19135.63 ft 16.4621 0.937 Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Location Lat/Long: N 60.86553200, W 151.60590692 Location Grid N/E Y/X: N 2511798.000 ftUS, E 213756.000 ftUS Grid Convergence Angle: -1.40281425° Grid Scale Factor: 0.99999324 Station ID MD Incl Azim TVD VSec I Nt-S I (ft) (°) e) (ft) (ft) (ft) 0.00 0.00 0.00 0.00 0.00 0.00 39.00 0.00 0.00 39.00 0.00 0.00 75.00 0.08 272.00 75.00 0.02 0.00 1 00.00 0.08 315.00 100.00 0.05 0.01 125.00 0.08 315.00 125.00 0.06 0.04 150.00 0.08 273.00 150.00 0.09 0.05 175.00 0.08 207.00 175.00 0.12 0.04 200.00 0.33 85.00 200.00 0.06 0.03 225.00 0.33 78.00 225.00 -0.08 0.05 250.00 0.17 30.00 250.00 -0.18 0.10 275.00 0.17 248.00 275.00 -0.17 0.11 300.00 1.08 267.00 300.00 0.09 0.09 325.00 2.17 267.00 324.99 0.77 0.05 350.00 3.50 269.00 349.96 1.96 0.01 375.00 5.00 279.00 374.89 3.65 0.17 380.00 5.17 278.00 379.87 4.05 0.24 400.00 4.00 276.00 399.80 5.49 0.43 500.00 3.75 278.00 499.57 11.60 1.25 K-01 RD2 survey.xls Page 1 of 6 Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North -> True North: Local Coordinates Referenced To: Schlumb8Pg8P Minimum Curvature 1 Lubinski 251.610° N 0.000 ft, E 0.000 ft KB 100.000 ft relative to Mean Sea Level +20.847° 55384.526 nT 73.53]0 April 27, 2001 BGGM 2001 True North +20.847° Well Head '~ E/-W (ft) 0.00 0.00 -0.03 -0.05 -0.08 Grid Coordinates Northing Easting (ftUS) (ftUS) 2511798.00 213756.00 2511798.00 213756.00 2511798.00 213755.97 2511798.02 213755.95 2511798.04 213755.92 DLS (° 11 OOft) 0.00 0.22 0.23 0.00 Geographic Coordinates Latitude Longitude N 60.86553200 W 151.60590692 N 60.86553200 W 151.60590692 N 60.86553200 W 151.60590706 N 60.86553204 W 151.60590723 N 60.86553210 W 151.60590736 -0.11 0.23 2511798.05 213755.89 N 60.86553214 W 151.60590753 -0.13 0.35 2511798.04 213755.87 N 60.86553210 W 151.60590767 -0.07 1.51 2511798.03 213755.93 N 60.86553208 W 151.60590732 0.07 0.16 2511798.05 213756.07 N 60.86553213 W 151.60590652 0.16 1.00 2511798.09 213756.16 N 60.86553226 W 151.60590602 ~ 0.14 1.29 2511798.11 213756.15 N 60.86553231 W 151.60590611 -0.13 3.68 2511798.09 213755.88 N 60.86553224 W 151.60590762 -0.83 4.36 2511798.07 213755.17 N 60.86553214 W 151.60591159 -2.07 5.33 2511798.06 213753.93 N 60.86553204 W 151.60591852 -3.91 6.67 2511798.27 213752.10 N 60.86553246 W 151.60592884 -4.35 3.83 2511798.34 213751.66 N 60.86553264 W 151.60593130 -5.93 5.90 2511798.58 213750.08 N 60.86553319 W 151.60594020 -12.64 0.28 2511799.56 213743.39 N 60.86553543 W 151.60597782 I Grid Coordinates I Geographic Coordinates I 11/12/2004-2:55 PM Station ID MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (° /1ooft) (nUS) (nUS) 600.00 6.62 262.00 599.16 20.20 0.91 -21.59 3.19 2511799.43 213734.44 N 60.86553448 W 151.60602801 625.00 7.23 264.50 623.98 23.15 0.56 -24.58 2.72 2511799.16 213731.44 N 60.86553352 W 151.60604480 650.00 7.75 259.50 648.76 26.35 0.10 -27.80 3.33 2511798.78 213728.21 N 60.86553226 W 151.60606288 675.00 7.72 250.60 673.54 29.70 -0.77 -31.05 4.79 2511797.99 213724.94 N 60.86552990 W 151.60608107 700.00 7.72 254.50 698.31 33.06 -1.77 -34.25 2.10 2511797.06 213721.72 N 60.86552715 W 151.60609903 725.00 7.62 241.50 723.09 36.37 -3.01 -37.32 6.94 2511795.90 213718.61 N 60.86552375 W 151.60611627 750.00 7.58 240.50 747.87 39.62 -4.62 -40.21 0.55 2511794.37 213715.68 N 60.86551937 W 151.60613249 775.00 7.42 240.00 772.66 42.82 -6.24 -43.05 0.69 2511792.82 213712.81 N 60.86551494 W 151.60614839 800.00 7.53 239.50 797.44 46.00 -7.87 -45.86 0.51 2511791.25 213709.96 N 60.86551046 W 151.60616415 825.00 7.55 239.00 822.23 49.20 -9.55 -48.68 0.27 2511789.64 213707.10 N 60.86550587 W 151.60617996 850.00 7.63 239.40 847.01 52.43 -11 .24 -51.51 0.38 2511788.02 213704.23 N 60.86550125 W 151.60619587 875.00 7.90 239.90 871.78 55.73 -12.95 -54.43 1.11 2511786.39 213701.27 N 60.86549658 W 151.60621222 ~. 900.00 8.25 240.30 896.53 59.17 -14.70 -57.47 1.42 2511784.71 213698.19 N 60.86549179 W 151.60622930 925.00 8.77 240.30 921.26 62.80 -16.53 -60.69 2.08 2511782.96 213694.93 N 60.86548678 W 151.60624732 950.00 9.32 239.80 945.94 66.65 -18.49 -64.09 2.22 2511781.08 213691.48 N 60.86548141 W 151.60626642 975.00 9.97 239.80 970.59 70.75 -20.60 -67.71 2.60 2511779.06 213687.81 N 60.86547565 W 151.60628673 1000.00 10.60 242.00 995.19 75.14 -22.77 -71.61 2.97 2511776.99 213683.85 N 60.86546971 W 151.60630861 1050.00 12.08 241.60 1044.21 84.83 -27.42 -80.27 2.96 2511772.56 213675.08 N 60.86545700 W 151.60635720 1100.00 13.38 241.80 1092.98 95.68 -32.64 -89.98 2.60 2511767.57 213665.25 N 60.86544272 W 151.60641162 1150.00 14.87 241 .1 0 1141.47 107.69 -38.4 7 -100.69 3.00 2511762.00 213654.40 N 60.86542676 W 151.60647173 1200.00 16.18 241.90 1189.64 120.86 -44.86 -112.45 2.65 2511755.91 213642.48 N 60.86540930 W 151.60653771 1250.00 18.00 243.70 1237.43 135.38 -51.56 -125.53 3.79 2511749.53 213629.25 N 60.86539096 W 151.60661103 1300.00 19.52 244.50 1284.78 151.32 -58.58 -139.99 3.08 2511742.86 213614.62 N 60.86537176 W 151.60669218 1350.00 20.97 244.30 1331.69 168.49 -66.06 -155.60 2.90 2511735.77 213598.84 N 60.86535130 W 151.60677970 1400.00 22.73 245.00 1378.09 186.96 -74.02 -172.41 3.56 2511728.22 213581.83 N 60.86532952 W 151.60687403 1450.00 24.43 244.90 1423.92 206.83 -82.49 -190.53 3.40 2511720.20 213563.51 N 60.86530636 W 151.60697567 1500.00 26.15 245.70 1469.12 228.06 -91.41 -209.94 3.51 2511711.76 213543.89 N 60.86528195 W 151.60708452 .~ 1600.00 29.58 244.90 1557.51 274.50 -110.95 -252.39 3.45 2511693.26 213500.97 N 60.86522849 W 151.60732262 1700.00 33.02 244.70 1642.95 326.08 -133.08 -299.39 3.44 2511672.29 213453.45 N 60.86516798 W 151.60758624 1800.00 35.58 244.60 1725.55 382.01 -157.20 -350.31 2.56 2511649.42 213401.95 N 60.86510198 W 151.60787187 1900.00 36.87 244.60 1806.22 440.66 -182.55 -403.69 1.29 2511625.39 213347.97 N 60.86503264 W 151.60817130 2000.00 39.33 245.30 1884.91 501.95 -208.66 -459.59 2.50 2511600.65 213291.45 N 60.86496120 W 151.60848484 2100.00 41.78 246.00 1960.88 566.61 -235.46 -518.82 2.49 2511575.31 213231.58 N 60.86488790 W 151.60881709 2200.00 43.43 246.10 2034.48 633.98 -262.94 -580.68 1.65 2511549.36 213169.06 N 60.86481273 W 151.60916409 2300.00 43.93 246.50 2106.80 702.75 -290.70 -643.92 0.57 2511523.16 213105.16 N 60.86473679 W 151.60951879 I Grid Coordinates I Geographic Coordinates I K-01 RD2 survey.xls Page 2 of 6 11/12/2004-2:55 PM Station ID MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude Longitude (It) (°) (°) (It) (It) (It) jlt) (" 11oolt) (ltUS) (ltUS) 2400.00 43.20 246.40 2179.26 771.39 -318.23 -707.10 0.73 2511497.18 213041.33 N 60.86466146 W 151.60987316 2500.00 43.08 246.60 2252.23 839.49 -345.50 -769.81 0.18 2511471.45 212977.97 N 60.86458687 W 151.61022488 2600.00 42.33 246.40 2325.71 907.05 -372.54 -832.00 0.76 2511445.94 212915.13 N 60.86451288 W 151.61057374 2700.00 41.80 246.60 2399.95 973.78 -399.26 -893.44 0.55 2511420.74 212853.06 N 60.86443979 W 151.61091835 2800.00 41.17 247.60 2474.87 1039.81 -425.04 -954.46 0.91 2511396.46 212791.43 N 60.86436927 W 151.61126060 2900.00 40.15 247.40 2550.72 1104.80 -449.97 -1014.66 1.03 2511373.01 212730.64 N 60.86430105 W 151.61159824 3000.00 39.40 247.20 2627.58 1168.60 -474.66 -1073.68 0.76 2511349.77 212671.03 N 60.86423350 W 151.61192928 3100.00 38.87 247.40 2705.15 1231.53 -499.01 -1131.91 0.54 2511326.85 212612.23 N 60.86416686 W 151.61225586 3200.00 38.57 247.50 2783.17 1293.92 -523.00 -1189.67 0.31 2511304.28 212553.89 N 60.86410123 W 151.61257988 3300.00 39.27 246.80 2860.97 1356.55 -547.40 -1247.57 0.83 2511281.31 212495.42 N 60.86403448 W 151.61290458 3400.00 39.68 246.80 2938.16 1419.90 -572.44 -1306.00 0.41 2511257.70 212436.39 N 60.86396596 W 151.61323232 3500.00 40.22 248.50 3014.82 1483.95 -596.85 -1365.38 1.22 2511234.76 212376.43 N 60.86389917 W 151.61356539 ~ 3600.00 40.67 248.40 3090.92 1548.73 -620.68 -1425.72 0.45 2511212.41 212315.52 N 60.86383397 W 151.61390381 3700.00 41.00 249.10 3166.58 1614.03 -644.38 -1486.66 0.56 2511190.21 212254.02 N 60.86376913 W 151.61424562 3800.00 41.37 249.10 3241.84 1679.82 -667.87 -1548.18 0.37 2511168.24 212191.95 N 60.86370485 W 151.61459065 3900.00 41.62 249.20 3316.74 1746.01 -691.45 -1610.10 0.26 2511146.18 212129.47 N 60.86364032 W 151.61493792 4000.00 41.42 249.30 3391.62 1812.24 -714.94 -1672.08 0.21 2511124.22 212066.93 N 60.86357606 W 151.61528559 4100.00 41.38 249.70 3466.63 1878.33 -738.10 -1734.03 0.27 2511102.58 212004.44 N 60.86351268 W 151.61563301 4200.00 41.10 249.70 3541.82 1944.22 -760.97 -1795.85 0.28 2511081.23 211942.07 N 60.86345010 W 151.61597977 4300.00 40.87 249.70 3617.31 2009.76 -783.72 -1857.37 0.23 2511059.99 211880.02 N 60.86338783 W 151.61632477 4400.00 40.22 248.60 3693.30 2074.71 -806.85 -1918.11 0.97 2511038.35 211818.73 N 60.86332453 W 151.61666547 4500.00 37.05 242.20 3771.44 2136.71 -832.70 -1974.86 5.10 2511013.90 211761.36 N 60.86325380 W 151.61698373 4600.00 37.35 243.00 3851.09 2196.42 -860.52 -2028.54 0.57 2510987.40 211707.02 N 60.86317767 W 151.61728478 4700.00 39.62 242.90 3929.36 2257.94 -888.82 -2083.96 2.27 2510960.47 211650.93 N 60.86310023 W 151.61759559 4800.00 42.92 242.70 4004.51 2323.11 -918.97 -2142.61 3.30 2510931.76 211591.55 N 60.86301774 W 151.61792456 4900.00 43.33 242.70 4077.50 2390.65 -950.33 -2203.36 0.41 2510901.91 211530.06 N 60.86293194 W 151.61826523 5000.00 43.83 242.70 4149.94 2458.75 -981.94 -2264.62 0.50 2510871.80 211468.04 N 60.86284543 W 151.61860879 '- 5100.00 43.33 242.70 4222.38 2526.86 -1013.56 -2325.87 0.50 2510841.69 211406.03 N 60.86275891 W 151.61895234 5200.00 43.17 243.10 4295.22 2594.58 -1044.78 -2386.87 0.32 2510811.98 211344.29 N 60.86267349 W 151.61929442 5300.00 42.25 243.20 4368.70 2661.67 -1075.41 -2447.39 0.92 2510782.84 211283.04 N 60.86258966 W 151.61963380 5400.00 41.25 243.00 4443.30 2727.53 -1105.54 -2506.77 1.01 2510754.17 211222.94 N 60.86250722 W 151.61996683 5500.00 42.10 243.00 4517.99 2793.27 -1135.72 -2566.01 0.85 2510725.45 211162.98 N 60.86242462 W 151.62029907 5600.00 41.37 244.80 4592.62 2859.23 -1165.01 -2625.78 1.40 2510697.63 211102.51 N 60.86234446 W 151.62063428 5700.00 41.17 245.30 4667.78 2924.76 -1192.84 -2685.59 0.39 2510671.28 211042.04 N 60.86226832 W 151.62096967 5800.00 40.83 245.70 4743.25 2989.99 -1220.04 -2745.29 0.43 2510645.54 210981.69 N 60.86219386 W 151.62130447 I Grid Coordinates I Geographic Coordinates I K-01 RD2 survey.xls Page 3 of 6 11/12/2004-2:55 PM Station ID MD Incl Azim TVD VSec NI-S EI-W DLS Northing Easting Latitude Longitude (ft) n n (ft) (ft) (ft) (ft) (O/1 OOft) (ftUS) (ftUS) 5900.00 40.83 245.90 4818.92 3055.04 -1246.84 -2804.92 0.13 2510620.21 210921.42 N 60.B6212051 W 151.62163891 6000.00 39.92 246.40 4895.10 3119.52 -1273.04 -2864.17 0.97 2510595.4 7 210861.55 N 60.86204882 W 151.62197116 6019.00 39.86 246.49 4909.68 3131.65 -1277.91 -2875.34 0.44 2510590.88 210850.27 N 60.86203549 W 151.62203380 6053.92 40.40 249.16 4936.38 3154.11 -1286.40 -2896.17 5.16 2510582.90 210829.23 N 60.86201225 W 151.62215067 6145.50 43.63 256.46 5004.45 3215.29 -1304.37 -2954.68 6.39 2510566.37 210770.30 N 60.86196305 W 151.62247878 6241 .1 0 48.11 263.46 5071.04 3283.06 -1316.16 -3022.17 7.04 2510556.23 210702.54 N 60.86193076 W 151.62285732 6334.39 52.34 269.06 5130.74 3352.34 -1320.72 -3093.66 6.47 2510553.42 210630.96 N 60.86191822 W 151.62325825 6429.72 56.32 274.55 5186.35 3424.93 -1318.19 -3171.00 6.27 2510557.84 210553.71 N 60.86192509 W 151.62369202 6523.57 57.40 274.42 5237.65 3497.33 -1312.05 -3249.34 1.16 2510565.90 210475.54 N 60.86194183 W 151.62413142 6615.91 56.73 271.93 5287.86 3569.39 -1307.75 -3326.71 2.38 2510572.09 210398.30 N 60.86195353 W 151.62456538 6707.92 55.99 272.21 5338.83 3641.16 -1304.98 -3403.26 0.84 2510576.73 210321.84 N 60.86196104 W 151.62499473 6802.21 55.60 271.46 5391.84 3714.33 -1302.49 -3481.20 0.78 2510581.14 210243.99 N 60.86196781 W 151.62543187 ~ 6896.49 56.80 269.40 5444.29 3788.48 -1301.91 -3559.54 2.22 2510583.63 210165.69 N 60.86196933 W 151.62587123 6989.24 58.00 269.91 5494.26 3862.78 -1302.38 -3637.67 1.37 2510585.08 210087.57 N 60.86196798 W 151.62630946 7084.94 57.85 271.84 5545.08 3939.32 -1301 . 14 -3718.75 1.72 2510588.30 210006.55 N 60.86197129 W 151.62676419 7177.18 57.34 272.73 5594.51 4012.18 -1298.04 -3796.56 0.98 2510593.31 209928.83 N 60.86197971 W 151.62720062 7270.24 57.34 271.94 5644.73 4085.46 -1294.84 -3874.84 0.71 2510598.42 209850.66 N 60.86198838 W 151.62763968 7366.04 58.11 272.13 5695.89 4161.36 -1291.97 -3955.79 0.82 2510603.27 209769.81 N 60.86199617 W 151.62809369 7457.95 57.97 271.83 5744.54 4234.46 -1289.27 -4033.72 0.32 2510607.87 209691.96 N 60.86200347 W 151.62853078 7549.61 58.34 271.75 5792.90 4307.55 -1286.84 -4111.54 0.41 2510612.21 209614.22 N 60.86201005 W 151.62896728 7644.88 58.20 273.07 5843.01 4383.29 -1283.43 -4192.50 1.19 2510617.60 209533.38 N 60.86201929 W 151.62942135 7740.02 58.02 272.96 5893.27 4458.50 -1279.19 -4273.17 0.21 2510623.82 209452.84 N 60.86203083 W 151.62987380 7832.01 58.20 273.18 5941.87 4531.19 -1275.00 -4351.16 0.28 2510629.91 209374.97 N 60.86204219 W 151.63031124 7924.86 57.63 273.80 5991 .19 4604.19 -1270.22 -4429.68 0.83 2510636.62 209296.59 N 60.86205521 W 151.63075166 8018.42 57.19 274.01 6041.58 4677.13 -1264.85 -4508.33 0.51 2510643.91 209218.10 N 60.86206981 W 151.63119277 8111.44 57.53 271.88 6091.76 4750.09 -1260.83 -4586.55 1.96 2510649.85 209140.00 N 60.86208073 W 151.63163148 8204.27 57.49 272.00 6141.62 4823.51 -1258.18 -4664.80 0.12 2510654.41 209061.84 N 60.86208789 W 151.63207040 ~I 8296.01 57.75 272.34 6190.75 4896.05 -1255.24 -4742.22 0.42 2510659.24 208984.51 N 60.86209583 W 151.63250463 8390.54 57.08 271.50 6241.66 4970.75 -1252.57 -4821.83 1.03 2510663.86 208905.00 N 60.86210305 W 151.63295111 8484.61 59.04 272.27 6291.42 5045.62 -1249.94 -4901.61 2.20 2510668.44 208825.31 N 60.86211016 W 151.63339858 8579.26 58.42 273.05 6340.55 5121.12 -1246.19 -4982.42 0.96 2510674.17 208744.61 N 60.86212033 W 151.63385184 8671.53 57.73 272.38 6389.35 5194.18 -1242.48 -5060.64 0.97 2510679.80 208666.50 N 60.86213039 W 151.63429058 8765.44 57.30 272.58 6439.78 5268.20 -1239.05 -5139.78 0.49 2510685.16 208587.47 N 60.86213967 W 151.63473448 8858.48 56.76 273.62 6490.42 5340.83 -1234.83 -5217.72 1.10 2510691.29 208509.66 N 60.86215111 W 151.63517163 8950.04 57.33 271.77 6540.23 5412.51 -1231.22 -5294.46 1.81 2510696.77 208433.03 N 60.86216089 W 151.63560203 I Grid Coordinates I Geographic Coordinates I K-01 RD2 survey.xls Page 4 of 6 11/12/2004-2:55 PM TVD VSec Nt-S E/-W > Station ID MD Incl Azim DLS Northing Easting Latitude Longitude (tt) n (°) (tt) (tt) (tt) (tt) r/100tt) (ttUS) ~ttUS) 9042.77 57.84 271.74 6589.93 5486.00 -1228.82 -5372.70 0.55 2510701.08 208354.87 N 60.86216735 W 151.63604089 9133.53 57.69 271.78 6638.34 5558.07 -1226.47 -5449.44 0.17 2510705.32 208278.22 N 60.86217370 W 151.63647128 9226.89 57.75 271.73 6688.20 5632.17 -1224.05 -5528.33 0.08 2510709.67 208199.41 N 60.86218021 W 151.63691378 9323.93 57.97 272.29 6739.83 5709.19 -1221.17 -5610.45 0.54 2510714.56 208117.38 N 60.86218799 W 151.63737436 9422.72 57.51 274.27 6792.56 5786.82 -1216.39 -5693.85 1.76 2510721.38 208034.13 N 60.86220094 W 151.63784212 9515.93 57.50 274.92 6842.64 5859.20 -1210.09 -5772.21 0.59 2510729.59 207955.94 N 60.86221807 W 151.63828166 9609.72 56.94 274.96 6893.42 5931.60 -1203.30 -5850.77 0.60 2510738.30 207877.57 N 60.86223653 W 151.63872230 9701.25 57.24 275.64 6943.15 6001.97 -1196.20 -5927.29 0.70 2510747.27 207801.26 N 60.86225585 W 151.63915146 9795.91 58.04 274.39 6993.81 6075.35 -1189.22 -6006.94 1.40 2510756.21 207721.80 N 60.86227484 W 151.63959822 9887.38 58.14 272.64 7042.17 6147.38 -1184.46 -6084.43 1.63 2510762.86 207644.45 N 60.86228775 W 151.64003289 9981.68 58.16 270.94 7091.93 6222.56 -1181 .96 -6164.49 1.53 2510767.32 207564.48 N 60.86229448 W 151.64048191 10075.44 57.55 271.51 7141.82 6297.34 -1180.26 -6243.86 0.83 2510770.96 207485.17 N 60.86229901 W 151.64092708 ~. 10169.71 55.97 272.05 7193.49 6371.35 -1177.81 -6322.66 1.74 2510775.33 207406.45 N 60.86230558 W 151.64136908 10263.84 56.46 270.60 7245.84 6445.00 -1176.01 -6400.87 1.38 2510779.05 207328.31 N 60.86231040 W 151.64180774 10358.91 55.97 270.37 7298.70 6519.76 -1175.34 -6479.89 0.55 2510781.66 207249.34 N 60.86231212 W 151.64225090 10400.23 56.23 269.75 7321.75 6552.30 -1175.30 -6514.18 1.40 2510782.53 207215.06 N 60.86231216 W 151.64244326 10455.40 55.46 267.84 7352.72 6595.91 -1176.26 -6559.82 3.19 2510782.69 207169.41 N 60.86230948 W 151.64269924 10542.84 56.32 266.25 7401.76 6665.69 -1180.00 -6632.12 1.80 2510780.73 207097.04 N 60.86229914 W 151.64310471 10637.69 55.46 266.04 7454.95 6741.71 -1185.28 -6710.47 0.93 2510777.37 207018.58 N 60.86228458 W 151.64354416 10731.71 54.91 266.48 7508.63 6816.39 -1190.31 -6787.50 0.70 2510774.22 206941.46 N 60.86227068 W 151.64397616 10826.05 53.4 7 261 .90 7563.84 6891.02 -1198.03 -6863.58 4.22 2510768.37 206865.21 N 60.86224946 W 151.64440284 10918.40 52.25 258.39 7619.61 6963.80 -1210.60 -6936.09 3.30 2510757.57 206792.41 N 60.86221494 W 151.64480951 11014.38 50.38 255.63 7679.61 7038.37 -1227.42 -7009.08 2.97 2510742.55 206719.03 N 60.86216883 W 151.64521885 11110.84 47.22 250.67 7743.16 7110.87 -1248.37 -7078.52 5.07 2510723.31 206649.10 N 60.86211141 W 151.64560822 11199.89 46.02 246.49 7804.34 7175.47 -1271.97 -7138.75 3.67 2510701.18 206588.31 N 60.86204674 W 151.64594597 11292.33 44.15 244.79 7869.60 7240.57 -1298.96 -7198.39 2.41 2510675.67 206528.03 N 60.86197283 W 151.64628034 11385.05 42.04 239.09 7937.33 7302.97 -1328.67 -7254.26 4.78 2510647.33 206471.45 N 60.86189145 W 151.64659365 ~' 11478.21 41.60 233.31 8006.78 7362.81 -1363.19 -7305.85 4.16 2510614.09 206419.04 N 60.86179695 W 151.64688283 11531.53 41.33 231.52 8046.74 7396.15 -1384.72 -7333.82 2.28 2510593.25 206390.54 N 60.86173801 W 151.64703966 11551.96 41.40 230.06 8062.07 7408.77 -1393.25 -7344.28 4.74 2510584.97 206379.87 N 60.86171465 W 151.64709830 11647.28 42.59 222.68 8132.96 7466.35 -1437.23 -7390.34 5.33 2510542.14 206332.75 N 60.86159428 W 151.64735648 11740.84 43.24 216.47 8201.51 7520.29 -1486.30 -7430.87 4.57 2510494.08 206291.03 N 60.86146000 W 151.64758362 11829.78 43.36 210.67 8266.26 7568.28 -1537.08 -7464.57 4.47 2510444.14 206256.10 N 60.86132103 W 151.64777242 11930.36 42.92 206.32 8339.67 7618.47 -1597.48 -7497.37 2.99 2510384.55 206221.83 N 60.86115574 W 151.64795619 12020.94 41.00 201.30 8407.05 7659.16 -1652.83 -7521.85 4.27 2510329.82 206196.01 N 60.86100430 W 151.64809327 I Grid Coordinates I Geographic Coordinates I K-01 RD2 survey.xls Page 5 of 6 11/12/2004-2:55 PM ~ Station ID MD Incl Azim TVD VSec NI-S EI-W DLS Northing Easting Latitude Longitude (It) (°) (°) (f!) (ft) (ft, (ft) (° /1 OOft) (ftUS) (ftUS) 12101.10 41.14 198.88 8467.48 7691.92 -1702.28 -7539.94 1.99 2510280.83 206176.72 N 60.86086900 W 151.64819452 12191.53 41.01 197.53 8535.65 7727.34 -1758.72 -7558.50 0.99 2510224.86 206156.78 N 60.86071458 W 151.64829843 12284.55 41.37 198.58 8605.65 7763.73 -1816.96 -7577.49 0.84 2510167.10 206136.37 N 60.86055524 W 151.64840471 12379.40 41.59 199.15 8676.72 7801.77 -1876.41 -7597.80 0.46 2510108.17 206114.61 N 60.86039259 W 151.64851842 12473.91 41.54 200.68 8747.43 7840.63 -1935.36 -7619.16 1.08 2510049.76 206091.81 N 60.86023130 W 151.64863798 12569.27 41.72 200.95 8818.71 7880.67 -1994.58 -7641.67 0.27 2509991.11 206067.86 N 60.86006929 W 151.64876402 12661.95 41.66 201.26 8887.92 7919.88 -2052.09 -7663.86 0.23 2509934.17 206044.26 N 60.85991195 W 151.64888829 12753.94 42.16 203.81 8956.38 7960.13 -2108.83 -7687.41 1.93 2509878.02 206019.33 N 60.85975670 W 151.64902016 12848.75 42.26 204.58 9026.60 8003.23 -2166.93 -7713.52 0.56 2509820.58 '205991.81 N 60.85959772 W 151.64916636 12941.02 41.49 205.13 9095.31 8045.42 -2222.81 -7739.41 0.92 2509765.34 205964.56 N 60.85944481 W 151.64931132 13034.38 40.68 209.89 9165.69 8089.44 -2277.21 -7767.71 3.46 2509711.66 205934.94 N 60.85929597 W 151.64946985 13128.00 40.60 212.60 9236.74 8135.89 -2329.33 -7799.33 1.89 2509660.33 205902.05 N 60.85915335 W 151.64964699 ~ 13222.40 40.75 213.86 9308.34 8184.12 -2380.79 -7833.05 0.88 2509609.70 205867.08 N 60.85901251 W 151.64983589 13315.43 40.36 213.15 9379.02 8231.72 -2431.23 -7866.44 0.65 2509560.10 205832.4 7 N 60.85887450 W 151.65002295 13408.48 38.92 213.96 9450.67 8278.45 -2480.70 -7899.24 1.64 2509511 .45 205798.46 N 60.85873912 W 151.65020674 13502.65 37.81 214.44 9524.51 8324.88 -2529.04 -7932.09 1.22 2509463.93 205764.44 N 60.85860682 W 151.65039078 13519.77 37.43 214.43 9538.07 8333.20 -2537.66 -7938.00 2.22 2509455.46 205758.32 N 60.85858324 W 151.65042389 13780.00 37.43 214.43 9744.72 8459.22 -2668.12 -8027.43 0.00 2509327.23 205665.73 N 60.85822622 W 151.65092490 K-01 RD2 survey.xls Page 6 of 6 11/12/2004-2:55 PM E: K-IRD2 WO with HWOU Unit ) ) Subject: RE: K-IRD2 WO with HWOU Unit . From: "Buster, Larry W" <lbuster@unocal.com> Date: Mon, 29 Nov 2004 05 :49:07 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us>, Tim Brandenburg <brandenburgt@unocal.com>, Jerry Bowen <jbowen@unocal.com>, Larry Buster <lbuster@unocal.com>, Evan Harness <eharness@unocal.com> cc: Jim Regg <jim_regg@admin.state.ak.us>, AOGCC North Slope Office <aogcc -prudhoe - bay@admin.state.ak.us> J¡J. - 0°1 Tom, I can speak to your question. We have met with representatives from our HWOU Contractor (CUDD) and have discussed proposed CL, KL and manifolding for the upcoming work. Keeping regulatory requirements and past lessons learned in mind, we will have a schematic of the proposed rig-up later this week. I will forward to you ASAP. Regards, Larry Buster UNOCAL Alaska -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] S en t: Sat urda y, Novemb'ei:"'''''2-7'''~''''''''''2'"6'()4'''''''1''';''"3-7''''''''P'M"""""'"''''''''''''''''''''''''''''''''''''''''''''''''"""""""".........."-""""''''' To: Tim Brandenburg; Jerry Bowen; Larry Buster; Evan Harness Cc: Jim Regg; AOGCC North Slope Office Subject: K-1RD2 WO with HWOU Unit Tim, et al: I have received the application to pull tubing to replace the ESP on the K-1RD2. Unocal proposes to employ a hydraulic workover unit (snubbing unit) to move the tubulars. Unocal has previously employed a HWOU on other platforms and wells in Cook Inlet including King Salmon. The application provided a "stack up" drawing, however there was no detail provided regarding the choke line, kill line or choke manifold. We would appreciate your sending this information. Please be advised, that Unocal should do everything possible to minimize the number of connections that might be proposed in either line and that "lines" assembled of chicksan are not acceptable. As the beginning of operations gets closer, please have your Drilling Supervisor(s) make contact with the Inspectors to make arrangements to inspect the equipment rig up. Please call or message with any questions. Tom Maunder, PE AOGCC \,,\~~~\\ ~c-',.~;};J ß ~\\\"'((.".,,~ "a--\'\c~ \"f",. ~-t~~"i aoo;:).. \>~\PS~\ \S ~ ~~'t,~ ~o0~cn"':,()-\: ~'(.\S\\"\ \"~N(¡\~, ~O N<-~ ~~Æ ~. b<t o.~â')~~. )tj.1'f1(1 \ I;,\~Q,,-\ 1 of 1 11/29/20047:32 AM Permit to Drill 2010090 DATA SUBMITTAL COMPLIANCE REPORT 612/2003 Well Name/No. TRADING BAY UNIT K-01RD2 Operator UNION OIL CO OF CALIFORNIA MD 13780 J 'I'VD 9745 ,-~ Completion Dat 5/712001 ~'~ Completion Statu 1-OIL Current Status 1-OIL UIC N APl No. 50-733-20054-01-00 REQUIRED INFORMATION Mud Log No Sample N._~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH I Dataset Name Scale Media No Start Stop ~ Received Number Comments 6000 13530~ 8/27/2001 ~,e321 9050 13714 ~C'J'S'~ 8/27/2001 ~2 6000-13530 9050-13714 Well Cores/Samples Information: Name Interval Dataset Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? ~ Analysis ~ R ~.r~.ivP. d ? Daily History Received? ~ N Formation Tops ~ N Comments: Compliance Reviewed By: Date: ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: X Alter casing: Repair well: Other: X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 100' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Trading Bay Unit/ P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: McArthur River Field 4. Location of well at surface 8. Well number 135' FEL, 724' FSL, Sec 17, T9N, R13W, SM K-1RD#2 At top of productive interval 9. Permit number/approval number 2185' FEL, 728' FNL, Sec. 19, T9N, R13W, SM 201-009 At effective depth 10. APl number 50-733-20054-02 At total depth 11. Field/Pool 2234' FWL, 1818' FNL, Sec 19, T9N, R13W, SM McArthur River Field / Hemlock 12. Present well condition summary Total depth: measured 13,780' feet Plugs (measured) true vertical 9,745' feet Effective depth: measu red 13,750' feet Junk (measu red) true vertical 9,722' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 75' 20" Driven 110' 109' Surface 2,349' 13-3/8", 61 # 2608 sx 2,384 2167' Intermediate Production 5,982' 9-5/8", 47/43.5# 1321 sx 6,017' 4908' Liner 7952' 7", 29# 550 sx 13,780' 9743' Perforation depth: measured (See Attachment) true vertical (See Attachment)RECEIVED Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 @ 5699' & 3-1/2", 9.2# L-80 @ 10,663' JUH 0 3 2002 Packers and SSSV (type and measured depth) .¢:.. i.~. ;i .... .~_~. 95' long ESP @ 10,663', ClBP @ 13,550' 13. Stimulation or cement squeeze summary , . , .................. . . .: ............ Anchorage Intervals treated (measured) Treatment description including volumes used an.d final pressure ,~.. : :.~--- -....::- , 14. Representative Daily Averaqe Production or Injection Data ~t~:J~j~ . ' ,G,.,a,.~c,Mc~f ......... ,:W.,Ate:~[ Casing.,~ressure Tubing Pressure Prior to well operation 212 BOPD 211 Mcfpd 1742 BWPD 1155 psi 85 psi Subsequent to operation 600 BOPD 382 Mcfpd 356 BWPD 120 psi 122 psi 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed.:~ ~'~~ Title: Form 10-404 Revi~/15/88 ORIGINAL SUBMIT IN DUPLICATE~ Zone GO-4 GO-5 GO-6 G-1 G-5 G-7/HB-1 HB3 HB-4 HB5 HB5 HB6 HB7 MD Top 11680 11732 11,780' 11,820' 11,864' 12,030' 12,090' 12,142' 12,659' 12,680' 12,710' 12,800' 12,950' 13,190' 13,230' 13,4O5' 13,445' 13,565' 13,610' MD Btm 11720 11742 11,810' 11,840' 11,891' 12 080' 12 120' 12 162' 12 674' 12 694' 12 790' 12 830' 13010' 13210' 13 370' 13 425' 13 460' 13 580' 13 650' TVD Top 8156 8194 8,229' 8,258' 8,290' 8,413' 8,458' 8,497' 8,885' 8,900' 8,923' 8,990' 9,101' 9,282' 9,313' 9,447' 9,478' 9,573' 9,609' TVD Btm 8185 8201 8,251' 8,273' 8,310' 8,450' 8,480' 8,512' 8,896' 8,911' 8,982' 9,012' 9,146' 9,298' 9,420' 9,462' 9,490' 9,585' 9,640' Amount 4O 10 3O 2O 27 5O 3O 2O 15 14 8O 3O 6O 2O 140 2O 15 15 40 Opened 5/7/01 Opened 5/7/01 Opened 5/7/01 Opened 5/7/01 Opened 5/7/01 Opened 5/7/01 Opened 5/7/01 Opened 5/7/01 Opened 5/7/01 Opened 5/7/01 Opened 5/7/01 Opened 5/7/01 Opened 7/3/01 Condition Opened 6//1501 & 7/3/01 Opened 1/13/02 Opened 1/13/02 Perf'd 1/13/02. isolated w/CIBP on 2/23/02 Perf'd 1/13/02. isolated w/CIBP on 2/23/02 18-Feb-02 19-Feb-02 20-Feb-02 21 -Feb-02 22-Feb-02 23-Feb-02 24-Feb-02 25-Feb-02 26-Feb-02 King K-1 RD#2 Daily Report of Operations Offloading equipment from boat. RU line & equip. Continue to RU equip & ND tree. NU BOPE. Function test same. Tested BOPE. PU Land joint. Remove BPV. Pulled hanger to rig floor. Remove same. POOH & stand 4-1/2" & 3-1/2" tbg in derrick. Finish POOH w/tbg. LD completion pkr. RU APRS. RIH w/Junk basket. Worked Junk Basket to 13,600'. POOH. PU CIBP on E/line. RIH set CIBP @ 13,540'. POOH & RD E/line. RU ESP running equip. PU ESP BHA. Finished PU ESP BHA. RIH w/ESP on 3-1/2" tbg x 4-1/2" completion string. Worked ESP BHA into liner top. Cont work ESP through top of liner. Continue RIH. PU tbg hanger. RI land tbg hngr w/90000# on hngr. ND BOPE. finish ND BOPE. NU tree. Tested same to 5000 psi. Release Rig. UNOCAL ) RKB to TBG Head = 33.7' Tree connection: ClBP Set (~ t 3,540' '~T ...... 10 ---- = HB-3 ~ -- HB-4 -- - HB-5 ... ---- -= HB-6 ~ _-- HB-7 PBTD = 13750' TD = 13780' MAX HOLE ANGLE = 59° @ 8485' GO-4 GO-5 GO-6 G-1 G-5 G-7 / HB-I Trading Bay Unit Well # K- 1 RD#2 As Completed 2/26/02 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61.0 K-55 12.515 35' 2,384' 9-5/8 47 N-80 BTC 8.681 35' 112' 9-5/8" 43.5 N-80 BTC 8.755 112' 6,043' 7" Liner 29 L-80 BTC-KC 6.184 5859' 13,779' Liner hanger 6.25 5850 5859 ZXP packer 6.31 5847 5850 Tieback Assembly 7.375 5828 5847 Tubing: 4-I/2" 12.6 L-80 BTC 3.958 34 5,698.79' 3- I/2" 9.2 L-80 BTC 2.992 5,698.79' 10,662.8 7' ESP Cable I/0SOLBC 3.37 5KV 90 FB 185 GAL w/(2) 0.375" SS SURF 10,714.5 1.611" X 2.361" TUBES-GAL-R 2 JEWELRY DETAIL NO. Depth ID Item 33.7 3.958 1. 2533.67 3.833 2. 4371.49 3.833 3. 5378.89 3.833 4. 5698.79 2.992 5. 6186.55 2.867 6. 6845.99 2.867 7. 7591.10 2.867 8. 8347.06 2.867 9. 10,622.14 2.66 10. 10,662.87 12" x 4-1/2" FMC 8rd Tbg Hngr 4-1/2" GLM #1 SFO-2 (7.063" OD) 4-1/2" GLM #2 SFO-2 (7.063" OD) 4-1/2" GLM #3 SFO-2 (7.063" OD) crossover 4- I/2" x 3- I/2" 3-1/2" GLM #4 GLMAX-I.0 (5.968" OD) 3-1/2" GLM #5 GLMAX-I.0 (5.968" OD) 3-1/2" GLM #6 GLMAX-1.0 (5.968" OD) 3-1/2" GLM #7 GLMAX-I.0 (5.968" OD) "XN" Profile Nipple, 2.813 Centrilift ESP Pump & Motor BHA. Length=94.73' PERFORATION DATA 20 ne .... . T'0p ....... : B~m 'A'm ou'nt ~" ! c0'nd'ii'i0n GO-4 11680 ' 11720 ! 40 Opened 5/7/01 GO-6 : 11,780' ' 11,810' 30 'Opened 5/7/01 11,820' 11,840' 20 i' Opened 5/7/01 ' ........ i":i';~"~3,'; ............... :1";f:§'~i"; .... ; :2'7 :'6P'¢'h~8"g/Yi0'i ; , ;; ....... G.-_! ............ !.2.,?.37.: . ..... .1.._2.~8__0: 5_0` ........ 12,090' 12,120' 30 i Opened 5/7/01 ............................ ?~.1..~..2: ....... :: ....... !.2_L?._2'. 2..0. Op~n~.d_~5.(~(..0...! ..................................... G-5 12,659' . 12,674' 15 Opened 5/7/01 ,' ..... :1'2';i~'~6'~ . ~','~'9~~ ~4 "6b'e'/i~'"5')~61 ~ ....... ~'~';'~-6' ..... "-~':~96' .... ; ...... ~0 :6'~-~'~8~5~/~6~ ................................................... G-7/HB-1 ! 12,950' . 13,010' 60 Opened 7/3/01 HB3 ' 13,190' 13,210' 20 HB-4 13,230' 13,370' 140 Opened 6111501 & 7/3/01 i2ii~5 ' :1'3,'3,-0~' :.'1~13,'2'5; 2'0 o'pened i'/i3~O2 HB5 13,445' i'313,60; :15 :' 6'~'6 k ~d-"¥/-i-~6~ ...................... HB6 13,565' 13,580' 15 Perf'd 1/13/02. isolated w/ClBP on 2/23/02 HB7 13,610' 13,650' 40 :Perf'd 1/13/02. isolated w/CIBPon 2/23/02 ' K- 1 RD2 Actual 02-26-02 REVISED2/26/02 Unocal Alaska 909 W. 9th Avenue . Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb @ unocal.cum UNOCAL Beverly Harrison Business Ventures Assistant DATA TRANSMITTAL February 5, 2002 To: Lisa Weepie Alaska Oil & Gas 333 W 7th Ave, # 1 O0 Anchora~le, AK 99501-3539 From' Beverly Harrison Unocal Alaska 909 W. 9th Avenue Anchora~te, AK 99501 Transmitting the following: I:,.::,.':~.':~.."~:':~::~;i: LO,G~,~P,E;~':~::...::i.?:':~~:.'':.'. -'i",SCAEE '.:LOG'DATE': ;.:..INTERVAL'.: .. cOPIES'~i,.,::~:i :..,':,Weli:?',,',..~!i..iMedium..I _ __~ IDIPHOLE SONIC IMAGING 5 INCH 12/27/2001 0-5630 1 A-15RD ..~!!.m ao]-I~ i'i~iP"R'~i'"'~'"'§'O'hi'~'"i"~'A'~i'N'~"""":"5"'i'R'~'N ........... ~ ............. i"~)~7/~'~ ............................ ~;'~'b ....................... ' ...................... ~ ..................... ~"~:'~"~'~'~ B-Line ~ ~ ~"~'~'~'~'~i"O'~'"'~'E'b'~'~'b ....................... 5'"'i'N'~'~ ~"/8/~6b'~ ................ ~'~6b':~'~"~"~' ~ ...................... ~"~'0'"~'"'2:'~' ................ ~i'i'~ .......................... /Mo- ua ~ ~"56~'~'E~¥i6'~""~'~"~6"~6'": ................ '~""i~'~'~ ........... ~ .......................... ~'/~'~6~ ~'~'~6:'~'~'~'~ .................................... ~ ...................... ~"~'~'0"~'~:'~"~"""l"~'ii'~- ...................... '~1 ?'b'b"~'~'E~'~'i'~'~'"'~'~'~6~'~ .................. ~"~'"'i'~'~'~ ............................... ~'~'~"~/~'6~' ............ ~"~'~:'~"~"~"~ ............................... ~ ........................ ~':'~"~ .......................... '"~'ii~ ........................ ~/'°°9 "~6~'~'E~'~i6~'"'~'~6~'~ ................... ~'~"~'i'~b'~~ ............................ '~'/~"'~/~6~"; ......... ~"~"~'~:"~"~"~'"~ .............................. ~ .................... k:¥~6~ ........................ ~"~:'Ei'~'~ ............... ; ~'9AKER N-2 BRIDGE PLUG 5 INCH 11/28/2001 1 ~M-12 Film '~-/1~ ~6'6~'E~6~'~'~i'~ .............................. ~'~'i~'~' ..................... ~~'~6'~ ................... 'i'"~'7~':~'~b' ............. ~ ...................... '~ ....................... ~:~'"~"~'6'''''~'''' ................ ~"~i'i'~ ................... bo,-~ /~'b'6~'~'"6'~'~'~'~i'~ ................................... ~'"'i'~'~'~ ........................ ~"~~6~ .................. ~"6~:~'~'~b' ..................................... ~ ....................... ~:'~"~'~6 ........................... ~"~':~i~'~ .............. ~J ?~'~'~'i'~'~'"'~i'~'R'~ ................................... ~"~'"iN'~'~ ......................... ~"~~'~ ......................... 6;'~"b'~'~ ........................ ~ ..................... ~ ....................... ~;'~"~'~6 ............................. ~i'i'~ ......................... ~/ Received b Date: r"~AR 0 ,'.i. 2002 Alaska 0il & Gas Cons. CommiWon ALASKA OIL AND GAS CONSERVATION COHHISSION February 20, 2002 TONY KNOWLES, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 UNOCAL Field Superintendents 260 Cavair Street Kenai, Alaska 99611 RE: No-Flow Verification TBU Well K-1RD2 ~.i~.~i~.~,0~'"';'~''~' TBU Well K-12 PTD 178-057 Gentlemen: On February 8 - 9, 2002 AOGCC Petroleum Inspector Lou Grimaldi witnessed "no-flow" tests on Wells K-1RD2 and K-12 at UNOCAL's King Salmon Platform, Trading Bay Unit, McArthur River Field. Mr. Grimaldi arrived on King Salmon Platform and proceeded to observe the wells. Over the course of the nearly 3 hour witnessed periods, the test performance of TBU wells TBU Well K-1RD2 (201-009) and K-12 (178-057) demonstrated that the wells are incapable of unassisted flow of hydrocarbons to the surface. Therefore, these wells need not be equipped with a commission approved fail-safe automatic surface-controlled subsurface safety valve ("SSSV") system. However, these wells must be equipped with fail-safe automatic surface safety valve ("SSV") systems capable of preventing uncontrolled flow and maintained in proper working condition. If for any reason any of the wells become capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well files on board King Salmon. Sincerely, Thomas E. Maunder,~E~~ Sr. Petroleum Engineer TEM/jjc Unocal Corporation j~ P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager February 6, 2002 RECEIVED ~as~aC)~&GaSO°~s'C°~s~°~ Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attention: Mr. Tom Maunder Subject: Trading Bay Unit Well K-1 rd2 APl No. 50-733-20054-01 10-404 Perforate Hemlock Dear Mr. Maunder: Please find enclosed in duplicate Form 10-404 for the perforation of the Hemlock in well K-1 rd2. The following intervals were perforated on 1/13/02: Bench Top Bottom Feet HB7 13,610 13,650 40 HB6 13,565 13,580 15 HB5 13,445 13,460 15 HB5 13,405 13,425 20 HB3 13,190 13,210 20 If you have any questions, please contact Ralph Holman at 263-7838. Sincerely, ,(~ Dan Williamson Drilling Manager RECEIVED Alaaka Oil & Gas Cons. Commis~on , O('' STATE OF ALASKA (' ALASKA L AND GAS CONSERVATION uOMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 100' KB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Trading Bay Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface Conductor #26, Leg 4 8. Well number 135' FEL, 724' FSL, Sec. 17, T9N, R13W, SM K-1 rd2 At top of productive interval 9. Permit number/approval 891' FNL, 2416' FEE, Sec. 19, TSN, R13W, SM ADL 18777 At effective depth 10. APl number '"~" .......... ' 50-733-20054-01 At total depth 11. Field/Pool 1401' FNLL, 2479' FEL, Sec. 19, T9N, R13W, SM McArthur River/Hemlock 12. Present well condition summary Total depth: measured 12570 feet Plugs (measured) 12214 (retainer) true vertical 9717 feet Effective depth: measured 12234 feet Junk (measured) 12180 (fish) true vertical 9469 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 110' 20" Driven 110' 110' Surface 2384' 13-3/8" 2608 sx 2384' 2149' Intermediate Production 9709' 9-5/8" 1321 sx 9709' 7672' Liner 12566' 7" 550 sx 12566' 9714' Perforation depth: measured 11680-11720, 11732-11742, 11780-11810, 11820-11840, 11864-11891, 12030-12080, 12090-12120, 12142-12162, 12659-12674, 12680-12694, 12710-12790, 12800-12830, 12950-13010, 13190-13210, 13230-13338, 13405-13425, 13445-13460, 13565-13580, 13610-13650 true vertical 8156-8185, 8194-8201, 8229-8251, 8258-8273, 8290-8310, 8413-8450, 8458-8480, 8497-8512, 8885-8896, 8900-8911, 8923-8982, 8990-9012, 9101-9146, 9282-9298, 9313-9395, 9447-9462, 9478-9490, 9573-9585, 9609-9640 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 @ 5696'; 3-1/2", 9.2#, L-80 @ 11327' Packers and SSSV (type and measured depth) Baker HS Ret. Pkr. @ 11269', Baker TE-5 SSSV RECEIVED 13. Stimulation or cement squeeze summary FE~'~ .~ ~. 200? Intervals treated (measured) Alaska 0il & Gas Con~. Commissior~ Treatment description including volumes used and final pressure 14. Representative Daily Avera,qe Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1001 222 119 1120 90 Subsequent to operation 472 140 772 1125 70 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ~,~ ~ ~¢,,~ /,~"(,~,~,,- Title: ~c~ /~,'/~ ~~ Date: /~,~, Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: childersd@unocal.com UNOCAL Debra A. Childers Technologist DATA TRANSMITTAL August 23, 2001 To' Lisa Weepie 333 W 7th Ave, # 100 Anchorage, AK 99501-3539 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99501 Unocal Alaska Transmitting the following' ,, o/-oocl TBU K-1RD2 CASED HOLE FORMATION / GR 5 INCH 4/25/01 11560-13720 1 B-Line d'BU K-1RD2 CASED HOLE FORMATION/GR 5 INCH 4/25/01 11560-13720 1 Film /T,BU K-1RD2 COMPLETION RECORD 2.5" HSD PJ 6 SPF 5 INCH 5/4/01 8100-13716 1 B-Line ~'BU K-1RD2 COMPLETION RECORD 2,5" HSD PJ 6 SPF 5 INCH 5/4/01 8100-13716 1 Film ,,.BUK-1RD2 COMPLETION RECORD 2.5" HSD PJ 6PF 5 INCH 7/3/01 127OO-1352O 1 B-Line BU K-1RD2 COMPLETION RECORD 2.5" HSD PJ 6PF 5 INCH 7/3/01 12700-13520 1 Film ... B U K-1RD2 COMPLETION RECORD 2.5" HSD POWER JET 6 SPF 5 INCH 6/14/01 12600-13570 1 B-Line U K-1RD2 COMPLETION RECORD 2'.5" HSD POWER JET 6 SPF 5 INCH 6/14/01 12600-13570 1 Film .... ,,T,,'BU K-1RD2 REAL TIME MEASURED DEPTH LOG / COMPOSITE FIELD 2 INCH 3/24/01 6000-13530 1 B-Line PRINT ~:BU K-1RD2 RST SIGMA POROSITY/GR-CCL 5 INCH 4/24/01 9050-13714 1 B-Line ... ,,TBU K-1RD2 RST SIGMA POROSITY / GR-CCL 5 INCH 4/24/01 9050-13714 1 Film ,., TBU K-1RD2 SURVEY REPORT 1 PAPER TBU K-1RD2 GLOBAE SOLVER 1 NOTE BOOK ~ ~BU K-1RD2 FORMATION EVALUATION ASCII DATA 1 CD ROM V FORMATION EVALUATION LOGS SURVEYS ,,T'BU K-1RD2 PDS LOGS 1 CD-ROM RECEIVED Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 2_6_3.-7828, AI~ Oil & Gas Cons. C~mmi~n Anchorage Schlumberger ELAN Global Solver Company Field Well Date Logged Date Processed Reference Number APl Number Log Analyst : UNOCAL : McArthur River : TBU K-IRD2 : 25-APR-2001 : 21-MAY-2001 : 21155 : 50-733-20054-01 : Douglas Hupp Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 (907) 273-1700 RECEIVED AUG ~ ? 200~ Alaska Oil & Gas Cons. Commiss~c... Anchorage interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations and shall not, except in the case of gross or willful negligence on our part, be liable or responsible for any loss, cost, damages or expenses incurred or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees. These interpretations are also subject to clause 4 of our general terms and conditions as set out in our current Iprice schedule. UNOCAL ,,Job Number 21155 1. Introduction Well K-1 RD2 Field McArthur River This report presents the results of Schlumberger's petrophysical analysis of well logs run on UNOCAL's well TBU K-1RD2. This well is located on the King Salmon platform located in the Cook Inlet, Alaska. Well logging information used in this interpretation included Sperry Sun resistivity, gamma ray, and bulk density data along with Schlumberger RST neutron porosity and sigma data. The purpose of this analysis was to evaluate the gas potential of two intervals located at 9060 ft to 9370 ft and 9610 ft to 9798 ft. The formations in the intervals evaluated consist of interbedded sand, shale, and coal. This interpretation was performed with Schlumberger's Elemental Log Analysis (ELAN)software using models developed specifically for the logging data available. The ELAN results consist of sand volume, illite volume, bound water volume, effective porosity, water saturation, oil saturation, and gas saturation. A log presentation is included in this report displaying the ELAN interpretation results. 2. Data Preparation The digital data of the Sperry LWD data was obtained from UNOCAL and the RST data was delivered to Schlumberger's Anchorage office from the Kenai field location. All data was depth shifted to the GR/OCL correlation log from 04-MAY-2001 at UNOCAL's request. A visual inspection of the data indicated that it was of good quality. The Sperry neutron porosity and RST neutron porosity overlay showed good agreement. An overlay of the Sperry and Schlumberger gamma ray logs indicated similar character with the expected offset due to the presence of metal casing and cement during the RST log. Environmental corrections had been applied to the RST log data in the field. This field data was used in the interpretation. The Sperry LWD data was assumed to have been environmentally corrected prior to delivery to Schlumberger. 3. Formation Evaluation The ELAN interpretation software utilizes a global solver to interpret well logging data based on a custom model developed for the local geology and available measurements. The custom built models include formation and fluid volumes, and equations describing each input measurement response. The ELAN solver adjusts calculated volumes until the input log reconstruction error is minimized. Two ELAN models were used in this interpretation, one for the sand and shale intervals, and a second model for coal and absent readings. UNOCAL .Job Number 21155 The sand and shale model consisted of the following solved quantities: Well Ko1 RD2 Field McArthur River · Volume Illite · Volume Quartz · Volume BoundWater · Volume Water · Volume Oil · Volume Gas Fluid saturations are based on a Dual-Water model. Input water resistivity used in this interpretation was 0.42 ohm-m at 77 °F (0.21 ohm-m at 150 °F). The coal model was used to identify coal formation and zones with missing data. The coal calculations simply substituted 100% coal with zero porosity for the formation volumes. Coal intervals were manually zoned based on Iow density (high density porosity) and high neutron porosity or where data was missing. 4. Discussion of Results: The intervals evaluated in this interpretation consisted on sands and shaly sands interbedded with coal. The sands have porosity ranges between 8% and 20% with Sw ranging from 70% to 80% in the clean sands. Gas saturations typically range from 10% to 25% with less than 10% So. One standard quick look technique used to identify gas is to compare the density and neutron porosity curves. In a clean sand containing gas, the neutron porosity typically reads lower than the density porosity (cross-over). This technique is dependent on having both porosities displayed on correct formation types. The enclosed log print displays the density and neutron porosity, in sandstone units, showing little to no cross over, indicating little to no gas present in the zones of interest. ' i STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Unocal Oil Company of California (UNOCAL) 201-009 3. Address 8. APl Number P. O. Box 196247, Anchorage, Ak 99519 50- 733-20054-1 4. Location of well at surface '~''" ' ..... ";" ~ 9. Unit or Lease Name -/-/-,//-~//~"'~'Tq . ~ . Trading Bay Unit/McArthur River Field 135' FEL, 724' FSL, Sec 17, T9N, R13W, SM ~ At Top Producing Interval -, ~ -~ 10. Well Number 4~~' FEL,-t~43C~FNL, Sec 19, T9N, R13W, SM: ~"' ~' " K-1RD 2 At Total Dep~ 7,1~ ............. ? _ [ 11. Field and Pool ~lCJ~F~r_,"i'~r~"FNL, Sec 19, TgN, R13W, SM Mc Arthur River Field / Hemlock '5. E~levation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 100' KB above MSLI ADL 17594 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 3/22/01 4-17-01 5-7-01 62 feet MSLI 1 17. Total Depth (M D+TVD) 18. Plug Back Depth (MD+TVD)I 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 13,780'MD/9,745' TVD 13,750' MD / 9722' 'TVD Yes: x No: 340 feet MD NA 22. Type Electric or Other Logs Run Schlumberger RST 13742 - 11300', 9800 - 9610', 9350 - 9050' Sperry MWD GR/RES/N-D 8525' - 12157' Schlumberger CHRT 12770-12650', 12580-12320', 12170-12010', 11800-11700', 11635-11560' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Surf 110' Driven Driven 0 13-3/8" 61¢ J-55 Surf 2384' 17-1/2" '2608 sx 0 9-5/8" 47/43.5¢ N-80 Surf 6017' 12-1/4" 1321 sx 0 7" 29# P-110 5828 13780' 8-1/2" 550 sx Window cut f/6017'- 6032' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) All perfs below are 2-1/2" power jet, 6 spf SIZE DEPTH SET (MD) PACKER SET (MD) GO-4 11680 - 11720 4-1/2" 35- 5696' GO-5 11732- 11742 3-1/2" 5697'- 11327' 7" Baker Ret. Pkr @ 11269' GO-6 11780 - 11810, 11820 - 11840, 11864 - 11891 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. G-1 12030-12080, 12090-12120, 12142-12162 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED G-5 12659-12674, 12680-12694, 12710-12790 G-5 12800-12830, 12750-12790, 12800-12810 GT/HB1 12950-13010, HB4 13230-13338 Top Perf 8157' TVD, Bottom Perf 9396' TVD 27. Abandoned Date First Production I Method of Operation (Flowing, gas lift, etc.) 5/7/2001 I flowing Gas lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 7/4/-2001 24 TEST PERIOD => 1098 294 165 NA 268 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 70 1115 24-HOUR RATE => 1098 294 165 32 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED JUL 0 5 Alaska Oil & Gas Cons. Commission Anchorage AFE #143749 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 0 1p~ [ G i N A L 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 lime of each phase. Tyonek E 8710' 6409' Tyonek F 9916' 7056' Tyonek GO4 11667' 8147' Tyonek G1 12011' 8399' Tyonek G5 12655' 8882' Tyonek G7 12930' 9086' Hemlock / HK1 13003 9140' HK2 13060 9184' HK 3 13173 9270' HK 4 13228 9312' HK 5 13404 9446' HK 6 13493 9516' HK 7 13582 9586' West Foreland 13662 9650' TD 13780 9744' 31. LIST OF ATTACHMENTS Wellbore schematic, Summary of Daily Operations 32. I hereby c_,~'~'~ that the f°r'eg°ing/~ t~ 'l r, and correct to the best of my knowledge Signed",-J ~_~~/~ ~I J~i~~~itle Drilling Manaqer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other 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. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Form 10-407 Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. RECEIVED Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". JUL 0 5 001 Alaska 0il & Gas Cons. Commission UNOCAL ) {' {i Trading Bay Unit Well # K-1RD2 17 RKB to TBG Head = 33.7' Tree connection: 1 G zone -- --Perfs ---'~--Proposed = =Perfs PBTD = 13750' TD = 13780' MAX HOLE ANGLE = 59° @ 8485' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61.0 K-55 12.515 35' 2,384' 9-5/8 47 N-80 BTC 8.681 35' 112' 9-5/8" 43.5 N-80 BTC 8.755 112' 6,017' 7" Liner 29 P-110 BTC-KC 6.184 5859' 13,'/79' Liner hanger 6.25 5850 5859 ZXP packer 6.31 5847 5850 Tieback 7.375 5828 5847 Asembly Tubing: 4-1/2" 12.6 L-80 BTC 3.958 35 5696' 3-1/2" 9.2 L-80 BTC 2.992 5697' ! 1.327' JEWELRY DETAIL NO. Depth ID Item 33.7 3.958 12" x 4-1/2" FMC 8rd Tbg Hngr 1. 3.958 4-1/2" L-80 12.6 #/ft BTC tubing 2. 338 - 343 3.81 Baker TE-5 TRSSSV (824-94-3805) / Upper SV Sub (824-94-3805) / Lower SV sub (824-94-3805) 3. 3.958 4-1/2" 12.6 #/ft L-80 BTC tubing 4. 2527 3.833 4-1/2" GLM gl SFO-2 (7.063" OD) 5. 4488 3.833 4-1/2" GLM #2 SFO-2 (7.063" OD) 6. 5561 3.833 4-1/2" GLM #3 SFO-2 (7.063" OD) 7. 5697 2.9!)2 c]'ossovcr 4-1/? x 3-1/2" 8. 2.992 3-1/2" L-80 9.2 #/ft BTC tubing 9. 6342 2.867 3-1/2" GLM #4 SFO-2 (5.968" OD) 10. 7227 2.867 3-1/2" GLM #5 SFO-2 (5.968" OD), 11. 8107 2.867 3-1/2" GLM #6 SFO-2 (5.968" OD) 12. 8990 2.867 3-1/2" GLM #7 SFO-2 (5.968" OD) 13. 9868 2.867 3-1/2" GLM #8 SFO-2 (5.968" OD) 14. 10720 2.867 3-1/2" GLM #9 SFO-2 (5.968" OD) 15. 11188 2.867 3-1/2" GLM #9 SFO-2 (5.968" OD) 16. 2.992 3-1/2" 9.2 #/ft L-80 Butt. tubing 17. 11269 3.00 Baker 7 x 3-1/2 HS Ret. Packer (784-60-6000) 18. 2.992 3-1/2" L-80, 9.2 #/ft Butt tubing 19. .11316 2.81 Baker "X" Profile Nipple 20. 11327 2.992 Baker Shear Out Ball Seat Sub / WL re-entry guide PERFORATION DATA Zone Top Perf Bottom Perf Feet condition GO-4 11680 11720 40 2-1/2" Power Jet 6spf GO-5 11732 11742 10 2-1/2" Power Jet 6spf GO-6 11780 11810 30 2-1/2" Power Jet 6spf GO-6 11820 11840 20 2-1/2" Power Jet 6spf GO-6 11864 11891 27 2-1/2" Power Jet 6spf G-1 12090 12120 30 2-1/2" Power Jet 6spf G-1 12030 12080 50 2-1/2" Power Jet 6spf G-1 12142 12162 20 2-1/2" Power Jet 6spf G-5 12659 12674 15 2-1/2" Power Jet 6spf G-5 12680 12694 14 2-1/2" Power Jet 6spf G-5 12710 12750 40 2-1/2" Power Jet 6spf G-5 12750 12790 40 2-1/2" Power Jet 6spf G-5 12800 12810 10 2-1/2" Power Jet 6spf G-5 12810 12830 20 2-1/2" Power Jet 6spf G-5 12750 12790 40 2-1/2" Power Jet 6spf G-5 12800 12810 10 2-1/2" Power Jet 6spf G-7, HB1 12950 13010 60 2-1/2" Power Jet 6spf HB4 13230 13338 108 2-1/2" Power Jet 6spf K-IRD2 Schematic (2).doc REVISED: 5/8/01 Unocal Alaska Drilling Drilling Summary Report K-1RD2 Rig 58 3/21/01 7/3/01 3-21-01 Pressure test TDS manual valve, IBOP, and standpipe to 250/3000 psi, OK, Install sheaves for finger pull back. Blow down standpipe, top drive, test pump, trip tank line, freeze protect test pump. R/U welders in derrick to install protection for TDS service loop. Top off OBM-450 bbls in pits, 150 bbls coil tubing tank. Complete installation of protection system in derrick for TDS service loop. Drain pill tank and fill with water. Drain trip tank. P/U BHA, Whipstock milling assembly, RIH, test MWD, M/U & RIH Baker 9-5/8" Windowmaster Whipstock assembly on drill pipe to 3371' 3-22-01 RIH w/BOT 9-5/8" WindowMaster whipstock assemble to 5915'. Break circulation and orientated face of whipstock to 30R. Continue to RIH to 3039' and set whipstock on top of cement retainer @ 31R. Confirm w/5K pull up & set down w/35K lbs and shear bolt. Pull to neutral weight. Test lines for OBM displacement. Pump 50 bbls of base oil & 40 bbls of OBM. Return line froze. Thaw out line. Resume OBM displacement. Mill window from 6017' to 6045'. 3-23-01 Continue to mill window from 6046'. Clean flow lines. Finish milling window to 6051 & check for drag. Circulate bottoms up & polish window. Perform FIT w/650 psi + 8.9 ppg MW = 11.6 EMW. Blow down lines & POOH. L/D BHA. Change out safety cables & install clamps on crash bar on service loop. P/U & test BHA #2. RIH. 3-24-01 Continue to RIH. Move eight stands of DP that had cement sheath in side. Continue to RIH to 6039'. Orient drilling assembly to 50R. Wash & ream to 6051'. Directional drill 8- 1/2" hole (rotary & slide) from 6051' to 6617'. 3-25-01 Directional drill 8-1/2" hole (rotary & slide) from 6617' to 7550'. 3-26-01 Directional drill 8-1/2" hole (rotary & slide) from 7550' to 7792'. Circulate. POOH to 6000'. Drop dart & pump dry job. Finish POOH. L/D bit & SP motor. Make up bit #2 Hycalog PDC. Test MWD. RIH to 6000', fill pipe & orient to 40R. Bent hydraulic cylinder on link tilt. Continue RIH 7707'. Reamed from 7707' to 7792'. Circulate to get rate up to 500 gpm. 3-27-01 Directional drill 8-1/2" hole(rotary & slide) from 7792' to 8639'. Repair leak on top drive. Drill from 8639 to 8732'. Adjust oil sensor. Drill from 8732' to 8939'. Stop drilling and let grind & inject unit catch up. Drill & slide from 8969' to 9007'. 3-28-01 Drill & slide 8-1/2" hole from 9007' to 9383'. Circulate & POOH to 6017'. Replace shot pin assembly on top drive pipe handler. Change out oil sensor on top drive. Pick up 72 singles while RIH. Repair rod oiler on pump #2 & repair coupling on motor x pump. 3-29-01 3-30-01 3-31-01 4-1-01 4-2-01 4-3-01 4-4-01 4-5-01 4~6-01 4-7-01 4-8-01 Finish repairing mud pump #2. Drill and slide 8-1/2" holefrom 9383' to 9673'. Change swabs on pump #2, change switch on derrick camera, change dies in air slips. Drill & slide from 9673' to 9926'. Drill and slide from 9926' to 10460'. Circulate and condition mud. Finish circulating & conditioning mud. POOH w/tight spot at 9920' (35K lbs). Finish POOH w/no additional tight spots. Test choke manifold, BOPE and equipment to 250/3000 psi, AOGCC waived witness. P/U bit #3, test MWD & motor. RIH to 6000' and fill pipe. Slip & cut drilling line. Continue RIH. Wash and ream from 10340' to 10460'. Drill and slide from 10460 to 10472'. Drill and slide 8-1/2" hole from 10472' to 10560'. Change out washed out swab on pump #2. Circulate w/pump #1 @ 40 SPM w/1170 psi. Drill and slide from 10560' to 10914'. Drill and slide 8-1/2" hole from 10914' to 11018'. Circulate and reciprocate while checking lost pressure, continue drilling w/one pump. Drill and slide from 11018 to 11259'. Drill and slide 8-1/2" hole from 11259 to 11521' Slide from 11521 to 11526'. Stand pipe hammer union started leaking. Remove & repair hammer union o-ring. Test line to 250/4000 psi. R/D circulating pin head & make up stand. Wash and ream to bottom. Drill and slide from 11526' to 11595'. Unable to slide. Circulate bottoms up. Change swab in pump #1. POOH to BHA. Prep to cut drill line. Slip and cut drill line. Finish POOH & L/D BHA. P/U DP in stands and stand back. M/U Sperry Sun LWD Memory Logging tools & M/U BHA #5 & bit #4. Attempt to repair Quadco depth control sensor. Re-install Schlumberger, Epoch & Sperry Sun depth control sensors. Load and calibrate Sperry LWD. RIH and fill pipe at 3835 & 6000'. Kelly up & break circulation at 8525'. Start Mad Pass w/Sperry Sun GR/RES/N-D Memory tool from 8525' to 8996' at 40 RPM, 2 BPM & logging in hole rate of 180 ft/hr. Continue Sperry Sun GR/RES/N-D Memory Mad Pass logging from 8996 to 11172'. Repair top drive electical malfuntion on ISOP control. Continue Mad Pass logging from 11172' to 11595'. Ream from 11581 to 11595'. Drill, slide and LWD 8-1/2" hole from 11595 to 11607'. Drill, slide and LWD 8-1/2" hole from 11607' to 11775'. Blow pop off on both pumps w/closed ISOP, reset & school on same. Drill, slide and log 8-1/2" hole from 11775' to 11915'. Drill, slide and LWD 8-1/2" hole from 11915' to 12154'. 4-9-01 4-10-01 4-11-01 4-12-01 4-13-01 4-14-01 Drill, slide and LWD 8-1/2" hole from 12154' to 12157'. Circulate and survey. Lost swab in pump #1. POOH to 6000'. Pull torque tube back in proper position & tighten bolts. Check bolts on crown, and remove stabbing board for repair. Continue to POOH. Remove source and L/D Sperry Sun LWD Memory Tool. Test BOP & Equipment to 250/3000 psi. State waived witness on BOP test. M/U & RIH w/bit #5 & BHA #6. P/U, strap & drift 5" DP. Continue to P/U, strap & drift 5" DP (45 jts). TIH & fill pipe at 3000'. Adjust torque tube and tighten bolts. Adjust brakes. TIH and fill pipe at 6000' and 9000'. Ream from 11783' to 12157'. Drill 8-1/2" hole from 12157' to 12302'. Top drive shut down due to air conditioning in MCC going down. Restart air conditioning & cool down MCC. Drill 8-1/2" hole from 12302' to 12495'. Drill & slide 8-1/2" hole from 12495' to 12854'. Slight seepage losses from 12750 to 12820' (30 bbls). Drill from 12854' to 13114' (slow penetration & hard walk right). Circulate B/U & POOH. Hole not filling properly, pump out of hole. Had 45 k lbs over pull at 13067'. Pulled good to 12388 and hole packed off hole. Worked free and back reamed to 11860' with little resistance. POOH clean to shoe w/proper fills. Finish POOH & L/D BHA. P/U new bit #6, motor & jars on BHA # 7. RIH. Slip and cut drilling line. RIH filling pipe at 3000, 6000 & 9817'. Set down 11945'. Kelly up and washed down w/little resistance. RIH to 12110' and set down. Kelly up, rotated through and had heavy motor work to 12250'. RIH to 12269' and set down. Kelly up and rotated through with no resistance. Ream from 12994' to 13114'. Drill 8-1/2" hole from 13114' to 13210'. Drill 8-1/2" hole from 13210' to 13315'. Circulate and condition mud. POOH to 13244'. Pulled 50 klbs over. Attempt to work through w/o success. Kelly up & back ream with out resistance. POOH to 12869', pulled 50 Klbs over and worked through on 3rd attempt. POOH to 12678', pulled 50 klbs over and worked through on 2nd attempt. 12667' to 12625' (coal) pulled 50 klbs over, kelly up and back reamed with high torque. POOH to 12250, pulled 50 klbs over, attempt to work through, kelly up and back ream with high torque to 12225'. Back ream to 11900' when weight indicator smooth out. POOH, changed BHA & bit & set AKO to "0". P/U bit # 7. RIH w/HWDP and test MWD. Clean rig floor, change quick release on high drum clutch, weld down automatic driller on drawworks, re-center top drive and weld stops on torque tube support brace. 4-15-01 4-16-01 Finish welding torque tube stops and Wildcat automatic driller hook-up. RIH with bit #7. Set down at 12353', kelly up and rotate through with out resistance. RIH and set down at 12640', 12701', 12712', 12767' and 12777' (each set down worked through on second attempt.) Safety ream 13115 to 13315' with no resistance. Drill 8-1/2" hole from 13315' to 13559'. Drill 8-1/2" hole from 13559' to 13758'. Circulate and pump Hi-Vis pill around and sweep hole. Pump and spot ventrol pill from 13578' to 11900'. POOH to 11600'. Tight spots 4-17-01 4-18-01 4-19-01 4-20-01 4-21-01 and pulled through with 75 klbs at 13367, 13244', 13158' and 13085'. Kelly up and back ream 12975 - 12890' with max torque of 22-28 klbs. Pulled to 12677' and packed off. Worked free. 12677 to 12605' worked through with 75 klbs. Pulled to 12424', 12424' to 12220' worked pipe to 50 klbs, kelly up and pump through without resistance. Pulled to 12050', worked pipe to 50 klbs and kelly up and circulated well clean. Pull to 11900' where hole drag smooth out. POOH and L/D BHA. Test BOP and equipment to 250/3000 psi, AOGCC waived BOP test witness. M/U bit # 8 & BHA # 9. RIH and fill drill pipe at 3000 & 6000'. Slip and cut drilling line. RIH to 10,915'. RIH & set down at 12313' and 12640'. Kelly up and rotate through without further resistance. Precautionary wash and ream from 13529' to 13578'. Drill 8-1/2" hole from 13578' to 13770'. Both pumps fail, work pipe while replacing swab and liner in each pump. Bring up pumps and packed off. Worked pipe and established circulation. Drill to 13780'. Circulate well clean. Make short trip to shoe. No tight spots observed. Circulate bottoms up. Spot 100 bbl ventrol pill. POOH. Tight spot at 13239' to 13190', pulled through on 3rd attempt with 100 klbs. Tight spot from 13105 to 13051', kelly up and pumped through. Tight spot 13037', kelly up and pump and back ream. POOH to 11500' with no resistance. Mix and pump dry job. POOH to 6000'. Inspect TDS tilt link crank assy. Found 2 cracks in fiberglass bushings and 2 sintered bronze bushings and crank pin. POOH to BHA. Stand back HWDP. L/D lead collar, stab, motor & bit. M/U bit #8 & BHA #10 w! Anadrill LWD logging tools. Load source. RIH w/LWD tools (ADN & CDR) filling pipe at 3000' & 6000'. Set down at 7594'. Kelly up & ream through. RIH filling pipe every 2000'. Set down at 12450'. Kelly up & ream trhough. RIH to 12524'. Attempt to work through and hung up. Kelly up w/full circulation. Jarred tools free w/60-80 klbs over and 20 klbs of torque. RIH & set down at 12772'. Work pipe & hung up. Circulate w/full circulation. Jar w/60 -100 over, slump w/50-80 klbs w/20 klbs of torque. Established 7' of pipe movement. Worked and freed pipe. Circulated hole clean while rotating and reciprocating pipe. POOH to 11600' (worked through tight spots at 12564', 12100', 11100 & 10950' by pumping and back reaming). POOH to BHA. Retrieve source and L/D Anadril's tools (ADN & CDR). M/U bit #8, motor & BHA #11. RIH to 6000'. Slip & cut drilling line, inspect link tilt and TDS. RIH to 13780' and saw no resistance. Circulate bottoms up. POOH. L/D 177 jts 5" DP & BHA. Pull wear bushing. Change top rams to 7" rams. Set test plug & shell test. P/U BOT cement head & make breaks. Change out DP pup jts from 5' to 15'. L/D cement head. Change out bails on TDS. R/U GBR and 7" casing equipment. P/U & RIH w!184 jts of 7" 29# P-110 KC_BTC casing. M/U Baker 7" x 9-5/8" Flex liner har w/liner top packer. RIH w/7" casing on drill pipe. M/U cement head on DP and establish circulation at 2.5 BPM w!650 psi. Slack off and tag bottom w!7" casing at 13780'. Unable to P/U casing string. Circulate & condition mud. Increase circulation to 4.5 BPM w/900 psi. Attempt to P/U casing w/no movement at 450 Klbs. Drop 1.75" Kirtsite setting ball. Pump to landing collar & pressure up to 1800 psi & set liner hanger. Pressure up to 2700 psi & released setting tool. Slacked off 30 klbs and pressured up to 3500 psi. No ball shear out. Worked pressure up from 4000 to 5000 psi with test pump. Sheared out and established circulation at 4.5 BPM & 900 psi. Circulate bottoms up. Mixed and pumped 10 bbls of Chem Wash 101,183 bbls of Dowell's Litecrete, 5 bbls of filtered inlet water. Displace DP wiper rubber with OBM. Displace DP w/100 bbls of drilling fluid and bumped plug 4-22-01 4-23-01 4-24-01 4-25-01 4-26-01 4-27-01 wi2000 psi. Good returns though out cement job. P/U 8' exposing setting dogs. Slacked off to set ZXP packer. Set 56 klbs down to set packer and slacked off to 70 Klbs P/U 32' and closed annular. Tested casing to 1500 psi for 15 minutes. Reversed out 2x drill pipe volume. L/D cement head. POOH & stand back 63 stands of DP. L/D 72 jts of 5" DP. L/D BOT liner hanger tool. Change out 7" rams to 5" rams and test. Change out breakout cathead with Grayling Rig 55's cathead. Back Icad boat with DP & cement equipment. Change out heads on iron rough neck to handle 3-1/2" DP. P/U handling tools for 3-1/2" DP. P/U and drift 3-1/2" DP. RIH w/BHA #12 w/6" RR clean out bit. RIH to and tagged up on landing collar at 13641'. Clean out cement to 13729'. Circulate and cut mud weight w/centrifuge. Offload boat w/4-1/2" & 3-1/2" completion string. Continue to circulate and cut mud weight back to 9.5 ppg. Test casing to 1565 psi, hold for 30 minutes w/pressure dropped to 1500 psi. Drill out float collar and clean out cement to 13750'. Test 9-5/8" x 7" to 1565 psi for 30 minutes, dropped to 1500. Displaced 60 bbls of base oil followed by 466 bbls of oil base mud from pits to K-24. Clean pill pit nad mix 40 bbls of Hi-Vis 9.3 ppg spacer. Displace well w/3% KCI/FiW taking OBM to pits. Observed hole drag increase from 235 k to 290 klbs. Torque increased from 10 K to 18 klbs. Clean trip tank. POOH & L/D DP. Finish L/D 5" and 3-1/2" DP and BHA #12. R/D iron rough neck for repairs. Displace an additional 79 bbls of OBM to K-24. RIH w/Schlumberger's RST cased hole logging tools to 13742'. Log up w/RST from 13742' to 11300', 9800' to 9610' and 9350' to 9050' (2932' of Icg intervals) Finish POOH & L/D RST logging tool. Re-head cable. Change out collector wire (shorted out 2 wires). P/U Schlumberger's Cased Hole Resistivity Tool. Test tools. RIH to CHRT 13750' to 12950 and 12850' to 12770' stopping at 4' stations w/2 -5 minutes per station. Continue logging w/CHRT stopping at 4' stations w/2 -5 minutes per station from 12770 - 12650', 12580' - 12320', 12170' - 12010', 11800 - 11700' and 11635' - 11560'. POOH w/CHRT tool and rig down Schlumberger. Change out top pipe rams to 4-1/2" and test to 250 / 3000 psi. R/U tubing running equipment. M/U Baker HS Hydraulic packer assembly and P/U & RIH w/138 jts of 3-1/2" 9.3 #/ft L-80 tubing w/6 gas lift mandrels. RIH w/171 jts of 3-1/2" L-80 9.2#/ft L-80 tubing and 7- 3-1/2" gas lift mandrels. RIH w/234 jts of 4-1/2" 12.6 #/ft, L-80 tubing and 3- 4-1/2" gas lift mandrels. Make up tubing hanger and land hanger. Displace well w/200 bbls of 3% KCL w/1% CRW 132 inhibited water. Drop 1-3/4" brass setting ball, allow 30 minutes for ball to drop. Pump 2 bbls, ball not on seat. Wait 5 minutes pump 20 bbls @ 4-5 BPM, ball not on seat. Wait 10 minutes, pump 60 bbls at 5 BPM, ball not on seat. Back out lock down screws, pull hanger to floor, 1 seal off hanger, replace hanger seal. Attempt to get ball to move down to seat. Re-land hanger, pump 45 bbls at 5 BPM, ball not on seat. R/U Pollard wireline and prep to make 2-1/4" blind box. 4-28-01 5-3-01 5-4-01 5-5-01 5-6-01 5-7-01 Finish R/U Pollard Wireline. RIH w/2-1/4" blind box and set down at 11161'. Worked WL & fell through on 3rd attempt. Set down at 11296' WLM (11325' TM), wireline shear out sub. Pumped 5 bbls at 1.5 BPM @ 400 psi. Moved blind box up 50' up hole. Pumped 5 bbls at 1.5 BPM @ 250 psi. Blind box restricting flow. POOH & R/D Pollard. Installed TIW valve& pumped down 2nd ball (zero gravity), ball seated after pumping 124 bbls of FIW. Pressured up to 3000 psi and set packer. Held pressure for 5 minutes. Bled tubing to 2000 psi. Pressured annulus to 1500 psi and held for 10 minutes. Pressured up tubing to 3800 psi and sheared out pump-out sub. Tubing pressure dropped to 2200 psi. Held for 5 minutes with no loss to annulus. R/D landing joints, X/O's, break down safety valves, puump-in subs, andsteel line connections. Install two way check. N/D BOPE. N/U tree, choke and actuator valves. Tested tubing adapter and tree to 5000 psi. Released Rig to move to K-13RD, Unload Schlumberger perforating equipment. Rig up lubricator and equipment. Re-head rope socket and held explosive safety meeting. Test lubricator to 500 / 2500 psi. Run in hole w/gun run #1 to noting jewelry on way in & tagged bottom at 13719' WLM. Log up to 8100' and tie in GR-CCL to RST log. Perforate G-5 interval 12810' - 12830' w/power jet HC 2-1/2" 60 deg phasing 6 spf gun #1. Pull up 50' and let well stabilize (1040 psi no gain or loss). POOH and cap well. Turn over to production for unloading. Unload well for -11 hrs and recovered 62 bbls of water & 100 bbls of oil w/0 cut. R/U & RIH w/gun run #2 noting jewelry on the way in. Perforate G-5 from 12800' to 12810' w/power jet HC 2-1/2" 60 deg phasing 6 spf. Perforate the following intervals w/Power Jet HC 2-1/2" 60 deg phasing 6 spf, flow well once gun cleared tubing tail after perforating. #3 gun run G-1 12090 - 12120' #4 gun run G-5 12750 - 12790' #5 gun run G-5 12710 - 12750' Re-head and release crane for rig work. Flow well erratically at 800 BOPD w/no cut Perforate the following intervals w/Power Jet HC 2-1/2" 60 deg phasing 6 spf, flow well once gun cleared tubing tail after perforating. #6 gun run G-5 12680 - 12694' #7 gun run G-5 12659 - 12674' #8 gun run G-1 12142 - 12162' all shots fired but had 2 splits in gun body. Perforate the following intervals w/Power Jet HC 2-1/2" 60 deg phasing 6 spf, flow well once gun cleared tubing tail after perforating. #9 gun run G-1 12039 - 12080' all shots fired but split bottom 20' of gun #10 gun run G-1 12030 - 12040' #11 gun run GO-4 11680 - 11720' #12 gun run GO-6 11864 - 11891' #13 gun run GO-5 11732 - 11742' Perforate the following intervals w/Power Jet HC 2-1/2" 60 deg phasing 6 spf, flow well once gun cleared tubing tail after perforating. #14 gun run GO-6 11780 - 11810' #15 gun run GO-6 11820 - 11840' R/D lubricator and Schlumberger. Turn well over to Production & release equipment to K-13RD for Bond Log. 7-2/3-01 Perforate the following intervals w/Power Jet HC 2-1/2" 60 deg phasing 6 spf, flow well once gun cleared tubing tail after perforating. G7/H B1 12950'-13010' HB4 13230'- 13338' RD Schlumberger. Gas lift well. Final Report. ANADRILL SCHLUMBERGER Survey report Client ................... : UNOCAL King Salmon Field .................... : McArthur River Unit Well ..................... : K-1RD2 API number ............... : 50-733-20054-02 Engineer ................. : M. Brown ~OUNTY: .................. : Cook Inlet ~£ATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : MEAN SEA LEVEL Depth reference .......... : Driller's Pipe Tally GL above permanent ....... : 0.00 ft KB above permanent ....... : Top Drive DF above permanent ....... : 100.00 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : . 0. O0 ft 0. O0 ft Platform reference point- '~atitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 253.38 degrees 17-Apr-2001 11:20:24 Page 1 of 4 Spud date ................ : 24-Mar-01 Last survey date ......... : 16-Apr-01 Total accepted surveys...: 87 MD of first survey ....... : 6000.00 ft MD of last survey ........ : 13780.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 20-Mar-2001 Magnetic field strength..: 1107.34 HCNT Magnetic dec (+E/W-) ..... : 20.88 degrees Magnetic dip ............. : 73.53 degrees MWD survey Reference Criteria Reference G .............. : 1002 03 mGal Reference H .............. : 1107 34 HCNT Reference Dip ............ : 73 73 degrees Tolerance of G ........... : (+/-) 2 50 mGal Tolerance of H ........... : (+/-) 6 00 HCNT Tolerance of Dip ......... : (+/-) 0 45 degrees Corrections Magnetic dec (+E/W-) ..... : 20.88 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 20.88 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 17-Apr-2001 11:20:24 Page 2 of 4 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 6000.00 39.92 246.40 2 6019.00 39.86 246.49 3 6053.92 40.40 249.16 4 6145.50 43.63 256.46 5 6241.10 48.11 263.46 0.00 19.00 34.92 91.58 95.60 TVD depth (ft) 4895.10 4909.68 4936.38 5004.45 5071.04 Vertical section (ft) (ft) 3108.63 -1273.04 3120.73 -1277.91 3143.12 -1286.40 3204.32 -1304.37 3272.37 -1316.16 Displ +N/S- Displ Total At DLS Srvy Tool +E/W- displ Azim (deg/ tool qual (ft) (ft) (deg) 100f) type type -2864.17 -2875.34 -2896.18 -2954.68 -3022.18 3134.34 3146.53 3169.02 3229.79 3296.34 246.04 0.00 TIP 246.04 0.44 MWD 246.05 5.16 MWD 246.18 6.39 MWD 246.47 7.04 MWD 6-axis 6 6334.39 52.34 269.06 7 6429.72 56.32 274.55 8 6523.57 57.40 274.42 9 6615.91 56.73 271.93 10 6707.92 55.99 272.21 93.29 95.33 93.85 92.34 92.01 5130.74 5186.35 5237.65 5287.86 5338.83 3342.18 -1320.72 3415.56 -1318.19 3488.87 -1312.05 3561.78 -1307.75 3634.34 -1304.99 -3093.66 -3171.00 -3249.34 -3326.71 -3403.26 3363.79 3434.08 3504.24 3574.53 3644.89 246.88 6.47 MWD 247.43 6.27 MWD 248.01 1.16 MWD 248.54 2.38 MWD 249.02 0.84 MWD 6-axis 6-axis 6-axis 6-axis -- 11 6802.21 55.60 271.46 12 6896.49 56.80 269.40 13 6989.24 58.00 269.91 14 7084.94 57.85 271.84 15 7177.18 57.34 272.73 94.29 94.28 92.75 95.70 92.24 5391.84 5444.29 5494.26 5545.08 5594.52 3708.31 -1302.49 3783.21 -1301.91 3858.21 -1302.38 3935.55 -1301.14 4009.22 -1298.04 -3481.20 -3559.54 -3637.67 -3718.75 -3796.56 3716.89 3790.16 3863.79 3939.80 4012.33 249.49 0.78 MWD 249.91 2.22 MWD 250.30 1.37 MWD 250.72 1.72 MWD 251.12 0.98 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 16 7270.24 57.34 271.94 17 7366.04 58.11 272.13 18 7457.95 57.97 271.83 19 7549.61 58.34 271.75 20 7644.88 58.20 273.07 93.06 95.80 91.91 91.66 95.27 5644.74 5695.89 5744.54 5792.90 5843.01 4083.32 -1294.85 4160.06 -1291.97 4233.96 -1289.27 4307.84 -1286.84 4384.44 -1283.44 -3874.84 -3955.79 -4033.72 -4111.55 -4192.50 4085.47 4161.42 4234.75 4308.22 4384.55 251.52 0.71 MWD 251.91 0.82 MWD 252.27 0.32 MWD 252.62 0.41 MWD 252.98 1.19 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 21 ~'22 23 24 25 7740.02 58.02 272.96 7832.01 58.20 273.18 7924.86 57.63 273.80 8018.42 57.19 274.01 8111.44 57.53 271.88 95.14 91.99 92.85 93.56 93.02 5893.27 5941.87 5991.19 6041.58 6091.76 4460.52 -1279.19 4534.06 -1275.00 4607.94 -1270.22 4681.76 -1264.85 4755.56 -1260.83 -4273.17 -4351.16 -4429.68 -4508.33 -4586.55 4460.53 4534.12 4608.20 4682.40 4756.69 253.33 0.21 MWD 253.67 0.28 MWD 254.00 0.83 MWD 254.33 0.51 MWD 254.63 1.96 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 26 27 28 29 30 8204.27 57.49 272.00 8296.01 57.75 272.34 8390.54 57.08 271.50 8484.61 59.04 272.27 8579.26 58.42 273.05 92.83 91.74 94.53 94.07 94.65 6141.62 6190.75 6241.66 6291.42 6340.56 4829.79 -1258.18 4903.14 -1255.24 4978.65 -1252.57 5054.34 -1249.94 5130.71 -1246.19 -4664.80 -4742.22 -4821.83 -4901.61 -4982.42 4831.50 4905.54 4981.86 5058.47 5135.90 254.91 0.12 MWD 255.17 0.42 MWD 255.44 1.03 MWD 255.69 2.20 MWD 255.96 0.96 MWD 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 17-Apr-2001 11:20:24 Page 3 of 4 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 31 8671.53 57.73 272.38 92.27 6389.35 5204 32 8765.44 57.30 272.58 93.91 6439.79 5279 33 8858.48 56.76 273.62 93.04 6490.42 5352 34 8950.04 57.33 271.77 91.56 6540.23 5425 35 9042.77 57.84 271.74 92.73 6589.94 5499 .60 -1242.48 -5060.65 .46 -1239.05 -5139.79 .93 -1234.83 -5217.73 .43 -1231.22 -5294.46 .72 -1228.82 -5372.71 5210.94 5287.03 5361.85 5435.74 5511.44 256.21 0.97 MWD 256.45 0.49 MWD 256.69 1.10 MWD 256.91 1.81 MWD 257.12 0.55 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 36 9133.53 57.69 271.78 90.76 6638.35 5572 37 9226.89 57.75 271.73 93.36 6688.21 5647 38 9323.93 57.97 272.29 97.04 6739.83 5725 39 9422.72 57.51 274.27 98.79 6792.56 5803 40 9515.93 57.50 274.92 93.21 6842.64 5877 41 9609.72 56.94 274.96 42 9701.25 57.24 275.64 43 9795.91 58.04 274.39 44 9887.38 58.14 272.64 45 9981.68 58.16 270.94 93.79 91.53 94.66 91.47 94.30 6893.42 6943.15 6993.82 7042.17 7091.93 595O 6021 6096 6169 6245 .58 -1226.47 -5449.44 .49 -1224.06 -5528.34 .35 -1221.18 -5610.45 .90 -1216.41 -5693.85 .19 -1210.11 -5772.21 .52 -1203.32 -5850.78 .81 -1196.22 -5927.29 .13 -1189.23 -6006.94 .03 -1184.47 -6084.44 .03 -1181.97 -6164.49 5585.75 5662.23 5741.82 5822.34 5897.70 5973.24 6046.79 6123.53 6198.66 6276.79 257.32 0.17 MWD 257.52 0.08 MWD 257.72 0.55 MWD 257.94 1.76 MWD 258.16 0.59 MWD 258.38 0.60 MWD 258.59 0.70 MWD 258.80 1.40 MWD 258.98 1.63 MWD 259.15 1.53 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 46 10075.44 57.55 271.51 47 10169.71 55.97 272.05 48 10263.84 56.46 270.60 49 10358.91 55.97 270.37 50 10400.23 56.23 269.75 93.76 94.27 94.13 95.07 41.32 7141.82 7193.49 7245.84 7298.70 7321.75 6320 6395 6469 6545 6578 .60 -1180.28 -6243.86 .41 -1177.83 -6322.67 .83 -1176.02 -6400.88 .35 -1175.35 -6479.89 .21 -1175.32 -6514.18 6354.44 6431.44 6508.01 6585.62 6619.36 259.30 0.83 MWD 259.45 1.74 MWD 259.59 1.38 MWD 259.72 0.55 MWD 259.77 1.40 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 51 10455.40 55.46 267.84 52 10542.84 56.32 266.25 53 10637.69 55.46 266.04 54 10731.71 54.91 266.48 55 10826.05 53.47 261.90 55.17 87.44 94.85 94.02 94.34 7352.73 7401.76 7454.95 7508.63 7563.85 6622.21 -1176.28 -6559.83 6692.56 -1180.01 -6632.12 6769.15 -1185.29 -6710.48 6844.40 -1190.33 -6787.50 6919.51 -1198.04 -6863.58 6664.45 6736.28 6814.35 6891.08 6967.35 259.83 3.19 MWD 259.91 1.80 MWD 259.98 0.93 MWD 260.05 0.70 MWD 260.10 4.22 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 56 10918.40 52.25 258.39 57 11014.38 50.38 255.63 58 11110.84 47.22 250.67 59 11199.89 46.02 246.49 60 11292.33 44.15 244.79 92.35 95.98 96.46 89.05 92.44 7619.61 7679.61 7743.16 7804.34 7869.60 6992.59 -1210.62 -6936.09 7067.34 -1227.43 -7009.09 7139.87 -1248.38 -7078.52 7204.34 -1271.99 -7138.76 7269.20 -1298.97 -7198.39 7040.95 7115~75 7187.76 7251.19 7314.65 260.10 3.30 MWD 260.07 2.97 MWD 260.00 5.07 MWD 259.90 3.67 MWD 259.77 2.41 MWD 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 17-Apr-2001 11:20:24 Page 4 of 4 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 11385.05 42.04 239.09 62 11478.21 41.60 233.31 63 11531.53 41.33 231.52 64 11551.96 41.40 230.06 65 11647.28 42.59 222.68 66 _~. 67 68 69 70 71 72 73 74 75 76 77 78 79 8O 81 82 83 84 85 86 87 92.72 93.16 53.32 20.43 95.32 11740.84 43.24 216.47 93.56 11829.78 43.36 210.67 88.94 11930.36 42.92 206.32 100.58 12020.94 41.00 201.30 90.58 12101.10 41.14 198.88 80.16 12191.53 41.01 197.53 12284.55 41.37 198.58 12379.40 41.59 199.15 12473.91 41.54 200.68 12569.27 41.72 200.95 12661.95 41.66 201.26 12753.94 42.16 203.81 12848.75 42.26 204.58 12941.02 41.49 205.13 13034.38 40.68 209.89 90.43 93.02 94.85 94.51 95.36 92.68 91.99 94.81 92.27 93.36 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 7937.33 8006.79 8046.74 8062.08 8132.96 8201.51 8266.27 8339.67 8407.05 8467.48 8535.66 8605.66 8676.72 8747.43 8818.71 8887.92 8956.38 9026.61 9095.31 9165.70 13128.00 40.60 212.60 93.62 9236.74 13222.40 40.75 213.86 94.40 9308.34 13315.43 40.36 213'.15 93.03 9379.02 13408.48 38.92 213.96 93.05 9450.68 13502.65 37.81 214.44 94.17 9524.51 13519.77 37.43 214.43 17.12 9538.07 13780.00 37.43 214.43 260.23 9744.72 7331.24 -1328.69 -7254.27 7390.54 -1363.20 -7305.85 7423.50 -1384.73 -7333.83 7435.97 -1393.27 -7344.29 7492.68 -1437.24 -7390.35 7545.55 -1486.31 -7430.88 7592.37 -1537.09 -7464.57 7641.08 -1597.50 -7497.38 7680.36 -1652.85 -7521.85 7711.84 -1702.30 -7539.94 7745.77 -1758.74 -7558.50 7780.62 -1816.98 -7577.49 7817.09 -1876.43 -7597.80 7854.42 -1935.38 -7619.16 7892.92 -1994.59 -7641.67 7930.64 -2052.10 -7663.87 7969.44 -2108.84 -7687.42 8011.07 -2166.94 -7713.52 8051.86 -2222.83 -7739.41 8094.54 -2277.22 -7767.71 8139.75 -2329.34 -7799.33 8186.77 -2380.81 -7833.05 8233.19 -2431.24 -7866.44 8278.78 -2480.71 -7899.24 8324.08 -2529.05 -7932.09 8332.21 -2537.67 -7938.00 8455.21 -2668.10 -8027.40 7374.95 259.62 4.78 7431.94 259.43 4.16 7463.41 259.31 2.28 7475.28 259.26 4.74 7528.80 258.99 5.33 7578.06 258.69 4.57 7621.19 258.36 4.47 7665.68 257.97 2.99 7701.31 257.61 4.27 7729.71 257.28 1.99 7760.42 256.90 0.99 7792.29 256.52 0.84 7826.08 256.13 0.46 7861.13 255.75 1.08 7897.69 255.37 0.27 7933.85 255.01 0.23 7971.42 254.66 1.93 8012.12 254.31 0.56 8052.29 253.98 0.92 8094.63 253.66 3.46 8139.75 253.37 1.89 8186.87 253.09 0.88 8233.58 252.83 0.65 8279.61 252.57 1.64 8325.52 252.32 1.22 8333.77 252.27 2.22 8459.23 251.61 0.00 Srvy Tool tool qual type type MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis Projected WELL K-1RD Measured Depth 0.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2380.00 2423.00 2502.00 2657.00 2844.00 2997.00 3154.00 3217.00 3311.00 3407.00 3561.00 3710.00 3741.00 3934.00 4060.00 4212.00 4334.00 4400.00 4426.00 4469.00 4489.00 4520.00 4581.00 4643.00 4736.00 4828.00 4926.00 5052.00 5207.00 Vertical Depth 0.00 399.03- 498.81 598.22- 697.36- 796.62- 895.64- 993..97 1091.31 1187.43 1281.70 1373.92 1463.60 1550.20 1633.59 1714.75 1794.35 1870.95 1944.98 2017.21 2088.54 2146.33 2177.65 2235.66 2350.85 2492.51 2609.71 2732.58 2781.89 2854.94 2928.75 3046.29 3158.74 3182.13 3326.68 3421.41 3536.13 3628.55 3678.74 3698.80 3732.45 3748.37 3773.13 3821.85 3871.03 3942.28 4009.56 4080.65 4172.04 4285.40 Subsea Depth 100.00 299.03 398.81 498.22 597.36 696.62 795.64 -893.97 -991.31 -1087.43 -1181.70 -1273.92 -1363.60 -1450.20 -1533.59 -1614.75 -1694.35 -1770.95 -1844.98 -1917.21 -1988.54 -2046.33 -2077.65 -2135.66 -2250.85 -2392.51 -2509.71 -2632.58 -2681.89 -2754.94 -2828.75 -2946.29 -3058.74 -3082.13 -3226.68 -3321.41 -3436.13 -3528.55 -3578.74 -3598.80 -3632.45 -3648.37 -3673.13 -3721.85 -3771.03 -3842.28 -3909.56 -3980.65 -4072.04 -4185.40 Drift Angle 0.00 4.00 3.75 6.25 7.50 7.00 8.00 10.50 13.25 16.00 19.50 22.75 26.25 30.00 33.50 35.75 37.25 40.00 42.25 43.75 44.50 43.75 43.25 42.75 42.00 40.75 40.00 38.50 38.50 39.00 39.75 40.25 41.00 41.00 41.50 41.25 41.00 40.75 40.50 39.50 38.50 37.25 37.00 37.00 37.50 40.00 43.00 43.50 43.50 43.00 Azimuth 360.00 276.00 278.00 272.00 249.00 245.00 235.00 246.00 245.00 246.00 246.00 247.00 247.00 247.00 248.00 248.00 248.00 248.00 247.00 248.00 247.00 247.00 247.00 245.00 247.00 247.00 247.00 248.00 248.00 248.00 248.00 249.00 249.00 248.00 250.00 250.00 250.00 251.00 251.00 248.00 246.00 243.00 242.00 243.00 243.00 243.00 243.00 243.00 243.00 243.00 Coordinates X 213756 213728 213722 213711 213699 213688 213676 213659 213638 213613 213582 213546 213505 213458 213407 213352 213295 213235 213173 213108 213043 212991 212964 212915 212818 212705 212613 212522 212485 212430 212372 212279 212186 212167 212046 211967 211873 211797 211756 211741 211716 211705 211688 211655 211621 211567 211511 211450 211372 211276 Y 2511798 2511801 2511802 2511803 2511798 2511794 2511786 2511779 2511770 2511759 2511746 2511732 2511716 2511697 2511678 2511657 2511636 2511614 2511589 2511565 2511539 2511518 2511508 2511486 2511448 2511403 2511367 2511332 2511319 2511298 2511276 2511243 2511210 2511203 2511162 2511136 2511104 2511080 2511067 2511061 2511051 2511046 2511037 2511021 2511005 2510979 2510952 2510923 2510886 2510840 Measured Depth Vertical Depth Subsea Depth Drift Angle Azimuth Coordinates X 5358.00 5539.00 5726.00 5918.00 6043.00 4397.61 4533.70 4675.36 4820.81 4916.56 -4297.61 -4433.70 -4575.36 -4720.81 -4816.56 42.00 244.00 41.25 245.00 40.75 247.00 40.75 247.00 40.00 248.00 211184 211075 210962 210845 210770 2510798 2510750 2510705 2510659 2510631 Re~ ADMINISTRATIVE APPROVAL NO. 80.80A Corrected Administrative Approval No. The application of Union Oil Company of Califomia, operator of the Trading Bay Unit (TBU), to drill and complete the TBU K-1RD2 well as pan of the pressure maintenance project. Shannon W. Martin Land/Legal Analyst UNOCAL Corporation P O Box 190247 Anchorage, AK 99519-0247 Dear Mr. Martin: Your application dated December 20, 2000 for a "Permit to Drill" for TBU well K-1RD2 is proposed to recover additional oil from the Middle Kenai "G" Oil Pool and Hemlock Oil Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completiOn of the TBU K-1RD2 well pursuant to Rule 5 of Conservation Order 80. NUNC PRO TUNC at Anchorage, Alaska and dated February 9, 2001. Daniel T. Seamount, Jr. Commissioner Camill60echsli Taylor Commissioner Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION AI,ASKA OILAND GAS CONSERYA~I~ION C0P~ISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Williamson Drilling Manager Union Oil Company of California (UNOCAL) P O Box 196247 Anchorage, AK 99519 Re'- Trading Bay Unit K-1RD2 UNOCAL Permit No: 201-009 Sur Loc: 135'FEL, 724'FSL, Sec. 17, T9N, R13W, SM Btmhole Loc. 1401'FNL, 2479'FEL, Sec. 19, T9N, R13W, SM Dear Mr. Williarnson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission at 279-1433. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~f~ day of February, 2001 dlffEnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL(, ,,qB GAS CONSERVATION CO(i.. VIlSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill: Redrill: X I lb. Type of well Exploratory: Stratigraphic Test: Development Oil: Re-Entry: Deepen:I Service: Developement Gas: Single Zone: Multiple Zone: /~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California (UNOCAL) 100' KB above MSL feet McArthur River Field 3. Address 6. Property Designation I.?$?¢~. Hemlock/G Intervals P.O. Box 196247, Anchorage AK 99519 ADL 18777 .,,~ 4. Location of well at surface Conductor No.26 Leg 4 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 135' FEL, 724' FSL, Sec 17, T9N, R13W, S.M. Trading Bay Unit AK Statewide Oil & Gas Bond At top of productive interval 8. Well number Number 891' FNL, 2416' FEL, Sec 19, T9N, R13W, S.M. K-1RD2 L,( ~ ¢_..~ 2_/~'~. At total depth 9. Approximate spud d, ate/ Amount $200,000 1401' FNL, 2479' FEL, Sec 19, T9N, R13W, S.M. 1~ ;2-/'¢/O / 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in propert~ 15. Proposed depth (MD and TVD) )roperty line 2479' E of Sect 19 feet 151' at 12091'MD feet 1902 13393' MD, 9575' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 6043' feet Maximum hole angle: 58 deg Maximum surface 2865 psig At total depth (TVD) 3800 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) Existing 20" Driven 110' 110' 110' 110' 110' Driven Existing 13-3/8" 61 lb J-55 Butt. 2384' surf surf 2384' 2148' 2608 sx Existing 9-5/8" 47/43.5 lb N-80 Butt. 9709' surf 37.0' 6043' KOP 4928' 1321 sx 8-1/2" 7" 29 lb N-80 Butt. 6173' 5918' 4820' 12091' 8398' 880 sx 6" 4-1/2" 12.6 lb L-80 Butt. 1402' 11991' 8310 13393' 9475' 150 sx 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary RECEIVED Total depth: measured 12570' feet Plugs (measured) 12214' (retainer) true vertical 9717' feet JAN 1 O ~,00~ Effective depth: measured 12234' feet Junk (measured) 12180' (fish) true vertical 9469' feet J~a,s[(~ 0i~ & 6as C;oQs, Casing Length Size Cemented Measured depth True ve~ical depth Structural i Conductor 110' 20" Driven 110' 110' Surface 2384' 13-3/8" 2608 sx 2384' 2149' Intermediate Production 9709' 9-5/8" 1321 sx 9709' 7672' Liner 12566' 7" 550 sx 12566' 9714' Perforation depth: measured See attached schematic true vertical See attached schematic 20. Attachments: Filing fee: X Property Plat: BOP Sketch: X Diverter Sketch: Drilling program: X Drilling fluid program: X Time vs. depth plot: Refraction analysis: Seabed report: 20 AAC 25.050 requirements: 21. I herby certify that the foregoing is true and correct to the best of my knowledge: Signed:~~_ ~~ cToitljr~ i s s io~n U~s elr!!i ~/~ /~¢ ~//')~ Date:/'"~ ¢~ Per~it Number.~.~/ ~ I APl number ~~¢"'~/I Approval date I Seo cover letter " '- 50- "7~'~ - ~L - .,.; ' ' ' for other requirements Conditions ofapproval Samples required: [ ]Yes [~1o Mud Icg r,e~uired: [4 Yes [ ] No Hydrogen sulfide measures J)(~ Yes [ ] No Pi~ectional survey required ,~I Yes [ ] No Required working pressure for BOPE [ ]2M; [ ]3M; [ ]5M; [ ]10M; [ ]15M~ ~,C~¢~, ~'a,¢O~' ~ c~% Other: ORIGINAL S~GNED BY D Taylor Seamount by order of Approved by Commissioner the Commission Date: ~:.;'~"; ../Z?.', ,... Form 10-401 Rev. 12-1-85 Submit in triplicate Attachment to Form 10-401 Permit to Drill King K-1RD2 Hazard Analysis The proposed drilling of Grayling K-1RD will entail sidetracking the well from 6043' and drilling an 8-1/2" hole to 12090' This interval encompasses the Tyonek D, E, F and top G sands. These sands are expected to be normally to subnormally to normally pressured. We plan on drilling this interval with an oil base mud system in the weight range from 9.0 to 9.2 ppg. If sloughing coals prove troublesome we have the ability to increase the mud weight to 10.0 ppg. A potential for lost circulation exist whilst drilling the 8-1/2" hole interval. Measures have been taken to ensure that adequate supplies of LCM is available onboard before drilling this hole section. The 6" hole section will encounter the G and Hemlock 1-7 intervals. There is potential for coal sloughing. The Hemlock is expected to have a pressure gradient of.42 psi/ft. We plan on using an oil based mud system for drilling this interval with mud weights in the range of 8.8 ppg to 9.4 ppg. If sloughing coals prove troublesome we have the ability to increase the mud weight to 10.0 ppg. The maximum expected downhole pressures that may be encountered is based on offset well information which indicate that at 9350' TVD a pressure of 3800 psi may be expected. This equates to a gradient of .41 psi/ft. The maximum surface pressure which may be encountered assumes full evacuation of the wellbore to a depth of 9575' TVD and a methane gas gradient of. 1 psi/ft. Thus 2865 psi surface pressure is assumed as the worst case. This well may encounter gas accumulations in the upper E and F sands at approximately 7500' TVD. If gas shows are significant, an intermediate logging pass will be made possibly followed by capturing a sample with a Schlumberger MDT logging tool. The Hemlock zones which are offset to this well have been producing with an H2S content of up to 400 ppm. Prior to the drilling ofK-1RD2 a full cascade system and individual SCBA's will be rigged up and placed in strategic locations on the platform. In addition a H2S Safety Technician will be onboard to service the equipment, conduct drills and refresh crew members in the proper use of this equipment. RECEIVED JAN 1 0 2001 Alas~ Oil & Gas Cons. Commission Anchorage Preliminary Procedure King K-1RD2 Mill Window and Drill 8-1/2" hole 1 MU one trip whipstock assembly. 2 RIH with one trip whipstock assembly. 3 Orient whipstock with MWD. Set packer/whipstock ~ 6100'. 4 Change over to OBM sytem. 5 Mill window in 9-5/8" casing. 6 Circulate bottoms up. 7 POOH with setting tool. 8 LD mills and MU drilling BHA. 9 RIH with BHA. 10 Drill 8-1/2" hole to 12090' 11 Log 8-1/2" hole section with LWD Run 7" Liner 12 Change top pipe rams 13 Test BOPE. 14 RU casing crews for 7" liner 15 RIH with 7" liner. .16 Continue to RIH with liner on drillpipe. 17 Set liner hanger and release running tool. 18 Cement liner 19 Set isolation packer and circulate string clean. 20 POOH with running tool. Drill 6" hole 21 22 23 24 25 Make up 6" BHA and RIH PU 3-1/2" Drill 6" hole to TD at 13,393' Circulate and condition mud system. Log 6" hole section with LWD POOH with BHA. Lay down BHA Run 4-1/2" Hydril 511 Liner 26 Test BOPE. 27 RU casing crews for 4-1/2" liner 28 RIH w~th/7~,iliJ),n, er~ 29 Continue t6RIH with liner on drillpipe. RECEIVED JAN 1 0 2001 Alaska Oil & (las Cons. Commission Anchorage 30 31 32 33 Set liner hanger and release running tool. Cement liner Set isolation packer and circulate string clean. POOH with running tool. Clean out 4-1/2" liner and displace to base oil 34 RIH with 2-7/8" liner cleanout string 35 Displace liner to densified base oil 36 POOH laying down excess pipe Run Completion 37 38 39 40 41 42 43 44 45 46 47 48 Pull wear bushing. RU to run 4-1/2" GL completion PU, rabbit and run completion. Space out, install SCSSV and PU hanger Land hanger ..... ~ Lay down landing joint RD .tubing running equip. ND BOPE. Install tree and test. Install Flowlines Prepare for rig move Perforate well after rig move. RECEIVED JAN 10 2001 Naska Oil & Gas Go'ns. Commission Anchorage UNOCAL ) 1 ILL SIZE WT Trading Bay Unit Well K-1RD Proposed Abandonment CASING AND TUBING DETAIL GRADE CONN ID MD TOP 20" Driven Surf. 13-3/8" 61 J-55 Butt 12.515" Surf 9-5/8" 47/43.5 N-80 Butt 8.681" Surf 7" Casing 29" N-80 But 6.181" 9,551' Tubing: 4-1/2" 12.6 N-80 But 3.958 ? 3-1/2" 9.2 N-80 Butt 2.992 9462' JEWELRY DETAIL NO. Depth ID Item I 6100' 9-5/8" Bridge Plug 2 Camco MMG Gas Lift Mandrels MD BTM. 110' 2,384' 9,709' 12,566 9,462' 11,958' 3 Camco KBMG Gas Lift Mandrels 9462' 10,642' 2.75 11,893' 3.00 11,893' 4.75 11,926' 2..75 11,958' 2.992 4-1/2" GLM at 6746, 7951', 8605', 8983', 9422' 3-1/2" GLM at 9870', 10314', 10602' X-over 4-1/2" Butt Box x 3-1/2" Butt Pin Otis Model RH packer Locator Seal Assy, w/25' of seals, 4" OD Otis Model "D" Packer (wireline set) 3-1/2" "X" Nipple Mule shoe 12,214' 7"Otis retainer 12,235' 7'Otis retainer 9,709' Bad casing: 11615-11572' 11002',10947' 10858',10780' 10706',10698' HB-1 Heavy scale HB-2 HB-3 .. HB-4 ~ HB-5 :::i:?i ;i ?!?;i:}'ii ?!::ii;!;:iiiii:;:.'i :i:!~:.. ?ii!:~.?ii~::.ii::~ HB-7 TD = 12,570' ETD = 12,214' MAX HOLE ANGLE = 50° @ 10,300' K- 1 RD Abandonment.doc Fish in Well Fish No.1 1900' drill pipe and radio active source at 12975'. (K-1 Open Hole) Fish No.2 Lost 19' strip gun (1/88) Fish No. 3 Two perf guns 21' long x 2.6" OD (9/77) PERFORATION DATA Interval From To HB-0 11838 11878 HB-1 11902' 11938' HB-2 11948' 12028' HB-3 12051' 12163' HB-4 12163' 12214' HB-4 12214' 12234' HB-5 12249' 12310' HB-6 12322' 12434' HB-7 12434' 12475' Status Squeeze Perfs Abandoned Abandoned Abandoned Abandoned Abandoned Abandoned Abandoned Abandoned REVISED: 9/27/00 DRAWN BY: NM UNOCAL ) RKB to TBG Head = 34' Tree connection: Trading Bay Unit Well # K-1RD#2 PROPOSED CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61.0 K-55 12.515 35' 2,384' 9-5/8" 43.5 N-80 BTC 8.755 35' 6,043' 7" Liner 29 L-80 BTC-KC 6.184 5918' 12,091' 4-1/2" Liner 12.6 L-80 Hydril 511 3.958 11,991 13393' Tubing: 4-1/2" 12.6 L-80 BTC 3.958 35 5700' 3-1/2" 9.2 L-80 BTC 2.992 5700' 11,500' JEWELRY DETAIL NO. Depth ID Item 34 4-1/2" Gaslift Mandrels w/ 3-1/2" Gaslift Mandrels w/ 2.992 2.821 2.992 12" x 4-1/2" OCT type "UH-TC-1A" Butt Tbg Hngr Baker TE-5 TRSSSV RK latches. Crossover, 4-1/2" x 3-1/2" BTC RK latches. Locator Seal Assy w/14' of seals FB-1 Baker Packer with 10' SBE 3-1/2" Butt tubing Otis "X" Profile Nipple WLEG Zone G-Zone Hemlock PERFORATION DATA ' Top Btm Amount Condition Depths to be determined from Open Hole logs Depths to be determined from Open Hole logs Proposed G zone Pelfs Proposed Hemlock Pelfs PBTD = 13126' TD -- 13166' MAX HOLE ANGLE = 58° @ 6400' K- 1 RD2 Proposed.doc REVISED: 12/15/00 K-lrd BOP Stack To, Table Hydril 5M 4.54' Btm of Trolly beam 4.75' ~ .82' Top of drill deck A 4 1116" 5M Foster HCRValve B 4 1116" 5M Manual gate valve C 3 1116" 5M Manual gate Kill line D 3 1/16" 5M Manual gate Kill line 16.00' 12.83' Graylock Hub Top of FMC Type 3 Unihead / t0' # Kin9 Sa./mon 10' Equdizer____~. ~J Mud Pi-t ~1 184 BBLS t6 BBL / FT 1.4 BBL / IN 10' Equalizer Mud Pits with Aug, 1993 Suciion Lines Mud Pit #2 ~~ 19 BBL / FT 1.6 BBL / IN 10~ Equdizer____~_ Suction Line Mud Pit ~3 839 ]3BLS 31 BBL / FT 8.6 BBL / IN 10~' E quQlizer____m~ '1 .... 10' Suc±ion__~.. 10' Equalize Mud Pit ~4 839 BBLS 31 BBL / Fl 8.6 BBL / tN 10' Suction ~ H I' ii 10' 0' 29' ]9' 9' TO 10" CROWN VENT 13LOW DOWN (~ OAS BUSTER TO CHOKE PANEL MANUAL 1 O" TO SHAKER SWACO CHOKE NOTE: SWACO CHOKES EACH HYDRAULICALLY ACTUATED VIA REMOTE. TO BOPE SWACO CHOKE CHOKE tvlANIFOLD Unocal PLATFORM RIGS ~-~/~' & 3-Vo", ~M UNOCAL ) K-O1RD2 Proposed Well Profile - Geodetic Report Report Date: Client:. Unocal Field: McArlhur River Unit Structure I Slot: King Salmon I K-01 (slot 26) Well: K-01' Borehole: K-O1RD2 UWI/AP~: 50-733-20054-00 Proposal Name I Modified Date: K-O1RD2 (P6) / December 12, 2000 Tort I Al. ID I DDI I ERD ratio: 198.590° 19114.08 tt / 6.403 / 0.952 Grid Coordinate System: NAD27 Naska State Planes, Zone 04, US Feet Location I. at/Long: N 60 5155.915, W 15136 21.265 : Location Grid N/E Y/X: N 2511798.000 flUS, E 213756.000 flUS Grid Convergence Angle: -1.40281425° Grid Scale Factor: 0.99999324 000__._ Stu' OnlyVerticalvertical. i. vD Computation Reference Section Sec,on Azimuth:Meth°d:Datum:Origin: Fe w,,"=--as'""'"' ~ Reference Elevation: Minimum Curvature I LubinskJ 260.020° N 0.000 It, E 0,000 It KB 100.0 It relalJve to Mean Sea Level Magnetic Declination: 20.943° Total Field Strength: 55364.204 nT Magnetic Dip: 73.532° Declination Date: November 30, 2000 Magnetic Declination Model: BGGM 2000 Nodh Reference: True North Total Corr Mag North -> True North: +20.943° Coordinate Reference To: Well Head Schlumberger Grid Coordinates Geo~lraphic Coordinates 1 StafionlD I MD I inc, i Azim I TVD I VSocI N~-S I E~-WIDLS Northing-I Eastlng LatitudeI Longitude (ft) (°) (°1 ("1 (ltl (~tl (.) (°/lOOft) (.US) (.US) Tie-In Survey 6043.00 40.00 248.00 4928.30 3084.47 -1237.12 -2914.17 0.00 2510632.60 210812.44 N 6051 43.729 W 151 37 20.106 KOP Crv 6/100 6050.00 40.00 248.00 4933.66 3088.87 -1238.81 -2918.34 0.00 2510631.02 210808.23 N 6051 43.713 W 151 37 20.190 6100.00 41.98 251.43 4971.40 3121.13 -1250.15 -2949.10 6.00 2510620.43 210777.20 N 60 51 43.601 W 151 37 20.811 6200.00 46.22 257.54 5043.23 3190.33 -1268.61 -3016.12 6.00 2510603.62 210709.75 N 60 51 43.419 W 151 37 22.164 6300.00 50.74 262.82 5109.53 3265.14 -1281.25 -3089.85 6100 2510592.79 210635.74 N 6051 43.294 W 151 37 23.653 End Crv Crv 6/100 6400.00 55.47 267.44 5169.57 3344.72 -1287.93 -3169.48 6.00 2510588.06 210555.97 6461.15 58.44 270.01 5202.91 3395.38 -1289.05 -3220.72 6.00 2510588.19 210504.72 11075.46 58.44 270.01 7618.09 7267.49 -1288.12 -7152.48 0.00 2510685.38 206574.19 11100.00 57.24 269.01 7631.15 7287.98 -1288.30 -7173.25 6.00 2510685.71 206553.42 11200.00 52.42 264.63 7688.76 7369.08 -1292.74 -7254.82 6.00 2510683.26 206471.77 N 60 51 43.228 W 151 37 25.261 N 60 51 43.217 W 151 37 26.295 N 60 51 43.209 W 151 38 45.682 N 60 51 43.207 W 151 38 46.102 N 60 51 43.163 W 151 38 47.749 11300.00 47.79 259.65 7752.90 7445.68 -1303.11 -7330.77 6.00 2510674.76 206395.59 11400.00 43.41 253.90 7822.88 7516.94 -1319.31 -7400.28 6.00 2510660.26 206325.70 11500.00 39.37 247.19 7897.92 7582.09 -1341.16 -7462.58 6.00 2510639.95 206262.89 11600.00 35.78 239.29 7977.21 7640.41 -1368.40 -7517.00 6.00 2510614.05 206207.82 11700.00 32.80 230.03 8059.88 7691.25 -1400.76 -7562.94 6.00 2510582.82 206161.10 N 60 51 43.060 W 151 38 49.282 N 60 51 42.901 W 151 38 50.685 N 60 51 42.685 W 151 38 51.943 N 60 51 42.416 W 151 38 53.042 N 60 51 42.097 W 151 38 53.969 11800.00 30.61 219.39 8145.02 7734.07 -1437.86 -7599.88 6:00 2510546.64 206123.26 N 60 51 41.732 W 151 38 54.714 K-01RD2 (P6) report.xls Page 1 of 2 12/13/2000-9:26 AM Grid Coordinates Geo~lraphic Coordinates I Station ID I MD I I,cl I I TVD I VS,c I N/-S I E -W I DLS Northing I ~sting Lat~deI Longitude 11900.00 29.39 207.62 8231.70 7768.39 -1479.32 -7627.44 6,00 2510505.86 206094.70 N 60 51 41.323 W 151 38 55.270 12000.00 29.26 195.35 8318.97 7793.84 -1524.66 -7645.30 6.00 2510460,98 206075.73 N 60 51 40.877 W 151 38 55.630 End Crv / G Tgt 12090.89 30.10 184,46 8398.00 7809.04 -1568.84 -7652.95 6.00 2510417.00 206067.00 N 60 51 40.442 W 151 38 55.784 H Tgt/Drp6/100 12852.61 30.10 184.46 9057.00 7904.28 -1949.68 -7682.64 0.00 2510037.00 206028.00 N 60 51 36.691 W 151 38 56.378 12900.00 27.26 184.46 9098.58 7909.95 -1972.35 -7684.41 6.00 2510014.38 206025.68 N 60 51 36.468 W 151 38 56.414 13000.00 21.26 184.46 9189.71 7920.18 -2013.29 -7687.60 6.00 2509973.53 206021.48 N 60 51 36.065 W 151 38 56.478 13100,00 15.26 184.46 9284.63 7927.99 -2044.51 -7690.03 6.00 2509942.38 206018.29 N 60 51 35.757 W 151 38 56.526 13200,00 9.26 184.46 9382.31 7933,28 -2065.66 -7691.68 6.00 2509921.28 206016.12 N 60 51 35.549 W 151 38 56.559 13300.00 3,26 184.46 9481.67 7936.00 -2076.52 -7692.53 6.00 2509910.44 206015.01 N 60 51 35.442 W 151 38 56.576 End Drp TD 13354.26 0.00 184.46 9535.90 7936.38 -2078.06 -7692.65 6.00 2509908.91 206014.85 N 6051 35.427 W 151 38 56.579 13393.36 0.00 184.46 9575.00 7936.38 -2078.06 -7692.65 0.00 2509908.91 206014.85 N 60 51 35,427 W 151 38 56.579 Le.qal Description: Surface: 723 FSL 140 FEL S17 T9N R13W SM Tie-In: 4765 FSL 3057 FEL S20 TgN R13W SM End Crv/G Tgt: 4432 FSL 2516 FEL S19 TgN R13W SM H Tgt/Drp 6/100: 4051 FSL 2547 FEL S19 T9N R13W SM BHL: 3922 FSL 2557 FEL S19 T9N R13W SM No~hina(Y)rflus] Eastina (x)rflus] 2511798.00 213756.00 2510632.60 210812.44 2510417.00 206067.00 2510037,00 206028.00 2509908.91 206014.85 K-01RD2 (P6) report.xls Page 2 of 2 12/13/2000-9:26 AM UNOCAL ) VERTICAL SECTION VIEW Client: Unocal Well: K-01RD2 (P6) Field: McArthur River Unit Structure: King Salmon Section At: 260.02 deg Date: December 13, 2000 Schlumberger v- O .-- . ! > LIJ 8000 9000, 2000 Ti~.l. n Survey6043 MO 4928 TV~ KOP Crv 6/'1ffi8050 I~ MD 5203 TVD Proposal , Survey Hold Angle 8.44° K-10RD Crv 6/! 00 11075 NID 7618 TVD 58.44'1 270.01' az End Crvl G Tgt120cJ1 I 8398 3VD 184.46' az ;} deparlum H Tgt I Drp 6/t~ 3000 K-18 4000 5000 6000 7000 8000 Vertical Section Departure at 260.02 deg from (0.0, 0.0). (1 in = 1000 feet) TD 13393 MD 0.00' 184.46' az del)an'urn 9000 9057 TVD UNOCAL ) PLAN VIEW Client: Unocal Well: K-01RD2 (P6) Field: McArthur River Unit Structure: King Salmon Scale: 1 in = 1000 ft Date: 13-Dec-2000 Schlumberger A A A 0 -2000 I O V V -g000 -8000 -7000 -6000 -5000 -4000 -3000 -2000 ' ' ' ' ' I True North .. ! -1000- ~.. ~ j /I ~ ~, --1000 = = · t l I -~ ~27 i I I I V -3000~ -4000 -9000 -2000 -8000 -7000 -6000 -5000 -4000 -3000 -2000 ........ 3000 4000 <<< WEST EAST >>> Drilling Fluids Program UNOCAL King Salmon Platform Well K-1RD2 Prepared by: Reviewed by: Presented to: M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax Lee Dewees Neil Magee December 9, 2000 DRILLING FLUIDS DRILLING FLUIDS M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 Phone (907) 274-5564 Fax (907) 2709-6729 December 9, 2000 UNOCAL 909 West 9th Avenue Anchorage, Alaska 99501 ATTN: Neil Magee Neil; Enclosed is a recommended mud program for the K-1 RD2 Well to be drilled on the King Salmon Platform. Included is a project summary, interval summary, an economic summary, and the project team. The 8.5" and 6" interval will be drilled with OBM (oil based mud). This program is based on using the OBM from the stor- age on the Granite Point Platform.. The K-1 RD2 wellbore should be displaced to OBM prior to milling the window. The production interval will be completed with a 4 1/2" liner. The liner will be displaced to base oil (Mapco 200). Oil mud should be conditioned (centrifuged) prior to storage for future use. Please call if you have any questions regarding the mud program. Lee Dewees Project Engineer M-I Drilling Fluids 907 274-5533 Project Summary Well K-1RD2 Hole Depth TVD Mud Mud Sum Cumulative Casing Casing Size Size Program System Weight Days Mud Cost I Existing Window 12 1/4" ~ Versadrill 8.5-9.0 20 $80,000 6500' 12,400' ~ , 12.400'- 6" 13.170' Versadrill 8.5-9.(} 20 S 145,0()0 1 iComplc- 13,~70' .\lapco Base Oil 7.4 5 S! 80.000 .Key .ISsue .No. 1 Sloughing Coal , If coal sloughing becomes a problem add Ventrol 401. Key .ISsue No. 2 .Hole Cleaning .Key I,s.~s u e No. 3 Drill Solids · Maintain sufficient 3 RPM reading in 8 1/2" interval to in- sure adequate hole cleaning. Sweep hole as needed to avoid cuttings buildup. Pump weighted sweeps in 6" interval to aid in hole cleaning. · Run as fine a mesh shaker screen as possible. Run centri- fuge during trips to reduce drill solids in mud. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax II DRILLING FLUIDS Interval Summary (8.5" hole) Well K-1 RD2 Drilling Fluid System Key Products Solids Control Potential Problems Shale Shakers / Desilter / Centrifuge Coal sloughing, hole cleaning, drill solids buildup Interval Drilling FlUid Properties Depth Mud Plastic Yield HTHP ::lnte~al:: iWeight ~:ViscOsity: :POint :: FlUid:LoSs O/W:: Gels: :(PPg) i(CPi) : (Ibl:J00ft2):i (mll3°min): Ratio :(Ibll00ff~) 6500'-12400' 8.5-9.0 20-25 18-22 4-5 cc's 85/15 15-30 · Displace hole to oil based mud. Insure no spacer or oil based mud is discharged. ,~ · Drill ahead, maintain low shear rate values with VG-69, Versamod, Versa HRP, and Alcomer 274. · Run centrifuge as needed to reduce solids buildup. · Pump weighted sweeps to aid in hole cleaning. · If sloughing coal becomes a problem, add 2 - 4 ppb of Ventro1401 to mud system or spot a concentrated pill of 20 - 25 ppb Ventrol 401 across coal zone prior to trips. · Run 7" liner. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax IJI~ILLING FLUlIJS Interval Summary (6" hole) Well K-I RD2 II Ill Solids Control Potential Problems Shale Shakers / Desilter / Centrifuge Coal sloughing, hole cleaning, drill solids buildup Interval Drilling Fluid Properties D~pth Mud Plastic Yield HTHP Interval:.:: w:ei~ht::: ViScOsitY: : :point FlUid:Loss: o/W, Gels: :,i::: : i~:: : (cp;:)::: :: :(IbltOOft:) ~: (ml/30~in)= RatiO:: 12400-13170 8.5-9.0 20 - 25 15-20 4 - 5 cc's 90/10 15 - 30 · .Drill ahead, maintain low shear rate values with VG-69, Versamod, Versa HRP, and Alcomer 274. · Run centrifuge as needed to reduce solids buildup. · Pump weighted sweeps to aid in hole cleaning. · If sloughing coal becomes a problem, add 2 - 4 ppb of Ventro1401 to mud system or spot a concentrated pill of 20 - 25 ppb Ventrol 401 across coal zone prior to trips. · Run 4 1/2" pm-drilled liner. Displace open hole volume to base oil (Mapco 200). · Pump a Kleenup spacer for displacement to brine. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLING FLUIDS Interval Summary (8.5" and 6" hole) Lost Circulation Problems Key Products Recommended LCM Pill Formulas Drilling Fluid / OM Seal / SafeCarb Fine, Medium, Coarse / Versa- HRP Lost Circulation Pill (Slight Losses) Volume OM' Seal Saf~C~rb' ' SafeCarb Versa HRP of Mud : Fine Medium ~ (barrels) : (PPb) ,;:i (PPb) :(PPb:) (PPb) 30 10 10 10 1/4 Lost Circulation Pill (Moderate LoSSes) Volume OM Seal safecarb SafeCarb Versa HRP of Mud Medium Coarse (barrels) :::::(pPb): := : (pPb) i:: (PPb): i: (PPb)::::~: 40 15 15 10 1/2 Lost Circulation Pill (Severe Losses) , ,, Volume OM Seal SafeCarb SafeCarb Versa H RP of Mud Medium Coarse Polymer (barrels) (ppb) (ppb) (ppb) (ppb) 50 15 20 130 1 · Versa HRP should be added last, only after all lost circulation material has been mixed. · If possible, spot pill across theft zone. Apply moderate pressure (50 - 100 psi) to squeeze pill into theft zone. (Do not exceed previous E.C.D. of circulation fluid). M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLING FLUIDS I K-22 J [ RECEIVED [ ~,::~ 09 2001 :1 K-12 ~ L:~Drof~ing~Prop Plots%King Prop OBMu g / / 0 /1,000 I ' 2,000 SCALE IN FEET 147 83' 33?' K-16 3,000 M-30 K-6 1 K-2 Unocal Corporation 909 W. 9th Avenue Anchorage, AK 99501 907-263-7660 UNOCAL Dan Williamson Drilling Manager 3 Janua~,2001 Ms. Julie Heusser Chairman Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Dear Mr. Seamount: Enclosed, please find the application for the Permit to Drill (Form 10-401) for the King Platform Well K-1RD2. The intent of this well is to exploit the G zone formation in the TBU Northwest Feature. Additionally Hemlock potential exists in the proposed target location. UNOCAL plans to spud this well approximately 5 February 2001. K-1RD2 will consist of approximately 6000' of 8-1/2" hole and 1300' of 6" hole drilled with with oil based mud. We plan on injecting the OBM liquid waste into King K-19 9-5/8" x 13-3/8" casing annulus. A separate letter will be sent outlining our request for annulus waste injection. Please contact the undersigned with any questions regarding this application. Sincerely, , Dan Williamson Drilling Manager enclosure Unocal Alaska ~""~ Union Oil Company of ~'~ 'nia 909 West 9th Avenue, . . Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 Ol- UNOCAL December 20, 2000 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 McArthur River Field, Hemlock Pool, G-Intervals, King Salmon Platform, Well K-1RD2 REQUEST FOR SPACING EXCEPTION ADL 18777 Dear " " .... .' Enclosed is our application for Permit to Drill McArthur River Field, Hemlock Pool, King Salmon Platform Well K-1RD2 (form 10-401) pursuant to 20 AAC 25.005 and our check No..~'0q¢~ t! in the amount of $100.00 as required under 20 AAC 25.005 (c)(1). Verification of Application by the undersigned stating that applicant is acquainted with the facts, pursuant to 20 AAC 25.055 (b), is attached as part of this application. Conservation order 228 establishes ten-acre drilling units for the McArthur River Field. 20 AAC 25.055 (a)(3) provides that no more than one well is to be drilled within any governmental quarter section; not closer than 1,000' from any well drilling to or capable of producing from the same pool. It is requested that the Commission approve an exception to the statewide spacing regulation for the .drilling of Well K-1RD2, ADL 18777. ~' , The specific location, interval and depth for the King Salmon Pl'atform Well K_ 1 RD2 are as follows: Surface Location: Surface Location: 135' FEL, 724' FSL, Sec 17, T9N, R13W, SM At Top Productive Interval: 891' FNL, 2416' FEL, Sec 19, T9N, R13W, SM At Total Depth: 1401' FNL, 2479' FEL, Secl9, T9N, R13W, SM Kickoff Depth: 6403' Distance to nearest well (K-10RD)' 151' at 12091'MD Unocal and Forcenergy are working interest owners in the K-1RD2 well. Furthermore, Unocal and Forcenergy are the owners and Unocal is the operator of all directly or diagonally offsetting sections. Thus, pursuant to 20 AAC 25.055 (d), notices by registered mail to contiguous landowners are not necessary. Pursuant to and 20 AAC 25.005 (c)(2) and AAC 25.055 (d)(2), enclosed is a plat showing the location of the well for which the exception is sought, all other completed and drilling wells on the property, and all other adjoining properties and wells. If you require additional information, you may contact me at 907-263-7882. Very Truly Yours, Shannon W. Martin Land/Legal Analyst Enclosures VERIFICATION OF APPLICATION FOR SPACING EXCEPTION COOK INLET, ALASKA ADL # 18777 Well: McArthur River Field Well K-1RD2 I, SHANNON W. MARTIN, Land/Legal Analyst, Union Oil Company of California, do hereby verify the following: I am acquainted with the application submitted for the drilling of the McArthur River Field, Well K-1RD2. I have reviewed the application submitted for the exception to 20 AAC 25.055 (a)(4) (statewide spacing) and all facts therein are true. I have reviewed the plat attached to said application, and it correctly portrays pertinent and required data. DATED at AnchOrage, Alaska this 20th day of December 2000. Shannon W. Martin Land/Legal Analyst STATE OF ALASKA THIRD JUDICIAL DISTRICT ) ) ss ) SUBSCRIBED TO AND SWORN before me this 20th day of December 2000. My Commission expires: u#orau.~ Trading Bay Unit King Salmon Platform Well K-1RD2 PROPERTY PLAT 0 1.000 2.000 3,00~ ~ I I SCALE IN FEET ADL-18731 Unocal Forcenergy ADL-389509 Forcenergy Trading Bay Unit Boundary ADL-21068 Unocal I ADL-18758-2 Unocal Forcenergy W. TRADI BAY 1 DLE RIVER ST. 2 ADL-18777 /J ' AD L-l ?59'4-1,A Unocal '~l~ ~ Unocal Forcenergy ! ' Forcenergy - - - - K-laRD K-10 K-101 K ...... 1 ]!:5 ])~.-- w. K-aRD~ K-19 3 ~ G-17 K-3RD G-15 G-29RD G-19 G-13 ADL-17594-2,A Unocal Marathon A-~DING BAY ~,-zj A-27 I ALASKA OIL AND GAS CONSERVATION COPl~IISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPRIOVAL NO. 80.80 Re' The application of Union Oil Company of Califomia, operator of the Trading Bay Unit (TBU), to drill and complete the TBU K-1RD2 well as part of the pressure maintenance project. Shannon W. Martin Land/Legal Analyst UNOCAL Corporation P O Box 190247 Anchorage, AK 99519-0247 Dear Mr. Martin: Your application dated December 20, 2000 for a "Permit to Drill" TBU well K-1RD2 is proposed to recover additional oil from the Middle Kenai "G" Oil Pool and the Hemlock Oil Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the TBU K-1RD2 well pursuant to Rule 5 of Conservation Order 80. Done at Anchorage, Alaska and dated February 9, 2001. Daniel T. Seamount, Jr. Commissioner Camill60echsli Taylor Commissioner Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION ,, , ADMINISTRATION INIT CLASS ~ ~,/ ~..~/~ WELL NAME J~- l ~ ~--PROGRAM: exp 1. Permit fee attached ........................ 2. Lease number appropdate',.;~' ~ ~..~:~??~././~).-.~/()( 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. dev v/ serv wellbore sag ann. disposal para req GEOL AREA 6~2~ ~.~'~ UNIT# ~ / ~ ~--%"~,P ON/OFF SHORE '/ reddl Sufficient acreage available, in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 10.9. Operator only affected party ................ Operator has appropfiate bond in force~_~..~.~_~ .C? ? .~.~?~ /c, ~ 11. Permit can be issued without conservation order ......... ~ N v ~, ~ ....... .:? ~ ...... ,' ~ . DATE 12. Permit can.be issued without administrative approval'.~, y ') ~.--~ /, I.~'~) / 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... N · 15. Surfa~ casing protects all known USDWs ........... ¥ N ,. 16. CMT vol adequate to circulate on conductor & surf csg ..... Y 17. CMT vol adequate to tie-in long string to surf csg ........ Y 18. CMT will cover all known productive hodzons .......... 19. Casing designs adequate for C, T, B & permafrost ....... ~ N 20. Adequate tankage or reserve pit ................. N (L,~,~-,=-~.~c,,~. c>-~%~,c~-~ ~--,,'--? ~ ,~,_%~--~.~'~-- ' 21. If a re-drill, has a 10403 for abandonment been approved... N "5~(~ -g-~'~c) '~. _ x ~,, 22. Adequate wellbore separation proposed ............. N 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ .L..~"~ 26. BOPE press rating appropriate; test to 5~[~ psig. Y N 27. Choke manifold complies w/APl RP-53 (May 84) ........ (~ N _ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY ~.. Permit can be issued wlo hydrogen sulfide measures ..... _Y. ~ -~, .~.//~-..~_.~ /.~ .~,,~ ,,--.c+.~.~-~, ..:~-<~¢.~__¢ ~;~, ~.'. (/~)~,,-~ ~ ~-d~." / 31. Data presented on potential overpressure zones .... ' i i ' ' 32. Se sm c analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) _./C ~ Y N "~ ?~-4~?/~~ £~ ~-.// ~'/Y"~F__ ,,~d/'/~ ' / "~" ............. 34. Contact name/phone for weekly progress reports [expl/~ry only] Y N , ~j'~ <,-5, ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N APPR . DATE (B) will not contaminate freshwater; or cause drilling waste Y N to surface; ~c-t,~b~) ~,T~.c..~*r~ ~',3% ~--.n~ ~" ~3,~- ~'~~ ~2-'-\c'~," (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOL~O. yG/y! ENGINEERING: ' UIC/Annular COMMISSION: Comments/Instructions: O Z O rtl c:~T~soffice\wordian\diana\checklist (rev. 11/01 I100)
