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Home My WebLink About196-1691. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Plug Back Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP Completion 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 14,660 feet 4,460 feet true vertical 7,210 feet N/A feet Effective Depth measured 4,460 feet 3,643 feet true vertical 3,407 feet 3,113 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / 13Cr / Vam Top 3,578' 3,082' Packers and SSSV (type, measured and true vertical depth)9-5/8"x5-1/2" Hys Iso Pkr N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Operations Manager Contact Phone: Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WTRSPL WAG Oil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 322-579 0 00 0 0160 06400 Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 112' Size 112' 4,914' Casing Conductor 8,461' N/A Water-Bbl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-169 50-029-22712-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: MILNE PT UNIT K-34 Plugs Junk measured Length measured TVD N/A ADL0375132 & ADL0375133 MILNE POINT / UGNU UNDEF WTRSP measured true vertical Packer Surface 20" 9-5/8" 112' 8,461'5,750psi Burst 1,490psi Collapse 470psi 3,090psi PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Meredith Guhl at 11:04 am, Jan 06, 2023 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.01.06 11:00:13 -09'00' David Haakinson (3533) RBDMS JSB 011023 WCB 10-24-2023 322-579 Plug Perforations Plug BackPerforate 196-169 Sundry Number ESP Completion DSR-1/6/23 MILNE PT UNIT K-34 MILNE POINT / UGNU UNDEF WTRSP _____________________________________________________________________________________ Revised By: TDF 1/5/2023 SCHEMATIC Milne Point Unit Well: MPU K-34 Last Completed: 12/18/2022 PTD: 196-169 TD =14,660’(MD) / TD = 7,210’(TVD) Orig. DF Elev.: 57.3’/ Orig. GL Elev.: 27.8’ 9-5/8” 11 12 & 13 9-5/8” HOWCO ‘ES’ Cementer @ 1,997’ 20” 2 & 3 1 PBTD = 8,363’ (MD) / PBTD = 4,881’(TVD) 6 20 17 TOC @ ~4460’19 14, 15 & 16 18 3/8” SS Capstring: Check Valve 1,700psi 4&5 7 &8 9&10 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A 19.124 Surface 112' 9-5/8" Surface 36 / K-55 / Btrc. 8.835 Surface 8,461’ TUBING DETAIL 4-1/2” Tubing 12.6 / 13Cr / Vam Top 3.958 Surface 3,578’ 3/8” Capstring Stainless Steel N/A Surface 3,578’ JEWELRY DETAIL No Depth Item 1 3,374’ XN-Nipple – Min ID = 3.725” 2 3,437’ Sencor Discharge Sub 3 3,438.7’ Discharge Head Adapter: SER # 900031002 4 3,439’ Upper Pump: 675 SERIES 045 STG 5 3,461’ Lower Pump: 675 SERIES 045 STG 6 3,493’ Gas Separator Intake 7 3,494’ Upper Tandem Seal: SER# 13838134 8 3,503’ Lower Tandem Seal: SER# 13838133 9 3,779 Upper Motor: 562 SERIES 500 HP/ 1800 171A 10 4,360’ Lower Motor: 562 SERIES 500 HP/ 1800 171A 11 4,574’ Motor Gauge & Cent. w/ Anode: 5SDHV086 - Btm @ 3,578’ 12 3,637’ 7" Tieback Sleeve 13 3,643’ 9-5/8" X 5-1/2" Hydraulic Isolation Packer 14 3,659’ 4-1/2" X Profile Nipple – 3.81” ID 15 3,669’ 4-1/2" LTC Production Overshot –Btm @ 3,675’ 16 3,672’ 4-3/4'' Hook Up Nipple 17 3,784’ 4-1/2'' 12.6# L-80 Wire Wrapped Screen 18 4,362’ Snap Latch Seal Assembly Note: 1.02' stung in-Btm @ 4,363’ 19 4,500’ Cement Retainer 20 8,363’ 9-5/8” HOWCO ‘EZSV’ Retainer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status UG4 3805’ 3835’ 3,182’ 3,194’ 30’ 12/10/2022 Open 3885’ 3930’ 3,212’ 3,227’ 45’ 12/10/2022 Open UG4A 4150’ 4350’ 3,303’ 3,369’ 200’ 12/10/2022 Open MB 7,262’ 7,362’ 4,441’ 4,482’ 100 11/23/1997 Closed MD2 7,427’ 7,572’ 4,508’ 4,566’ 145 11/23/1997 Closed ME 7,707’ 7,732’ 4,620’ 4,630’ 25 11/23/1997 Closed WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 70 deg. @ PBTD Hole angle thru perfs= 65-67 deg. TREE & WELLHEAD Tree CIW 4-1/16” 5M ‘FLS’ Wellhead 11”x 11” 5M FMC Gen 6 Unibore w/ two 2” 5M valves on side ports 11” x 4.5” tubing hanger 4.5” TCII threads top and bottom and 4” CIW-H BPV profile GENERAL WELL INFO API: 50-029-22712-00-00 Drilled and Cased by Nabors 22E - 11/22/1996 Completed by Nabors 4ES – 1/25/1997 Completed by ASR#1 - 12/18/2022 OPEN HOLE / CEMENT DETAIL 20” Cmt w/250 sx Arcticset 1 (Approx.) in a 24” Hole 9-5/8” 1,740 sx PF ‘E’, 357 sx Class ‘G’, 204sx PF ‘C’ in a 12-1/4” Hole Well Name Rig API Number Well Permit Number Start Date End Date MP K-34 ASR #1 50-029-22712-00-00 196-169 12/3/2022 12/18/2022 assist BOP rep change out both door packing seals on VBR rams. prep to test BOP. Attempt to BOPE test. Test 3-1/2" JT with VBRs good test. On 4-1/2" VBR test, VBR's (kill side) developed an external leak. Decision made to change seals again. Change out packing seals on kill side VBR door. Attempt to BOPE test. Test 3-1/2" with VBR's, same result, (kill side) developed an external leak. Decision made to change VBR (kill side) door out completely, Blow down stack & change out. Line up to fill IA w/ 9.3 PPG NACL brine. Fill at 1.5 BPM w/ 40psi. Monitor IA on vac then static. Test BOPE as per approve sundry, AOGCC waived witness. Perform accumulator drawdown. Testing complete. Blow down testing lines. L/D tests JTs. & prep for well operations. W/ wellhead rep. Pull CTS & BPV. Fill pits w/ 9.3 ppg brine. P/U landing JT. Screw into hanger. Open IA well on vac. BOLDS, unseat hanger. P/U hanger off seat at 91k. P/U wt = 86k. Drag seen f/ 88k to 84k swing. B/O hanger & L/D. Run ropes over sheave tie ESP/ Cap line on spools. Prep to POOH w/ ESP. POOH w/ 4-1/2" 12.6# L-80 VAM TOP ESP completion. L/D to pipe shed. F/ 6,840' T/ 5,786'. Wellhead rep. Tested CTS plug & ensured control ports are sealed. (Good). Via crane, Install stack A onto wellhead & set rig floor. Raise derrick. Engage lock pins. Tighten guy lines. Hook up accumulator lines, function test BOPE. Torque bolts on stack. Install flow spools & catch pan. Circ fluid thru stack. P/U 2.375" test JT. set & lock in rams for shell test.. Run heated glycol lines, Perform temp checks on lines. Perform shell test w/ bag. Good test. Test BOPE as per approved sundry, AOGCC inspector Guy Cook waived witness. Test BOPE t/ 250 psi low & 2500 psi high f/ 5/5 charted mins. 12/3/2022 - Saturday Continue testing BOPs. found water coming from the weep hole on blinds (kill side). mobilized BOP rep and seal kit. help BOP rep change out packing seals on blind ram. prep to test BOP. Continue testing BOPs as per approved sundry. Completed to test #8. Rig service. Check equipment .Discovered leaking coolant line. Replace leaking coolant hose. cont. to replace coolant hose. Restart rig & inspect. (good). cont. to attempt to completed BOPE test #9. VBR established leak. With BOPE rep. on site. Prep to rebuild rams. Change out VB ram top seals, & closing rubbers. Slight damage on ends of top seals. Completed 3-1/2" VBR test, continue on to test with 4-1/2" VBR, Discovered external leak on Top VBR (kill side) With BOPE rep. on site. Prep to rebuild packing on VBR's. Blow down stack, & Open up VBR doors for packing change. 12/6/2022 - Tuesday 12/4/2022 - Sunday Cont'd testing BOPE as per approved sundry T/ 250 psi low & 2500 psi high F/ 5/5 charted mins. While perform equipment checks observed glycol heater line leaking. Shut down operation & clean up. Environmental notified & spill accessed to be 15 gallons. On test #7 noticed external leak on other Blind ram door "choke side". Decision made to change out whole door. With BOPE rep. change door on blinds. Re-install accumulator lines. Test function & pressure test to ensure packing sealed. (good). Change out manual choke valve on stack due to slight leak on previous test. Remove choke HCR & install new manual. Test manual valve ensure function (good) Stab New HCR on choke line as well. Torque all bolts & line up to cont. testing BOPE. Line up to pressure test new equipment on BOPE, Perform low to 250 psi & 2500 psi high, Slight bled of test. Function new equipment & grease. cont. to proof test equipment. 12/5/2022 - Monday 12/2/2022 - Friday No operations to report. 11/30/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 12/1/2022 - Thursday No operations to report. W/ wellhead rep. Pull CTS & BPV. Requirement of sundry. -WCB P/U landing JT. Screw into hanger. Open IA well on vac. BOLDS, unseat hanger. P/U hanger off seat at 91k Test BOPE as per approved sundry, AOGCC inspector Guy Cook waived witness. Test BOPE t/ 250 psi low & 2500 psi high f/ 5/5 charted mins. Well Name Rig API Number Well Permit Number Start Date End Date MP K-34 ASR #1 50-029-22712-00-00 196-169 12/3/2022 12/18/2022 12/9/2022 - Friday Complete pumping of cement. 350 bbls total, chased w/ 5 bbls fresh water, Avg rate & psi 3.5 BPM w/ 320 psi. 12 bbls of 9.3 ppg brine f/ rig, pump at 1 bpm 900 psi. during chasing of cement, pressure increased to 2200 psi at 1 bpm. cont. to pressure up for final squeeze pressure of 2975 psi. Bleed off IA pressure & open bag. Unstung from cement retainer. Pull JT #144 & 143 out of hole. Rigged up to reverse circulate at 4450' MD. Reverse Circ staging up T/ 3 BPM 1250 psi. Taking samples to ensure clean brine back to surface. Pump a total of 57 bbls of 9.3 ppg brine. POOH F/ 4450' T/ 4,343'. Rig down cementers, blow down lines. Prep to POOH. POOH w/ cement stinger F/4,343' T/ 10'. Well taking proper displacement. L/D cement stringer. Hardened cement behind 1 stinger bow spring. Clean & clear floor. Rig down ESP hanging in derrick. Load guns in shed & prep for E-line. Rig up E-line tools & equipment. Spot in & hold PJSM. RIH w/ 8.5" GR & JB. lost all down weight at 3850'. Inc. deviation change 3 per 100' at depth. Total inc. 69. POOH. Inspect tools on surface, small cement chucks in JB. Decision made to run TCP. Change out handling equipment f/ gun run. Service Rig. P/U & M/U 4-1/2" TCP 12 SPF GUNS. as per completion reps. Inspect & assemble. Total guns assy. & firing head T/ 572'. Hole full, returning correct displacement. 12/7/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Cont. POOH w/ 4-1/2"" 12.6# L-80 VAM TOP ESP completion. L/D to pipe shed. F/ 5,786' T/ 126'. L/D ESP assy. Pump X 2, intake seals X2, motor, centralizer. Damage found on ESP cable at intake & corrosion on centralizer. L/D to Pipe Shed. Clamp totals = 173 CC, 1 SC, 2 PRO C, 9 Pump C. Missing to "doors" for protectolizer clamps. L/D to shed. Remove ESP from Shed. Change pipe handling equipment. Rack & tally 3-1/2" PH6. Load clean out BHA. P/U 9-5/8" scraper assy. & inspect. XO t/ PH6. RIH W/ 9-5/8" scraper assy. on . 3-1/2" 12.9# P110 PH6 F/ 22' T/ 3547'. Fill hole w/ 9.3ppg Brine at a rate of 5 BPH. 12/8/2022 - Thursday Cont. RIH W/ 9-5/8" scraper assy. on 3-1/2" 12.9# P110 PH6 F/ 3,547' T/ 4,609'. Fill hole w/ 9.3ppg Brine at a rate of 5 BPH. Reciprocate x2 in packer intervals 3,560'-3,660' & 4,350' - 4,550', Observed no drag w/ scraper. POOH W/ 9-5/8" scraper assy. on 3-1/2" 12.9# P110 PH6 F/ 4,609' T/ 22' Fill hole w/ 9.3ppg Brine at a rate of 5 BPH. L/D scraper BHA & inspect. Clean & clear floor. Remove BHA from shed & Load up cement retainer. Strap & tally. M/U 9-5/8" cement retainer & XO to PH6 workstring. RIH W/ 9-5/8" cement retainer on 3-1/2" 12.9# P110 PH6 F/ 20' T/ 1,535'. Fill hole w/ 9.3ppg Brine at a rate of 5 BPH. Service Rig. HYD leak on elevator hose. Down time. Repair elevator hose. cont. RIH W/ 9-5/8" cement retainer on 3-1/2" 12.9# P110 PH6 F/ 1,535' T/ 4,500'. Fill hole w/ 9.3ppg Brine at a rate of 5 BPH. Set Cement retainer. P/U =46k. S/O = 29K. Rotate 12 turns to right, slack off to depth 4,504' P/U T/ 76K f/ 30k over. S/O T/ 21k f/ 8K down. P/U T/ 104K f/ 58k over. S/O T/ -1k Push f/ 30K down. S/O T/ -13k Push f/ 42K down. Cement retainer Set. Pressure test IA t/ 1,500 PSI. Hold f/ 30 mins charted (Good). Bleed off, rotate 12 turns. Unsting from Cement retainer. Sting back in apply 590 psi to IA. Rig up to cement w/ Halliburton. Rig up hard lines. PJSM w/ crew & Cementers. PT lines to 3,000 psi (good). Pump 15 bbls fresh water followed by 200bbls 15.3 ppg cement at 3.5 BPM w/ 180psi. Cont. to cement. RIH W/ 9-5/8" cement retainer on 3-1/2" 12.9# P110 PH6 F/ 1,535' T/ 4,500'. Pump 15 bbls fresh water followed by 200bbls 15.3 ppg cement M/U 9-5/8" cement retainer & XO to PH6 workstring. Unstung from cement retainer Complete pumping of cement. 350 bbls total final squeeze pressure of 2975 psi L/D ESP assy Reciprocate x2 in packer intervals 3,560'-3,660' & 4,350' - 4,550', RIH W/ 9-5/8" scraper assy Set Cement retainer Tubing and old ESP removed from well. -WCB Cont. POOH w/ 4-1/2"" 12.6# L-80 VAM TOP ESP completion. L/D to pipe shed. Over 3x the planned vol of cement was pumped. -WCB Well Name Rig API Number Well Permit Number Start Date End Date MP K-34 ASR #1 50-029-22712-00-00 196-169 12/3/2022 12/18/2022 Hilcorp Alaska, LLC Weekly Operations Summary Continue testing BOPE as per approved sundry. Test to 250 psi low / 2500 psi high. All tests charted for 5/5 minutes. Blow down all testing equipment. Change over rig pipe handling equipment to 4-1/2". Fill the hole with 17 bbls. 9.3# Brine. Remove Pipe from the pipe racks. Load Rack and Tally the 4-1/2" Screens, 2-3/8" Inner String, and the Snap Latch Assembly. RIH with the Snap Latch Assembly W/ 4-1/2" 12.6# L-80 Wire Wrapped Screens and Centralized Pipe Assembly to 683'. RIH with 22 joints of 2-3/8" Inner Work String inside of the Snap Latch and Screen assembly. M/U the 9-5/8 JS-2 Retrievable Packer Assembly and RIH on 3-1/2" 12.95# PH-6 Drill Pipe to the Sump Packer at 4362" MD. Continue T/ M/U TCP assy. RIH T/ firing head T/ 585'. XO & M/U to workstring. Change handling equipment. Service rig, fluid check. Damaged / leaking Hydraulic hose found in RIG. Shut down & change out. RIH W/ 4-1/2 " TCP guns conveyed on 3-1/2" PH6 12.95# P110 pipe to Depth of 4360', last motion up. P/U wt 46K S/O wt = 26K. Rig up E-line to correlate depth. PJSM. RIH w/ 1-11/16" gamma/ CCL. Record & log. Correlate w/ RA tag & historic open hole log. POOH rig down E-line. Pick up to place on depth as per Well plan. Top shot 3,805' T/ bottom Shot 4,350' MD. Good indication of fire on floor. Monitor Well. Slight flow increase. W/ Pipe rams shut bleed off gun gas out gas buster. CO2 present. Fill hole w/ 14 bbls. Well taking fluid, open pipe rams. 20 BPH loss rate. P/U wt = 46K S/O wt = 26K. POOH w/ spent TCP assy. T/ firing head F/ 4360' T/ 585'. M/U safety joint f/ well control. Change out handling equipment. for 4-1/2" TCP guns. PJSM. L/D 4-1/2" "Spent" TCP GUNS. as per completion reps. Inspect & dissemble. Hole losing 11 BPH. 12/10/2022 - Saturday cont. RIH w/ 9-5/8" sump packer on 3-1/2" 12.95# p110 PH6 pipe F/ 22' T/ 4,367'. P/U & to place 9-5/8" perm packer on depth at 4,360' Drop 1.43" ball. Wait 5 min then pump at 1.5 BPM. PSI up on hyd. setting tool T/ 4,200'. Bleed off psi & s/o 10k on packer, (packer set) Pull / sheared off. setting tool on packer w/ 45k P/U wt. Line up to pickle pipe w/ sand. R/U sand pods lining up down stream of mud pumps. Service RIG. Pump sand down pipe at 3/4 BPM W/ 1,800 psi. Pump 200 lbs of sand. Psi increase to 2,100 psi. Total pumped 30 bbls. Reverse circulate remnant sand out of pipe. Pump 90 bbls reversing w/ 3/4 BPM 600 psi. Observe no sand to shakers. POOH w/ setting tool on 3-1/2" 12.95# p110 PH6 pipe. F/4,360' to surface. Pull pulling wet. L/D setting tool. Last JT & setting tool packed off w/ sand. Clear out & L/D. Clean & clear floor. Prep for BOPE test. Loss rate to well = 8.4 BPM. Load test joints, P/U test plug. Drain stack, set plug . Load stack w/ fresh water. Open IA & monitor loss rate. P/U 2-3/8" test JT & circulate surface lines with fresh water. Across stack to purge all air. Test BOPE as per approved sundry. Preform tests T/ 250 psi low & 2500 psi high. All test held for 5/5 charted mins. Current on test # 5 at time of report. 12/13/2022 - Tuesday 12/11/2022 - Sunday Complete Laying down TCP guns. All shots fired. Clear floor of TCP handling Equipment. P/U equipment F/ scraper run. M/U 9- 5/8" scraper, 4-3/4" bumper sub & XO to PH6 workstring. RIH w/ 9-5/8" Scraper assy. on 3-1/2" 12.95# p110 PH6 pipe F/ 22' T/ 2,028'. Rig service, Inspect derrick & change air filters on rig. con't RIH w/ 9-5/8" Scraper assy. on 3-1/2" 12.95# p110 PH6 pipe F/ 22' T/ 4,375'. Seeing 1-5k drag through perfs, Pump double displacement. Rig up lines to reverse circulate. Reverse circulate at 3.5 bbls w/ 355 psi. Observed no gas. After 2x bottoms up, slight cement contamination returning. Pump until fluid clean. Pump a total of 290 bbls, lost 95 bbls for cir 25 bbls to cuttings box. dynamic losses 34 BPH. POOH w/ 9-5/8" Scraper assy. on 3-1/2" 12.95# p110 PH6 pipe F/ 4,375' T/ 22'. Pump double displacement. L/D scraper Assy. Inspect, no excess wear. L/D clean & clear floor. M/U 9-5/8" sump packer. & J-hyd setting tool, XO to PH6. RIH w/ 9-5/8" sump packer on 3-1/2" 12.95# p110 PH6 pipe F/ 22' T/ 1,600'. 12/12/2022 - Monday Pump sand down pipe at 3/4 BPM W/ 1,800 psi. Pump 200 lbs of sand. RIH w/ 9-5/8" sump packer on 3-1/2" 12.95# p110 PH6 pipe F/ 22' T/ 4,367'. P/U & to place 9-5/8" perm packer on depth at 4,360' Drop 1.43" ball. M/U 9-5/8" sump packer RIH with 22 joints of 2-3/8" Inner Work String inside of the Snap Latch and Screen assembly. M/U the 9-5/8 JS-2 Retrievable Packer Assembly and RIH on 3-1/2" 12.95# PH-6 Drill Pipe to the Sump Packer at 4362" MD. Top shot 3,805' T/ bottom Shot 4,350' MD. & J-hyd setting tool Well Name Rig API Number Well Permit Number Start Date End Date MP K-34 ASR #1 50-029-22712-00-00 196-169 12/3/2022 12/18/2022 12/17/2022 - Saturday 12/16/2022 - Friday Continue to POOH laying down 3-1/2" PH-6 and the Packer running tool. R/U Haliburton Slickline. Make two runs to retrieve the Ball & Rod. One run to Retrieve the RHC plug. R/D Slickline. R/U Summit Equipment. Hang Sheave in the mast. Run ESP cable and the Capillary line threw the sheave. Rack & Tally 4-1/2" VAMTOP CR Tubing and ESP Assem. M/U ESP Assembly Centralizer, Motor Gauge, 2 ea. Motors, Upper & Lower Tandem, Gas Separator, 2 ea. Pumps, Discharge Head, Service with oil and test. Pumps where froze. Spent +/- 2 hours thawing out pumps to ensure the shafts would turn. Summit did final checks before running in. Started RIH at report time with ESP Completion on 4-1/2 VAMTOP 12.6# 13 CR tubing. Pump 3 bbls. per hour for hole fill. 12/14/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Engage the sump packer at 4364' Set 15K down to verify stung in. Pull up to 59K to unsnap the snap latch. After unsnapping the weight dropped off to 50K to verify. Re-engage the sump packer. Set the 9-5/8" GP Packer. Close annular and attempt to test backside with no success. Made three attempts, moving the packer up hole 1 ft. each time. no test. Found the packer would set each and every time, but the by-pass would not fully close. On the final attempt, moving the packer up hole 5 ft. The packer set and the By-Pass closed. Pressure tested the backside to 1000 psi. Good test. Prepare all equipment for Gravel Pack Operation, R/U Sand Hopper and related lines. Transferred fluids in preparations. Established initial circulating pressures at (1 bpm @ 80 psi,)(1.5 bpm @ 180 psi,)( 2 bpm @ 330 psi.)( 2.5 bpm @ 540 psi.)( 3 bpm @ 680 psi.) Load sand injector pots and begin pumping sand at 1 BPM -160 PSI. Work up to a steady rate at 2.5 BPM 560 PSI. 15:05 HRS Observed pressure increase to 750 PSI @ 2.5 BPM 560 PSI. 15:05 HRS Observed pressure increase to 750 PSI @ 2.5 BPM. 15:20 HRS Pressure increase to 900 PSI @ 2.5 BPM. 15:40 HRS Pressure increase to 1800 PSI @ 1.7 BPM. 16:08 HRS Pressure increased to 3400 PSI @ .8 BPM rate Stop Mixing sand. 16:10 HRS Screened out @ 2600 PSI, Bled pressure to formation to 125 PSI Total fluid pumped 363.6 BBLS Total sand away 11,700 LBS 234 Sacks. 16:15 HRS Pressure to Pressure to 2600 PSI Bled to formation 125 PSI. Pressure to 2800 PSI Bled to formation down to 65 PSI. Pressure to 3420 PSI Bled to formation to 50 PSI. Open the By- Pass. Pressure down annulus, and observe pressure drop to the tbg side. Bypass is open. Pump down annulus to reverse circulate 2 Tubing volumes to the slop tank. Observed no sand at returns. OE decision to POOH for upper completion. Blow down and Rig down all Gravel Pack Equipment. Transfer all returns to Disposal Facilities. Clean up. Release GP / JS-2 Packer and POOH laying down 3-1/2" PH-6 Drill Pipe, the 22 joints of 2-3/8" work string and the JS-2 Packer. Rack and Tally Upper Completion. 12/15/2022 - Thursday Continue to Rack & Tally Upper Completion and first row of PH-6 Drill Pipe. M/U Upper Gravel Pack Completion as per Program Detail. with 8.13" Overshot, 9-5/8" Isolation Packer, 7" Tieback Sleeve, Running Nut and XN Nipple. RIH with Upper Completion on 3-1/2" PH-6 Drill Pipe to Engage Overshot over Hook up nipple. Drop Ball & Rod. After latching up the Drill pipe elevators, Employee observed the bolts holding the setting plate had sheared off. Remove and Repair damaged Elevators. Phase 1 weather moved in. Decided to wrap insulate and heat the drill pipe and hose above the rig floor before pumping and testing. Pressure up the Tubing side to 3800 psi and hold for 30 minutes to set the Hydraulic Isolation Packer. PT the backside and the Packer to 1500 psi for 30 charted minutes. Blow down all circulating lines and equipment. R/D circulating equipment on the rig floor. Swivel up. Release from the 9-5/8" Hydraulic Isolation Packer. Flow Check the well static and POOH laying down PH-6 Drill Pipe to 1200'. Shut down to clean the Rig and equipment. PT the backside and the Packer to 1500 psi for 30 charted minutes PT required in the sundry. -WCB Load sand injector pots and begin pumping sand at 1 BPM -160 PSI. Work up to a steady rate at 2.5 BPM 560 PSI. 15:05 HRS Observed pressure increase to 750 PSI @ 2.5 BPM 560 PSI. 15:05 HRS Observed pressure increase to 750 PSI @ 2.5 BPM. 15:20 HRS Pressure increase to 900 PSI @ 2.5 BPM. 15:40 HRS Pressure increase to 1800 PSI @ 1.7 BPM. 16:08 HRS Pressure increased to 3400 PSI @ .8 BPM rate Stop Mixing sand. 16:10 HRS Screened out @ 2600 PSI, Bled pressure to formation to 125 PSI Total fluid pumped 363.6 BBLS Total sand away 11,700 LBS 234 Sacks Well Name Rig API Number Well Permit Number Start Date End Date MP K-34 ASR #1 50-029-22712-00-00 196-169 12/3/2022 12/18/2022 Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. Continue to RIH with 4-1/2" ESP Completion as per program detail to 3578' MD. Test ESP Cable every 2000'. Pump 2.5 BPH for hole fill. Ran a total of 85 joints 4-1/2 VAMTOP. 50 Cross Collar Clamps, 4 Seal Clamps, 3 motor clamps, 4 pump clamps,1 splice clamp. PUW = 56K, SOW=34K. Make up Landing Joint and Tubing Hanger. Terminate ESP Cable through the Hanger. Summit did final checks. Land Tubing Hanger with BPV Installed. RILDS. Well is secured. Monitored Cap Line Pressure while Landing hanger. Start Rigging Down. Suck out the Pits. Obtain Confined Space Permit for Pit Cleaning operations. R/D rig Floor Pipe Handling Equipment. R/D all ESP Running Equipment. Move Pipe Sheds to A-Pad. Clean Pits 1 & 2. Rig Released at 00:01 on 12-18-2022. Continue Rigging Down. Clean Pits 3 & 4. Move Catwalk from the rig and stage off to the side. Remove Accumulator Hoses from the BOP's. R/D Bird Bath. N/D Flow Spools. R/D Circulating Lines. Pull Racking Pins. Install Rack Stabilizers. Lay Mast Down And Secure. No operations to report. 12/20/2022 - Tuesday 12/18/2022 - Sunday Continue to RDMO. Lay Down Mast and Secure for Transport. Rig Down Pit Modules and secure for Transport. With Crane support fly the Flow Spools and Equipment from the rig floor. Fly the Rig Floor onto transport trailer and secure. N/D BOP Stack and Secure to Transport trailer. N/U Production Tree and test void to 500 low / 5000 high for 5min. / 10 min. Summit perform final checks on ESP Cable and Cap Line. 12/19/2022 - Monday 1 Regg, James B (OGC) From:Alaska NS - ASR - Well Site Managers <AlaskaNS-ASRWellSiteManagers@hilcorp.com> Sent:Tuesday, December 13, 2022 7:58 PM To:DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Regg, James B (OGC) Cc:Alaska NS - ASR - Well Site Managers Subject:BOPE Test 12-13-2022 Attachments:MPU K-34 BOPE test 12-13-22.xlsx Please find attached BOPE Test for 12‐13‐2022 Regards, ASR DSM’s Hilcorp DSM: 907‐685‐1266 Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Milne Point Unit K-34PTD 1961690 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:ASR 1 DATE:12/13/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1961690 Sundry #322-579 Operation:Drilling:Workover:x Explor.: Test:Initial:Weekly:x Bi-Weekly:Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1366 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2 3/8"P Flow Indicator P P #2 Rams 1 2 7/8" x 5"P Meth Gas Detector P P #3 Rams 1 Blinds P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"P Time/Pressure Test Result HCR Valves 1 2 1/16"P System Pressure (psi)3010 P Kill Line Valves 2 2 1/16"P Pressure After Closure (psi)1750 P Check Valve 0 NA 200 psi Attained (sec)16 P BOP Misc 0 NA Full Pressure Attained (sec)54 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 / 2255 PSI P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 20 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0 NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/12/22 05:26 Waived By Test Start Date/Time:12/13/2022 3:00 (date)(time)Witness Test Finish Date/Time:12/13/2022 8:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Hilcorp Test preformed w/ 2-3/8", 3-1/2", and 4-1/2" joints C. Pace / C. Greub Hilcorp Alaska LLC S.Heim / R. Gallen MPU K-34 Test Pressure (psi): askans-asr-toolpushers@hilcorp.co ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022)2022-1213_BOP_Hilcorp_ASR1_MPU_K-34         STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Su bm it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 12/6/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name: PTD #1961690 Sundry #322-579 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1366 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2 3/8"FP Flow Indicator P P #2 Rams 1 2 7/8" x 5"FP Meth Gas Detector P P #3 Rams 1 Blinds FP H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"FP Time/Pressure Test Result HCR Valves 1 2 1/16"FP System Pressure (psi)3050 P Kill Line Valves 2 2 1/16"P Pressure After Closure (psi)1750 P Check Valve 0 NA 200 psi Attained (sec)17 P BOP Misc 0 NA Full Pressure Attained (sec)61 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 @ 2218 P No. Valves 16 FP ACC Misc 0 NA Manual Chokes 1 FP Hydraulic Chokes 1 P Control System Response Time:Time (sec) Test Result CH Misc 0 NA Annular Preventer 21 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0 NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:7 Test Time:107.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 11/30/22 18:56 Waived By Test Start Date/Time:12/2/2022 10:30 (date) (time)Witness Test Finish Date/Time:12/6/2022 22:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Hilcorp Test performed w/ 2-3/8", 3-1/2", and 4-1/2" joints, Test# 2 fail / pass. Change Manifold valve C-10. Re-test (good) Tests # 3,4,5 F/P Found leaking ram body doors and blind body on double gate. Change whole double gate. Re-preform all tests due to failed DG. retest all (good) Test #6 F/P changed HCR choke re-test (good) Test # 7 F/P change C1 "choke manual" re-test (good) Test # 8 F/P flushed choke to allow better bleed choke test. re-test (good) Bottle precharge pressure 1,000 psi. Excluding repairs total test time. 18hrs. J. Werlinger/ C. Greub Hilcorp Alaska LLC A. Haberthur/ R. Gallen MPU K-34 Test Pressure (psi): askans-asr-toolpushers@hilcorp.co ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022) 2022-1206_BOP_Hilcorp_ASR1_MPU_K-34 FP FP FP FP FP FP FP 7 107.5 Test # 7 F/P change C1 "choke manual" re-test (good) Test Excluding repairs total test time. 18hrs. Manifold valve C-10. Test performed w/ 2-3/8", 3-1/2", and 4-1/2" joints, Test# 2 fail / pass. Change leaking ram body doors and blind body on double gate. F/P changed HCR choke leaking ram body doors and blind body on double gate. Change whole double gate. Re-preform all tests due to failed Test # 7 F/P change C1 "choke manual" Test # 7 F/P change C1 "choke manual" DG. retest all (good) Test #6 F/P flushed choke Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/02/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221202 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 222-34 50283201860000 222039 11/22/2022 AK E-Line Perf BRU 233-23 50283201360100 222050 11/3/2022 AK E-Line GPT BRU 244-27 50283201850000 222038 11/23/2022 AK E-Line Perf GPT CLU 05RD2 50133204740200 222092 11/17/2022 AK E-Line Perf MPU K-34 50029227120000 196169 11/10/2022 AK E-Line Punch CLU 13 50133206460000 214171 11/12/2022 Halliburton SBHP END 3-25B 50029221250200 203021 11/24/2022 Halliburton PPROF PBU S-15 50029211130000 184071 11/24/2022 Halliburton RBT PBU Z-221 50029237040000 221095 11/17/2022 Halliburton IPROF PBU Z-221 50029237040000 221095 11/19/2022 Halliburton IPROF Please include current contact information if different from above. T37345 T37346 T37347 T37348 T37349 T37350 T37351 T37352 T37353 T37353 By Meredith Guhl at 12:25 pm, Dec 02, 2022 MPU K-34 50029227120000 196169 11/10/2022 AK E-Line Punch Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.02 12:24:17 -09'00' Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/16/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221116-1 Well API # PTD # Log Date Log Company Log Type AOGCC Eset# MPU KͲ37 50029226740000 196076 11/8/2022 READ CaliperSurvey MPU KͲ34 50029227120000 19616911/9/2022 READ CaliperSurvey Please include current contact information if different from above. 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Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.10.07 16:14:03 -08'00' RBDMS JSB 101122 ZtK tĞůů͗DWh<Ͳϯϰ ĂƚĞ͗ϭϲ^ĞƉƚϮϬϮϮ tĞůůEĂŵĞ͗DWh<Ͳϯϰt^tW/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϮϳϭϮͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^/t^t΀^W&Ăŝů΁WĂĚ͗<ͲWĂĚ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗EŽǀĞŵďĞƌϭ͕ϮϬϮϮZŝŐ͗^Zϭ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍zĞƐĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗dŽŵ&ŽƵƚƐWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϵϲͲϭϲϵ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗dŽĚĚ^ŝĚŽƚŝ;ϵϬϳͿϳϳϳͲϴϰϮϬ;KͿ;ϵϬϳͿϲϯϮͲϰϭϭϯ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗dĂǇůŽƌtĞůůŵĂŶ;ϵϬϳͿϳϳϳͲϴϰϰϵ;KͿ;ϵϬϳͿϵϰϳͲϵϱϯϯ;DͿ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ ϭϳϮϲƉƐŝΛϯϲϬϬ͛ds ϳͬϯϭͬϮϬϭϴ^,W^ͮϵ͘ϮϮWW' DW^W͗ ϭϯϲϲƉƐŝ 'ĂƐŽůƵŵŶ'ƌĂĚŝĞŶƚ;Ϭ͘ϭƉƐŝͬĨƚͿ DĂǆ/ŶĐůŝŶĂƚŝŽŶϳϯ͘ϱΣΛϱϯϬϲ͛D ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ dŚĞDŝůŶĞWŽŝŶƚ<ͲϯϰǁĞůůǁĂƐĚƌŝůůĞĚĂƐĂ<ƵƉĂƌƵŬĚĞǀĞůŽƉŵĞŶƚǁĞůůƚŚĂƚd͛ĚĂƚϭϰ͕ϲϲϬ͛͘dŚĞǁĞůůǁĂƐ ƉůƵŐŐĞĚďĂĐŬĨŽƌĂŶhŐŶƵǁĂƚĞƌƐŽƵƌĐĞǁĞůůŝŶƚŚĞĐĞŵĞŶƚĞĚϵͲϱͬϴ͟ĐĂƐŝŶŐŝŶEŽǀĞŵďĞƌϭϵϵϳ͘dŚĞŝŶŝƚŝĂů^W ĂŶĚƐƵďƐĞƋƵĞŶƚ^WƐĨĂŝůĞĚĂŶĚǁĞƌĞƌĞƉůĂĐĞĚϴƚŝŵĞƐĨƌŽŵϮϬϬϮƚŽƚŚĞŵŽƐƚƌĞĐĞŶƚŝŶEŽǀ͘ϮϬϮϬ͘dŚĞĂǀĞƌĂŐĞ ƌƵŶƚŝŵĞǁĂƐϮ͘ϱǇĞĂƌƐǁŝƚŚƚŚĞŵŽƐƚƌĞĐĞŶƚĨĂŝůƵƌĞũƵƐƚŽǀĞƌϰǇĞĂƌƐ͘^WƚĞĂƌĚŽǁŶƐŶŽƚĞƐŽůŝĚƐ͕ƐĐĂůĞĂŶĚ ĐŽƌƌŽƐŝǀĞĚĂŵĂŐĞƚŽƚŚĞƉƵŵƉƐĂƐĐŽŶƚƌŝďƵƚŽƌƐƚŽĨĂŝůƵƌĞ͘ 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ϳ͕ϱϴϮ͛ϵͲϱͬϴ͟ϯϲͲϰϯ͘ϱηsĞƌƐĂƚƌŝĞǀĞWĂĐŬĞƌ ϭϴ ϳ͕ϲϬϱ͛ϱͲϭͬϮ͟EͲϴϬůĂŶŬWŝƉĞ ϭϵ ϳ͕ϲϵϳ͛ϱͲϭͬϮ͟Ϭ͘ϭϮ'Ă͘WƌĞͲWĂĐŬ^ĐƌĞĞŶ;/сϰ͘ϳϳϴ͟Ϳ ϮϬ ϳ͕ϳϯϳ͛ϵͲϱͬϴ͟,KtKt^ƵŵƉWĂĐŬĞƌ Ϯϭ ϴ͕ϯϲϯ͛ϵͲϱͬϴ͟,KtK͚^s͛ZĞƚĂŝŶĞƌ WZ&KZd/KEd/> <ƵƉĂƌƵŬ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ D ϳ͕ϮϲϮ͛ ϳ͕ϯϲϮ͛ ϰ͕ϰϰϭ͛ ϰ͕ϰϴϮ͛ϭϬϬ ϭϭͬϮϯͬϭϵϵϳ KƉĞŶ DϮ ϳ͕ϰϮϳ͛ ϳ͕ϱϳϮ͛ ϰ͕ϱϬϴ͛ ϰ͕ϱϲϲ͛ϭϰϱ ϭϭͬϮϯͬϭϵϵϳ KƉĞŶ Dϳ͕ϳϬϳ͛ ϳ͕ϳϯϮ͛ ϰ͕ϲϮϬ͛ ϰ͕ϲϯϬ͛Ϯϱ ϭϭͬϮϯͬϭϵϵϳ KƉĞŶ ^t^͗ϰͲϭͬϮ͕͟ϭϮƐƉĨ;ϮϰŐƌ͘ϰϯ,Ϳ͕,Ϭ͘ϳ͕͟WĞŶĞƚƌĂƚŝŽŶϳ͘ϴϴ͕͟ϭϯϱͬϰϱĚĞŐƌĞĞƉŚĂƐŝŶŐ t>>/E>/Ed/KEd/> <KWΛϯϱϬ͛ DĂǆ,ŽůĞŶŐůĞсϳϬĚĞŐ͘ΛWd ,ŽůĞĂŶŐůĞƚŚƌƵƉĞƌĨƐсϲϱͲϲϳĚĞŐ͘ dZΘt>>, dƌĞĞ /tϰͲϭͬϭϲ͟ϱD͚&>^͛ tĞůůŚĞĂĚ ϭϭ͟ǆϭϭ͟ϱD &D'ĞŶϲhŶŝďŽƌĞǁͬƚǁŽϮ͟ϱDǀĂůǀĞƐ ŽŶƐŝĚĞƉŽƌƚƐϭϭ͟ǆϰ͘ϱ͟ƚƵďŝŶŐŚĂŶŐĞƌϰ͘ϱ͟d//ƚŚƌĞĂĚƐ ƚŽƉĂŶĚďŽƚƚŽŵĂŶĚϰ͟/tͲ,WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϳϭϮͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϮϮͲ ϭϭͬϮϮͬϭϵϵϲ ŽŵƉůĞƚĞĚďǇEĂďŽƌƐϰ^ʹ ϭͬϮϱͬϭϵϵϳ ZtK^WZĞƉůĂĐĞŵĞŶƚ ďǇEĂďŽƌƐϰ^ʹ ϰͬϮϱͬϮϬϬϮ ZtK^WZĞƉůĂĐĞŵĞŶƚďǇEĂďŽƌƐϰ^Ͳ ϯͬϯϭͬϮϬϬϯ ZtK^WZĞƉůĂĐĞŵĞŶƚďǇEĂďŽƌƐϯ^ʹϰͬϮϮͬϮϬϬϳ ZtK^WZĞƉůĂĐĞŵĞŶƚďǇŽǇŽŶϭϲʹϱͬϭϭͬϮϬϭϰ ZtK^WZĞƉůĂĐĞŵĞŶƚďǇEŽƌĚŝĐϯʹϰͬϮϯͬϮϬϭϱ 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ŽŶƐŝĚĞƉŽƌƚƐϭϭ͟ǆϰ͘ϱ͟ƚƵďŝŶŐŚĂŶŐĞƌϰ͘ϱ͟d//ƚŚƌĞĂĚƐ ƚŽƉĂŶĚďŽƚƚŽŵĂŶĚϰ͟/tͲ,WsƉƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϳϭϮͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϮϮͲϭϭͬϮϮͬϭϵϵϲ ŽŵƉůĞƚĞĚďǇEĂďŽƌƐϰ^ʹϭͬϮϱͬϭϵϵϳ KWE,K>ͬDEdd/> ϮϬ͟ŵƚǁͬϮϱϬƐǆƌĐƚŝĐƐĞƚϭ;ƉƉƌŽǆ͘ͿŝŶĂϮϰ͟,ŽůĞ ϵͲϱͬϴ͟ϭ͕ϳϰϬƐǆW&͚͕͛ϯϱϳƐǆůĂƐƐ͚'͕͛ϮϬϰƐǆW&͚͛ŝŶĂϭϮͲϭͬϰ͟,ŽůĞ DŝůŶĞWŽŝŶƚ ^ZZŝŐϭKW %23( Εϰ͘ϰϴΖ Εϰ͘ϱϰΖ Ϯ͘ϬϬΖ ϱϬϬϬη ϮͲϳͬϴΗǆϱΗsZ ϱϬϬϬη ůŝŶĚ ^͕ϭϭϱDyϳϭͬϭϲϱD;/ĨEĞĞĚĞĚͿ ϮϭͬϭϲϱD<ŝůů>ŝŶĞsĂůǀĞƐ ϮϭͬϭϲϱDŚŽŬĞ>ŝŶĞsĂůǀĞƐ ,ZDĂŶƵĂůDĂŶƵĂůDĂŶƵĂů ^ƚƌŝƉƉŝŶŐ,ĞĂĚ STATE OF ALASKA ALI"OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing E Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well Q Re-enter Susp Well❑ Other: ESP Change Out 0 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development ❑ Exploratory ❑ 196-169 3.Address: Stratigraphic❑ Service Q 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 _ 50-029-22712-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0375132 MILNE PT UNIT UGNU K-34 1 �, ,..P(� b'1�' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Ugnu Undef WTRSP )L P 2 8 201b 11.Present Well Condition Summary: L kTt•(- .cc I c•ect AOGCC Total Depth measured 14,660 feet Plugs measured 8,363 feet true vertical 7,210 feet Junk measured N/A feet 7,188,7,372, Effective Depth measured 83,636 feet Packer measured 7,422&7,737 feet 4,411,4,486, true vertical 4,881 feet true vertical 4,506&4,633 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' 1,490psi 470psi Surface 8,461' 9-5/8" 8,461' 4,914' 5,750psi 3,090psi Perforation depth Measured depth See Attached Schematic SCANNED FEB 2 22017 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13Cr/Vam Top 6,840' 4,286' (3)Versatrieve Packers and SSSV(type,measured and true vertical depth) BWD Sump N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A 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 0 180 0 Subsequent to operation: 0 0 4,571 0 2,810 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑✓ Exploratory❑ Development Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WTRSP Q Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-322 fa— Contact Ted Kramer Email tkramer@hilcorp.com Printed Name Bo York Title Operations Engineer Signature i Op•", . : e& Volk_ Phone 777-8345 Date 9/23/2016 I ai,4, jam. S-f(. L lb`1�f� RBDMS �v SE? 9 1016 Form 10-404 Revised 5/2015 Submit Original Only 14 • • Milne Point Unit Well: MPU K-34 SCHEMATIC Last Completed: Proposed HIilcorp Alaska,LLC PTD: 196-169 NOTE: TREE&WELLHEAD Orig.DF Elev.:57.3'/Orig.GL Elev.:27.8' 4/22/2007-Ran 109 new joints due to corrosion. Tree CIW 4-1/16"SM'FLS' j ' New tubing hanger installed due to bad BPV profile 11"x 11"SM FMC Gen 6 Unibore w/two 2"SM valves 2d' ; and landing joint threads. New cable install Wellhead on side ports 11"x 4.5"tubing hanger 4.5"TCII threads top and bottom and 4"CIW-H BPV profile OPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sx Arcticset 1(Approx.)in a 24"Hole ' 9-5/8""HOMO 9-5/8" 1,740 sx PF'E',357 sx Class'G',204sx PF'C'in a 12-1/4"Hole 'ES'Cementer . @1,997 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A 19.124 Surface 112' 9-5/8" Surface 36/K-55/Btrc. 8.835 Surface 8,461' TUBING DETAIL 44/2" Tubing 12.6/13-CR/Vam Top 3.958 Surface 6,840' WELL INCLINATION DETAIL KOP @ 350' Max Hole Angle=70 deg. @ PBTD Hole angle thru perfs=65-67 deg. JEWELRY DETAIL No Depth Item 1 6,673' X-Nipple-Minimum ID=3.725" 2 6,738' Discharge Head-HPDIS 3 6,739' Upper Pump-28HC7800 High Pressure Housing 4 6,762' Middle Pump-28HC7800 SXD S 6,786' Lower Pump w/Integral Intake-28HC7800 SXD 6 6,787' Upper Tandem Seal-HSB3DBUTMSEHL PFSA MnimumlD= 7 6,794' Lower Tandem Seal-HSB3DBLTMSEHL PFSA 3.725"@ 6,673' 4 8 6,802' Motor-CL4 HMI 1 9 6,836' Sensor ra► 10 6,838' Centralizer-Bottom @ 6,840' 2 11 7,188' 9-5/8"36-43.54 Versatrieve Packer 12 7,211' 5-1/2"N-80 Blank Pipe 13 7,251' 5-1/2"0.12 Ga.Pre-Pack Screen(ID=4.7781 s s 14 7,372' 9-5/8"HOWCO Versatrieve Packer 15 7,395' 5-1/2"N-80 Blank Pipe 6&7 16 7,422' S-1/2"0.12 Ga.Pre-Pack Screen(ID=4.778") td 17 7,582' 9-5/r 36-43.54 Versatrieve Packer 18 7,605' 5-1/2"N-80 Blank Pipe a 8 19 7,697 5-1/2"0.12 Ga.Pre Pack Screen(ID=4.778") 20 7,737' 9-5/8"HOWCO BWD Sump Packer fig 21 8,363' 9-5/8"HOWCO'EZSV'Retainer 10 GRAVEL PACK DETAIL 11 Upper Ugnu:4,200lbs of 20-40 Carbolite proppant behind screen v 12 �CaiJ �� Middle Ugnu:20,400lbs of 20-40 Carbolite proppant behind screen X' 13 t,,,)� Lower Ugnu:S,000lbs of 20-40 Carbolite proppant behind screen r1a PERFORATION DETAIL 1st i %16 an s Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status fl 17 MB 7,262' 7,362' 4,441' 4,482' 100 11/23/1997 Open ' 18 MD2 7,427' 7,572' 4,508' 4,566' 145 11/23/1997 Open k 19 ME 7,707' 7,732' 4,620' 4,630' 25 11/23/1997 Open r x' ' 20 SWS:4-1/2",12spf(24gr.43C BH),EHD 0.7",Penetration 7.88",135/45 degree phasing m_:- _,'21 GENERAL WELL INFO 9-5/8' API:50-029-22712-00-00 Drilled and Cased by Nabors 22E -11/22/1996 • Completed by Nabors 4E5-1/25/1997 TD=14,660(MD)/TD=7,210(TVD) RWO ESP Replacement by Nabors 4ES-4/25/2002 PBTD=8,363'(MD)/PBTD=4,881'(TVD) RWO ESP Replacement by Nabors 4ES-3/31/2003 RWO ESP Replacement by Nabors 3S-4/22/2007 RWO ESP Replacement by Doyon 16-5/11/2014 RWO ESP Replacement by Nordic 3-4/23/2015 Revised By:TDF 9/23/2016 RWO ESP Replacement by ASR 1-9/4/2016 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP K-34 Pump Truck 50-029-22712-00-00 196-169 8/9/16 9/4/16 Daily Operations: 8/3/2016-Wednesday No activity to report. 8/4/2016-Thursday No activity to report. 8/5/2016- Friday No activity to report. 8/6/2016-Saturday No activity to report. 8/7/2016-Sunday No activity to report. 8/8/2016- Monday No activity to report. 8/9/2016-Tuesday Well Kill Ops Little Red Services, 2-Peak Trucks Arrived on Location at 21:30 hrs. with 600 bbl. 8.9 ppg Filtered Brine, Started Pumping at 22:00hrs. Pump Down Tubing with 300bb1 @ 4 Bpm 1,700 Psi, Close Back Side in Pump 50 bbl away @ 1,700 psi Opened Back Side up to Flow back Tank Pumped 250bb1 @ 1,700psi (Total bbl Pumped 600.Total Returns to Tank 275 bbl.)Tubing psi=0 Ann psi=0. Well Head Rep installed BPV in Hanger. Nipple down Tree, Check Hanger Threads 4.5 TCII 8 Turns Check Travel on LDS (Good) Nipple up Bop Stack Torqued up Flanges, Set Co,man and Change House Trailers, Set Mud Boat. • • x Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP K-34 ASR#1 50-029-22712-00-00 196-169 8/9/16 9/4/16 Daily Operations: `, 8/10/2016-Wednesday Spot Well Cover with Crane over MPK-34, Set Rig floor on Well cover, Spot Mud tanks, Move rig on to Mud Boat, Raise Derrick& Pin same. Install Stairs on Rig. Plug in and test Gas alarms, Rig up Rig floor, Connect hoses to mud tanks, Kill & Choke line, Connect Koomey lines to BOP. Rig up &Test BOPs per AOGCC, (AOGCC Guy Cook Witness Test)Tested to 250/3,000psi, Unable to get Good Solid Test @ 3,000psi, Lock Down Screws leaking on Wellhead,Tighten lock down screws. Pipe Rams Leaking, Bleed Pressure off Open Ram Doors change out 2-7/8" x 5" Variable Pipe Rams and Door Seals, (Tested Fire and Gas Alarms), (Tested High Fluid Level Alarms in Pits) (Tested Good). Shell Tested Bop 250/3,000psi. Test BOPs per AOGCC, Tested to 250/3,000psi,Test with 2 7/8" &4.5" Test joints,Test Annular to 250/1,500psi. Conduct Accumulator Test (Tested Good) Rig Down Test Equipment Same. Well Head Rep Remove TWC Valve. Pump 200 bbl. 8.9 ppg Brine 50 bbl.Tubing 150 bbl.Annulus Hang ESP Sheave in Derrick, Hang E-Trunk and Drain Hose, Make up XO and TIW Valve on Landing Joint (Open Tubing and Annulus Psi=0). Pick up Landing Joint Make up into Hanger Bolds Open IA Psi=O Pulled Tubing Hanger to the Rig Floor unset at 99k Free Pull at 93k Break out Hanger and Landing Joint Lay Down Same. 8/11/2016-Thursday TOOH, Laying down 4.5"VAM Top tubing(Total Joints 171) (Bad Spot in ESP Cable between joints 67-68) (Check ESP Cable at Pump Motor is Grounded out). Break and Lay Down ESP Pump Assembly, No Visible Sand in Pump Discharge Head, Observed Heavy Corrosion on Pump intake, Lower Seal Assembly and Motor. Change over Handling Equipment from 4.5" to 2-7/8", Load and Tally 104 Joints 2-7/8 PH-6 Work String on Pipe Racks.TIH 2-7/8" PH-6 Work String for Kill string to 2,650'. 8/12/2016-Friday TIH with 2-7/8" Kill String to 2,750'. Discussion with Work Over Engineer and decision was made to run ESP,TOOH, lay down 2-7/8" Kill string. Rig up floor for 4.5" Handling tools. Make up and service ESP assembly. While Installing and servicing Pump Assembly, Made up First Pump onto Intake Connection of the Pump then Lowered to Rig Floor,Then was unable to Turn Main Shaft Locked up Tight, Broke and L/D Pump, Pick and Make up Second Pump Assembly With same Results, Break Apart Trouble Shoot Pump Problems with no Results, the Operations Engineer was called, Decision was Made L/D ESP Pump Assembly, Run 2-7/8" Kill String, Break and L/D ESP Pump Assembly, Remove 4.5 Vam Top Tubing from Pipe Racks. Load and Tally 102 Joints 2-7/8" Kill String on Pipe Rack, Change over Handling Equipment to 2-7/8 TIH 2- 7/8 Kill String to 3,294'. 8/13/2016-Saturday Make up Tubing Hanger and landing joint, Land Tubing Hanger, Run in Lock down screws. Install BPV. Rig down, lay Derrick over, Move Pipe racks, Rig down cat walk, move Rig to A pad. Remove Rig Floor&Well cover. Nipple Down BOP, Nipple Up Dry hole Tree,Test Hanger Void to 500/5,000psi. Pull BPV, Set TWC,Test Tree to 5,000psi. Pull TWC, Little Red Freeze Protect well. Move Rig& Equipment from K pad to A pad.Spot Equipment on MPA-Pad, Service Rig Engines, Clean Rig floor walls, Organize and clean Tool skids, Prep BOP equipment for shipping out. 8/14/2016-Sunday No activity to report. 8/15/2016- Monday No activity to report. 8/16/2016-Tuesday • • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP K-34 ASR#1 50-029-22712-00-00 196-169 8/9/16 9/4/16 Daily Operations: No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP K-34 ASR#1 50-029-22712-00-00 196-169 8/9/16 9/4/16 Daily Operations: 8/24/2016 -Wednesday No activity to report. 8/25/2016-Thursday No activity to report. 8/26/2016 - Friday No activity to report. 8/27/2016-Saturday No activity to report. 8/28/2016-Sunday No activity to report. 8/29/2016- Monday Safety meeting with all Crew members & Milne Point Orientation for all new employees. (Notified AOGCC of right to witness BOP Test @ 14:16 HRs on 8-29-16). Move Rig & Equipment from MPA-pad to MPK-34, Spot Tool pusher co, man, Change House Trailers, Spot mud Boat, Pit Module, Unload Double Ram bope from Charlie Trucking, Install Test Recorder in Choke House, L/D Spill Containment under pipe racks and Cat walk & Berm up (AOGCC Inspector Jeff Jones waived witness of BOP Test @ 15:32 PM 8-29-16). Well Kill Operations Pumped 560 bbl. 8.9 ppg Brine Check Tubing &Ann psi=0. Well Head Rep (Greg Ruge)Tee Bar-Install TWC Valve. Nipple down Tree, Nipple up Bop,Torque up Flange Bolts to 6,700 ft./lbs. Install Well House, Stairs, Rig Floor, Spot Rig on Mud Boat, Raise Derrick. 8/30/2016-Tuesday Continue Rigging up on MPK-34, Rig up circulating lines, Kill line, Choke line, Koomey lines, Set Cat walk& pipe Racks, Connect and Test gas alarms with Milne Point Electrician. Rig up &Test BOPS per AOGCC requirement,Test all Rams & valves to 250/3,000 psi.Tested Annular to 250/1,500 psi. on 2-7/8" Test joint,Tested with 2-7/8"Test joint &4.5" test joint. Test Accumulator& PVTs. Pull TWC. Rig-Repair Cleaning and Maintaining Rig. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP K-34 ASR#1 50-029-22712-00-00 196-169 8/9/16 9/4/16 Daily Operations: 8/31/2016-Wednesday Continue to Troubleshoot Rig Engine &wait on parts for same, Continue cleaning on Rig and organizing. Set Matting boards &continue to prep F-54 for Rig move, Spot & Fill Upright tanks with 800 bbls of seawater for upcoming work over on F-54, Crews work with VMS Shop &Carpenter shop. 9/1/2016-Thursday Continue to Maintain Rig& Equipment while waiting on Rig Engine Parts.;Remove and Install new Thermostat in Rig Engine. Make up Landing joint, Install in Tubing hanger and Pull Hanger, lay down same and landing joint.Trip out of the hole laying down kill string. (Total Jts102) ( Closed Blind Rams). Rig-Repair-Change out Fan Clutch and Motor Oil on Rig Motor-Load and Tally 4.5 Vam top Completion Tubing on Racks, Displace Well with 5 bbl. 8.9 ppg Fluid every 1' Hour. 9/2/2016- Friday Continue to Repair Rig Engine, Install New Fan Clutch,Test Run Equipment for proper Temperatures on Engine. Make up & Service ESP Assy.TIH with ESP Assembly on 4.5" Vam Top Chrome Tubing with 3/8" Cap Injection line. Checking ESP Cable Conductivity @ 1,970' with 45 its Ran, Showing very low Readings on Meggar, Centrilift Rep was called and Decision was made to Pooh Check Cable Splice Made above the ESP pump Assembly. POOH, Lay down 4.5 Vam Top Chrome Tubing and 3/8" Cap Injection Line, Cable Splice at The Top of the ESP Pump Assembly Metal Armor Behind the Flat Guard Protector was Damaged, Cut and Remove Cable Splice Check ESP Cable back to ESP Reel (Cable is Good) Check ESP Cable back to Motor, (Very Poor Reading) Continued Pooh Breaking down Laying Down Pump Assembly, Pulled ESP Cable back into Spooling unit Centrilift Rep Replace and Make new ESP Cable Splice on MLE Head. 9/3/2016-Saturday Make up &Service New ESP Assembly with New Centrilift Motor, Splice on new Motor lead in spooling unit.TIH with ESP Assembly&4.5"Vam Top chrome Tubing and 3/8" Cap Injection Line Check Cable Every 1,000 ft. Ran 151 Joints in the hole. Centrilift Rep Making Reel to Reel ESP Cable Splice @ 6,094'. 9/4/2016 Sunday Centrilift Rep Making Reel to Reel ESP Cable Splice @ 6,094'. Continue to TIH with ESP Assembly&4.5" Vam Top Chrome Tubing. Make up landing joint& Hanger, Install Cap line & ESP Penetrator. Install Field Connector to ESP Cable and attach to Penetrator. Land Tubing Hanger, Run in Lock down screws, Back out& Lay down landing joint. Install BPV. Disconnect Gas Alarms, Change handling tools over from 2.875" to 4.5" Disconnect Circulating hoses, Koomey Lines, Choke & Kill lines from BOP. Move Pipe Racks& Catwalk, Move Misc. loads and remove spools from BOP,4 bolt BOPs, Lower Derrick, Haul Co man and Change House Trailers to MPF Pad. ASRC Crane assisted in Removal of Rig Floor and well House Removal of Bope Stack, Unable to Install Tree Port Hole for the Cap Injection Line Needed Bored out, Removed Adapter flange from Tree &Sent to Machine shop to bore out for Swage Lock Fitting to FMC Specifications. 9/5/2016- Monday No activity to report. 9/6/2016-Tuesday No activity to report. OF 77", • • V yw\*\\�y7,... THE STATE Alaska Oil and Gas ,,;,-s1, of® TT c Conservation Commission AL�� S ' ' itt _:i.- 333 West Seventh Avenue h. f GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 '�� Main: 907.279.1433 OF ALAS ' Fax: 907.276.7542 www.aogcc.alaska.gov Bo Yorke' �9L 17, Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Milne Point Field,Undefined WTRS Pool,MPU UGNU K-34 Permit to Drill Number: 196-169 Sundry Number: 316-322 Dear Mr. York: 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, Cathy . Foerster Chair DATED this ei day of June,2016. RBDMS /JUN 1 3 2016 r• WV STATE OF ALASKA .IUN 0 7 20)6 ALASKA OIL AND GAS CONSERVATION COMMISSION (M,a g`?L 4 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-Out❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC , Exploratory ❑ Development ❑ 196-169 3.Address: Stratigraphic ❑ Service 0, 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22712-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 2 I MILNE PT UNIT UGNU K-34- 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0375132 Milne Point Field/Ugnu Undef WTRSP 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14,660' , 7,210' , 8,363' , 4,881' 1,621 8,363' N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' 1,490psi 470psi Surface 8,461' 9-5/8" 8,461' 4,914' 5,750psi 3,090psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic. See Attached Schematic 4-1/2" 12.6#/13-CR/Vam Top 6,824' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): - 9-5/8"Versatrieve Packer x 4 and N/A + 7,188(MD)/4,411(TVD),7,372(MD)/4,486'(TVD),7,582(MD)/4,570(TVD)&7,737(MD)/ 4,633(TVD)and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic 0 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: 6/14/2016 ❑ ❑ ❑ Suspended ❑ Commencing Operations: OIL WINJ WDSPL 16.Verbal Approval: Date: GAF ] WAG ❑ WTRSP D• SPLUG El Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved l.,LAeC herein will not be deviated from without prior written approval. Contact Ted Kramer ��!! Email tkramerehilcorp.com Printed Name Bo York Title Operations Manager Signature Phone 777-8345 Date 6/7/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness 2 Sundry Number: .3 `� 22 Plug Integrity ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1f 3ao,- /„.-, ., P tc s- f-- Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: /U yo 1f RBDMS / JUN 1 3 2016 APPROVED BY Approved by: 147J. COMMISSIONER THE COMMISSION Date: C_ 9...7//c .r-i�. fht c/vies. ,,,‘,/8-46 OR1 G NA Submit Form and I Form 10-403 Revised 1112015 Ljd for 12 months from the date of approval. Attachmentss in Duplicate • Well Prognosis Well: MPK-34 Hikory Alaska,LL Date:6/06/2016 Well Name: MPU K-34 API Number: 50-029-22712-00 Current Status: SI Water Source Well Pad: K-Pad Estimated Start Date: June 14, 2016 Rig: ASR#1 > Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-169 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985)867-0665 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Numbers are based on expected BHP at mid perf of 4,536'TVD Current Bottom Hole Pressure: 2,075 psi @ 4,536' TVDss (SBHPS 05/01/2014/8.81 ppg EMW) Maximum Expected BHP: 2,075 psi @ 4,536' TVDss (No new perfs being added) / MPSP: 1,621 psi (0.10 psi/ft gas gradient) Brief Well Summary: The Milne Point K-34 well was drilled as a Kuparuk development well that TD'd at 14,660'.The well was plugged back for an Ugnu water source well in the cemented 9-5/8" casing in November 1997. The initial ESP and subsequent ESPs failed and were replaced in 2000, 2002, 2003, 2007, and 2014.The recent pump failed January 24, 2015. A workover in April 2015 was performed with the Nordic #3 where the ESP was replaced. The casing was tested to 1,500 psi at 6,880' MD on 4/21/15. A downhole chemical injection line will be re-run as part of the new completion (previously observed corrosion issues). Notes Regarding Wellbore Condition • Casing tested to 1,500 psi down to 6,880' on 4/21/2015. 4e*" `'tz' Objective: Pull failed ESP,verify that the screens are open, and run a new ESP. Brief RWO Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services and 500 bbl returns tank with choke manifold. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.9 ppg filtered NaCI brine down tubing, taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. H • Well Prognosis Well: MPK-34 Hilcorp Alaska,LL Date:6/06/2016 7. RD Little Red Services. 8. Set BPV. RU crane. ND Tree. NU 11" BOPE. RD Crane. 9. NU BOPE house.Spot mud boat. WO Rig Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.9 ppg filtered NaCI brine prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/1,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 4-1/2"test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (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.) a. 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 test. 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 1U the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking • anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.9 ppg filtered NaCI brine as needed. 15. MU landing joint or spear and recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 16. POOH and lay down the 4-1/2"tubing. Tubing may be re-used. Lay down failed ESP. f. Thread protectors required to lay down the 4-1/2" 13Cr Vam Top tubing. g. Replace bad joints of tubing as necessary. h. Utilize standard Chrome Tubing handling procedures. 17. PU, RIH with scraper assembly to —7,188' MD on 2-7/8" WS. Circulate the well clean. POOH with Scraper. • Well Prognosis Well: MPK-34 Ililcora Alaska.LLQ Date:6/06/2016 18. PU mule shoe on 600' of 2-3/8"tubing, crossed over back to 2-7/8" work string. RIH to top of screens. Continue into screens reverse circulating to insure screens are open to 7,737'. POOH with WS. 19. PU new ESP completion consisting of the ESP, GLM's„ chemical injection line, and RIH on 4-1/2" Vam Top 13Cr tubing as per schematic. a. Set base of ESP in low dogleg area (+/-6,850'). 20. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 21. RU Pump Truck. Freeze Protect down back side (+/- 115 bbls.to 2,000'). 22. Set BPV. Post-Rig Procedure: 23. RD mud boat. RD BOPE house. 24. RU crane. ND BOPE. 25. NU existing 4-1/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 26. RD crane. Move 500 bbl returns tank and rig mats. 27. Replace gauge(s) if removed. 28. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. FWD Circ to Kill Tank Flow Diagram 6. REV Circ to Kill Tank Flow Diagram 7. Bleed to Pits Flow Diagram 8. Blank RWO Changes Form H . 40 Milne Point Unit Well: MPUK-34 • SCHEMATIC Last Completed: 5/10/2014 flikoru Alaska,LLC PTD: 196-169 CASING DETAIL Orig.DFElev.:57.3'/Orig.GL Elev.:27.8' Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A 19.124 Surface 112' 2G' 9-5/8" Surface 36/K-55/Btrc. 8.835 Surface 8,461' TUBING DETAIL 4-1/2" Tubing 12.6/13-CR/Vam Top 3.958 Surface 6,824' 9-5/8"HMCO 3/8" Capstring Stainless Steel N/A Surface 6,824' 'ES Cementer A(@1,997' JEWELRY DETAIL OA No Depth Item 1 2,685' X-Nipple 2 6,670' XN-Nipple el 1 3 6,731' Tandem Pumps 4 6,770' Tandem Seal Section 5 6,785' Motor 6 6,822' Well Lift MGU w/6 Fin Centralizer-Bottom=±6,824' 3/8"SSCapstring . 7 7,188' 9-5/8"36-43.5#Versatrieve Packer 8 7,211' 5-1/2"N-80 Blank Pipe 9 7,251' 5-1/2"0.12 Ga.Pre-Pack Screen(ID=4.778") 10 , 7,372' 9-5/8"HOWCO Versatrieve Packer 11 7,395' 5-1/2"N-80 Blank Pipe 12 7,422' 5-1/2"0.12 Ga.Pre-Pack Screen(10=4.778") 13 , 7,582' 9-5/8"36-43.5#Versatrieve Packer 14 7,605' 5-1/2"N-80 Blank Pipe 15 7,697' 5-1/2"0.12 Ga.Pre-Pack Screen(ID=4.778") 16 7,737' 9-5/8"HOWCO BWD Sump Packer 17 8,363' 9-5/8"HOWCO'EZSV'Retainer PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 2 MB 7,262' 7,362' 4,441' 4,482' 100 11/23/1997 Open :' Pt MD2 7,427' 7,572' 4,508' 4,566' 145 11/23/1997 Open ME 7,707' 7,732' 4,620' 4,630' 25 11/23/1997 Open SWS:4-1/2",12spf(24gr.43C BH),EHD 0.7",Penetration 7.88",135/45 degree phasing r i 1 F„ 3 GRAVEL PACK DETAIL WELL INCLINATION DETAIL 4° 111 Upper Ugnu:4,200lbs of 20-40 Carbolite proppant behind screen WELL @ 350' 4° ail Middle Ugnu:20,400lbs of 20-40 Carbolite proppant behind screen Max Hole Angle=70 deg. @ PBTD 4 Lower Ugnu:5,000lbs of 20-40 Carbolite proppant behind screen Hole angle thru perfs=65-67 deg. J OPEN HOLE/CEMENT DETAIL 5 -,4 20" Cmt w/250 sx Arcticset 1(Approx.)in a 24"Hole tit mi9-5/8" 1,740 sx PF'E',357 sx Class'G',204sx PF'C'in a 12-1/4"Hole " 6 /^ 14A-' TREE&WELLHEAD :. 7 ()1/4,(2)‘' Tree CIW 4-1/16"5M'FLS' `'"" ` 8 11"x 11"5M FMC Gen 6 Unibore w/two 2' 5M valves on side ports 11"x 4.5" ii I I 1 g I I 9 p(61t' Wellhead tubing hanger 4.5"TCII threads top and bottom and 4"CIW-H BPV profile " 10GENERAL WELL INFO ;, Ili iii t 11 API:50-029-22712-00-00 12 /� Drilled and Cased by Nabors 22E -11/22/1996 6 = ".13 f li Completed by Nabors 4ES-1/25/1997 14 1 P° ' RWO ESP Replacement by Nabors 4ES-4/25/2002 15 RWO ESP Replacement by Nabors 4ES-3/31/2003 5 _ 16 i� RWO ESP Replacement by Nabors 3S-4/22/2007 V t* ,../r_____ RWO ESP Replacement by Doyon 16-5/11/2014 9-5/gay17 nRWO ESP Replacement by Nordic 3 4/23/2015 NOTE: TD=14,660(MD)/TD=7,2117(TVD) C.II- 4/22/2007-Ran 109 new joints due to corrosion.New tubing PBTD=8,363'(MD)/PBTD=4,881'(TVD) hanger installed due to bad BPV profile and landing joint threads. New cable install Created By:TDF 5/21/2015 H . • Milne Point Unit Well: MPU K-34 • PROPOSED Last Completed: Proposed tlileorp Alaska,LLC PTD: 196-169 CASING DETAIL Orig.DF Elev.:57.3'/Orig.GL Elev.j . L:27.8' Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A 19.124 Surface 112' 20 9-5/8" Surface 36/K-55/Btrc. 8.835 Surface 8,461' TUBING DETAIL 4-1/2" Tubing 12.6/13-CR/Vam Top 3.958 Surface ±6,850' 9-5/8'HOMO 3/8" Capstring Stainless Steel N/A Surface ±6,850' 'ES'Cementer @1,997 JEWELRY DETAIL OA No Depth Item 1 ±2,685' X-Nipple 1 2 ±6,695' XN-Nipple 1 3 ±6,756' Tandem Pumps 1 4 ±6,795' Tandem Seal Section 5 ±6,810' Motor 6 ±6,847' Well Lift MGU w/6 Fin Centralizer-Bottom=±6,850' 3/8"SSCapstring j 7 7,188' 9-5/8"36-43,54 Versatrieve Packer 8 7,211' 5-1/2"N-80 Blank Pipe 9 7,251' 5-1/2"0.12 Ga.Pre-Pack Screen(ID=4.778") 10 7,372' 9-5/8"HOWCO Versatrieve Packer 11 7,395' 5-1/2"N-80 Blank Pipe 12 7,422' 5-1/2"0.12 Ga.Pre-Pack Screen(ID=4.778") 13 7,582' 9-5/8"36-43.54 Versatrieve Packer 14 7,605' 5-1/2"N-80 Blank Pipe 15 7,697' 5-1/2"0.12 Ga.Pre-Pack Screen(ID=4.778") 16 7,737' 9-5/8"HOWCO BWD Sump Packer 17 8,363' 9-5/8"HOWCO'EZSV'Retainer PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 11_1 MB 7,262' 7,362' 4,441' 4,482' 100 11/23/1997 Open II 2 { MD2 7,427' 7,572' 4,508' 4,566' 145 11/23/1997 Open ,, ; ME 7,707' 7,732' 4,620' 4,630' 25 11/23/1997 Open ',. "t i ' SWS:4-1/2",12spf(24gr.43C BH),EHD 0.7",Penetration 7.88",135/45 degree phasing i 3 <' `ks GRAVEL PACK DETAIL WELL INCLINATION DETAIL x w 1a, Upper Ugnu:4,200lbs of 20-40 Carbolate proppant behind screen KOP @ 350' Middle Ugnu:20,400lbs of 20-40 Carbolite proppant behind screen Max Hole Angle=70 deg. @ PBTD v' moo 4 it tiN '' Lower Ugnu:5,000lbs of 20-40 Carbolite proppant behind screen Hole angle thru perfs=65-67 deg. t„. "itv 1,1'. ., 5 OPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sx Arcticset 1(Approx.)in a 24"Hole t, k 9-5/8" 1,740 sx PF'E',357 sx Class`G',204sx PF'C'in a 12-1/4"Hole 6 k, ;; TREE&WELLHEAD • -=- -:- 7 Tree CIW 4-1/16"5M'FLS' 8 11"x 11"5M FMC Gen 6 Unibore w/two 2"5M valves on side ports 11"x 4.5" , ,9 Wellhead tubing hanger 4.5"TCII threads top and bottom and 4"CIW-H BPV profile 1-,, "10 GENERAL WELL INFO ' 11 API:50 029 22712-00-00 12 Drilled and Cased by Nabors 22E -11/22/1996 1, -_ =' *13 Completed by Nabors 4ES-1/25/1997 X14 RWO ESP Replacement by Nabors 4ES-4/25/2002 15 RWO ESP Replacement by Nabors 4ES-3/31/2003 ' -. ._.116 RWO ESP Replacement by Nabors 3S-4/22/2007 s#. RWO ESP Replacement by Doyon 16-5/11/2014 9-5/8"7• - *'17 RWO ESP Replacement by Nordic 3-4/23/2015 NOTE: TD=14,660(MD)/TD 7,210(ND) 4/22/2007-Ran 109 new joints due to corrosion.New tubing PBTD=8,363'(MD)/PBTD=4,881'(TVD) hanger installed due to bad BPV profile and landing joint threads. New cable install Created By:STP 6/06/2016 0 ! ' Iti Milne Point ASR Rig 1 BOPE nit orp,Ait.4,0.W 11" BOPE Stripping Head r .l 3.98' J' Shaffer 3 4 11"_ 5000 111 irtrignirt C , u J W 4.54' °A *c H VBR or Pipe Rams 51w3°m11"-5000 I Lo —d Blind Wit; ��; /I 1i lei iii iii ii 21/16 5M Kill Line Valves \ ^ 21/16 5M Choke Line Valves el! el 2.00' , €�� .�" — _ _ t �J , Manual Manual Manual HCR Updated 8/19/2015 • • MPU K-34 EXISTING TREE/WELLHEAD Wellhead/Tree Ilitcorp Alaska,LI:.(. Milne Point Unit 111 Illa I.i ,,. vrI oak itl Y ii150,0: t,,,.... 4 1/16"CIW 5M Swab Valve . 0A Awl MBAIII III , - v i' .i Ifpir tir iii , \ IE aa' 4 1/16" CIW SM Wing Valve in 0 4 1/16" CIW 5M SSV with Baker actuator ' t '. > 4 1/16" CIW 5M Master Valve A00' II . III 11"x 4 1/16" CIW 5M oAll WI A°'x ESP Tbg Adapter I A Ill I=mo ,„ ; 11"x 11"FMC 5M =AO ... ` ■_ Tubing Head " y 1 1 IfI - 2 1/16"CIW 3M Valve 2 1/16"CIW 3M Valve • • . 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Co a) 0 c % Q to 0 X 3 R R e 44 c et 0 / X .0 / ■ Co \ 0 / a Co ° v o0 / ) -. e - E G a m co o CO a 0 o \ / < STATE OF ALASKA ` AL,-..,KA OIL AND GAS CONSERVATION COMA._ .,SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown H Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well 2 Re-enter Susp Well ❑ Other: ESP Change-out ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development ❑ Exploratory ❑ 196169 3.Address: Stratigraphic❑ Service ❑✓ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22712-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0375132 MILNE PT UNIT UGNU K-34 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Poiunt Field/Ugnu Undef WTRSP 11.Present Well Condition Summary: ....______=- Total _______=-Total Depth measured 14,660 feet Plugs measured 8,363 RECEIVED true vertical 7,210 feet Junk measured N/A feet 7,188',7,372', MAY 2 2 2015 Effective Depth measured 8,363 feet Packer measured 7,582'&7,737' feet 4,411',4,4865', AtGCC true vertical 4,881 feet true vertical 4,570'&4,633' feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' 1,490psi 470psi Surface 8,461' 9-5/8" 8,461' 4,914' 5,750psi 3,090psi Intermediate Production Liner Perforation depth Measured depth See Attached Schematic feet SC04°E True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13-CR/Vam Top 6,824' 4,281' 9-5/8"Versatrieve See Packer info Packers and SSSV(type,measured and true vertical depth) Packer x4 N/A Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 4,680 0 1,904 14.Attachments(required per 20 AAC 25.070 25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory El Development❑ Service E Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil U Gas U WTRSP U Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-205 Contact Chris Kanyer Email ckanyerc hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signaturei � Phone 777-8377 Date 5/21/2015 526-,i;s" RBDMSi MAY 2 9 2015 Form 10-404 Revised 5/2015 _ '/ Submit Original Only / 1'/1/4-- H (A-6' Milne Point Unit Well: MPU K-34 SCHEMATIC Last Completed: 5/10/2014 llilcorp Alaska,LLC PTD: 196-169 CASING DETAIL Orig.DF Elev.:57.3'/Orig.GL Elev.:27.8' Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A 19.124 Surface 112' 20L 9-5/8" Surface 36/K-55/Btrc. 8.835 Surface 8,461' TUBING DETAIL 4-1/2" Tubing 12.6/13-CR/yam Top 3.958 Surface 6,824' 9-5/8"I HOMO 3/8" Capstring Stainless Steel N/A Surface 6,824' 'ES Cementer @1,99T JEWELRY DETAIL No Depth Item 1 2,685' X-Nipple l2 6,670' XN-Nipple 1 3 6,731' Tandem Pumps t 4 6,770' Tandem Seal Section 5 6,785' Motor ( 6 6,822' Well Lift MGU w/6 Fin Centralizer-Bottom=±6,800' 3/8"SS Capstring 7 7,188' 9-5/8"36-43,54 Versatrieve Packer 8 7,211' 5-1/2"N-80 Blank Pipe 9 7,251' 5-1/2"0.12 Ga.Pre-Pack Screen(ID=4.778") 10 7,372' 9-5/8"HOWCO Versatrieve Packer 11 7,395' 5-1/2"N-80 Blank Pipe 12 7,422' 5-1/2"0.12 Ga.Pre-Pack Screen(ID=4.778") 13 7,582' 9-5/8"36-43.54 Versatrieve Packer ' 14 7,605' 5-1/2"N-80 Blank Pipe 15 7,697' _ 5-1/2"0.12 Ga.Pre-Pack Screen(ID=4.778") 16 7,737' 9-5/8"HOWCO BWD Sump Packer • 17 8,363' 9-5/8"HOWCO'EZSV'Retainer PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status MB 7,262' 7,362' 4,441' 4,482' 100 11/23/1997 Open 2 ;"k MD2 7,427' 7,572' 4,508' 4,566' 145 11/23/1997 Open Ii I ►i ME 7,707' 7,732' 4,620' 4,630' 25 11/23/1997 Open } SWS:4-1/2",12spf(24gr.43C BH),EHD 0.7",Penetration 7.88",135/45 degree phasing H 3 y , GRAVEL PACK DETAIL WELL INCLINATION DETAIL _i_ 4:. Upper Ugnu:4,200lbs of 20-40 Carbolite proppant behind screen KOP @ 350' ,v ma ,: Middle Ugnu:20,400lbs of 20-40 Carbolite proppant behind screen Max Hole Angle=70 deg. @ PBTD i, am �.)4 Lower Ugnu:5,000lbs of 20-40 Carbolite proppant behind screen Hole angle thru perfs=65-67 deg. ;i a OPEN HOLE/CEMENT DETAIL : 20" Cmt w/250 sx Arcticset 1(Approx.)in a 24"Hole v 9-5/8" 1,740 sx PF'E',357 sx Class'G',204sx PF'C'in a 12-1/4"Hole 1 6 G TREE&WELLHEAD r.. 7 Tree CIW 4-1/16"5M'FLS' ' 8 Wellhead 11"x 11"5M FMC Gen 6 Unibore w/two 2"5M valves on side ports 11"x 4.5" i• 'y ' '10 tubing hanger 4.5"TCII threads top and bottom and 4"CIW-H BPV profile 1GENERAL WELL INFO a a 11 DAPI:50-029-22712-00-00 i' ;1 142- Drilled and Cased by Nabors 22E -11/22/1996 - 13 O Completed by Nabors 4ES-1/25/1997 14 RWO ESP Replacement by Nabors 4ES-4/25/2002 q,15 RWO ESP Replacement by Nabors 4ES-3/31/2003 x;16 RWO ESP Replacement by Nabors 3S-4/22/2007 17 RWO ESP Replacement by Doyon 16-5/11/2014 9-5/8"'' RWO ESP Replacement by Nordic 3-4/23/2015 fNOTE: 4/22/2007-Ran 109 new joints due to corrosion.New tubing TD=14,660(MD)/TD=7,210(TVD) hanger installed due to bad BPV profile and landing joint PBTD=8,363'(MD)/PBTD=4,881'(TVD) threads. New cable install Created By:TDF 5/21/2015 } Hilcorp Alaska, LLC „i,,.,,,.,,,,,:,ska,LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date K-34 50-029-22712-00-00 196-169 4/18/2015 4/23/2015 Daily Operations: 4/15/15-Wednesday No operations to report. 4/16/15-Thursday No operations to report. 4/17/15-Friday No operations to report. 4/18/15-Saturday MIRU.Accepted Rig.Spot tanks, berm cellar, MU hardline to kill tanks. Pull BPV, off loaded 9.2#kill fliud.Tested lines to 3,000psi-test ok. SITP 150psi,SICP 270psi, casing would not bled off. Bled tubing to Opsi and started pumping down tbg @ 4pbm, continued circulating well volume.SD pump, monitored well tubing on vacuum. Casing on slight blow,vent to kill tank. 635 bbls pumped,356 bbls returned, 279 bbls lost. 4/19/15-Sunday NU Bop's pulled BPV and installed TWC,c/o UPR's to 3-1/2". RU test equipment,filled and purged stack and manifold, preformed shell test(250psi low/3,000psi high). Performed BOPE test per AOGCC sundry.Annular(250psi low/3,000psi high),Valves (250psi low/3,000psi high), Rams(250psi low/3,000psi high). Performed Koomey drawdown test and gas dection. 2 f/p were recorded HCR Kill and 3-1/2" pipe rams.AOGCC test witness waived. RU GBR handling tools, pulled TWC, MU landing jt, backed out lock down pins, pulled 130k to unseated tbg hanger and pulled to rig floor, meg esp cable, decompleted hanger BO/LD same, pull stand and thread cable to spooler. POOH w/ESP completion LD 4-1/2"tbg, 10 jts from ESP at report time 4/20/15- Monday Continued TOOH L/D completion,visually inspected all other jts good. BO/LD ESP assembly, no body wear,sand around ESP connectons and intake. RU dutch riser,spotted SL Unit, PU/MU lubricator and tested to 500psi. PU and RIH w/PDS logging tool and tagged at 6,857'. Logged from 6,857'to 1,500'. POOH and LD tool. Note 3/4"stainless steel band was recovered with tool. PU and RIH w/pressure temperture tool to 6,850'. Logged up to 1,500', POOH,tool malfuctioned. PU and RIH w/PNL tool to 6,850' logged up at report time. 4/21/15-Tuesday Contiuned Logging up to 1,500', RIH to 2,100'and striped up to 1,800'. Pumped 2 bpm while logging to maintain consistent fluid level. POOH. LD Tool. Memory tool did not record data. Battery malfunctioned. RDMO SL Unit. Preped rig to trip test packed, racked 3-1/2" PD and tallied.Off loaded 225 bbls of 8.9#brine. PU/MU 9-5/8" RTTS,TIH w/same and 215 jts of 3-1/2 DP and set @ 6,880'.Set RTTS and_pressure Jested csgto 11500psi held for3010ns-test ok. Released RTTS and reversed circulated 116 bbls. Returns are rust and a trace of sand.With returns clean SD pump. Monitored well static.TOOH LD 3-1/2" DP and RTTS. RU GBR handling tools, prep rig floor to run ESP completion. Hilcorp Alaska, LLC ,,,., Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP K-34 50-029-22712-00-00 196-169 4/18/2015 4/23/2015 Daily Operations: 4/22/15-Wednesday PU MU and service new ESP assembly,flange on top of the second pump had bad treads,chased treads with a tap and MU.Stung new cable and cap-string over sheave. Make motor and cap connection.Test all cap string,check break @ 3,400 psi. RU GBR chrome casing handling tool. RIH with ESP completion 3 jts in the ESP cable wedged between the roller and the dove tail on the air slips causing the armor to crease. Cut cable LD 3 jts and spliced at the motor tail.Tested splice good.TIH with ESP completion PU XN-nipple and continued TIH checking cable and cap every 2,000'. 5,900' at report time. 4/23/15-Thursday Continued to TIH w/ESP completion to hanger depth @ 6,822',depths are as follows: Hanger, Pup,66 jts of 4-1/2 12.6# 13Cr VamTop Tbg, pup jt,X-nipple @ 2,685', Pup jt, 66 jts of 4-1/2 12.6#13Cr VamTop Tbg, Pup jt,XN-nipple @ 6,670', Pup jt, 1 jt of 4-1/2 12.6#13Cr VamTop Tbg, Pup jt, Discharge Head @6,730', Pump @ 6731' 6,743' 6,757',Tandem Seal @ 6,770, Motor @ 6,785', Centralizer @ 6,822'. PU landing joint. Install hanger and penetrators.Test cable and cap string. Cut and splice cable connector and cap string, install same. Meg check connector. Land string SW 130K up 85k down. Run in lock down screws. ND BOP/NU tree.Orient tree.Test all breaks and void 250/5,000 psi. Rig released at 16:00hrs. 4/24/15-Friday No operations to report. 4/25/15-Saturday No operations to report. 4/26/15-Sunday No operations to report. 4/27/15- Monday No operations to report. 4/28/15-Tuesday No operations to report. • vnF 77.1 THE STATE Alaska Oil and Gas °fALASK:A Conservation Commission. a ,_-4 - 333 West Seventh Avenue w4 k GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 — Main: 907.279.1433 Op ALAS Fax 907.276 7542 \t, www.aogcc.alaska.gov �'[ r Chris Kanyer Operations Engineer r„q Hilcorp Alaska, LLC I (0 ` `�' 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 kAt4)J Re: Milne Point Field, Kuparuk River Oil Pool, MPU)K-34 Sundry Number: 315-205 Dear Mr. Kanyer: 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, Daniel T. Seamount, Jr. Commissioner DATED this / day of April, 2015 Encl. BEDEWED • STATE OF ALASKA APR 0 7 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑✓ " Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate ❑ Pull Tubing 0 ` Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other: ESP Change-out ❑, • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ' Exploratory ❑ Development ❑ 196-169 • 3.Address: Stratigraphic ❑ Service 0, 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22712-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑✓ MILNE PT UNIT UGNU K-34 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0375132 • Milne Poiunt Field/Ugnu Undef WTRSP ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 14,660 . 7,210 ' 8,363 • 4,881 . 8,363' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1,490psi 470psi Surface 8,461' 9-5/8" 8,461' 4,914' 5,750psi 3,090psi Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size. Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4.5" 13Cr Vam Top 6,800' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 9-5/8"Versatrieve Packer x 4 and N/A 7,188(MD)/4,411(TVD),7,372(MD)/4,486'(ND),7,582(MD)/4,570(ND)&7,737(MD)/ 4,633(ND)and N/A 12.Attachments: Description Summary of Proposal E 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development❑ Service E- 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/20/2015 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WTRSP Q • Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanver ar7.hilcorp.com Printed Name Chns Kan er Title Operations Engineer Signature ate.,., Phone 777-8377 Date 4/7/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315- 205 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: ..)L 3 coo /9 S i_ 66 1 l- ( AAAA- P r ie.P S,,) c N Q) CC a- D Spacing Exception Required? Yes El No Subsequent Form Required: / d — Li D LI APPROVED BYel Approved by: COMMISSIONER THE COMMISSION Date: 4 7 , lS 2 . .roan ana C3 Form 1 3(Revised 10/2012) a aGi t is li�I for 12 months from the date of approval. '' 'u1�)/S chments in Duplicate m ,4ei., 45---- • Well Prognosis Well: MPK-34 Hilcorp Alaska,LL Date:4/7/2015 Well Name: MPK-34 API Number: 50-029-22712-00-00 Current Status: SI Water Source Well Pad: K Pad Estimated Start Date: April 21, 2015 Rig: Nordic 3 Reg.Approval Req'd? April 20, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-169 First Call Engineer: Chris Kanyer (907)777-8377 (0) (907) 250-0374 (M) Second Call Engineer: Bo York (907)777-8345 (0) (907)727-9247 (M) AFE Number: 1550551 Current Bottom Hole Pressure: — 1,727 psi @ 3,600' ND (Last BHP measured 5/1/2014) Maximum Expected BHP: — 1,727 psi @ 3,600'ND (No new perfs being added) Max.Allowable Surface Pressure: 483 psi (Based on actual reservoir conditions and water cut of 100% (0.44psi/ft)with an added safety factor of 1000'ND of gas cap) Brief Well Summary: The Milne Point K-34 well was drilled as a Kuparuk development well that TD'd at 14,660'. The well was / plugged back for an Ugnu water source well in the cemented 9-5/8" casing in November 1997. The initial ESP and subsequent ESPs failed and were replaced in 2000, 2002, 2003, 2007, and 2014. The recent pump failed January 24, 2015. The most recent casing pressure test performed after cement/plugback operations of the open hole below the 9-5/8" casing shoe on 11/20/1996. A casing pressure test will be completed during this workover. Due to observed corrosion issues, a downhole chemical injection line will be run as part of the new completion.'' No subsidence issues are expected in this well. Notes Regarding Wellbore Condition ' I 'I� („0,j-Et -sok.,-1(..,L w1-1/' Current well status is shut in QiLpredacer`No subsidence issues suspected. RWO Objective: Pull ESP, pressure test casing, & run 4-1/2' ESP completion with downhole chemical injection. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Circulate well with 8.5ppg seawater and monitor well. 3. If necessary,circulate well with 9.3ppg brine (or appropriate kill weight fluid. Monitor well. 4. ND tree, NU 11" BOPE and test to 250psi low/3,000psi high, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. V5. Contingency: (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.) a. 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. b. With stack out of the test path,test choke manifold per standard procedure Well Prognosis Well: MPK-34 llilcorp Alaska,LL Date:4/7/2015 c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. 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. 6. Unseat hanger and pull 4-1/2" ESP completion from 6,800' to surface and lay down same. Contingency: (Pending condition of pulled completion) 7. RIH with cleanout BHA to+/-7,000'. POOH with same. 8. RIH and set test packer at+/-6,900' (within 500ft of open perforations). 9. Perform a charted casing pressure test to 1,500psi for 30min. Bleed off pressure and POOH with same. 10. MU and RIH with ESP and 3/8"chemical injection line on 4-1/2"Vam 13CR tubing. Set ESP at+/-6,800'. Land tubing hanger. 11. ND BOP, NU and tree. 12. RDMO workover rig and equipment. 13. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit Well: MPU K-34 El SCHEMATIC Last Completed: 5/10/2014 Hilcorp Alaska,LLC PTD: 196-169 CASING DETAIL Orig.DF Elev.:57.31 Orig.GL Elev.:27.8' Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A 19.124 Surface 112' ZO1 L' 9-5/8" Surface 36/K-55/Btrc. 8.835 Surface 8,461' TUBING DETAIL 4-1/2" Tubing 12.6/13-CR/Vam Top 3.958 Surface 6,800' 9s/6^HMCO JEWELRY DETAIL 'ES Cementer �@1,99T No Depth Item 1 2,673' 4.5"X-Nipple(3.813 No-go ID) 2 6,647' 4.5"XN-Nipple(3.725 No-go ID) 3 6,706' Tandem Pumps:HPH-28HC7800,SXD-28HC7800&SXD-28HC7800 1 4 6,746' Tandem Seal Section:HSB3DBUTMSEHL PFSA&HSB3DBDLTMSEHL PFSA 5 6,761' Motor:HMI/800,4,225volt,114 amp&800 hp 6 6,798' Well Lift MGU w/6 Fin Centralizer-Bottom=6,800' 7 7,188' 9-5/8"36-43.5#Versatrieve Packer • 8 7,211' 5-1/2"N-80 Blank Pipe 9 7,251' 5-1/2"0.12 Ga.Pre-Pack Screen(ID=4.778") 10 7,372' 9-5/8"HOWCO Versatrieve Packer 11 7,395' 5-1/2"N-80 Blank Pipe 12 7,422' 5-1/2"0.12 Ga.Pre-Pack Screen(ID=4.778") 13 7,582' 9-5/8"36-43.5#Versatrieve Packer - 14 7,605' 5-1/2"N-80 Blank Pipe 15 7,697' 5-1/2"0.12 Ga.Pre-Pack Screen(ID=4.778") 16 7,737' 9-5/8"HOWCO BWD Sump Packer ' 17 8,363' 9-5/8"HOWCO'EZSV'Retainer PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status MB 7,262' 7,362' 4,441' 4,482' 100 11/23/1997 Open II I MD2 7,427' 7,572' 4,508' 4,566' 145 11/23/1997 Open Et 2 ME 7,707' 7,732' 4,620' 4,630' 25 11/23/1997 Open 'Ay� SWS:4-1/2",12spf(24gr.43C BH),EHD 0.7",Penetration 7.88",135/45 degree phasing fi Y GRAVEL PACK DETAIL 4 3 Upper Ugnu:4,200lbs of 20-40 Carbolite proppant behind screen ti Middle Ugnu:20,400lbs of 20-40 Carbolite proppant behind screen Lower Ugnu:5,000Ibs of 20-40 Carbolite proppant behind screen ,4 WELL INCLINATION DETAIL KOP @ 350' 5 Max Hole Angle=70 deg. @ PBTD y Hole angle thru perfs=65-67 deg. Y 6 OPEN HOLE/CEMENT DETAIL tI 20" Cmt w/250 sx Arcticset 1(Approx.)in a 24"Hole 7 9-5/8" 1,740 sx PF'E',357 sx Class'G',204sx PF'C'in a 12-1/4"Hole 8 9 L4, TREE&WELLHEAD. [ 1 . ti J•10 (A.-. Tree CIW 4-1/16"5M'FLS' 11 �`'" w �,,� Wellhead 11"x 11"5M FMC Gen 6 Unibore w/two 2"5M valves on side ports 11"x 4.5" L [ ] s 12 L� `tiM� tubing hanger 4.5"TCII threads top and bottom and 4"CIW-H BPV profile 92 13 GENERAL WELL INFO 14 API:50-029-22712-00-00 ,' [ 15 Drilled and Cased by Nabors 22E -11/22/1996 16 Completed by Nabors 4ES-1/25/1997 �; RWO ESP Replacement by Nabors 4ES-4/25/2002 17 9-5/8" 5/8 ?' RWO ESP Replacement by Nabors 4ES-3/31/2003 -i-'''------/ RWO ESP Replacement by Nabors 35-4/22/2007 RWO ESP Replacement by Doyon 16-5/11/2014 1D=14,6601MD)/TD=7,210'(1VD) NOTE: PBTD=8,363'(MD)/PBTD=4,881'CND) 4/22/2007-Ran 109 new joints due to corrosion.New tubing hanger installed due to bad BPV profile and landing joint threads. New cable install Created By:TDF 2/12/2015 • Milne Point Unit II • Well: MPU K-34 PROPOSED Last Completed: 5/10/2014 lli[carp Alaska,LLC PTD: 196-169 CASING DETAIL Orig.DF Elev.:57.3/Orig.GL EIev.:27.8' Size Type Wt/Grade/Conn ID Top Btm : 20" Conductor 91.1/H-40/N/A 19.124 Surface 112' 20 9-5/8" Surface 36/K-55/Btrc. 8.835 Surface 8,461' TUBING DETAIL 4-1/2" Tubing 12.6/13-CR/Vam Top 3.958 Surface ±6,800' 95/8'HOMO 3/8" Capstring Stainless Steel N/A Surface ±6,800' 'ES Canenter �1,997 JEWELRY DETAIL � No Depth Item 1 ±2,673' X-Nipple MR 2 ±6,647' XN-Nipple 9 1 3 ±6,706' Tandem Pumps 4 ±6,746' Tandem Seal Section 5 ±6,761' _ Motor 6 ±6,798' Well Lift MGU w/6 Fin Centralizer-Bottom=±6,800' 3/8"55Capstring 7 7,188' 9-5/8"36-43.5#Versatrieve Packer 8 7,211' _ 5-1/2"N-80 Blank Pipe 9 7,251' 5-1/2"0.12 Ga.Pre-Pack Screen(10=4.778") 10 7,372' 9-5/8"HOWCO Versatrieve Packer 11 7,395' 5-1/2"N-80 Blank Pipe 12 7,422' 5-1/2"0.12 Ga.Pre-Pack Screen(I0=4.778") 13 7,582' 9-5/8"36-43.5#Versatrieve Packer 14 7,605' 5-1/2"N-80 Blank Pipe 15 7,697' 5-1/2"0.12 Ga.Pre-Pack Screen(ID=4.778") 16 _ 7,737' 9-5/8"HOWCO BWD Sump Packer 17 8,363' 9-5/8"HOWCO'EZSV'Retainer PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status Iii MB 7,262' 7,362' 4,441' 4,482' 100 11/23/1997 Open E-1 2 iii 47,1 MD2 7,427' 7,572' 4,508' 4,566' 145 11/23/1997 Open ME 7,707' 7,732' 4,620' 4,630' 25 11/23/1997 Open r. SWS:4-1/2",12spf(24gr.43C BH),END 0.7",Penetration 7.88",135/45 degree phasing s GRAVEL PACK DETAIL " Upper Ugnu:4,200Ibs of 20-40 Carbolite proppant behind screen a• �= Middle Ugnu:20,400lbs of 20-40 Carbolite proppant behind screen 3 4 Lower Ugnu:5,000Ibs of 20-40 Carbolite proppant behind screen 1ii I WELL INCLINATION DETAIL t5 KOP @ 350' 'F Max Hole Angle=70 deg. @ PBTD 4 Hole angle thru perfs=65-67 deg. 6 r 7 OPEN HOLE/CEMENT DETAIL '" 8 20" Cmt w/250 sx Arcticset 1(Approx.)in a 24"Hole 9-5/8" 1,740 sx PF'E',357 sx Class'G',204sx PF'C in a 12-1/4"Hole r g9 4 - t10 TREE&WELLHEAD 11 Tree CIW 4-1/16"5M'FLS' "' 11"x 11"SM FMC Gen 6 Unibore w/two SM valves on side ports 11"x 4.5" 112 2"Wellhead 1 •13 tubing hanger 4.5"TCII threads top and bottom and 4"CIW-H BPV profile 14 GENERAL WELL INFO .., [ 115 API:50-029-22712-00-00 t i - ''.16 Drilled and Cased by Nabors 22E -11/22/1996 17 Completed by Nabors 4ES-1/25/1997 9-5/8,,,. RWO ESP Replacement by Nabors 4ES-4/25/2002 RWO ESP Replacement by Nabors 4ES-3/31/2003 ' RWO ESP Replacement by Nabors 3S-4/22/2007 1D=14,660'(MD)/TD=7,210'(TVD) RWO ESP Replacement by Doyon 16-5/11/2014 PBTD=8,363'(MD)/PBTD=4,881'(TVD) NOTE: 4/22/2007-Ran 109 new joints due to corrosion.New tubing hanger installed due to bad BPV profile and landing joint Created By:TDF 6/4/2015 threads. New cable install • 11" BOP Stack iii ii Yill, Hydril 11" 5M \ 11214W_ Shaffer 0 _MOM. 2 3/8" Rams variables , Hydril — _ _ 11" 5M Blinds . •o Optional valve port ci.> 0t: N u, /,,'I7((` -J IL 1 'I ,I - (I Pages NOT Scanned in' this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning pr.oject. They are available in the original file and viewable by direct inspection. / q~ -' / ~"~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: GraYScale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [:] Other, No/Type .OVERSIZED Logs of vadous kinds Other COMMENTS: Scanned b )M~dr~-D~rem, Naltmn Lowell TO RE-SCAN Notes: • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 *~ Anchorage, Alaska 99519 -6612 December 30, 2011 St AtiNEOF=EB .f, 1 ZU1Z Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 3 '\ �- 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPK -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPK -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPK 10/29/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPK -02 1960810 , 50029226750000 0.2 NA 0.2 NA 5.1 9/5/2011 MPK -05 1960680 50029226700000 1.9 NA 1.9 NA 17.9 8/24/2011 MPK-06 1961910 50029227250000 1.5 NA 1.5 NA 8.5 8/27/2011 MPK-09 2050140 50029232470000 1.9 NA 1.9 NA 12.8 8/24/2011 MPK -13 1960400 50029226550000 1.7 NA 1.7 NA 14.5 8/24/2011 MPK -17 1960280 50029226470000 1 NA 1 NA 2.6 8/24/2011 MPK -18A 1970270 50029227330100 4.6 NA 4.6 NA 23.8 8/27/2011 MPK -21A 2031620 50029227180100 0.4 NA 0.4 NA 6.9 10/29/2011 MPK -22 2050220 50029232490000 2 NA 2 NA 5.1 8/27/2011 MPK -25 1960320 50029226500000 4.2 NA 4.2 NA 30.6 8/24/2011 MPK -30 1961680 50029227110000 1.5 NA 1.5 NA 17.0 8/25/2011 MPK-33 1962020 50029227290000 1.7 NA 1.7 NA 15.3 8/24/2011 "--)"' MPK-34 1961690 50029227120000 2.5 NA 2.5 NA 25.5 8/25/2011 MPK-37 1960760 50029226740000 2 NA 2 NA 17.0 8/24/2011 MPK-38 1960300 50029226490000 3.2 NA 3.2 NA 15.3 8/25/2011 MPK -43A 1970410 50029227380100 1.7 NA 1.7 NA 13.6 9/162011 . . Maunder, Thomas E ~ From: Sent: To: Subject: MPU, Well Operations Supervisor [welloperationssupervisor@BP.com] Saturday, May 26,20075:19 AM Thomas Maunder RE: MPK-34 (196-169) Attachments: MPK-34.ZIP \~<ø-'~~ ~ MPK-34.ZIP (6 1<6) Hi Tom, I know that Mark replied to this e-mail earlier, but since that time we got a gas analysis of the Ugnu gas from MPK-34. I have attached it for your review. Please let me know if you have any questions. Thanks, John R. Cubbon MPU Well Operations Supervisor 1-907-670-3330 SCANNED JUL 1 0 2007 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, May 14, 2007 10:00-AM To: MPU, Well Operations Supervisor Subject: MPK-34 (196-169) John, I was just reviewing the 404 report for the April workover on this well and it is mentioned of having to bleed down the lA from 1500 psi and that it was "...all gas...". I spoke with Dave Reem and he indicated that since this is an Ugnu water supply well that over time the annulus does develop a gas head. I was wondering if you could provide a little further information on this. I am curious about the development of the gas head, how much pressure develops, what the normal fluid level is and if it is necessary to bleed the lA. Does this only affect Ugnu water supply wells? Thanks in advance for the information. I look forward to your reply. Tom Maunder, PE AOGCC . . GPB LABORATORY ANALYTICAL REPORT 907-659-5654 Email: GPBLab@bp.com Collection Date 05/19/07 05/19/07 Facility MILNE PT MILNE PT Well MPK-34 MPK-34 Location INNER ANNULUS INNER ANNULUS SampleType GAS GAS COMPOSITION COMPOSITION Sample Description MPU GAS MPU GAS COMPOSITION COMPOSITION Analysis Name Analysis Unit Combination Result Combination Result LINE PRES PSIG 175 175 LINE TEMP DEG.F 82 82 METHANE-MOL% MOL% 92.172 92.223 ETHANE-MOL% MOL% 1.849 1.816 PROPANE-MOL% MOL% 0.825 0.772 I-BUTANE-MOL% MOL% 0.190 0.166 N-BUTANE-MOL% MOL% 0.290 0.247 I-PENTANE-MOL% MOL% 0.087 0.070 N-PENTANE-MOL% MOL% 0.070 0.058 C6P-MOL% MOL% 0.182 0.272 C02-MOL% MOL% 3.294 3.330 NITROGEN-MOL% MOL% 1.041 1. 046 MOL WEIGHT 18.033 18.057 BTU GRSDRY IDEAL BTU@14.696PSIA 1016.9 10 17.2 BTU GRSDRY REAL BTU@14.65PSIA 1016.0 1016.3 BTU GRSSAT IDEAL BTU@14.73 PSIA 1001.5 1001.8 BTU NET BTU@14.696PSIA 915.5 915.1 BTU GRSSAT REAL BTU@14.65 PSIA 998.3 998.6 SPG REAL, 14.65 0.6238 0.6247 PSIA SPG REAL 0.6238 0.6247 SPGIDEAL 0.6226 0.6235 COMPRESSIBILITY 0.997730 0.997731 FAC. 02CONTAM MOL% 0.095 0.044 \~~/ \~q Re: MPK-34 (196-169) . . Subject: Re: MPK-34 (196-169) From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Mon, 14 May 2007 11 :42:20 -0800 To: "MPU, Well Operations Supervisor" <welloperationssupervisor@BP.com> cc: Steve Davies <steve_davies@admin.state.ak.us>, Dave Roby <dave_roby@admin.state.ak.us>, Jim Regg <jim Jegg@admin.state.ak.us> Mark, Thanks much. It seemed strange to read the workover report and see the pressure values and that they were bleeding gas. It makes sense since it is the Ugnu which does have heavy oil, gas and water in it. I'd appreciate if you would share the gas analysis when completed. Call or message with questions or further info. Tom Maunder, PE AOGCC MPU, Well Operations Supervisor wrote, On 5/14/2007 11:35 AM: Tom, Our source well does develop a gas head on the annulus. I know when the well was new we actually had a permanent bleed line plumbed into the production header. Since the well has been in production over time the gas accumulation is allot slower. We no longer use this system. During this completion we did see some corrosion in the tubing and replaced most of the string. We plan to get gas samples once the well stabilizes. If you are interested in UGNU gas our well MPH-02 is a producer in the UGNU that accumulates a gas head. This well will be used as part of our HOTT heavy oil project. We have plans of sampling that gas as well. I will follow through and audit our daily read sheets in order to get you a build rate on K-34 IA. I'll also try to get a few fluid level shot to quantify the increase in the annulus. This may take some time due to the slower build up rate. Hopefully this is what you were looking for. John returns May 23rd. Thanks, Mark O'Malley ACT! , MPU Well Ops Supervisor Phone : 670-3330 Cell : 943-1047 E-Mail: omallemd@bp.com -----Original Message----- From: Thomas Maunder [mailto:tom ~aunder@admin.state.ak.us] Sent: Monday, May 14, 2007 10:00 AM To: MPU, Well Operations Supervisor Subject: MPK-34 (196-169) John, I was just reviewing the 404 report for the April workover on this well and it is mentioned of having to bleed down the IA from 1500 psi and that it was "...all gas...". I spoke with Dave Reem and he indicated that since this is an Ugnu water supply well that over time the annulus does develop a gas head. I was wondering if you could provide a little further information on this. I am curious about the development of the gas head, how much pressure develops, what the normal fluid level is and if it is necessary to bleed the lA. Does this only affect Ugnu water supply wells? Thanks in advance for the information. I look forward to your reply. Tom Maunder, PE AOGCC 10f2 5/14/200711:42 AM REl,C.'VI.-U ~. . - STATE OF ALASKA utA\ 5=/p..P~ ALA~ Oil AND GAS CONSERVATION cO~I~Jû07 REPORT OF SUNDRY WELIrd¡QPiiU1GHSommission Anchorage Water Supply for Injection 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program ~ Repair Well ~ Pull Tubing o Operation Shutdown 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 57.2 - 8. Property Designation: ADL 375132 11. Present well condition summary Total depth: measured 14660 " feet true vertical 7210 / feet Effective depth: measured 8363 feet true vertical 4881 feet Casing Length Size Structural Conductor 78' 20" Surface 8429' 9-5/8" Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 7262' - 7732' 4441' - 4630' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): o Re-Enter Suspended Well ~ Other Change Out ESP o Plug Perforations 0 Stimulate o Perforate New Pool 0 Waiver o Perforate 0 Time Extension 4. Well Class Before Work: 5. Permit To Drill Number: o Development 0 Exploratory 196-169 . o Stratigraphic ~ Service 6. API Number: 50-029-22712-00-00 ' 9. Well Name and Number: 10. Field 1 Pool(s): Milne Point Unit 1 Ugnu - Plugs (measured) N/A Junk (measured) N/A MD TVD Burst Collapse 112' 112' 1490 470 8461' 4914' 5750 3090 S~JiNNED MAY 1 4 2007 5-1/2",17# L-80 6807' Gravel Pack Assemblies: (2) 9-5/8" Versatrieve Packers, 9-5/8" Howco Versatrieve Packer, 9-5/8" Howco BWD Sump Packer, 9 -5/8" Howco 'EZSV' Retainer at 8363' 7188' and 7582', 7372', 7737' Treatment description including volumes used and final pressure: 13. Oil-Bbl Re resentative Dail Avera e Production or In'ection Data Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory 0 Development ~ Service ~ Daily Report of Well Operations 16 W II St t ft d k -''''-- ~ - "- (") \ . e a us a er propose wor : ......o.:~...... 7'-J ~j> "1 ~ Well Schematic Diagram 0 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WbSPL 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: Contact Aras Worthington, 564-4102 Printed Name Sondra Stewmçm ORIGINAL Title Technical Assistant Ph Prepared By Name/Number: "'Ò1;ondra Stewman, 564-4750 Submit Original Only Tree: CIW 41/16" 5M 'FL Wellhead: 11" x 11" 5M FMC Gen 6 Unibore wI two 2" 5M valves on side ports 11" 5M x 4 1/8" 5M adapter and 11" x 4.5" tbg. hng. 4.5" NSCT thread top and bottom and 4" CIW-H BPV profile. 20" 91.1 ppf, H-40 115' I KOP @ 350' Max. hole angle = 70 deg. @ PBTO Hole angle thru' perfs = 65-67 deg 5.5" 17 ppf, L-80 Imp. Btrc. tubing ( drift ID = 4.767", cap. = 0.0233 bpf) 95/8",40 ppf, L-80 Btrc. prod. csg. ( drift 10 = 8.679", cap. = 0.0773 bpf) 4/22/07 NOTE: Ran 109 new jts. due to corrosion. New tbg hanger installed due to bad BPV profile and Landing Joint threads. New cable install Gravel Pack Summary UDDer Uanu: 4200 Ibs. of 20-40 Carbolite proppant behind screen. Middle Uanu: 20,400 Ibs. of 20-40 Carbolite proppant behind screen. Lower Uanu: 5000 Ibs. of 20-40 Carbolite proppant behind screen. Peñoration Summary Ref loa: Schlumberger GRlCCUCBL dated 11/18/96 U nu Formation Size SPF Interval (lVD) 4.5" 12 7262' - 7362' (4384 - 4425') 4.5" 12 7427' - 7572' (4451 - 4508') 4.5" 12 7707' - 7732' (4563 - 4573') SWS: 4-112", 12spf (24 gr. 43C BH), EHO 0.7", Penetration 7.88", 135/45 deg phasing MPU K-34 WSW Orig. lev. = 57.3' (N 22E) Orig. GL Elev. = 27.8' DF To csg. hng. = 31.70' (N 22E) 9 5/8" Howco 'ES' Cementer I 1997' md I HPMTAR 1:1 - 28HC7800 I 6717' md I HPHVMAR 1:1 - 28HC7800 HPHVL T AR 1: 1 - 28HC2800 Tandem Seal Section I HSB3DBUTMSEHLSB/ 6756' md HSB3DBL TMCOLEHLHU Motor, 800 HP, HMI 4160/114 6 fin Centralizer 9-518" 36-43.5# Versatrieve Pkr. 5-1/2" N-80 Blank pipe 5-1/2" 0.12 Ga. Pre-Pack Screen (104.778") 9-5/8" Howco Versatrieve Pkr. 5-1/2" N-80 Blank pipe 5-1/2" 0.12 Ga. Pre-Pack Screen (104.778") 9-5/8" 36-43.5# Versatrieve Pkr. 5-112" N-80 Blank pipe 5-1/2" 0.012 Ga. Pre-Pack Screen (104.778") 9-5/8" Howco 'BWO Sump Pkr. PBTO - 9 5/8" Howco 'EZSV' retainer 9 5/8" float shoe 6770' md I 6804' md I I 7188' md 17211' md 17251' md I 7372' md 1 1 7395' md I I 7422' md I I 7582' md I I 7605' md I I 7697' md I I 7737' md 1 I 8363' md 1 I 8461' md 1 DATE EV.BY COMMENTS MILNE POINT UNIT 11/22/96 JBF Drilled and Cased by Nabors 22E WELL K-34 WSW 11/25/97 JBF Initial Completion by Nabors 4ES API NO: 50-029-22712 04/25/02 GMH Nabors 4ES RWO ESP Replacement 03/31/03 Hulme Nabors 4ES RWO ESP Replacement 04/22/07 REH Nabors 3S RWO ESP Replacement BP EXPLORATION AK Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-34 MPK-34 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/3/2007 Rig Release: 4/17/2007 Rig Number: Spud Date: 11/3/1996 End: 4/17/2007 4/612007 09:00 . 12:00 3.00 RIGD P PRE Scope down and UD Derrick on MPF-13. 12:00 - 18:00 6.00 RIGD P PRE Disconnect lines between Rig components and prepare to pull Mud Pits away from Rig Sub Carrier. Hold PJSM and Safe Work Plan reviewed with crew. Pull out Gen Set #1 and prepare to send in for repairs. Begin to RD the Carrier and prepare it for driving. The center, off-driller-side Stomper Tower (a support tower for the Carrier) was bent during the lowering of the Rig into its driving position. The Tower will need to be replaced with a new one and welded into place. 18:00 - 00:00 6.00 RIGD P PRE Back the Pipe Shed and Pits modules off of well slot MPF-13 and stage on the East end of the Pad. This was discussed with and approved by the Pad Operator and MPU Operations Coordinator. We will be staying on MPF-Pad until all repair operations are complete prior to mobilizing to MPK-Pad to alleviate SIMOPS issues on MPK-Pad. Install Air Compressor to run lights in the Carrier. At 23:00 hrs, back the Carrier off of well slot MPF-13 with the Pad Operator, Toolpusher and Well Site Leader. Spot the Carrier next to the Pits module on the East end of the Pad. 4/7/2007 00:00 - 06:00 6.00 RIGD P PRE Clean up and pick up all the Herculite around well slot MPF-13. Cut the Herculite into 20' x 20' pieces for disposal. Ensure the area around the well is cleaned up and left in good shape. Use Tioga Heater to heat the Carrier where the welding will occur on the Stomper Tower. Clean up the front of the Carrier where the Gen Set was located. Continue to scrub and clean up the Carrier, Pits and Pipe Shed Modules. 06:00 - 18:00 12.00 RIGD P PRE Continue cleaning and maintaning the Rig. Cut the top of the Stomper Tower with GBR rep and send in to shop in Deadhorse to have an identical piece fabricated. 18:00 - 00:00 6.00 RIGD P PRE GBR rep arrives back on location with new fabricated top. PJSM and begin welding the new top onto the Stomper Tower. The new top piece had 4 fish plates welded to its inner wall that slid inside of the orginal bottom piece and were welded onto the bottom piece to provide more support. Welding was complete at 21 :00 hrs. Clean, paint and maintain the Rig. Hold After Action Review on pulling off of well slot with the Carrier. 4/8/2007 00:00 - 18:00 18.00 RIGD P PRE Continue cleaning and painting the Rig. At 01 :00 hrs, perform a "dry run" of re-installing the Breezeway that connects the Pits Module to the Carrier - OK. Wait on Generator Set repairs at Deadhorse. Another air compressor went down so decision made to continue to wait on Generator Set prior to moving the Rig. ETA on the Gen Set is midnight tonight. 18:00 - 00:00 6.00 RIGD P PRE Continue to clean and maintain the Rig. 4/9/2007 00:00 - 03:00 3.00 RIGD P PRE Clean and maintain the Rig. 03:00 - 04:00 1.00 RIGD P PRE Gen Set arrives on location at 03:00 hrs. Stage the Carrier perpendicular to the well row in preparation for re-installing the Gen Set. Spot Rig Mats next to the Breezeway to utilize as a ramp for the Bed Truck. 04:00 - 10:00 6.00 RIGD P PRE PJSM with Nabors Crew, Toolpusher, WSL and Bed Truck Driver. Review Safe Work Plan for re-installing the Gen Set. Back Bed Truck onto Mats and next to the Breezeway. Attach Come-A-Longs and pull the Gen Set off of the Bed Truck into the Carrier. Slide Gen-set into place and connect to Air Inlet Printed: 4/2312007 11 :02:25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-34 MPK-34 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/3/2007 Rig Release: 4/17/2007 Rig Number: Spud Date: 11/3/1996 End: 4/17/2007 4/912007 04:00 - 10:00 6.00 RIGD P PRE shroud, bolt to floors, Install Exhaust system. 10:00 - 16:00 6.00 RIGD P PRE Cat mechanic, rig mechanic, and Nabors Oilfield Camp (NOC) mechanic service Cat engine and connect generator leads to elctrical distribution system and hookup fuel supply lines. RIU diesel charge pump to fill diesel fuel lines. Fuel system plugged. RIU temporary tank and got engine started and running, but generator needs to be excited. 16:00 - 21 :00 5.00 RIGD P PRE Troubleshoot fuel supply problem and wait on Nabors electrician to drive from 9ES to F-pad to set up generator. Enabled Carrier to move utilizing Motor #1. Move the Carrier next to the Pits Module. Feed diesel to the Motors from the Pits Module. Continue working on the Generator. 21 :00 - 23:30 2.50 RIGD P PRE The Gen Set is carrying a load just fine and is up and running. Both Motors running and lined up for Rig Move as normal. Call out Peak Trucks for Rig Move. 23:30 - 00:00 0.50 MOB P PRE Trucks arrive on location. Prepare to move all Rig Modules to MPK-34. 4/10/2007 00:00 - 00:30 0.50 MOB P PRE Continue loading Trucks and preparing for Rig move. 00:30 - 06:00 5.50 MOB P PRE Move Rig and Modules from MPF-13 to MPK-34. 06:00 - 10:00 4.00 RIGU P PRE Center Rig Sub over well and center it. Pull off and spread out Herculite. Night Pad Operator waived witnessing the rig move over the well due to his shift changeout. Move Rig Camp, Shop, and Generator Trailer to K-pad and spot same. 10:00 - 12:30 2.50 RIGU P PRE RIU Pipe Shed and Mud Pits to Rig Sub. P/U and spot Tiger Tank. Veco Dispatch was contacted to ensure Peak could perform this service since they were already onsite. 12:30 - 16:00 3.50 RIGU P PRE Prepare all areas of the Sub Carrier to raise and scope the Derrick. Hold PJSM with Crew, Tool Pusher, WSL, and ADW Drilling Safety representative to raise and scope up Derrick. Raise and scope Derrick. 16:00 - 18:00 2.00 RIGU P PRE RIU Mud Lines, and Electrical Lines. Jeff Jones with AOGCC waived witness for BOPE Test. Accept Rig @ 1800-hrs. 18:00 - 21 :30 3.50 RIGU P PRE RIU Hardline to the Tiger Tank. RIU to Tree to Circulate. PIT surface lines to 3,500-psi. PIT Hardline to 1,000 psi. 21 :30 - 22:30 1.00 DHB P DECOMP TII = 0/1500 psi. P/U Lubricator and pull BPV wI Wells Support assistance. TII = 230/1500 psi. UD Lubricator. 22:30 - 00:00 1.50 KILL P DECOMP PJSM. TII = 200/1500 psi. Bleed off gas from IA. Bled from 1500 psi to 1250 psi in 10 minutes. Circulate 170-Bbls of 9.2 ppg brine at 2.5 BPM and 500 psi while taking all returns (all gas) to the Tiger Tank. TII =350/320 psi. No returns seen in Tiger Tank. Gas vented during the entirity of circulation. 4/11/2007 00:00 - 06:00 6.00 KILL P DECOMP PJSM. TII = 200/1500 psi. Bleed off gas from IA. Bled from 1500 psi to 1250 psi in 10 minutes. Circulate 170-Bbls of 9.2 ppg brine at 2.5 BPM and 500 psi while taking all retums (all gas) to the Tiger Tank. TII =350/320 psi. Shut in Choke and Bullhead 60-Bbls into the formation. Monitor well. TII = vac/320 psi. Circulate 320-Bbls of 9.2 ppg brine at 3 BPM and 880 psi while taking returns to the Tiger Tank. Got fluid returns 10-Bbls of the 320-Bbls Circulation. 06:00 - 08:00 2.00 KILL P DECOMP Continue well kill circulation. Check fluid weight in returns after 660-Bbls and get 7.5-ppg freeze protect MeOH. Resume pumping and SI @ 0800-hrs after 885-Bbls pumped. At start of well kill circulation: 32-Bbls in Pits + 3-ea 290-Bbls truckloads. Printed: 4/23/2007 11 :02:25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-34 MPK-34 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/3/2007 Rig Release: 4/17/2007 Rig Number: Spud Date: 11/3/1996 End: 4/17/2007 4/11/2007 06:00 - 08:00 2.00 KILL P DECOMP Have 250-Bbls of returns in Tiger Tank and 112-Bbls in Pits for losses of 540-Bbls = 870-Bbls + 32-Bbls - 112-Bbls - 250-Bbls. 08:00 - 09:00 1.00 KILL P DECOMP SI and Monitor well for 30-minutes. Tubing on vacuum and Inner Annulus is O-psi. Start pump and fill tubing and it takes 17-Bbls for a fluid level at +1-745'. 09:00 - 14:00 5.00 WHSUR P DECOMP P/U TWC and dry rod into hanger. Make three attempts and TWC will not seat; keeps rotating. Confer with town Engineer, call out MPt Well Support Techs to bring out another TWC. Try to install the BPV that came out of the well and it will not screw into hanger profile. Take off the outer O-ring seal and try again and it will not screw in. Give the well a 20-Bbl drink. FMC tech and the Well support Tech both look into tree with flashlight and cannot see a thread profile, but can see all the way to the pup-joint below the Hanger. Confer with town Engineer to tell him that FMC Tech is calling Lead Slope-based FMC JIT Specialist. He is on his way out, but he says that records show there should be a 4", threaded 'H' profile in the Hanger. That style Hanger used only a threaded profile. 14:00 - 16:00 2.00 WHSUR P DECOMP Give well a 20-Bbl drink. Tubing O-psi, IA O-psi. P/U lubricator and have Well support Tech RIH and try to set TWC with lubricator. It appeared that the TWC was screwing in, but not acting like it was engaged, so tried two more times to set it, then POH with Lubricator and the TWC was not on the rod. P/U Lubricator and RIH, screw into TWC and POH. Cannot see that it had engaged threads. Wait on Lead FMC hand. 16:00 - 16:30 0.50 WHSUR P DECOMP FMC P/U TWC and RIH to screw into profile. TWC feels like it drops into a thread, then into another but won't catch and hold. POH and try another TWC provided by Well Support and it also acts the same way. FMC says the threads in the profile are likely "rolled" and will not hold. 16:30 - 21 :30 5.00 WHSUR C DECOMP M/U lines to test IBP from above and below. PJSM. Bring 5-1/2" pulling equipment to the Floor. Wait on SLB E-Line. Gravity feed IA every 1-hr. Losing 20 Bbls/hr. 21 :30 - 00:00 2.50 DHB C DECOMP PJSM. RlU SLB E-Line. 4/12/2007 00:00 - 05:00 5.00 DHB C DECOMP PJSM. RIH wI E-Line and set 3-318" IBP with center of the element @ 1520' MD. POH wI E-Line. PIT IBP to 3,500-psi from above for 10 minutes and chart. Pump 157-Bbls, 3-BPM at 40-psi down backside to test from below, no test, and to fill annulus. Shoot Fluid Level and find it at 200' from surface. 05:00 - 06:30 1.50 DHB C DECOMP RID SLB E-Line. 06:30 - 07:30 1.00 WHSUR P DECOMP N/D Tree. Find the Hanger threads and the TWC/BPV threads are washed out. Will need a Spear to pull the Tubing Hanger. 07:30 - 12:00 4.50 BOPSU P DECOMP Install 11 " x 13-5/8" DSA. N/U BOPE. 12:00 - 22:00 10.00 BOPSU P DECOMP Test BOPE to 250-psi low, 3500-psi high and record on chart recorder. BOPE test witness waived by Jeff Jones, AOGCC. BlindlShear Rams did not pass the initial test. Upon inspection, found driller side ram to be washed out. Replaced Blind/Shear Rams with Blind Rams. Continually filling IA via gravity feed. Losses were at 20-Bbls/hr until 1430-hrs. Losses dropped to 8-Bbls/hr at 1600-hrs and then to O-Bbls/hr at 1730-hrs. 22:00 - 00:00 2.00 DHB C DECOMP N/D Air Boot, Flow Nipple and Riser. N/U Shooting Flange. Losses at 22-Bbls/hr at 2130-hrs. 4/13/2007 00:00 - 03:00 3.00 DHB C DECOMP RlU SLB S-Line. PIT SWS equipment to 2,500 psi. Printed: 4/23/2007 11 :02:25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-34 MPK-34 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/3/2007 Rig Release: 4/17/2007 Rig Number: Spud Date: 11/3/1996 End: 4/17/2007 4/13/2007 03:00 - 06:30 3.50 DHB C DECOMP RIH with S-Line 3-times to pullIBP. First run: released and equalized the IBP at 1520', but did not latch up. Tool stripped down and found it was the wrong one. Second run: latched up and pulled to 200', but operator decided to drop downhole a few feet, then pulled ap and the IBP had released. Third run: chased IBP to 5300', latched it and POOH. Fluid losses @ -15 Bblslhr since 1800-hrs yesterday. 06:30 - 09:30 3.00 DHB C DECOMP PJSM. RID SWS slickline equipment. 09:30 - 12:00 2.50 PULL C DECOMP PIU Baker Spear, M/U to single joint of 3-1/2" DP and RIH to the 4-1/2", 12.6# pup joint immediately below the Hanger, engage hanger. Wait on Centrilift and FMC personnel. RlU elephant trunk and pass cable retrieval rope over sheave. Hold Pre-tour meeting at 1130-hrs with returning Day crew for the first day of their hitch. 12:00 - 13:00 1.00 PULL C DECOMP Crew change and PJSM for Day crew with 2-Centrilift personnel, 2-FMC personnel, Baker fisherman, rig crew, Tool Pusher and WSL. Discussed the need for all non-essential personnel to be clear of the Rig Floor when picking up on the Landing Joint. Looked downhole to the Hanger and saw something on top of the Hanger that appeared to be a rag or glove. PIU T-bar and RIH to tag it and determined it to be a large chunk of soft debris that broke apart when it was tagged. 13:00 - 13:30 0.50 PULL P DECOMP Clear Rig Floor. PIU on DP and Hanger comes easily at 95,000-lbs, then weight slacks off to 90K as the Hanger is slowly pulled to the Floor. Debris on top of the Hanger appears to be like layered mud and gray formation fines. 13:30 - 14:30 1.00 PULL P DECOMP Tie-off cable to retrieval rope. Test Cable and find 2.2-0hms Phase-to-Phase, 1.8K-Ohms Phase-to-Ground. Cut cable and pull back out of the way. Back out Baker spear and break-off and UD. Break-off and UD Hanger, 4-1/2" pup joint, and 4-1/2" x 5-1/2" XO. Fill hole and it takes 130-Bbls, but does not come to surface. Can't shoot fluid level due to open annulus. Agree to double displace and pump an extra 20-Bbls per hour while POOH. 14:30 - 17:30 3.00 PULL P DECOMP RlU to equipment to POOH and UD 5-1/2" tubing in Pipe Shed. 17:30 - 00:00 6.50 PULL P DECOMP POH wI 5-1/2" IBT-M Tubing while UD into the Pipe Shed. Removing O-Ring Seals from Tubing as they are in poor condition. First 10-jts have pitting on pin end threads and possible erosion within the pipe. Filling hole with double displacement and 20-Bbls/hr. 11 O-jts out @ OOOO-hrs. 4/14/2007 00:00 - 04:00 4.00 PULL P DECOMP Continue POH wI 5-1/2" ESP completion while UD joints into the Pipe Shed. Fill hole with double displacement and 20-Bbls/hr. 120 jts pulled @ 0120-hrs. A total of 87 LaSalle Clamps were recovered. Missing 2 "doors" out of Protectolizer clamps and one 6-1/2' section of Flat Guard. 04:00 - 09:00 5.00 PULL P DECOMP Clear Rig Floor of laSalle Clamps and Thread Protectors. Break and UD ESP per Centrilift's recommendations. 09:00 - 09:30 0.50 BOPSU P DECOMP N/D Air Boots and Flow Riser. 09:30 - 10:30 1.00 BOPSU P DECOMP N/U Shooting Flange. 10:30 - 17:00 6.50 EVAL P DECOMP PIU SWS slickline equipment through Pipe Shed and bring to Rig Floor. RlU SWS XO from Shooting Flange to 2-ea risers, Wireline BOP, and Lubricator. PT SWS equipment to 2500-psi. Printed: 4/2312007 11 :02:25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-34 MPK-34 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/3/2007 Rig Release: 4/17/2007 Rig Number: Spud Date: 11/3/1996 End: 4/17/2007 4/14/2007 17:00 - 19:00 2.00 EV AL P DECOMP Confer with town. Located an existing GRlCCL log in Milne Point Well files. Log data exists from 8400' MO to 50' MD. Decision made to cancel Memory GRlCCL log. 19:00 - 20:00 1.00 EVAL P DECOMP RID SLB S-Line. N/D Shooting Flange. N/U Air Boot and Flow Nipple. 20:00 - 20:30 0.50 EVAL DECOMP Nabors Safety Meeting concerning employee harassment. 20:30 - 23:00 2.50 RUNCO RUNCMP RID Elephant Trunk. RID Single Sheave. RlU Double Sheave. Load new ESP cable into Spooler. Build berming for old 5-1/2" Tubing. Bring ESP cable over Double Sheave. 23:00 - 00:00 1.00 RUNCO RUNCMP PJSM. Discuss upcoming ISO Audit. Unload ESP components and put old ESP components inside boxes and remove from Pipe Shed. 4/15/2007 00:00 - 10:30 10.50 RUNCO RUNCMP PJSM. M/U ESP components and RIH. M/U and service ESP Pumps and Motor. Strap the good joints of 5-1/2" IMBT Tubing in Pipe Shed. Will RIH 55-jts of new IMBT on top of 57-joints of reused IMBT. Will finish the completion string with 57-joints of 5-1/2",17#, L-80 Hydril563 tubing with T-95 collars. Test fit a LaSalle clamp around Hydril 563 T-95 collar; good. The Hydril collars are same dimensions as the IMBT collars: 9.5" long x 6.05" diameter. 10:30 - 15:30 5.00 RUNCO RUNCMP RIH new Centrilift ESP on 57-jts of 5-1/2", 17#, IMBT from original completion that had been UD in the Pipe Shed. 10-jts RIH @ 1215-hrs. 20-jts @ 1250-hrs. 30-jts @ 1330-hrs. 50-jts @ 1515-hrs. Centrilift check conductivity. Load tubing with brine. 15:30 - 21 :00 5.50 RUNCO RUNCMP Remove remainder (109-jts) of the original completion from the Pipe Shed and place on sills on top of containment. Load Pipe Shed with new 5-1/2",17#, L-80 Hydril and IMBT tubing. 21 :00 - 00:00 3.00 RUNCO RUNCMP Continue RIH with 57-jts of new 5-1/2", 17#, IMBT from Pipe Shed. Place La Salle Clamps on every other joint. Use Best-O-Life 2000 Pipe Dope. 4/16/2007 00:00 - 03:30 3.50 RUNCO RUNCMP Continue RIH with new 5-1/2",17#, IMBT from Pipe Shed. Place La Salle Clamps on every other joint. Use Best-O-Life 2000 Pipe Dope. Conductivity test good. 03:30 - 08:00 4.50 RUNCO RUNCMP PJSM. Clear Rig Floor. RlU Stabbing Board. RlU Nabors Torque Turn Casing Equipment. 08:00 - 13:00 5.00 RUNCO RUNCMP Continue RIH with 50-jts of new 5-1/2",17#, Hydril563 from Pipe Shed. Place La Salle Clamps on every other joint. Use Jet Lube Seal Guard. Torque Turn all Hydril connections to 6,700-lb-ft. String jt #125 (Hydril #13) @ 1030-hrs. String jt #145 (Hydril #34) @ 1145-hrs. String jt #156 (Hydril #45) @ 1240-hrs. String jt #162 (Hydril #50) @ 1300-hrs. Conductivity test good. 13:00 - 15:00 2.00 RUNCO RUNCMP RID Torque Tum equipment, change out elevators. P/U Floor Safety Valve and M/U to the string, H/U circulating line and pump 40-Bbls of brine to fill tubing and clear pump. 15:00 - 16:00 1.00 RUNCO RUNCMP P/U and M/U Landing Joint to Tubing Hanger, then M/U to string. P/U wt = 102,000-lbs, SIO wt = 60,000-lbs. 16:00 - 19:00 3.00 RUNCO RUNCMP Space out cable for splice to bottom Field Connection for Penetrator. Centrilift make splice to bottom Field Connection. Pass the remainder of the cable through the elephant trunk to the Spooler. 2 Flatguards run, 6 Protectolizers run, 8 SS Bands run, and 87 laSalle Clamps run. Printed: 4/23/2007 11 :02:25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-34 MPK-34 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 4/3/2007 Rig Release: 4/17/2007 Rig Number: Spud Date: 11/3/1996 End: 4/17/2007 4/17/2007 20:30 - 00:00 00:00 - 05:00 POST POST Land Hanger and RILDS. Dry Rod TWC in and test from above to 1,000 psi and chart. Unable to pressure up from below since the IA is on a strong vac. N/D BOPE. Inspect Hanger. N/U Lock Down Flange, Tubing Head Adapter, and Tree. RlU to PIT Tree. PIT Tubing Head Adapter and Tree to 5,000 psi. Good test. Conduct final conductivity checks at Hanger Penetrator. Phase to phase = 2.6- ohms. Phase to ground = 1.76G-ohms. P/U Lubricator and pull TWC. Install BPV. UD Lubricator. RID Stabbing Board and secure Cellar. Release rig @ 0800-hrs. Prep for Rig Move, wait on PEAK trucks 05:00 - 05:30 05:30 - 06:00 0.50 DHB P 0.50 RIGD P POST POST 06:00 - 17:00 11.00 RIGD P POST Printed: 4/23/2007 11 :02:25 AM RE: MPU Water Supply Wells Subject: RE: MPU Water Supply Wells From: "MPU, Well Operations Supervisor" <welloperationssupervisor @BP.com> Date: Fri, 02 Mar 2007 13:49 :38 -0900 To: Thomas Maunder <torn maunder @admsn.state.ak.us> Tom, I from what I know, they have always been ESPs. If you would like, I can dig back through the well files. Please let me know. Thanks, John R. Cubbon swiliNED APR 1. 2 2.011 MPU Well Operations Supervisor 1- 907 - 670 -3330 Original Message From: Thomas Maunder [mailtc:tom maunder:•a.dmin.state.a.us] Sent: Friday, March 02, 2007 1:28 PM To: MPU, Well Operations Supervisor Subject: Re: MPU Water Supply Wells Thanks John. For the ESP wells, they have always been ESPs correct? Tom MPU, Well Operations Supervisor wrote, On 3/2/20071:17 PM: Hi Tom, C:k \S O tM V �°-� - `cv(p- The information for these wells is as follows: F -02 ESP Completion Active Water Supply Well t A2A ESP Completion Active Water Supply Well t S - \ S B -01 ESP Completion Non - Active Water Supply Well (has not been utilized since at least 2004, and likely much longer) %0 _ d� F -21 ESP Completion Active Water Supply Well ‘C\( _ \� S- F-58 ESP Completion Active Water Supply Well \C( o _ ` S b F -77 ESP Completion Active Water Supply Well \ S S - Z (0 S -22 Jet Pump Com letion in the UGNU. Has been SI since 2005 due to excessiv san production. S-90 Drilled as a hot Ivishak water supply well in 2006. We are evaluating completion options and trying to overcome potential corrosion challenges due to the high CO2 content of the water. Tentative plan to put into service later in 2007. I hope this helps Tom. If you have any questions, or need any further details, please don't hesisitate to let me know. Thanks John R. Cubbon MPU Well Operations Supervisor 1 -907- 670 -3330 1 of 2 3/2/2007 1:58 PM RE: MPU Water Supply Wells Original Message From: Thomas Maunder [mailto: .omm und.ergadmi.n.stat .ak.us] Sent: Monday, February 26, 2007 3:13 PM To: Cubbon, John R Subject: MPU Water Supply Wells John, I see that MPF -02 was just worked over. In the course of checking a few things, I noticed in our production report that this well was reported to be a flowing completion and it appears to have been since completion in August 1996. I have checked our reports on your other wells and found the following: MPA -02A -- submersible, SI or no information to August 1995, then flowing or no information since. MPB- 01 - - -- submersible, SI or no information to January 1998, then flowing to September 2001 and SI since MPF- 21 - - -- flowing since completion June 1997 MPF- 58 - - -- flowing since completion November 1996 MPF- 77 - - -- flowing since completion April 1996 MPK- 34 - - -- flowing since completion December 1997 MPS- 22 - - -- hydraulic pump or flowing since completion in October 2003, SI mostly MPS- 90 - - - -no water production reported I think the production method for all the wells is ESP. Am I correct? I am not sure where the error might be coming from. When you confirm the production method, I will get with our stat techs here and see how we are receiving the information. Then I will get back to you and we can see what changes may be needed. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 2 of 2 3/2/2007 1:58 PM RE: Milne Point K-pad water supply well MPK-34 (PTD #1961690)... e e Subject: RE: Mi1J1~,PointK-pad water supply well M~(P'11il\~~~16~:!andF-Pad water supply \\,ellsMPF-02, 21,58, and77 (PTD #1960700, #1961350, #1961560; and #1951360), .from: "MPU, Well Operations Supervisor" <welloperations~upervisor@BP.com> Date: Thu, 29 Dec 200507:05:21 -0900 'Vi>: T1fo~~;,.Maunder <tom _ ~,!~~d,~@admin.statê.åk.us>j ,j Thanks Tom! JRC From: Thomas Maunder (mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, December 29, 2005 6:50 AM To: MPU, Well Operations Supervisor Cc: MPU, Operations Manager; Jim Regg Subject: Re: Milne Point K-pad water supply well MPK-34 (PTD #1961690) and f-Pad water supply wells MPf-02, 21, 58, and 77 (PTD #1960700, #1961350, #1961560, and #1951360) Hi John, I did some checking as well. Your understanding regarding a regulatory requirement for SSV s on water supply wells is correct. There is no requirement to employ SSV s on such wells. Thanks for checking. Tom Maunder, PE AOGCC MPU, Well Operations Supervisor wrote, On 12/2812005 6:12 PM: Hi Tom, As per our conversation yesterday, I am curious if we are required to have a functioning SSV on our water supply wells here at Milne Point. These wells produce from the Prince Creek and Ugnu formations and are not hydrocarbon producing. From what I can gather reading through the regulations, I can't see where we are required to have a functioning SSV on these wells, but wanted to check with you to make sure. The wells were equipped with SSVs when they were drilled, but we would like to remove the panels and use them elsewhere if they are not required on our source water wells. Our source water wells are not capable of unassisted flow and are produced with Electrical Submersible Pumps. These wells are equipped with pilots that will shut down the ESP if the flowline pressure drops below 500 psi (Le. we develop a leak). Thanks for your help on this Tom and please don't hesisitate to let me know if you need any further information. Best Regards, John R. Cubbon MPU Well Operations Supervisor 1-907 -670-3330 I of 1 12/29/20057:10 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Pedorate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 57.2' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface \ 8. Well Number MPK-34i 3577' NSL, 1954' WEL, SEC. 03, T12N, R11E, UM X = 584604, Y = 600571~ 9. Permit Number / Approval No. At top of productive interval X,i 196-169 1422' NSL, 2992' WEL, SEC. 02, T12N, R11E, UM X = 588872, Y = 6003608 10. APl Number At effective depth 50- 029-22712-00 937' NSL, 2055' WEL, SEC. 02, T12N, R11E, UM X = 589816, Y = 6003135 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 3452' NSL, 2182' WEL, SEC. 12, T12N, R11E, UM X: 595004, Y: 6000434 ' L~G N (,[,~ 12. Present well condition summary Total depth: measured 14660 feet Plugs (measured) true vertical 7210 feet Effective depth: measured 8363 feet Junk (measured) true vertical 4881 feet Casing Length Size Cemented MD TVD Structural Conductor 78' 20" 250 sx Arctic Set I (Approx.) 112' 112' Surface 8429' 9-5/8" 1740 sx PF 'E', 357 sx 'G', 204 sx PF 8461' 4914' Intermediate Production Liner RECEIVED Perforation depth: measured 7262' - 7362', 7427' - 7572', 7707' - 7732' APR ! 6 _003 true vertical 4441' - 4482', 4508' - 4566', 4620' - 4630' Alaska 0il & Gas Cons. Commission Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 6799' Anchorage Packers and SSSV (type and measured depth) Gravel Pack Assemblies: 9-5/8' Versatdeve Packer at 7188' and 7582'; 9-5/8' Howco Versatdeve Packer at 7372'; 9-5/8' Howco 'BWD' Sump Packer at 7737'; 9-5/8' Howco 'F_ZSV' retainer at 8363' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service Water Supply for Injection [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Sond~~ Title Technical Assistant Date ~. -( ,z~ _(.~'?..,) ,(~'"~[~__~F: .[~-.~¥ ~ ~ ?.~.~ _ ~ . ~-, '. ~- '. ~. ~. PreparedByNarne/Number: SondraStewman, 564-4750 Form 10-404 Rev. RBDMS BFL Submit In Duplicate '~'"~ ADD BP EXPLORATION '.'- ..... '. Page.l.lof'2 Operati.ons'Summary'Report '... "": : · . · .: .. . · . .. .. . .. . · . .... Legal Well Name: MPK-34 Common Well Name: MPK-34 Spud Date: 11/3/1996 Event Name: WORKOVER Start: 3/29/2003 End: 3/31/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/31/2003 Rig Name: NABORS 4ES Rig Number: 4ES i .......... : ::: ~:: Date From-To Hours Task COde: :NPT ': phase ] Description of Operations :__ 3/29/2003 00:00 - 06:30 6.50 MOB P DECOMP Continue moving Rig from F-Pad to K-Pad. 06:30 - 07:30 1.00 MOB P DECOMP Spot Sub Base, Rig Pits, and Tiger Tank. 07:30 - 09:00 1.50 MOB P DECOMP Raise and scope Derrick. Take on 8.7 lb/gal Brine in pits. Accept Rig at 09:00 hrs. 09:00 - 10:30 1.50 MOB P DECOMP Spot Pipe Shed and Rig Camp. Continue to fill Rig Pits. 10:30 - 12:00 1.50 KILL P DECOMP RU lines to Tree and Tiger Tank. 12:00- 12:30 0.50 KILL P DECOMP RU Lubricator. Pull BPV. LD Lubricator. 12:30 - 13:00 0.50 KILL P DECOMP Safety and Pre-Job meeting NAD, BP, and Baroid. 13:00 - 13:30 0.50 KILL !P DECOMP Test lines to 3,500 psi. Good. Open well. TP = 100 psi. Csg = 220 PSI. 13:30 - 14:00 0.50 KILL P DECOMP Open well. Reverse out 60 Bbls of methanol. 3 BPM @ 400 Psi. 14:00 - 17:00 3.00 KILL ~ DECOMP Kill well Circulate welll w/8.7 PPG Brine. 4 BPM @ 1500 Psi. Bullhead 80 Bbls down annulus. 4 BPM @ 1500 Psi. 17:00 - 18:00 1.00 KILL ~ DECOMP Monitor well. Well slightly out of balance. Circulate 4 BPM @ 1400 Psi. S/D & monitor well, well dead. 18:00 - 18:30 0.50 WHSUR ~ DECOMP Install TWC valve & test same to 2500 Psi. 18:30 - 19:30 1.00 WHSUR ~ DECOMP N/D x-mas tree. Load out from cellar. 19:30 - 22:30 3.00 BOPSUF; ~ DECOMP N/U DOPE. Pull variable rams & install 5 1/2" rams. 22:30 - 00:00 1.50 BOPSUF~ ~ DECOMP Begin DOPE test as per BP/AOGCC requirements. LP 250 Psi, HP 3500 Psi. Also tested Koomey. 3/30/2003 00:00 - 01:30 1.50 BOPSUR ~ DECOMP Finish testing DOPE. LP 250 Psi, HP 3500 Psi. Test witnessing waived by John Spaulding wi AOGCC. 01:30 - 02:00 0.50 WHSUR P DECOMP P/U lubricator, Pull TWC & L/D same. 02:00 - 02:30 0.50 WHSUR P DECOMP M/U landing jt. BOLDS. 02:30 - 03:00 0.50 WHSUR P DECOMP Pull hanger to floor. P/U wt 105K. Test ESP penetrator. L/D hanger & landing jt. 03:00 - 06:00 3.00 PULL P DECOMP Start POOH w! ESP assy and 5 1/2" tbg. LD in singles in pipe shed. Crew change. 06:00 - 06:30 0.50 PULL P DECOMP PJSM. Lub Rig. 06:30 - 11:00 4.50 PULL P DECOMP Finish POOH with 5 1/2" Tbg = 166 jts. ESP Assy to surface. 11:00 - 14:00 3.00 PULL P DECOMP Inspect and lay down ESP Assy. Motor "fried". 14:00 - 15:30 1.50 PULL P DECOMP C&C Floor. RU to run new ESP Assy. Change-out ESP cable spools in Spooling Unit. 15:30 - 20:00 4.50 RUNCOI~ COMP !Pick-up, inspect, and service ESP sections. Perform electrical check. 20:00 - 00:00 4.00 RUNCOI~ COMP RIH w/ESP on 5 1/2" tubing. 3/31/2003 00:00 - 04:30 4.50 RUNCOI~ COMP Con't to RIH w/ESP on 5 1/2" tbg. Ran 166 jts 5 1/2" 17#, L-80, MBTC tubing. P/U 100K, S/O 65K. Ran 88 LaSalle Clamps, 2 Flat Clamps, 5 Protectolizers 04:30 - 06:00 1.50 RUNCOI~ COMP M/U tubing hanger. Make final penetrator splice on hanger. Test same. Crew change. 06:00 - 07:00 1.00 RUNCOI~ COMP PJSM. Attach field connector and test. Good. 07:00 - 07:30 0.50 RUNCOI~ COMP Land Tbg Hanger. RILDS. 07:30 - 08:00 0.50 RUNCOI~ COMP Set and test TWC. 08:00 - 09:30 1.50 BOPSUR P COMP ND DOPE. 09:30 - 10:30 1.00 WHSUR P COMP NU Production Tree. 10:30 - 11:00 0.50 WHSUR P COMP Test Tree and adaptor flange to 5,000 psi. Good. 11:00-12:00 1.00 WHSURi P COMP PU Lubricator and pull 'rwc. Begin to rig down TT and Pits. 12:00 - 14:00 2.00 RUNCOkP COMP RU HB&R. Freeze Protect well with 50 bbls Methanol dwn Tbg and 90 bbls of diesel dwn Annu. RD HB&R. Continue to RD Rig and equipment. 14:00 - 15:00 1.00 WHSUR P COMP PU Lubricator and install BPV. LD Lubricator. 80ANNED. 0 5 2003 Printed: 4~8~2003 9:03:28 AM BP EXPLORATION" 'page 2'of 2 .. Operations SummarY.Report ........ .. .. Legal Well Name: MPK-34 Common Well Name: MPK-34 Spud Date: 11/3/1996 Event Name: WORKOVER Start: 3/29/2003 End: 3/31/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/31/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours TaSk c°del ~ NPT::~: Phase :~:: ,: '" Description:of Operations'.. . 3/31/2003 15:00 - 16:00 1.00 RIGD P COMP Blow down lines. Secure well and cellar. Release Rig...LMH. I i i I Printed: 4/8/2003 9:03:28 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS i. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2, Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 57.2' [] Exploratory 7, Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3577' NSL, 1954' WEL, SEC. 03, T12N, R11E, UM MPK-34 At top of productive interval 9. Permit Number / Approval No. 196-169 1422' NSL, 2286' EWL, SEC. 02, T12N, R11E, UM 10. APl Number At effective depth 50- 029-22712-00 4342' SNL, 3225' EWL, SEC. 02, T12N, R11E, UM 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 1827' SNL, 3097' EWL, SEC. 12, T12N, R11E, UM 12. Present well condition summary Total depth: measured 14660 feet Plugs (measured) true vertical 7210 feet Effective depth: measured 8363 feet Junk (measured) true vertical 4881 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arctic Set I (Approx.) 112' 112' Surface 8429' 9-5/8" 1740 sx PF 'E', 357 sx 'G', 204 sx PF 8461' 4914' Intermediate Production Liner Perforation depth: measured 7262'- 7362', 7427' - 7572', 7707' - 7732' true vertical 4441' - 4482', 4508' - 4566', 4620' - 4630' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 6791' Packers and SSSV (type and measured depth) Gravel Pack Assemblies: 9-5/8" Versatrieve Packer at 7188' and 7582'; 9-5/8' Howco Versatrieve Packer at 7372'; 9-5/8' Howco 'BWD' Sump Packer at 7737'; 9-5/8" Howco 'EZSV' retainer at 8363' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run ~A/-[-' ~;..~ [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service Water Supply for Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Sondra~ Title Technical Assistant Date Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate : ::: : :: : Bp EXPLORATION Page 1 of 2 :i ; ::: ; ;operati°nSSUmmary Report Legal Well Name: MPK-34 Common Well Name: MPK-34 Spud Date: 11/3/1996 Event Name: WORKOVER Start: 4/19~2002 End: 4~25~2002 Contractor Name: NABORS Rig Release: 4/25/2002 Rig Name: NABORS 4ES Rig Number: 4 Date : From,To::llFIOUrs tActiVityllc°deI NPT Phase Description of Operations 4/19/2002 12:00 - 13:00 1.00 RIGU I p I DECOMP INSPECT &ACCEPT RIG ,SET TANK,RUN HARD LINE 13:00 - 14:30 1.50 RIGUi P DECOMP R/U HARD LINES T/TREE 14:30 - 15:30 1.00 KILL P DECOMP PULL BPV W/LUBRICATOR 15:30 - 16:30 1.00 KILL P DECOMP iREMOVE SINGLE 54"SHEAVE-HANG DOUBLE 54"SHEAVE 16:30 - 18:00 1.50 KILL P DECOMPI CLEAN RIG -TAKE ON S.W. (3% KCL) 18:00 - 21:30 3.50 KILL P DECOMP HANG ELEPHANT HOSE -PRESS. TEST TO 3500 PSI 21:30 - 23:30 2.00 KILL P DECOMP CIRC. WELL BORE CLEAN OF HYDROCARBONS ,W/8.5 KCL WATER 23:30 - 00:00 0.50 KILL P DECOMP MONITOR WELL 4/20/2002 00:00 - 00:30 0.50 KILL P ~ DECOMP CLEAN RIG-TAKE ON S.W.(3% KCL) 00:30 - 01:00 0.50' WHSUR P DECOMP INSTALLED TWC &TEST TO 2500 PSI 01:00 - 02:00 1.00 WHSUR P DECOMP BLOW DN LINES & R / DN LINES 02:00 - 03:00 1.00 WHSUR P DECOMP NIPPLE DN TREE 03:00 05:30 2.50 BOPSUR~P DECOMP NIPPLE UP DOPE INSTALL CHOKE & KILL LINES 05:30 06:00 0.50 BOPSUF~P DECOMP R / UP TEST EQUIPT 06:00 - 07:00 1.00 BOPSU~P DECOMP CHG. PIPE RAMS TO 5 I/2",CHG.BOTH DOOR SEALS 07:00 - 10:00 3.00 BOPSUF:P DECOMP TEST DOPE TO 250 LOW & 3500HIGHT (TEST WAIVED BY i CHUCK SHEVE WITH AOGC.) 10:00 - 12:30 2.50 PULL P I DECOMP PULL TWC ,M / U LANDING JT ,PULL .& L / D HANGER & L / · JT MONITOR WELL 12:30 - 13:30 1.00 PULL P DECOMP iCIRC. METH. & GAS OUT UNTIL CLEAN @ 3 BPM 13:30 - 18:30 5.001 PULL P DECOMP POOH L / DN 5 1/2" TBG--HOLE FILL NOT CORECT 18:30 - 23:30 5.00 PULL P DECOMP i MONITOR WELL .FLOW NC1.1 BBL IN 15 M NS. SHUT N & MONITOR-PREPARE TO BULLHEAD DN ANN. 23:30 - 00:00 0.50 PULL P DECOMP START BULLHEAD 8.5# KCL, 4 BPM @ 200 PSI 4/21/2002 00:00 01:30 1.50 PULL P DECOMP BULLHEAD 200BBL DN ANN.--MONITOR WELL,FLOWED BACK 6 BBLS (WELL DEAD) ( PUMP 8.5# KCL @ 4 BPM ) 01:30 - 04:00 2.50 PULL P DECOMP CONT. POOH L/D 5 1/2' TBG. 04:00 - 06:00 2.00 PULL P DECOMP INSPECT & L/D ESP 06:00 - 07:00 1.001 PULL P DECOMP CLEAN RIG & LOAD PIPE SHEAD 07:00-07:30 0.50! STIM IP COMP R/U TO RUN 2 1/16 & 2 7/8' TBG 07:30 - 08:30 I 1.00 BOPSUI~P COMP CHANGE 5 1/2" RAMS TO 2 7/8" TEST 250& 3500 PSI OK 08:30 - 09:30 1.00 1STIM P I COMP cHGTIH W/OUT2 1/16"TBGELEVATORS( CS &HYDRIL)WsLIPS / 2.75" CT JET NOZZEL 09:30 - 18:00 8.50 STIM P COMP P/U & RIH W/2 7/8"TBG TO 6591 FT.(INSTALL XN I COMP NIPPLE)CeNT RIH TO 7364 18:00 - 19:00 1.00 STIM P , M/U TI W(FULL OPENING) CeNT RIH TO 7560 FT 19:00 - 21:00 2.00 STIM P i COMP W/O TIW VALVES -MU TIW &TI H TO 7740 21:00 - 23:00 2.00 STIM P I COMP RU SLICK LINE,RIH SET PLUG IN XN NIPPLE POOH 23:00 - 23:30 0.50 STIM PI COMP TEST TBG & VALVE ASSY. TO 3500 PSI 23:30 - 00:00 0.50 STIM P COMP RIH TO RETRIEVE PLUG 4/22/2002 00:00 - 01:00 1.00 STIM ~ COMP RIH RETREIVE PLUG--RD SLICK LINE 01:00 - 03:00 2.00 STIM ~ COMP RU FOR ACID JOB,TEST LINES TO 5000# EST. INJECT. RATE 3 BPM @1300 PSI . PICKEL TBG W/12 BBLS OF 10%HCL,TRY TO REVERSE 03:00 - 06:00 3.00 STIM P COMP OUT COULD NOT,CONT. W/1ST. STAGE OF ACID ~ TREATMENT AS PER PROGRAM (18 BBLS 10%HCL--18 BBL ,9-1 MUD ACID, 30 BBL 3% NH4CL FLUSH,40 BBL 06:00 - 07:00 1.00 STIM P COMP I SOURCE WATER--30 PSI PRESS ON TBG. RAISE WT. OF KCL IN PITS TO 8.5#--PUMP 43 BBL DN 07:00 - 08:00 1.00 STIM :P LD 6 JTS. TBG.( TO 7550 FT )-RU LINES FOR ACID 08:00 - 11:30 3.50 STIM I P TEST LINES TO 5000 PSI--PUMP 2ND.STAGE AS PER , Printed: 413012002 3:14:08 PM : : i i:: :i :BP EXpLORATiON Page2of2 i:~ ~::: ~ : oPerati°nSlSummary Report Legal Well Name: MPK-34 Common Well Name: MPK-34 Spud Date: 11/3/1996 Event Name: WORKOVER Start: 4/19/2002 End: 4/25/2002 Contractor Name: NABORS Rig Release: 4/25/2002 Rig Name: NABORS 4ES Rig Number: 4 08:00 I P ] COMP 4/22/2002 - 11:30 3.50 STIM I PROGRAM (103 BBL 10% HCL--103BBL MUD ACID--216 BBL 11:30 I COMP NH4CL) 30 PSI PRESS ON TBGAFTER SHUT DN. - 20:00 8.50 STIM i C B D LINES-MONITOR WELL,30PSI ON TBG REMOVE it ELEPHANT HOSE SERVICE CLEAN FLOOR STRING UP ROPE FOR ESP CABLE- WHILE WAIT ON 750BBL NH4CL i ~ 'FROM DEAD HORSE 20:00 - 00:00 4.00 STIM P ! , COMP BULLHEAD 40 BBL 8.5# NH4CL DN TBG (TBG DEAD) B/O TIW VALVE, LD 5 JTS. TO 7360 FT --PUMP 3 RD. STAGE AS PER PROGRAM (71 BBL 10% HCL -71 BBL OF 9-1 MUD ACID,- 216 BBL NH4CL 4/23/2002 00:00 - 04:00 4.00 STIM P COMP I P,/D DOWELL --BULLHEAD 475BBL OF 8.5# NH4CL DN TBG !WITH RIG PUMPS, 3 BPM @700 PSI MONITOR WELL -BLOW DN LINES & BRK OUT TIW VALVE 04:00 - 09:30 5.50 STIM P~ COMP~ LD 2 7/8"TBG- CHG. ELEV. ECT-.LD 2 1/16" TBG 09:30 - 10:30 1.00 BOPSUF~P i COMP I CHG. 2 7/8" RAMS TO 5 1/2 PIPE RAMS-TEST 250/3500 PSI 10:30 - 11:00 0.50 RUNCOI~I~I COMP RU TO RUN 5 1/2" TBG-PLACE PUMP ASSY. IN PIPE / I SHEAD 11:00- 15:30 4.50 RUNCOr¢~ ] COMP MU SERVICE ESPASSY. 115:30 - 22:30 7.00 RUNCOI~:~I COMP PU 5 I/2"TBG & RIH WITH ESP TO 5,000 FT.( 120 JTS. I ] )-ESP TEST BAD--PREP. TO TOH 22:30 - 00:00 i 1.50' RUNCOI~i~I DFAL COMP TOH W / ESP LAYING DN 5 1/2" TBG 4/24/2002 00:00 - 04:30 4.50 RUNCOI~iN DFAL COMP RIH W / ESP ON 5 1/2" TBG TO 5000 FT.CHECK ESP TESTED BAD--PREP. TO TOH 04:30 - 06:00 1.50 RUNCOr~i DFAL COMP TOH WITH ESP LAYING DN. 5 1/2" TBG CUT FLAT CABLE, i PULL PUMP OUT OF HOLE & INSPECT ESP CABLE &PUMP I --CABLE CHECKED BAD --PUMP, OK ! 06:00 - 07:30 1.50 FISH N DPRB COMP RIG HES SLICKLINE FOR GPJJB RUN. 07:30 14:00 6.50 FISH N DPRB COMP MADE 3- RUNS WITH 8.35" GPJJB TO # 1 TO 6748' & i RECOVER 7- BANDS RUN # 2 TO 6837' & RECOVER 8- ~, BANDS & PIECES OF JUNK. RUN # 3 TO 7153' & RECOVER I 3- BANDS. & RIG DOWN HES. RUNCO MAKE UP ESP AND SERVICE SAME. i 14:00 - 18:00 4.00 IX~ COMP 18:00 - 00:00 6.00 RUNCOI~I COMP i RIH WITH ESP COMPLETION 4/25/2002 00:00 - 01:00 1.00 RUNCOI~ COMP RIH WITH ESP COMPLETION TO SETTING DEPTH. @ 6790' 01:00 - 04:30 3.50 RUNCOI~P COMP MU HANGER & MAKE ESP CONNECTOR SPLICE & TEST SAME & LAND HANGER & RILDS 04:30 - 07:30 3.00 BOPSURP COMP SET TWC & TEST & NIPPLE DN BOP'S 07:30 - 08:00 0.50 WHSUR P COMP NIPPLE UP TREE 08:00 - 09:00 1.00 WHSUR I P COMP TEST TREE & FLGS TO 5000 PSI. 09:00 - 10:00 1.00WHSUR ~P COMP RIG LUBRICATOR & PULL TWC & SET BPV. RELEASE RIG MI @ 1000 HRS. 4/25/2002 4/26/2002 00:00 - 0.00 RUNCO COMP I ! I I I Printed: 4/30/2002 3:14:08 PM · -' STATE OF ALASKA ALASH_. .)IL AND GAS CONSERVATION CON, 3SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 57.2' [] Exploratory. 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3577' NSL, 1954' WEL, SEC. 03, T12N, R11E, UM MPK-34 At top of productive interval 9. Permit Number / Approval No. 196-169 1422' NSL, 2286' EWL, SEC. 02, T12N, RllE, UM 10. APl Number At effective depth 50- 029-22712-00 4342' SNL, 3225' EWL, SEC. 02, T12N, R11 E, UM 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 1827' SNL, 3097' EWL, SEC. 12, T12N, RllE, UM 12. Present well condition summary Total depth: measured 14660 feet Plugs (measured) true vertical 7210 feet Effective depth: measured 8363 feet Junk (measured) true vertical 4881 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 20" 250 sx Arctic Set I (Approx.) 112' 112' Surface 8429' 9-5/8" 1740 sx PF 'E', 357 sx 'G', 204 sx PF 8461' 4914' Intermediate Production Liner i EC[iV[ Perforation depth: measured 7262' - 7362', 7427' - 7572', 7707' - 7732' MAR Gl 2000 true vertical 4441' - 4482', 4508' - 4566', 4620' - 4630' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 6861' Anch0]'age, Packers and SSSV (type and measured depth) Gravel Pack Assemblies: 9-5/8' Versatrieve Packer at 7188' and 7582'; 9-5/8' Howco Versatrieve Packer at 7372'; 9-5/8' Howco 'BWD' Sump Packer at 7737'; 9-5/8' Howco 'EZSV' retainer at 8363' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service Water Supply for Injection [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble .~_A/~~... Title TechnicalAssistant III Date 02-~(~--OO, ,,..~"'~ i Prepared By Name/Number: Terrie Hubble, 564-4628~ Form 10-404 Rev. 06/15/88 Submit In Duplicate Progress Report Facility M Pt K Pad Well MPK-34 Page 1 Rig Nabors 4ES Date 21 February 00 Date/Time 14 Feb O0 18:00-02:00 18:00-02:00 15 Feb 00 02:00 02:00-05:00 02:00-05:00 05:00 05:00-06:00 05:00-06:00 06:00 06:00-15:00 06:00-15:00 16 Feb 00 17 Feb 00 15:00 15:00-16:30 15:00-16:30 16:30 16:30-20:00 16:30-20:00 20:00 20:00-23:30 20:00-23:30 23:30 23:30-00:30 23:30-00:30 00:30 00:30-01:30 00:30-01:30 01:30 01:30-06:00 01:30-06:00 06:00 06:00-13:00 06:00-10:30 10:30 10:30-13:00 13:00 13:00-06:00 13:00-19:30 19:30 19:30-04:00 04:00 04:00-06:00 06:00 Duration 8hr 8hr 3hr 3hr lhr lhr 9hr 9hr 1-1/2 hr 1-1/2 hr 3-1/2 hr 3-1/2 hr 3-1/2 hr 3-1/2 hr lhr lhr 1 hr 1 hr 4-1/2 hr 4-1/2 hr 7hr 4-1/2 hr 2-1/2 hr 17hr 6-1/2 hr 8-1/2 hr 2hr Activity Move rig Rig moved 100.00 % Move rig & rig up raise & scope derrick & safe out equipment. At well location - Slot Wellhead work Retrieved Hanger plug rig lubricator & pull bpv & rig lines to tiger tank from tree etc. Equipment work completed Fluid system Fill pits with Fresh water Completed operations Well control Circulated closed in well at 6866.00 ft Pjsm & kill well, Had problem with getting well to quit flowing back 8.3 source h20 from tbg. side. raise brine wt to 8.6 ppg. & circ well & annulus kept flowing until 8.6 at surface. Monitor well & well static. Hole displaced with Fresh water - 200.00 % displaced Wellhead work Retrieved Xmas tree Install twc & test to 2500 psi. & remove tree. Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi Wellhead work Removed Hanger plug Equipment work completed Wellhead work Removed Tubing hanger Equipment work completed Pull Tubing, 5-1/2in O.D. Laid down 2800.00 ft of Tubing Stopped: To hold safety meeting Pull Tubing, 5-1/2in O.D. (cont...) Laid down 6866.00 ft of Tubing 166 joints laid out Rigged down sub-surface equipment - ESP Equipment work completed Run Single completion, 5-1/2in O.D. Rigged up sub-surface equipment - ESP change spools in spooler & mu esp assy etc. Equipment work completed Ran Tubing to 6866.00 ft (5-1/2in OD) On bottom Rigged up Tubing hanger install tbg. hanger & make esp splice. Stopped: To hold safety meeting Facility M Pt K Pad Progress Report Well MPK-34 Page Rig Nabors 4ES Date 2 21 February 00 Date/Time 06:00-07:30 06:00-07:30 07:30 07:30-09:00 07:30-09:00 09:00 09:00-10:30 09:00-10:30 10:30 10:30-11:00 10:30-11:00 11:00 11:00-11:30 11:00-11:30 11:30 11:30-06:00 11:30-14:00 14:00 Duration 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 18-1/2 hr 2-1/2 hr Activity Run Single completion, 5-1/2in O.D. (cont...) Installed Tubing hanger finish splice & land hanger & rilds. & set twc & test to 2500 psi. Tie-down bolts energised Nipple down BOP stack Rigged down BOP stack Equipment work completed Wellhead work Installed Xmas tree Equipment work completed Test well control equipment Tested Xmas tree Pressure test completed successfully - 5000.000 psi Wellhead work Installed Hanger plug pull twc & set bpv Equipment work completed Fluid system Freeze protect well - 125.000 bbl of Diesel Completed operations STATE OF ALASKA ALASKA 'LAND GAS CONSERVATION CO fISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown [~Stimulate []Plugging []Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3577' NSL, 1954' WEL, SEC. 3, T12N, R11 E, UM At top of productive interval 1423' NSL, 2290' EWL, SEC. 2, T12N, R11E, UM At effective depth 1819' SNL, 3109' EWL, SEC. 12, T12N, R11E At total depth 1820' SNL, 3107' EWL, SEC. 12, T12N, R11E, UM 5. TypeE~ well: Development [] Exploratory [] Stratigraphic [~ Service 6. Datum Elevation (DF or KB) KBE = 57.3' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-34 9. Permit Number / Approval No. 196-169 396-223 10. APl Number 50-029-22712 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition sum.mary Total depth: measured 14660 feet true vertical 7210 feet Effective depth: measured 8363 feet true vertical 4881 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 80' 20" 8429' 9-5/8" Plugs (measured) Junk (measured) Cemented 250 sx Arctic Set I (Approx.) 1740 sx PF 'E', 357 sx 'G', 204 sx PF 'C' MD TVD 112' 112' 8461' 4875' Perforation depth: measured ~ 7262'-7362'; 7427'-7572'; 7707'-7732' true vertical 4441 '-4482'; 4508'-4566'; 4620'-4630' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 @ 6868' Packers and SSSV (type and measured depth) N/A FEB 02 2000 /~aska 0il & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas F"] Suspended Service Water Supply for Injection 17. I hereby certify that the foregoipg is true and c/ofrect to tine best of my knowledge Signed ANGELAM. SORRENTINO~J~~Titlo SurveillanceEngineer Prepared By Name/Number: Michael Williams, 564-4657 Form 10-404 Rev. 06/15/88 Submit In Duplicate 1/11/2000 MPK-34 DESCRIPTION OF WORK COMPLETED Stimulation Operation A Mud Acid Stimulation Treatment was performed using the following fluids: Milne Point Unit K-34 is a water source well in the Ugnu formation which supplies injection water to K pad injectors K-18i, K-21i, and K-43Ai. A stimulation was pumped on MPK-34 January 11, 2000 to remove fines migration in the near wellbore region and increase water production. The well was stimulated by pumping the following down the tubing and into the gravel pack: 50 bbls 7 ~% HCl, 180 bbls of 9:1 Mud Acid (HF), 140 bbls 3% NH4Cl over flush, 180 bbls Clay Acid (H3BO4 + HF), and 90 bbls 3% NH4CI followed by 50 bbls MeOH for freeze protection. The well was shut in for 48 hours and then returned to production. Fluids Pumped ] BBLS. Description 50 Meoh 50 7 %% HCL 180 9.1 Mud Acid (HF) 140 3% NH4CI 180 Clay Acid (H3BO4 + HF) 600 Total BBLS , E!VED FE.9 02 2000 AJaska Oil & Gas Cons. Commi,~ion Anchorage ~.:..STATE OF ALASKA -- ALASKA Ol .ND GAS CONSERVATION COMk. .SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: I~ Operation Shutdown [] Stimulate [~ Plugging F-I Perforate I~ Pull Tubing I~AIter Casing [] Repair Well []Other 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 5. Type of well: [] Development I-q Exploratory [] Stratigraphic I~ Service 4. Location of well at surface 3577' NSL, 1954' WEL, SEC. 3, T12N, R11E At top of productive interval N/A At effective depth 4342' SNL, 2054' EWL, SEC, 2, T12N, R11E At total depth 1820 SNL, 3107' EWL, SEC. 12, T12N, R11E Datum Elevation (DF or KB) PLAN RTE = 57.3 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-34 9. Permit Number / Approval No. 96-169 10. APl Number 50-029-22712 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 14660 feet true vertical 7175 feet Effective depth: measured 8363 feet true vertical 4881 feet Casing Length Structural Conductor Surface Intermediate Production Liner Size 82' 20" 8431' 9-5/8" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx.) 1740 sx PF'E',357 sx Class'G',204 sx MD TVD 112' 112' 8461' 4875' Perforation depth: measured true vertical 7262'-7362';7427'-7572';7707'-7732' 4441'-4482';4508'-4566';4620'-4630' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 @ 6868' Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure OR GINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 15. Attachments :._~ Copies of Logs and Surveys run i~ Daily Report of Well Operations 16. Status of well classifications as: [] Oil [~ Gas [] Suspended Casing Pressure Tubing Pressure Service Water Supply for Injection 17. I hereby certify that the fore~ing is tr~e and~rrec~,~he best of my knowledge Signed //~/~ ANGELASORRENTINO v ~/"}...~_.~¢1/v/ ~'4 Title Production Engineer Prepared By Name/Number: Date l~~¢ . ~'~j-' Michael Wi/lam.C, 564-4657 _, ~ Submit In Duplicat~ Form 10-404 Rev. 06/15/88 MPK-34 DESCRIPTION OF WORK COMPLETED Stimulation Operation 04/16/99 A Mud Acid Stimulation Treatment was performed using the following fluids: SUMMARY K-34 water source well was treated with 173 bbls of mud acid and 112 bbls of 7.5%HCl with 2 foam diverter stages. Before the treatment, water production rate was 5800 bpd with K-21i shut in and K-18i and K-43i open choke at 65 HZ. After the treatment, water production rate was 8700 bpd also with K-21i shut in and K- 18i and K-43i open choke. Water production rate was 9000 bpd with all three injectors open choke at 62 HZ. Fluids Pumped BBLS. Description 112 7.5% HCL 173 Mud Acid 285 Total Pumped REC ivFED "~" 0 5 1999 0il & Gas CoNs. Commission A~¢or~e AOGCC Geological Materials Inventory PERMIT 9 6-169 BP EXPLORATION Log Data Sent Received PERF ~?~' 7600-7800 / (~ ~3 ~ V./~ ) 1/21/1998 1/29/1998 SRVY CALC RPT ~CHLUM 0-14660.2 1/21/1998 2/2/1998 SUMP PACK SET k.d~' 7600-7800 1/21/1998 1/29/1998 7549 W~SCHLUM CDR/ADN 12/12/1996 12/13/1996 Box ADN-TVD l,,JZ- 4900-7200 12/12/1996 12/13/1996 AND-MD ~-~'8481-14660 12/12/1996 12/13/1996 CBT ~'f~' 50-8410 11/19/1996 11/22/1996 CDR-MD -~* 4997-14660 12/12/1996 12/13/1996 CDR-TVD ~' 3600-7200 12/12/1996 12/13/1996 ~0-407 Completion Date I I/~[ ~/e!~? Daily well ops //~4/'7) Are dry ditch samples required? yes ~______..-~o And received? ~ .... no Was the well cored? Are tests required? Well is in compliance Comments yes ~'no yes ~. no .s Initial Analysis _description received? Received?~S~-~'~fi*o UIC Wednesday, October 13, 1999 Page 1 of 1 STATE OF ALASKA (~. iZ {'' ~, IV ~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG~'~."' '-;:, ' ...... 1 Status of Well Classification of~e~,~¢ej~l'l~c:s I--IOil I--]Gas [--]Suspended E~Abandoned [~Service Water Supply for Injection 2. Name of Operator 7. Permit Number BP Exploration (AlaSka)Inc. 96-169 396-223 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22712 4. Location of well at surface i" ';-fi,,:.~.;;71'.'2?.i;!.i:;;; ~ ~,~,,,,,,,,,,,,~. 9. Unit or Lease Name 3577' NSL, 1954' WEL, SEC. 3, T12N, R11E, UM: / [/~ ~¢?~ ! i~,~~~ Milne Po,hr Un,t At top of productive interval 10. Well Number 1423' NSL, 2290' EWL, SEC. 2, T12N, R11E, UM i'-'- ..... ;?'--.;~- - il ,:.~.~,~..,~,..~ MPK-34 At total depth ..............1 .'~'~'~-~.,~ ;¢. 1,. 11. Field and Pool 1820' SNL, 3107' EWL, SEC. 12, T12N, R11 E, UM .......... Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 57.3'I ADL 375132 12. Date Spudded11/3/96 113' Date I'D' Reached ! 14' Date C°mp" Susp" °r Aband'l15' water depth' if Offsh°re 116' N°' °f c°mpleti°nsl 1/17/96 11/25/97 N/A MSLI One 17. Total Depth (MD+TVD)]18. Plug Back Depth (MD+TVD)I19. Directional Survey t20. Depth where SSSV set 121. Thickness of Permafrost 14660 7210 FTI 8363 4881 FTI [~Yes i~No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run C T, NRIGINAL 23. CASlNG~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 34' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 32' 8461' 12-1/4" 1740 sx PF 'E', 357 sx Class 'G', 204 sx PF 'C' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 12 spf 5-1/2", 17#, L-80 6868' MD TVD MD TVD 7262'-7362' 4441 '-4482' 7427'-7572' 4508'-4566' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7707'-7732' 4620'-4630' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See Attachment 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) December 6, 1997I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL iGAs-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. TUBL 7210' 4420' TSBF 7828' 4671' TSBE 7932' 4714' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true an ,d,,correct to the be~ of my knowledge SignedChipAIvord '~¢~~ ~.j~.,~)~' '~~'~' '~ ~/~Title Engineerin~ Supervisor Date C~/ /.~//~ a© MPK-34 96-169 396-223 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1-' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 WELL NAME: MPK-34 26. (10-407) Attachment- Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) 8363'-14660' Gmvelpac, 7188'-7372' Gmvelpac, 7372'-7582' Gmvelpac, 7582'-7737' Amount & Kind of Material Used Freeze protect with 150 bbls diesel Cement plug, 113 bbls 'G' 4200# Carbolite 20/40 behind pipe 20,400# Carbolite 20/40 behind pipe 5000# Carbolite 20/40 behind pipe Performance Enquiry Report Operator BP Exploration Date 03:34, 01 Feb 98 Page 1 The analysis is from - 20:30, 13 Nov 96 - to - 20:30, 13 Nov 96 Programs in Result Table: MPK-34 Drill and Complete Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) MPK-34 Event 20:30, 13 Nov 96 20:30, 13 Nov 96 0 hr 0 min Obtained leak off 14.3 Hole Size MDR 8-1/2 Facility Date/Time 14 Nov 97 15 Nov 97 16 Nov 97 17 Nov 97 18 Nov 97 19 Nov 97 20 Nov 97 21 Nov 97 M Pt K Pad Progress Report Well MPK-34 Page 1 Rig Nabors 4ES Date 31 January 98 12:00-15:00 15:00-15:30 15:30-22:00 22:00-00:00 06:00-08:00 08:00-10:30 10:30-16:00 16:00-18:00 18:00-19:00 19:00-20:00 20:00-02:30 02:30-03:00 03:00-06:00 06:00-10:30 10:30-15:30 15:30-16:30 16:30-18:00 18:00-20:30 20:30-21:30 21:30-02:00 02:00-04:30 04:30-06:00 06:00-14:00 14:00-18:00 18:00-19:30 19:30-21:30 21:30-03:30 03:30-06:00 06:00-09:00 09:00-13:00 13:00-18:00 18:00-22:30 22:30-03:00 03:00-06:00 06:00-09:00 09:00-11:00 11:00-15:30 15:30-18:00 18:00-23:00 23:00-01:00 01:00-03:00 03:00-04:00 04:00-06:00 06:00-11:30 11:30-17:30 17:30-18:00 18:00-19:00 19:00-00:30 00:30-04:00 04:00-06:00 06:00-08:30 08:30-11:30 11:30-16:00 16:00-20:00 Duration 3hr 1/2 hr 6-1/2 hr 2hr 2hr 2-1/2 hr 5-1/2 hr 2hr lhr lhr 6-1/2 hr 1/2 hr 3hr 4-1/2 hr 5hr lhr 1-1/2 hr 2-1/2 hr lhr 4-1/2 hr 2-1/2 hr 1-1/2 hr 8hr 4hr 1-1/2 hr 2hr 6hr 2-1/2 hr 3hr 4hr 5hr 4-1/2 hr 4-1/2 hr 3hr 3hr 2hr 4-1/2 hr 2-1/2 hr 5hr 2hr 2hr lhr 2hr 5-1/2 hr 6hr 1/2 hr lhr 5-1/2 hr 3-1/2 hr 2hr 2-1/2 hr 3hr 4-1/2 hr 4hr Activity Rigged down High pressure lines Held safety meeting Rig moved 100.00 % Rigged up Drillfloor / Derrick Rigged up BOP stack Tested BOP stack Ran Tubing to 0.0 ft (3-1/2in OD) Ran Tubing to 1000.0 ft (3-1/2in OD) Ran Tubing to 2000.0 ft (3-1/2in OD) Circulated at 2000.0 ft Ran Tubing to 8298.0 ft (3-1/2in OD) Monitor pressures Circulated at 8298.0 ft Circulated at 8298.0 ft Circulated at 8298.0 ft Circulated at 8298.0 ft Pulled Tubing in stands to 8298.0 ft Pulled Tubing in stands to 0.0 ft Rigged up Logging/braided cable equipment Conducted electric cable operations Perforated Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Installed Packer assembly Installed Packer assembly Pulled Tubing in stands to 7737.0 ft Pulled Tubing in stands to 7737.0 ft Rigged up Tubing handling equipment Singled in drill pipe to 1200.0 ft Singled in drill pipe to 7592.0 ft Pulled Drillpipe in stands to 0.0 ft Ran Tubing in stands to 600.0 ft Ran Tubing in stands to 7737.0 ft Stung into Permanent packer Gravel pack - 60.000 bbl pumped at 780.0 psi, screen out at 1100.0 psi Gravel pack - 60.000 bbl pumped at 780.0 psi, screen out at 1100.0 psi Pulled Tubing in stands to 7581.0 ft Ran Drillpipe in stands to 7572.0 ft Ran Drillpipe to 7572.0 ft (3-1/2in OD) Ran Drillpipe in stands to 7572.0 ft Laid down 1875.0 ft of 3-1/2in OD drill pipe Laid down 7572.0 ft of 3-1/2in OD drill pipe Ran Tubing to 7405.0 ft (3-1/2in OD) Perforated Perforated from 7427.0 ft to 7572.0 ft Pulled Tubing in stands to 7405.0 ft Ran Tubing in stands to 7540.0 ft Circulated at 7582.0 ft Circulated at 7582.0 ft Pulled Tubing in stands to 7582.0 ft Ran Tubing in stands to 7582.0 ft Pulled Tubing in stands to 7582.0 ft Facility Date/Time 22 Nov 97 23 Nov 97 24 Nov 97 25 Nov 97 M Pt K Pad Progress Report Well MPK-34 Page 2 Rig Nabors 4ES Date 31 January 98 20:00-21:00 21:00-23:00 23:00-01:30 01:30-02:00 02:00-03:30 03:30-06:00 06:00-10:00 10:00-14:00 14:00-18:00 18:00-18:30 18:30-21:00 21:00-23:30 23:30-01:30 01:30-04:00 04:00-05:00 05:00-06:00 06:00-09:30 09:30-13:00 13:00-14:00 14:00-18:00 18:00-21:30 21:30-02:00 02:00-06:00 06:00-07:30 07:30-14:00 14:00-15:30 15:30-17:00 17:00-18:00 18:00-21:00 21:00-01:30 01:30-06:00 06:00-13:00 13:00-15:00 15:00-17:00 17:00-18:00 18:00-19:00 19:00-21:00 Duration lhr 2hr 2-1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 4hr 4hr 4hr 1/2 hr 2-1/2 hr 2-1/2 hr 2hr 2-1/2 hr lhr lhr 3-1/2 hr 3-1/2 hr lhr 4hr 3-1/2 hr 4-1/2 hr 4hr 1-1/2 hr 6-1/2 hr 1-1/2 hr 1-1/2 hr lhr 3hr 4-1/2 hr 4-1/2 hr 7hr 2hr 2hr lhr lhr 2hr Activity Ran Tubing in stands to 0.0 ft Ran Tubing to 0.0 ft (3-1/2in OD) Ran Tubing in stands to 7582.0 ft Set packer at 7372.0 ft with 0.0 psi Set packer at 7372.0 ft with 3000.0 psi Gravel pack - 0.000 bbl pumped at 0.0 psi, screen out at 0.0 psi Gravel pack - 420.000 bbl pumped at 1600.0 psi, screen out at 2000.0 psi Pulled Tubing in stands to 7372.0 ft Ran Tubing to 7372.0 ft (3-1/2in OD) Ran Tubing in stands to 7372.0 fi Pulled Tubing in stands to 0.0 ft Tested All rams Perforated Ran Tubing in stands to 7237.0 ft Perforated from 7262.0 ft to 7362.0 ft Pulled Tubing in stands to 7237.0 ft Pulled Tubing in stands to 7237.0 ft Ran Tubing in stands to 7372.0 ft Circulated at 7372.0 fi Pulled Tubing in stands to 0.0 ft Ran Tubing to 0.0 fi (3-1/2in OD) Ran Tubing in stands to 7188.0 ft Gravel pack - 100.000 bbl pumped at 2000.0 psi, screen out at 2400.0 psi Gravel pack - 100.000 bbl pumped at 2000.0 psi, screen out at 2400.0 psi Laid down 7188.0 fi of Tubing Worked on BOP - Pipe ram Installed Completion string handling equipment Ran Tubing to 0.0 fi (5-1/2in OD) Ran Tubing to 0.0 fi (5-1/2in OD) Ran Tubing to 0.0 fi (5-1/2in OD) Ran Tubing to 2425.0 ft (5-1/2in OD) Ran Tubing to 6749.0 ft (5-1/2in OD) Ran Tubing to 6749.0 ft (5-1/2in OD) Removed BOP stack Installed Tubing on landing string Tested Xmas tree Freeze protect well - 150.000 bbl of Diesel Facility Date/Time 02 Nov 96 03 Nov 96 04 Nov 96 05 Nov 96 06 Nov 96 M Pt K Pad Progress Report Well MPK-34 Rig Page Date 15:31-18:00 18:00-18:30 18:30-20:30 20:30-21:30 21:30-03:30 03:30-06:00 06:00-06:30 06:30-06:45 06:45-12:00 12:00-13:00 13:00-14:00 14:00-14:30 14:30-15:00 15:00-16:00 16:00-18:00 18:00-18:30 18:30-19:30 19:30-21:30 21:30-00:00 00:00-00:15 00:15-06:00 06:00-06:30 06:30-06:45 06:45-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-21:30 21:30-22:30 22:30-23:00 23:00-00:30 00:30-01:00 01:00-05:45 05:45-06:00 06:00-06:30 06:30-06:45 06:45-10:45 10:45-12:00 12:00-13:30 13:30-14:30 14:30-15:15 15:15-15:30 15:30-18:00 18:00-18:30 18:30-03:00 03:00-03:15 03:15-04:15 04:15-06:00 06:00-06:30 06:30-06:45 06:45-07:45 07:45-08:30 08:30-09:30 09:30-11:00 Duration 2-1/4 hr 1/2 hr 2hr lhr 6hr 2-1/2 hr 1/2hr 1/4 hr 5-1/4 hr lhr lhr 1/2 hr 1/2 hr lhr 2hr 1/2 hr lhr 2hr 2-1/2 hr 1/4 hr 5-3/4 hr 1/2 hr 1/4 hr 11-1/4 hr 1/2 hr lhr lhr lhr lhr 1/2 hr 1-1/2 hr 1/2 hr 4-3/4 hr 1/4 hr 1/2 hr 1/4 hr 4hr 1-1/4 hr 1-1/2 hr lhr 3/4 hr 1/4 hr 2-1/2 hr 1/2 hr 8-1/2 hr 1/4hr lhr 1-3/4 hr 1/2 hr 1/4 hr lhr 3/4 hr lhr 1-1/2 hr Activity Rigged down Drillfloor / Derrick Held safety meeting Rig moved 50.00 % Rig waited · Production facilities Rig moved 100.00 % Rigged up Drillfloor / Derrick Held safety meeting Held drill (H2S) Rigged up Divertor Made up BHA no. 1 Repaired Drillstring handling equipment Tested Divertor Held safety meeting Made up BHA no. 1 Drilled cement to 80.0 ft Held safety meeting Drilled cement to 115.0 ft Made up BHA no. 1 Drilled to 390.0 ft Held drill (Spill) Drilled to 1090.0 ft Held safety meeting Held drill (Kick while drilling) Drilled to 1758.0 ft Held safety meeting Drilled to 1947.0 ft Circulated at 1947.0 ft Pulled out of hole to 179.0 ft Serviced Top drive R.I.H. to 1500.0 ft Reamed to 1758.0 ft R.I.H. to 1947.0 ft Drilled to 2457.0 ft Held drill (Fire) Held safety meeting Held drill (Kick while drilling) Drilled to 2998.0 ft Circulated at 2998.0 ft Pulled out of hole to 180.0 ft Serviced Top drive R.I.H. to 2900.0 ft Reamed to 2998.0 ft Drilled to 3189.0 ft Held safety meeting Drilled to 4045.0 ft Held drill (Abandonment) Circulated at 4045.0 ft Pulled out of hole to 1976.0 ft Held safety meeting Held drill (Kick while drilling) Circulated at 1949.0 ft Pulled out of hole to 150.0 ft Serviced Top drive R.I.H. to 4048.0 ft 1 31 January 98 Facility M Pt K Pad Progress Report Well MPK-34 Rig Nabors 411~~-~' Page Date 2 31 January 98 Date/Time 07 Nov 96 08 Nov 96 09 Nov 96 10 Nov 96 11 Nov 96 11:00-18:00 18:00-18:30 18:30-22:30 22:30-00:30 00:30-02:00 02:00-03:45 03:45-04:00 04:00-06:00 06:00-06:30 06:30-06:45 06:45-08:00 08:00-09:00 09:00-10:00 10:00-12:00 12:00-18:00 18:00-18:30 18:30-02:00 02:00-02:15 02:15-06:00 06:00-06:30 06:30-06:45 06:45-10:00 10:00-12:00 12:00-16:00 16:00-17:30 17:30-18:00 18:00-18:30 18:30-19:00 19:00-21:30 21:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-18:45 18:45-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-12:00 12:00-12:30 12:30-13:15 13:15-14:00 14:00-15:00 15:00-18:00 18:00-18:30 18:30-18:45 18:45-20:00 20:00-22:30 22:30-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-18:00 Duration 7hr 1/2 hr 4hr 2hr 1-1/2 hr 1-3/4 hr 1/4 hr 2hr 1/2 hr 1/4 hr 1-1/4 hr lhr lhr 2hr 6hr 1/2hr 7-1/2 hr 1/4 hr 3-3/4 hr 1/2 hr 1/4 hr 3-1/4 hr 2hr 4hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 8-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1/4hr 10-1/4 hr lhr 1/2hr 1-1/2 hr 4hr 1/2 hr 3/4 hr 3/4 hr lhr 3hr 1/2hr 1/4 hr 1-1/4 hr 2-1/2 hr 6-1/2 hr lhr 1/2 hr lhr 1/2hr 10hr Activity Drilled to 4524.0 ft Held safety meeting Drilled to 4997.0 ft Circulated at 4997.0 ft Pulled out of hole to 2525.0 ft Backreamed to 2045.0 ft Held drill (H2S) Pulled BHA Held safety meeting Held drill (Kick while tripping) Made up BHA no. 2 Serviced Block line Serviced Top drive R.I.H. to 4997.0 ft Drilled to 5407.0 ft Held safety meeting Drilled to 5977.0 ft Held drill (Kick while drilling) Drilled to 6164.0 ft Held safety meeting Held drill (Spill) Drilled to 6536.0 ft Circulated at 6536.0 ft Pulled BHA Made up BHA no. 3 Downloaded MWD tool Held safety meeting Serviced Top drive R.I.H. to 6536.0 ft Drilled to 7376.0 ft Held safety meeting Drilled to 7990.0 ft Held safety meeting Held drill (Fire) Drilled to 8481.0 ft Circulated at 8481.0 ft Held safety meeting - Circulated at 8481.0 ft Pulled out of hole to 170.0 ft Pulled out of hole to 0.0 ft Downloaded MWD tool R.I.H. to 1100.0 ft Serviced Top drive R.I.H. to 5000.0 ft Held safety meeting Held drill (Kick while tripping) R.I.H. to 8481.0 ft Circulated at 8481.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Rigged up Casing handling equipment Held safety meeting Ran Casing to 6100.0 ft (9-5/8in OD) Facility Date/Time 12 Nov 96 13 Nov 96 14 Nov 96 15 Nov 96 16 Nov 96 M Pt K Pad Progress Report Well MPK-34 Rig Nabors 18:00-18:30 18:30-18:45 18:45-21:30 21:30-01:00 01:00-02:30 02:30-04:00 04:00-06:00 06:00-06:30 06:30-09:00 09:00-10:00 10:00-10:30 10:30-12:00 12:00-14:00 14:00-15:15 15:15-15:30 15:30-18:45 18:45-19:15 19:15-19:30 19:30-23:30 23:30-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-09:30 09:30-13:30 13:30-14:30 14:30-15:00 15:00-16:30 16:30-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-20:30 20:30-01:00 01:00-02:30 02:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-22:00 22:00-23:00 23:00-23:30 23:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-02:30 02:30-03:30 Duration 1/2 hr 1/4 hr 2-3/4 hr 3-1/2 hr 1-1/2 hr 1-1/2 hr 2hr 1/2 hr 2-1/2 hr lhr 1/2 hr 1-1/2 hr 2hr 1-1/4 hr 1/4 hr 3-1/4 hr 1/2 hr 1/4 hr 4hr 4hr lhr 1-1/2 hr 1/2 hr lhr lhr lhr 4hr lhr 1/2hr 1-1/2 hr 1-1/2 hr 1/2 hr lhr 1/2 hr 1/2 hr 4-1/2 hr 1-1/2 hr 3-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1-1/2 hr lhr lhr lhr 1/2 hr 6-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr lhr lhr 6hr lhr Activity Held safety meeting Held drill (Kick while tripping) Ran Casing to 8461.0 ft (9-5/8in OD) Circulated at 8461.0 ft Mixed and pumped slurry - 479.000 bbl Displaced slurry - 635.000 bbl Circulated at 1997.0 ft Held safety meeting Circulated at 1997.0 ft Mixed and pumped slurry - 300.000 bbl Displaced slurry - 151.000 bbl Cleared Mud shakers Rigged down Divertor Installed Adapter spool Tested Adapter spool Rigged up BOP stack Held safety meeting Held drill (H2S) Tested BOP stack Racked back drill pipe Serviced Top drive Made up BHA no. 4 Held safety meeting Made up BHA no. 4 R.I.H. to 2000.0 ft Drilled installed equipment - Cementing packer R.I.H. to 8376.0 ft Circulated at 8376.0 ft Tested Casing Serviced Block line Held drill (Stripping) Held safety meeting Drilled installed equipment - Float collar Circulated at 8501.0 ft Performed formation integrity test Drilled to 8914.0 ft Functioned downhole tools at 8914.0 ft Drilled to 9192.0 ft Held safety meeting Drilled to 10234.0 ft Held safety meeting Drilled to 10424.0 ft Circulated at 10424.0 ft Pulled out of hole to 8461.0 ft Serviced Top drive R.I.H. to 10424.0 ft Drilled to 11088.0 ft Held safety meeting Drilled to 12250.0 ft Held safety meeting Drilled to 12403.0 ft Repaired M.W.D. tool Drilled to 12972.0 ft Circulated at 12972.0 ft Page Date 3 31 January 98 Facility Date/Time 17 Nov 96 18 Nov 96 19 Nov 96 20 Nov 96 21 Nov 96 M Pt K Pad Progress Report Well MPK-34 Rig Nabors ~ ~ Page Date 03:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-12:00 12:00-13:00 13:00-15:00 15:00-16:00 16:00-18:00 18:00-18:30 18:30-00:00 00:00-00:30 00:30-01:00 01:00-01:30 01:30-06:00 06:00-06:30 06:30-15:00 15:00-17:00 17:00-22:30 22:30-01:00 01:00-01:30 01:30-06:00 06:00-06:30 06:30-07:30 07:30-09:00 09:00-10:00 10:00-14:00 14:00-15:00 15:00-16:00 16:00-17:00 17:00-18:00 18:00-18:30 18:30-19:30 19:30-02:00 02:00-06:00 06:00-06:30 06:30-08:00 08:00-10:00 10:00-15:00 15:00-20:00 20:00-22:00 22:00-02:30 02:30-03:30 03:30-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-11:00 11:00-13:00 13:00-14:00 14:00-22:00 22:00-01:30 01:30-05:30 05:30-06:00 Duration lhr lhr 1/2 hr 1/2 hr 5-1/2 hr lhr 2hr lhr 2hr 1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 8-1/2 hr 2hr 5-1/2 hr 2-1/2 hr 1/2hr 4-1/2 hr 1/2 hr lhr 1-1/2 hr lhr 4hr lhr lhr lhr lhr 1/2 hr lhr 6-1/2 hr 4hr 1/2 hr 1-1/2 hr 2hr 5hr 5hr 2hr 4-1/2 hr lhr 2-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 2hr lhr 8hr 3-1/2 hr 4hr 1/2 hr Activity Pulled out of hole to 11000.0 ft Serviced Top drive R.I.H. to 12972.0 ft Held safety meeting Drilled to 13351.0 ft Tested Mud pumps Pulled out of hole to 11050.0 ft R.I.H. to 13351.0 ft Drilled to 13.0 ft Held safety meeting Drilled to 14006.0 ft Circulated at 14006.0 ft Pulled out of hole to 13350.0 ft R.I.H. to 14006.0 ft Drilled to 14197.0 ft Held safety meeting Drilled to 14660.0 ft Circulated at 14660.0 ft Pulled out of hole to 1100.0 ft Pulled BHA Serviced Drillfloor / Derrick Conducted electric cable operations Held safety meeting Conducted electric cable operations Serviced Block line Serviced Top drive Ran Drillpipe in stands to 14660.0 ft Rigged up Travelling block Circulated at 14660.0 ft Mixed and pumped slurry - 72.000 bbl Pulled Drillpipe in stands to 12800.0 ft Held safety meeting Circulated at 12800.0 ft Laid down 6000.0 ft of Drillpipe Ran Drillpipe in stands to 8380.0 ft Held safety meeting Ran Drillpipe in stands to 8396.0 ft Set Cement retainer at 8396.0 ft with 0.0 psi Pulled Drillpipe in stands to 0.0 ft Ran Drillpipe in stands to 8391.0 ft Set Cement retainer at 8391.0 ft with 0.0 psi Pulled Drillpipe in stands to 0.0 ft Serviced Block line Ran Drillpipe to 4000.0 ft (5in OD) Held safety meeting Ran Drillpipe in stands to 8363.0 ft Set Cement retainer at 8363.0 ft with 0.0 psi Mixed and pumped slurry - 41.000 bbl Circulated at 8270.0 ft Tested Casing Laid down 8300.0 ft of Drillpipe Rigged down BOP stack Installed Xmas tree Fill pits with Water based mud 4 31 January 98 Client: BP Field: MILNE POINT Well Name: MPK-34 Permanent Datum: MSL Depth Measured From: RKB Elevation of Kelly Bushing: Elevation of Drill Floor: Elevation of Ground Level: Magnetic Declination: Grid Convergence: Total Correction: TIE IN POINT Measured Depth: True Vertical Depth: N/S disp (-ve for S) ENV disp (-ve for W) 0.00 FT 0.00 FT 0.00 FT 0.00 FT 28.04 DEG 0.00 DEG 28.04 DEG MEASURED INTERVAL VERTICAL TARGET DEPTH DEPTH SECTION FT FT FT FT 0 0.00 0.00 0.00 112.0 112.00 112.00 0.00 166.3 54.30 166.30 -0.15 223.1 56.80 223.10 -0.49 314.9 91.80 314.90 -0.32 Schlumberger ANADRILL Survey Calculation Report 57.30 FT 57.30 FT 27.80 FT Inclination: 0.00 DEG Azimuth: 0.00 DEG Azimuth from Rotary Table to Target: 117.90 DEG STATION AZIMUTH LATITUDE DEPARTURE INCLN. N/-S E/-W DEG DEG FT FT 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,32 299.60 0,07 -0.13 0.36 287.50 0.21 -0.44 0.79 72.80 0.48 -0.11 380.2 65.30 380.18 0.68 1.47 83.30 0,71 1.15 435.5 55.30 435.46 1.97 1.73 85.60 0.86 2.69 526.7 91.20 526.61 4.42 2.08 78.50 1.29 5.68 617.5 90.80 617.34 7.30 2.32 88.80 1.66 9.13 680.5 63.00 680.28 9.82 2.92 89.60 1.70 12.01 740.5 60.00 740.15 13.41 4.52 830.4 89.90 829.71 20.85 5.49 922.1 91.70 920.78 31.05 7.83 1013.0 90.90 1010.66 44.13 9.36 1108.9 95.90 1105.25 59.00 9.60 DISPLA- atAZIMUTH DLS CEMENT FT DEG D/HF 0.00 0.00 0.00 0.00 0.00 0.00 0.15 299.60 0.59 0,49 295.19 0.14 0,49 347.06 1.20 1.35 58.28 1.08 2.82 72.29 0.48 5.83 77.17 0.46 9.28 79.69 0.51 12.13 81.95 0.95 99.30 1.33 15.88 15.93 85.22 2.86 99.70 0,03 23.61 23.61 89.93 1.08 102,80 -2.09 34.03 34.09 93.52 2.58 101.70 -4.96 47.30 47.56 95.99 1.69 95.30 -7.28 62.90 63.32 96.61 1.13 1205.0 96.10 1199.57 75.29 12.48 86.80 -7.44 81.26 1300.3 95.30 1291.99 94.89 15.70 84.60 -5.66 104.38 1396.1 95.80 1384.20 117.39 15.79 91.40 -4.75 130.32 1491.7 95.60 1476.20 141.19 15.79 97.10 -6.68 156.23 1585.8 94.10 1566.91 164.99 15.11 102.50 -10.92 180.91 1683.1 97.30 1660.41 191.49 17.09 114.30 -19.55 206.33 1777.1 94.00 1749.05 222.64 21.83 125.30 -35.35 233.21 1873.4 96.30 1837.42 260.60 24.94 123.90 -57.02 264.68 1967.7 94.30 1921.95 302.13 27.67 124.50 -80.52 299.23 2063.5 95.80 2006.11 347.70 29.42 122,00 -105.59 337.52 81.60 95.23 3.43 104.53 93.10 3.42 130.40 92.09 1 .'93 156.37 92.45 1.62 181.24 93.45 1.69 207.25 95.41 3.92 235.87 98.62 6.35 270.75 102.16 3.28 309.87 105.06 2.91 353.65 107.37 2.21 Page 1 MEASURED INTERVAL VERTICAL DEPTH DEPTH FT FT FT 2159.2 95.70 2089.12 2254.8 95.60 2170.59 2349.9 95.10 2249.46 2444.6 94.70 2326.04 2541.1 96.50 2402.67 TARGET SECTION FT 395.26 445.27 498.39 554.09 612.74 STATION INCLN. DEG 30.26 32.83 35.09 36.98 37.89 AZIMUTH DEG 118.60 117.50 118.00 117.10 117.00 LATITUDE N/-S FT -129.59 -153.09 -177.83 -203.58 -230.26 DEPARTURE E/-W FT 378.63 422.77 469.78 519.17 571.41 DISPLA- CEMENT FT 400.19 449.63 502.31 557.66 616.06 at AZIMUTH DEG 108.89 109.91 110.73 111.41 111.95 2636.7 95.60 2477.31 672.45 39.45 115.50 -256.67 624.99 675.64 112.33 2732.6 95.90 2550.47 734.39 41.10 115.80 -283.50 680.87 737.54 112.61 2825.1 92.50 2618.86 796.63 43.54 116.30 -310.86 736.82 799.71 112.87 2923.6 98.50 2688.21 866.53 46.94 116.30 -341.84 799.51 869.52 113.15 3017.7 9~10 2751.19 936.41 49.03 115.90 -372.59 862.29 939.34 113.37 3114.1 96.40 2813.81 1009.65 49.95 115.80 -404.55 928.25 1012.57 113.55 3208.0 93.90 2873.38 1082.17 51.29 115.40 -435.91 993.70 1085.11 113.69 3303.6 95.60 2931.46 1158.01 53.88 114.80 -468.11 1062.46 1161.01 113.78 3399.0 95.40 2986.76 1235.66 55.27 115.60 -501.21 1132.80 1238.72 113.87 3494.6 95.60 3039.51 1315.34 57.75 116.60 -536.29 1204.38 1318.39 114.00 3589.1 94.50 3087.98 1396.42 60.52 116.50 -572.54 1276.94 1399.42 114.15 3684.6 95.50 3132.88 1480.69 63.39 3779.1 94.50 3172.86 1566.31 66.55 3875.5 96.40 3208.67 1655.79 69.82 3966.6 91.10 3239.65 1741.46 70.43 4067.3 100.70- 3274.11 1836.07 69.54 -611.08 -651.27 -693.07 -732.43 -775.83 -816.67 -858.77 -900.97 -944.23 -987.34 4161.4 94.10 3307.04 1924.22 69.49 4257.6 96.20 3339.46 2014.79 71.12 4352.3 94.70 3370.09 2104.40 71.14 4448.2 95.90 3402.58 2194.61 69.25 4544.0 95.80 3438.23 2283.51 67.06 117.90 118.10 117.60 117.10 117.50 117.70 117.70 118.50 118.80 119.20 4638.9 94.90 3475.02 2370.96 67.32 119.60 -1030.28 4734.2 95.30 3511.25 2459.08 67.99 119.10 -1073.48 4828.9 94.70 3547.27 2546.62 67.30 120.00 -1116.67 4923.1 94.20 3582.69 2633.83 68.52 120.50 -1160.65 5019.2 96.10 3616.87 2723.48 69.82 122.10 -1207.31 5115.2 96.00 3648.14 2814.05 72.15 121.20 -1254.93 5209.8 94.60 3676.18 2904.30 73.37 119.80 -1300.78 5305.7 95.90 3703.53 2996.20 73.50 117.50 -1344.85 5399.5 93.80 3731.65 3085.66 71.60 116.00 -1385.12 5495.3 95.80 3764.85 3175.44 67.85 115.40 -1424.09 115.80 117.00 116.90 117.20 116.60 1351.89 1427.48 1506.60 1582.70 1666.78 1744.89 1825.08 1904.13 1983.31 2061.08 2137.29 2214.12 2290.31 2365.71 2442.44 2519.70 2597.55 2678.21 2758.11 2839.06 2918.28 2995.88 3074.12 3151.75 3228.80 5591.1 95.80 3803.07 3263.20 65.11 5686.2 95.10 3842.28 3349.81 66.19 5781.7 95.50 3879.90 3437.58 67.42 5875.5 93.80 3914.55 3524.73 69.22 5967.7 92.20 3946.74 3611.11 69.91 1483.58 1569.03 1658.37 1743.96 1838,49 1926.55 2017.03 2106.53 2196.61 2285.36 2372.65 2460.63 2548.03 2635.08 2724.54 2814.92 2905.04 2996.90 3086.38 3176.21 3264.03 3350.67 3438.44 3525.60 3612.00 -1462.04 -1500.57 -1540.35 -1579.99 -1619.08 114.32 114.52 114.70 114.83 114.96 115.08 115.20 115.32 115.46 115.60 115.74 115.87 115.99 116.13 116.30 116.48 116.60 116.66 116.67 116.64 116.61 116.61 116.61 116.62 116.63 DLS D/HF 1.97 2.75 2.39 2.07 0.95 1.90 1.73 2.66 3.45 2.24 0.96 1.46 2.75 1.61 2.74 2.93 3.27 3.35 3.43 0.85 0.96 0.21 1.69 0.80 1.99 2.'32 0.48 0.85 1.14 1.39 2.06 2.58 1.91 2.30 2.54 3.96 2.89 1.62 1.29 1.94 0.97 Page 2 MEASURED DEPTH FT 6062.2 6157.1 6246.5 6339.2 6435.0 6527.7 6623.2 6716.3 6809.7 6905.7 7001.8 7094.9 7189.6 7283.8 7378.1 7474.3 7568.4 7664.4 7759.7 7854.3 7948.4 8043.6 8138.9 8233.9 8327.9 8392.1 8539.4 8630.8 8726.3 8819.2 8912.1 9004.0 9098.6 9194.3 9287.5 9381.6 9475.7 9569.3 9668.7 9760.1 INTERVAL FT 94.50 94.90 89.40 92.70 95.80 92.70 95.50 93.10 93.40 96.00 96.10 93.10 94.70 94.20 94.30 96.20 94.10 96.00 95.30 94.60 94.10 95.20 95.30 95.00 94.00 64.20 147.30 91.40 95.50 92.90 92.90 91.90 94.60 95.70 93.20 94.10 94.10 93.60 99.40 91.40 VERTICAL DEPTH FT 3982.11 4022.43 4061.95 4101.73 4140.79 4176.56 4211.46 4244.19 4276.18 4308.42 4341.68 4375.73 4411.97 4449.83 4488.35 4527.04 4564:20 4602.39 4641.98 4681.93 4720.80 4759.57 4797.97 4834.62 4868.63 4890.88 4941.21 4972.96 5007.27 5041.68 5076.58 5110.76 5145.43 5180.52 5214.52 5248.35 5282.11 5315.79 5351.59 5384.61 TARGET SECTION FT 3698.71 3784.60 3864.79 3948.52 4035.99 4121.51 4210.40 4297.56 4385.30 4475.71 4565.87 4652.50 4739.98 4826.19 4912.22 5000.27 5086.71 5174.78 5261.42 5347.14 5432.83 5519.78 5607.00 5694.63 5782.25 5842.47 5980.88 6066.56 6155.63 6241.79 6327.75 6412.98 6500.95 6589.94 6676.71 6764.49 6852.31 6939.61 7032.33 7117.55 STATION INCLN. DEG 66.12 63.59 63.94 65.23 66.65 67.96 69.16 69.68 70.26 70.49 69.02 68.08 66.92 65.68 66.10 66.47 67.01 66.11 64.79 65.25 65.96 65.97 66.51 68.11 69.46 69.99 70.05 69.30 68.59 67.94 67.92 68.41 68.60 68.38 68.83 69.04 68.91 68.90 68.89 68.75 AZIMUTH DEG 116.90 117.80 118.00 117.80 118.00 118.70 118.10 118.00 119.10 118.40 116.60 117.40 116.30 116.00 116.30 116.70 117.30 116.40 116.10 116.80 117.60 118.40 118.30 119.20 118.40 117.80 116.00 117.00 115.10 114.60 114.70 116.40 115.70 116.40 119.30 119.30 119.00 119.40 118.20 118.70 LATITUDE NAS FT -1658.51 -1697.96 -1735.49 -1774.67 -1815.60 -1856.21 -1898.49 -1939.47 -1981.41 -2O24.90 -2066.54 -2105.87 -2145.39 -2183.41 -2221.34 -2260.64 -2299.89 -2339.67 -2378.01 -2416.21 -2455.38 -2496.20 -2537.62 -2579.78 -2621.99 -2650.35 -2712.98 -2751.22 -2790.29 -2826.49 -2862.40 -2899.19 -2937.84 -2976.94 -3017.48 -3060.45 -3103.24 -3145.84 -3190.51 -3231.11 DEPARTURE E/-W FT 3307.03 3383.33 3454.20 3528.20 3605.51 3680.77 3758.96 3835.88 3912.96 3992.23 4072.20 4149.41 4227.46 4304.89 4382.15 4460.97 4538.00 4616.58 4694.32 4771.09 4847.31 4924.08 5000.84 5O77.68 5154.47 5207.59 5331.04 5407.74 5487.84 5566.18 5644.42 5721.38 5800.46 5880.45 5957.17 6033.74 6110.45 6186.68 6267.94 6342.88 DISPLA- CEMENT FT 3699.61 3785.50 3865.67 3949.38 4036.84 4122.33 4211.18 4298.32 4386.03 4476.40 4566.55 4653.20 4740.69 4826.94 4913.00 5001.08 5087.53 5175.60 5262.28 5348.03 5433.72 5520.65 5607.84 5695.44 5783.02 5843.23 5981.66 6067.37 6156.47 6242.71 6328.73 6414.01 6502.02 6591.05 6677.80 6765.53 6853.30 6940.56 7033.24 7118.44 at AZIMUTH DEG 116.63 116.65 116.68 116.70 116.73 116.76 116.80 116.82 116.86 116.89 116.91 116.91 116.91 116.89 116.88 116.87 116.88 116.88 116.87 116.86 116.86 116.88 116.90 116.93 116.96 116.97 116.97 116.96 116.95 116.92 116.89 116.87 116.86 116.85 116.86 116.90 116.92 116.95 116.98 1t6.99 DLS D/HF 4.02 2.80 0.44 1.41 1.49 1.58 1.39 0.57 1.27 0.73 2.33 1.29 1.63 1.35 0.53 0.54 0.82 1.27 1.41 0.83 1.08 0.77 0.57 1.90 1.64 1.20 1.15 1.31 2.09 0.81 0.10 1.80 0.72 0.72 2.94 0.22 0.33 · 0.40 1.13 0.53 Page 3 MEASURED DEPTH FT 9854.2 9948,3 10043.3 10139.3 10234.1 10331.1 10425.4 10518.7 10611.3 10707.7 10803.3 10899.8 10995.2 11087.8 11182.9 11275.5 11367.2 11462.0 11557.4 11651.9 11748.2 11843.2 11937.2 12029,8 12124.6 12221.3 12311.8 12408.5 12502.3 12597,3 12693.8 12786.0 12880.1 12974.3 13070.3 13162,4 13259.0 13352,2 13446.3 13541.4 INTERVAL FT 94.10 94.10 95.00 96.00 94.80 97.00 94.30 93.30 92.60 96.40 95.60 96.50 95.40 92.60 95.10 92.60 91.70 94.80 95.40 94.50 96.30 95.00 94,00 92.60 94,80 96.70 90.50 96.70 93.80 95.00 96.50 92.20 94.10 94.20 96.00 92.10 96.60 93.20 94.10 95.10 VERTICAL DEPTH FT 5418.87 5452.96 5486.86 5520.99 5554.91 5590.22 5624.83 5659.00 5693.12 5729.05 5764.79 5800.75 5836.41 5870.90 5905.79 5939.84 5974.45 6010.37 6045.86 6080.63 6116.38 6152.21 6187.59 6222.00 6256.63 6291.81 6325.40 6361.38 6396.16 6431.58 6467.32 6501.55 6537.28 6573.01 6608.80 6643.07 6678.99 6713.72 6748.70 6784.01 TARGET SECTION FT 7205.19 7292.88 7381.62 7471.35 7559.87 7650.21 7737.92 7824.73 7910.81 8000.26 8088.93 8178.48 8266.95 8352.85 8441.29 8527.38 8612.28 8699.98 8788.50 8876.34 8965.73 9053.68 9140.75 9226.69 9314.92 9404.99 9489.01 9578.75 9665.86 9753.99 9843,58 9929.18 10016.23 10103.39 1O192.47 10277.96 10367.63 10454,11 10541.47 10629.77 STATION INCLN. DEG 68.55 68.97 69.21 69.14 68.93 68.38 68.56 68.47 68.29 67.94 68.15 68.10 68.00 68.26 68.70 68.15 67.50 67.97 68.35 68.47 67.95 67.73 68.06 68.30 68.86 68.47 67.95 68.36 68.12 68.10 68.42 68.00 67.36 68.06 68.17 68.14 68.20 68.04 68.32 68.08 AZIMUTH DEG 118.70 118.70 118.30 117.70 117.20 118.60 119.20 118.60 118.20 118.10 117.90 118.50 119.30 119.70 119.20 118.50 119.70 119.20 119.60 119.50 119.10 119.50 119.20 119.30 118,80 118.20 119,10 118.90 118.50 119.80 119.40 118.40 118.00 118.00 117.50 117.30 118.10 118,20 118.40 118,10 LATITUDE NAS FT -3273.20 -3315.32 -3357.67 -3399.79 -3440.60 -3482.87 ~3525.26 -3567.22 -3608.16 -3650.37 -3691.99 -3734.31 -3777.07 -3819.39 -3862.89 -3904.44 -3945,73 -3988.87 -4032.34 -4075.67 -4119.43 -4162,49 -4205,18 .-14247,18 -4290,03 -4333.01 -4373.30 -4416,82 -4458.65 -4501.59 -4545.86 -4587.24 -4628.37 -4669.29 -4710.77 -4750.11 -4791.80 -4832.60 -4874.01 -4915.81 DEPARTURE F_/-W FT 6419.75 6496.69 6574.67 6653.90 6732.46 6812.30 6889.10 6965.10 7040.82 7119.70 7197.98 7276.91 7354.37 7429.17 7506.20 7581.63 7655.82 7732.22 7809.37 7885.81 7963.79 8040.51 8116.43 8191.43 8268.58 8347.74 8421.48 8499.98 8576.40 8653,38 8731.32 8806.27 8882.98 8959.94 9038.78 9114.67 9194.07 9270,33 9347.24 9425.02 DISPLA- CEMENT FT 7206.04 7293.71 7382.43 7472.15 7560.67 7651,00 7738.68 7825,45 7911.51 8000.95 8089.61 8179,15 8267.59 8353.46 8441.86 8527.94 8612.81 8700.48 8788.97 8876.77 8966.14 9054.07 9141.11 9227.03 9315.25 9405.30 9489.32 9579.04 9666.13 9754.25 9843.82 9929.41 10016.45 10103.61 10192.69 10278,17 10367,85 10454,33 10541.68 10629,97 at AZIMUTH DEG 117.02 117.04 117.05 117.06 117.07 117,08 117.10 117,12 117.13 117.14 117.15 117.17 117.18 117.21 117.23 117.25 117.27 117.29 117.31 117.33 117.35 117.37 117.39 117.41 117,42 117.43 117.44 117.46 117.47 117,48 117.50 117.52 117.52 117.53 117.53 117.53 117.53 117,53 117.54 1t7.55 DLS D/HF 0.21 0.45 0.47 0.59 0.54 1.46 0.62 0.61 0.45 0..38 0.29 0.58 0.78 0.49 0.67 0.92 1,40 0.70 0.56 0.16 0.66 0.45 0.46 0.28 0,77 0.70 1.09 0.47 0.47 1.27 0,51 1.11 0.79 0.74 0.50 0.20 0.77 0.20 0.36 0.39 Page 4 MEASURED INTERVAL VERTICAL DEPTH DEPTH FT FT FT 13637,9 96.50 6820.03 13728.5 90.60 6853.69 13821.5 93.00 6887.88 13915.9 94.40 6922.53 14009.6 93.70 6957.35 TARGET SECTION FT 10719.29 10803.41 10889.89 10977.70 11064.69 14103.7 94.10 6992.98 11151.78 14199.1 95.40 7030.02 11239.69 14293.5 94.40 7067.44 11326.35 14388.6 95.10 7105.42 11413.54 14483.0 94.40 7142.65 11500.29 14570.2 87.20 7175.90 11580.90 Survey Projected to TD 14660.20 90.00 7209.58 11664.36 STATION INCLN. DEG 68.09 68.30 68.55 68.39 67.98 67.52 66.78 66.52 66.40 67.15 68.02 68.02 AZIMUTH DEG 117.60 118.30 117.30 118.00 117.20 117.40 117.60 117.20 118.20 118.10 117.90 117.90 LATITUDE N/-S FT -4957.63 -4997.06 -5037.39 -5078.14 -5118,44 -5158,39 -5198.98 -5238.87 -5279.39 -5320.32 -5358.16 -5397.22 DEPARTURE E/-W FT 9504.18 9578.49 9654.99 9732.77 9809.86 9887.25 9965.23 10042.18 10119.37 10195.86 10267.04 10340.79 DISPLA- CEMENT FT 10719.50 10803.61 10890.09 10977.90 11064.89 11151.99 11239.90 11326.57 11413.75 11500.49 11581.10 11664.56 at AZIMUTH DEG 117.55 117.55 117.55 117.55 117.55 117.55 117.55 117.55 117.55 117.56 117.56 117.56 DLS D/HF 0.48 0.75 1.04 0.71 0.91 0.53 0.80 0.48 0.97 0.80 1.02 0.00 Page 5 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11734 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 · , Field: Milne Point (Cased Hole) 1/21/98 Well Job # Log Description Date BL RF Sepia LIS Tape MPB-25 PERFORATION RECORD 9 8 01 01 1 1 MPU C-15 INJECTION PROFILE 971 1 24 1 1 ,, MPG-11 STATIC PRESSURE SURVEY 9 71 2 2 3 I 1 ..... MPG-11 PERFORATION RECORD 9 71 2 2 3 I 1 MPG-11 PERFORATION RECORD 9 71 2 2 9 I 1 MPG-12 PERFORATING RECORD 9 8 01 10 I 1 MPG-12 ~ERFORATING RECORD 9 8 01 1 3 I 1 ,, MPG-12 3ERFORATING RECORD 9 8 01 16 I 1 ,, MPJ-17 RFT 971 1 1 6 I 1 MPJ-17 ~ERF RECORD 971 1 19 I 1 , MPJ-17 CHEMICAL CUT RECORD 971 1 19 I 1 MPK-34 PERFORATION RECORD 971 1 1 7 I 1 MPK-34 SUMP PACKER SET RECORD 9 71 1 17 I I ,, MPL-35 :TCP GR TIE IN W/PRESS-TEMP 971207 I I . .,, ,, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) December 12, 1996 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the LWD Depth Corrected CDR/ADN, CDR/ADN-TVD for well MPK-34, Job # 96377 was sent to: BP Exploration (Alaska)Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 1 OH LIS Tape 3 Bluelines 1 Film :i. Depth Shier State of Alaska' I OH LIS Tape Alaska Oil & Gas Conservation 1 Bluelines Attn: Lori Taylor I RFolded Sepia 3001 Porcupine Drive Anchorage, AK 99501 OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 1 OH LIS Tape 1 Bluelines 1 RFolded Sepia Sent Certified Mail Z 777 937 511 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska ~5,~,9~~V~ Date Delivered' Fr, 1996 Oil & Co s. c mmi. ion Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received / GeoQuest 500 W. International Airport Fload Anchorage, AK 99518-1199 ATTN: Sherrie NO., 10582 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 11/19~96 Well Job # Log Description Date BL RF Sepia LIS Tape MPU E-05 INJECTION PROFILE LOG 9 61 1 1 0 1 1 MP K-34 CEMENT BOND LOG 9 61 I 1 8 1 1 ~,, .__ ___ __. __. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. Irfternational Airport Road Anchorage, Alaska 99618-1199 ~ ~- STATE OF ALAS~ '~' ALAS~ ,LAND GAS CONSERVATION CO~, .....SSION APPLICATION FOR SUNDRY APPROVAL 1, T~e of Request', ~ Abandon ~ Suspend ~ ~[~i'~g ~ Time E~ension ~ Pe~o~e Altar C~ing ~ Repair Well ~ Pull Tubing ~ VaCate ~ Other ~ ~hangs Approved Program ~ ~emti0n 8hutdo~ ~ Re. Enter Suspended Well ~ Stimulate Chang~ m Wemr Sour~Well 2. Name of Operator BP Exploration (Alaska) Ino, 3. Address P.O. Box lg6612, Anchorage, Alaska 99519-6612 4, Location of well at surface 3577' NSL, lg54' WEL, SEC. 3, T12N, R11E At top of productive interval N/A At effective depth 1819' SNL, 3109' EWL, SEC. 12, T12N, RllE At total depth 1819' SNL, 3t09' EWL, SEC. 13, T12N, R11E Type of well: [] Development [] Exploratory [] Stratigraphic [] Service Datum Elevation (DF or KB) Plan RTE = 57.3' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-34 9. PermE Number 96.169 lO. API Number $0-029-22712 11, Field and Pool Milne Point Unit / 8ohrader Bluff 12. Present well condition summary Total depth: measured 14660 feet Plugs (measured) true vertical 7175 feet Effective depth: measured 14660 feet Junk (measured) true veni.cal 7175 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arctic Set I (Approx.) 11 Surface 8429' 9-5/6" 174o ~x PF 'E', ~.57 sx 'G', 204 sx PF 'C' 8461' 4875' Intermediate Produotion Liner Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A ORIGINAL 13. Attachments [] Description summary cf proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation 15, Status of well classifications as: November 18, 1996 16. If proposal was verbally approved ~ Oil [] Ga~ [] Suspended Blair Wondzell 11/17/96 Service Water Supply for Injection Name of ap_[3rover .__~_D_ate approved Contact Engineer N~me/Number; James Roben~on, 584.5159 Prepared By Name/Number: Kathy Campoamor, 17. I hereby certify that the f_or.[.~g~.g.~,s tT a~nd ~o]~-'ct to the best of my knowledge Signed .~ - 10 ~ ~ Title Senior Drilling Engineer Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug'.integrity /~//' BOP Test ~ Location clearance Mechanical Integrity Test :~pp__roved by order of the Commission Form 10.403 Rev. 06/15/88 0ri{~h~l~~'~m;required lo-~ ~ 7 David W, Johns'ior, Commi~ioner~ Approved Copy Returned NOV 1 9 1996 Alaska 011 & Gas Cons. Commission Anchorage ~ilna Pt, Well~ ~ K-a4 wa~ drilled by NABOR9 RIG~ 22E to ~ depth of 14,660' LWD Iog~ rew~lad th~ w~ll ~a "W~T". Therefore the KUPARUK 9ANDS are to be ~b~ndon~d by ~l~cing ~ c~nt ~lug from TD te 500 teat ~bove the top hydro~rbon bearing ~na ~t 14,400' md, A 9-5/8" 4o¢ ~zsv will then b~ pl~c~d no I~ th~n ~0 feet and no greater th~n 100 t~l ~bow lh~ ~-~/8" o~ing ~hoe, The 9-~/8" wellbore will tken be uaed aa an Ugnu and 8ohrad~r Bluff sour~ w~t~r production well. 9-5/8", 40#, L-80, BTC casing was set at 8,461' md/±4,900' TVD during the drilling of MP K~34. Verbal approval was obtained from B. Wondzell with AOGCC in a phone conversation with J. E. Robertson on BPXA Shared Services Drilling on or about 17NOV96 at ±2215 hrs to abandon the KUPARUK SANDS and set the EZSV as outlined below. PU 5" muleshoe. RIH to TD at 14,660' md. Circulate and condltlon weltbore, Spot a 70 bbl balanced cement plug. Slowly pull 20 stands above the calculated top of the cement plug. CBU. POOH. NOTE: Calculated Top Of Cement is 13,900' md which is SOO feet above highest hydrocarbon bearing sand at 14,400' md, NOTE: Volume based on 8-1/2" hole from TD to .500' above KUPARUK 'C' SAND .t, 30%. PREMIUM G + 0.40% HALAD 344 , 0.20% CFR3 + HR$ AS NECESSARY WT: 15.8 PPG. YIELD: 1.15 FT3/$K , PU 9-5/8", 40# EZSV, RIH and set same at ±8,386' md. pump 14 bbl cement down through the ezsv. Unsting and leave 4 bbl on top of EZSV. NO'F~ 9-5/8" shoe is at 8,451' md. Volume below EZSV based on 20' of 12-1/4" open hole + 30% +80' of 8-1/2" hole 30% 4. 75 ft ineide g-5/8", 40# casing. PREMIUM G * ,2% CFR-3 WT: 15,8 PPG YIELD: 1.15 FT31$K . Displace well with seawater and enough diesel to cover from the base of permafrost to surface. 4, Test casing to 3500 psig. 5. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. INAL RECEIVED NOV 1 9 1996 Alaska 011 & Gas Cons. Comrnissio, Anchorage TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 16, 1996 Steve Shultz Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPK-34 BP Exploration (Alaska) Inc. Permit No: 96-169 Sur. Loc. 357TNSL, 1954'WEL, Sec. 3, T12N, R11E, UM Btmhole Loc. 3399~NSL, 2045'WEL, Sec. 12, T12N, R11E, UM Dear Mr. Schultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. . Chairman- "x~~~ BY ORDER OF THE COMMISSION dlf/Enclosures CCi Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA ~JIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil ila' Type°fw°rk r-IRe-Entry I-IDeepenI r-IService I-I Development Gas I-ISingle Zone []Multiple Zone !2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 57.3' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 375132 14. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3577' NSL, 1954' WEL, SEC. 3, T12N, R11E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 3592' NSL, 2409' WEL, SEC. 12, T12N, R11E MPK-34 At total depth 9. Approximate spud date Amount $200,000.00 3399' NSL, 2045' WEL, SEC. 12, T12N, RllE 10/14/96 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028254, 2045'I No Close Approach 2560 14817' MD / 7267' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 300' Maximum Hole Angle 68.2 o Maximum surface 2983" psig, At total depth (TVD) 7102' / 3693 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' i250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btm 4799' 31' 31' 4830' 3557' 2437sxPF'E', 1087sx'G', 150sxPF'E' 8-1/2" 7" 26# L-80 Btrc 14787' 30' 30' 14817' 7267' 470 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: true measured vertical feet feet Plugs(measured) ORIGINAL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner O'~T. I 0 ~'"~. Perforation depth: measured Al-ask.:: Oil & C-.-~s '~ .... true vertical '-"'~': :~': c...;.~ 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Roberfson, 564-5159 Prepared By Name/Number: Kathy Campoamor, 564-5122 the fq.regoing isSUe and correct to the best of my knowledge l.,here ce,i ,hat SignedSteveShultz Title Senior Drilling Engineer Date ~'~ -- - ~Commission Use Only /' / Permit Number I APl Number I Approval Date I See cover letter ,~-'"....//~--- ? 50- ~ ~--,~' --- ~--- ~ ~/" ~ / ~ .--//~, --'~,~, for other requirements Conditions of Approval: Samples Required [] Yes. ~ No Mud Log Required [] Yes ,,~ No Sulfide Measures_/~__e_ses [] No Directional Survey Required __--~Yes [] No Hydrogen Required Working Pressure for BOPE [] 2M; []3M; [~ 5M; [] 10M; [] 15M Other: ,Jr(giflal ~l~!~u ~ ~ by order of Approved By D~,vid W. Johnston commissioner the commission Date//~""'//~ -"~'~ Form 10-401 Rev. 12-01-85 Submit In Triplicate .. · MP K-34 Well '~//~/~"'"' ]'/~ ~.,~ 7" PRODUCTION CASING ~~.~ OEMENT PROGRAM- HALLIBURTON I (DEEPSET SURFACE CASING) S.'['.AGE, CEMENT JOB A_C_!~O$~LT_HE_KUI=ARU K &_.SC HR _ADER BLUFF I NTEF~VA_L: P.1 CIRC. TEMP: 115° F BHST 170° F at 7040' TVDSS. SPACER: 50 bbls fresh water 70 bbls Alpha Spacer mixed as per Halliburton specifi;ations weighted to 1,0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 30 LB/SACK SILICATE, 1.25% Halad 344 WEIGHT; 15,8ppg YIELD: 2.81 cu ft/sk MIX WATER: 16.0 gal/ak APPROX # SACKS: 469 8ACKS THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 45(~c/30 rain @ 140° FREE WATER; Oct @ 4~ degree angle. CENTRALIZER I~LACEMENT: . 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 22 joints of 7" casing (44). This will cover J:300' above 1he KUPARUK Sand, Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: , Stage 1 cement volume is calculated to cover 500 FT MD above the Schrader Bluff Sand with 30% excess, RECEIVED OCT ] 6 ]996 ~aska 0Il & 13as Cons. Commission Anchorage OCT i6 '96 ii:50AM SHA~ED SERVICES D~ILLIMG P.2 MILNE POINT WELL~.K-34: 7", 26#, L-80, LONGSTR'"G CASING HOLE $,...: (IN) 8,50 TD (FT IdD)~ FREEZE PROTECT DIESEL (BBL): ~ CASING OD (IN) 7,000 CASINO tD (IN): 6,276 TOP OF KUPARUK SANDS (F-I' MD) TOP OF SCHRADER BLUFF SANDS (IrT MD)~ LENGTH OF SHOE JOINTS (FT)i" ---lllll i ID OF SHOE JOINTS (IN) VOLUME OF SHOE JOINTS (BBL) 14,225 7,419~ II. ~..-2.m m.~ 80.00[ 6.276 3.06 8-1/2" X 7" ANN VOLUME (GAUGE) (BBL/FT) 0.0226 8-1/2" X 7" VOLUME (+30%) (BBL/FT) ?" x 8.1/4" Btraight Blade TURBOLATOI~S REQUIRED: (2/JT_F/$J TO 300' ABOVE 'C' SAND +2 IN 9-5/8".. SHOE,! 0.0294 TAIL SLURRY TAIL SLURRY YIELD (FT3/SACK) #SACKS TAIL SLURRY IN ANNULUS (+30%) #SACKS LEAD SLURRY IN SHOE JOINTS TOTAL SACKS TAIL REQUIRED FOR JOB ANNULAR VOLUME LEAD SLURRY + 30% (BBL) VOLUME OF SHOE JOINTS (BBL) TOTAL VOLUME TAIL SLURRY (BBL) .' 2.81 463,34 6,12 469.46 231,88 3,06 234.94 WATER REQUIREMENT F/TAIL (GAL/SACK) TOTAL WATER REQUIRED F/TAIL (BBL) HEIGHT OF LEAD BEHIND PIPE ~ 30% EXCESS (FT) ..... . .... -- ........ ,, ESTIMATED TOP OF TAIL CEMENT BEHIND PIPE (FT.M_p),. 16,00 178.84 7,898 6,919 TOTAL WATER REQUIRED FOR 7" WATER FOR SPACER (BBL) WATER AHEAD (BBL)L' WATER FOR TAIL CEMENT (BBL) WATER BEHIND (BBL)I______:~_,_' 58.33 178.84 i'0,00 TOTAL WATER REQUIRED (_B..BL): 2 6 7.1 7 I SPACER REQUIRED (BBL) TOTAL CEMENT TO BE PUMPED (BBL): WATER AHEAD + WATER BEHIND (BBL): ESTIMATED FREEZE PROTECTION DIESEL (BBL); ESTIMATED DISPLACEMENT SEAWATER (BBL): RETURNS EXPECTED DURING JOB (BBL): 70.00 234,94 30.00 80.00 483.83 898.77 RECEIVED OCT I ~ 1996 Alaska Oil & Gas Cons. Commission Anchorage Shared Services Drilling Contact: James E. Robertson I Well Name: IMP K-34 Well Plan Summary 564-5159 IType of Well (producer or injector)' IKuparuk Producer Surface Location: 3577 NSL 1954 WEL Sec 03 T12N R11E UM., AK Target Location: 3592 NSL 2409 WEL Sec 12 T12N RllE UM., AK Bottom Hole Location: 3399 NSL 2045 WELSec12T12N R11E UM.,AK IAFE Number: 1337049 I IEstimated StartDate- 114 OCT 961 I Rig: INabors 22-E IOperating days to complete' 14 Well Design (conventional, slimhole, etc.): IMilne Point Ultra Slimhole Longstring 9- 5/8", 40# Surface X 7", 26# Longstrincj Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1,844 1,807 Top Schrader Bluff 7,419 4,51 9 Top of Schrader Bluff Sands (8.3 ppg) Seabee Shale 8,003 4,736 Base of Schrader Bluff Sands (8.3 ppg) HRZ 13,363 6,727 High Resistivity Zone Top Kuparuk 1 4,077 6,992 Kuparuk Cap Rock Target (Kuparuk 14,373 7,102 Kuparuk 'C' Sand (10.0 ppg) 'C1' Sand) TOP 'B7' SAND 14,534 7,162 Kuparuk B7 (10.0 ppg) Planned TD 14,817 7,267 TD dependent on logs Potential TD 15,316 7,395 If C1 and B7 sands oil bearing, will require sufficient CDR tool coverage ov A sands to determine if they are oil bearing. uas,n~l/, uD,n~l Pro,( ram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tb!] O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btrc 4799 31/31 4830/3557 12 1/4" 9-5/8" 40# L-80 btrc 8122 31/31 8153/4792 Potential if hydrates not a problem. 8- 1/2" 7" 2 6 # L-80 btrc 14787 30/30 1481 7/7267 Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at +7102 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3693 psi is 2983 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface MWD Directional surface to TD. Intermediate N/A Final Cased Hole Loss: MWD Directional and LWD (GR/CDR/CDN). N/A Mudloggers are NOT required for this well. Mud Program: ISpecial design INone-SPUDMUD considerations Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 100 15 8 10 9 8 to to to to to to to 11.0 50 35 1 5 30 1 0 1 5 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 1 0 3 7 8.5 6 - 8 to to to to to to to 11.0 50 1 5 1 0 20 9.5 4- 5 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1300' I68.20 (No Shut Ins) Maximum Hole Angle: Close Approach Well: Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. 1. The base of the Permafrost for all wells located in the Milne Point Unit is _+1,850' TVD. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AQGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 2. There are _+5 wells on Milne Pt. 'K' Pad. There may be additional unidentified wells within one quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 3. The wastes to be disposed of during drilling operations can be defined as "DRILLING WASTES". 4. The cement design for this well ensures that annular pumping into hydrocarbon zones will not OCCUr. MP K-34 Proposed Summary of Operations , , , . , , . , , 10. 11. 12. 13. 14. 15. 16. Drill and Set 20" Conductor. Weld a starting head on conductor as well as a nipple to aid in performing potential wellhead stability cement job. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD from surface to 12-1/4" TD. Run and cement 9-5/8" casing. ND 20" Diverter, NU and Test 13-5/8" BOP MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 20' of new formation. Perform LOT. Drill 8.5" hole to TD as per directional plan. Run and Cement 7" Casing. Displace cement with seawater and enough diesel to cover from the base of permafrost to surface. Test casing to 3000 psig. ND BOPE, NU and Test Tree. RDMO Nabors 22E. Perforate and Stimulate in absence of rig. Displace well with appropriate weight brine and set a wireline retrievable bridge plug. MIRU a completion rig. NU & Test BOPE to 5000 psig. Complete well with 2-7/8" tubing. Install Surface Lines and Wellhouse and put the well on production. DRILLING HAZARDS AND RISKS: Seethe updated Milne Point K-Pad Data Sheet prepared by Pete Van Dusen for information on K pad and review recent wells drilled on F Pad. Most of the trouble time on recent wells has been due to equipment mechanical problems with the surface equipment, rather than formation drilling problems. Hydrates: We will have hydrates on K Pad. Use the coldest mix water available to minimize warming of the interval and thereby breakout of the hydrtes. Use 7-3/4" mud motors to allow lower flow rates and therefore a cooler mud system. Control flow rates to below 600 GPM when hydrates are present to again keep mud temperatures to a minimum. Minimize circulation times. The addition of lecithin to the mud system in surface is expected to minimize destabilization of the hydrates. Close Approach: There are no close approaches associated with the drilling of MP K-34. Casing Design: The well is designed for shallow set surface casing (above the Schrader Bluff Sands) for planning purposes only. If the surface hole on MP K-34 can be drilled without excessive mudweights through the Schrader Bluff Sands prudence dictates a deep set surface casing design to be implemented. However, if it is necessary to weight up to 11.0 ppg above the Schrader Bluff Sands in order to manage hydrates then casing will be set above the Schrader Bluff at 3500' TVD SS. Lost Circulation: The Kuparuk sands and a number of shallower intervals typically are highly fractured. Be prepared to treat these losses while drilling initially with LCM treatments. This will become even more prevalent in the production hole when we shallow set surface casing. Weighting up before entering the reservoir will be the most likely time we would lose circulation Stuck Pipe Potential: There have been no cases of stuck pipe at 'K' pad to date IN SURFACE HOLE. However, well M P F- 53 was stuck coming out on the short trip at surface casing point. Subsequent fishing operations were not successful and a very expensive BHA was lost in the hole. If significant gravels are encountered stop and raise funnel viscosity to 150 cp viscosity immediately. In the 8-1/2" hole section here have been several cases of stuck pipe occuring at the top of the Kuparuk - with both the intervals above and below the Schrader Bluff open. The stuck pipe intervals and short trip guidelines on the Pad Data Sheet should be followed to avoid stuck pipe incidents. Running casing should be as smooth and quickly as possible to avoid stopping casing and possibly getting stuck. Formation Pressure: Schrader Bluff SAND Kuparuk Sand Target 4462' TVD SS 7045' TVD SS 1949 PSI 3663 PSI 8.4 PPG EMW 10.0 PPG EMW The maximum expected pore pressure for this well is 10.0 ppg EMW (3663 psi @ 7045' TVD SS). Reservoir pressure is not expected to exceed this estimate. MP K-34 9-5/8" DEEP SET CEMENT PROGRAM - HALLIBURTON (SHALLOW SET SURFACE CASING) CASING SIZE: 9-5/8" CIRC. TEMP 60 deg F at 2840' TVDSS. SPACER: 75 bbls fresh water (ADD DYE TO SPACER). LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder + (CELLO-FLAKES (1/4 lb/sack) in first stage only) WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk STAGE1 LEAD: ANUULAR VOLUME FROM BASE OF PERMAFROST TO STAGE COLLAR AT 1300' MD + 200% EXCESS + 80'md 9-5/8", 40# capacity for float joints. 753 SACKS THICKENING TIME: > 4 hrs at 50° F. STAGE2 LEAD: FROM STAGE COLLAR AT 1300' MD TO SURFACE + 200% EXCESS 1684 SACKS THICKENING TIME: > 4 hrs at 50° F. TAIL CEMENT TYPE: ADDITIVES: WEIGHT: APPROX #SACKS: Premium G 0.2% CFR-3,0.2% HALAD-344, 2.0% CaCI2 + CELLO-FLAKES 15.8 ppg YIELD:1.15 ft3/sx MIX WATER' 5.0 gal/sk I 087 THICKENING TIME: Greater than 4 hrs at 50° F. FLUID LOSS: 100-150 cc FREE WATER: 0 TAIL CEMENT FROM TD TO BASE OF PERMAFROST + 30% EXCESS WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: WELLHEAD STABILITY CEMENT WILL BE PUMPED IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing (15 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. MP K-34 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON (SHALLOW SET SURFACE CASING) SINGLE STAGE CEMENT JOB FROM TD TO 5 0 0' MD ABOVE SCHRADER BLUFF: CIRC. TEMP: 140° F SPACER: 20 bbls fresh water BHST 170° F at 7040' TVDSS. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: 0.2% CFR-3, 30#/SACK SILICATE, 1.25% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 470 SACKS THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: , . 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 18 joints of 7" casing (44). This will cover +300' above the KUPARUK Sand. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary, CEMENT VOLUME: , Stage I cement volume is calculated to cover 1000 FT MD above the Kuparuk 'C' Sand with 30% excess. SHARED SERVICES DRILLINg' ANADRILL AKA-DPC APPROVED FOP, PERMITTING ONLY PLAN Anadr~ ]] Schlumberger _ __ MPK-34 (PC) VERTICAL SECTION VIEW Section at' 117.90 TVD Scale.' 1 inch = 1600 feet Dep Sca]e.' t inch: ]600 feet Drawn · 26 Sep 19~'~, : A .......... ~rKer ]oentlflCatlon ~ ~ Al KB 0 0 0 B '- BI EDP/BUILD t/100 300 300 0 C-- C) BUILD 1.5/:lO0 600 600 7 3.C ~ 0 ' [" D) BUILO 2/t00 900 899 31 .7.. E) CURVE 2/t00 1300 1290 102 ~5.... E F} END 2/100 CURVE 1806 1772 252 20... ........... 6) BUILD 2.5/100 1906 1865 288 20.E [ ~ - - q -"~-- ...................... - - ' ......... : ..... ~ ~%qmT~la)~f' '~oI H) ENO 2.5/100 BUILD 3796 3173 1577 68.~ I) 9-5/8' CASING POINT 4630 .3567 2637 68.; d) TARGET ~4373 7~02 1~398 68.; - - ~ ...... .K) 7' CASING PDINT 14818 7267 11810 68.; L) TD 14BIB 7267 !I810 BB.; , , --' ~ [~1~111~% .... ir, [, '~' ,., J .... ~ ' ....... , ........... ......... ' -=:::=:=== :=:::~:.=-===:-=-:E-:~: E -' -- E .: .: ~ : = .: .: : -: : --' -- : I : = = = -- = = -- : -' : = : -- -- = :I E--E--: ]~ . j · ,, · 0 800 1600 2400 3200 4000 4800 5600 6400 7200 BO00 ca00 9600 10400 ! 1200 12000 i2eoo 13600 Section Departure ~ma~')l] {c)96 NPICI4P2 3.~.05 Il: 13 AN Pi ¢. ..h 'SHARED SERVICES ii i i i Marke? I(lenti! ication A) IARGET BJ 7' CASING POINT c~ To MO BK8 SECTN INCLN 14373 7102 11398 B8.20 14818 72§7 11810 B8.20 14818 7267 11810 68.20 DRTLL:I:NG i · m i m ANADRI LL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN Anadrj ]1 Schlumberger MPK-34 (P2) VERTICAL SECTION VIEW !Section at: ~7.~0 IYD Scale · 1 ~ncn - ~00 ~eet ~ep Scale · ~ inch = ~00 feet Drawn ' 26 Sep 1995 ~__ [- , , .... · , --, .... 'T~ie' -©~ ............... 'Ti~L~' ' I~ ........................................ ';-../L,,' -~- 1. -- , , - ..... ~ , I 9RL~' - ro~ ~: ................... ' I ':~ ' r:¢~t' '. ...... : .- ................ L .......... ! ..... , - - -- ~,,,~_ _. .... [ .:I" I ...... ~'~~._~ ..... ~- .... ~ ' ~' T 'linEal' ' ~,4~ . .... ~ 'T~T -~7~ '2 .................... -'T--~a~- - T~, ..... ~ -,,,-,,,. ,. ...... .. ,..... ,r :I ' .... .............. ! ...... . .... i, ..... ,, I~nadr~!! ('c196 lt~K34p2 3.o~.o6 ]I: 15-~ PI I0~00 10300 10400 10500 t0§00 10700 10800 20900 11000 lliO0 ll~O0 21300 11400 21500 Ii600 11700 11800 itS00 12000 Section Departure ii ii i i i i 0 0 ,. K3 0 FOR PERMITTING, ONLY P.LAN ~: z ¢~" MPK-34 (P2) VERTICAL SECTION VIEW Section at: 117.90 TVD Scale ' ! ~nch = lO0 feet Dep Scale · 1 inch = t00 feet Drawn · 26 Sep ~9'1~, J ~ -~ . "-~-~'~".,~,~..~ ' -'.~,~~]- --'.. ..... ---- I ...... I" ' ! '" I 4900 4950 5000 5050 5100 5J50 5200 5250 5300 5350 5400 5450 5500 5550 5600 5650 5700 5750 5800 Section Departure (~aclrJ]l (c)96 1~34P2 3.01).06 il: 15 ~ PI ]umberger MPK-34 (Pe) J ANADRILL AKA-DPC ~ : PLAN VIE o~- APPROVED ~, ~L0$UI:IE .....- ~18il feet 81 AzimuU~ FORP~RM.~TII'4G.... DECLINATION.: *28.057 IE) ' SCALE ....... : 1 inch = 1600 feet o-- ~ ~ . ~- DRA~N ..... , ~.~ Sep 19~¢ "~ -"~~ ..... ,.]LAN. . ...~g~' _ __ _. " .. .. i iii t iiH _ illll i O- - % , - ,arker Identi ficat ion HD N/S E/~ A} KB 0 0 N 0 E B} K~/BUILD 1/100 300 0 N 0 E 0-- ~;~ C} BUILO 1.5/100 ~0 0 N B E ' ' ~ . - D} BUILD 2/100 900 0 N 35 E ~ ~, % K) 7' ~SING POINT 14818 5450 5 10478 E ~~ ~ L) TO 14818 5450 S 10478 E ....... ,'~,? ,~.~. ..... ...... ~ -' , :~ ~:~' . , ~_ - ;,. ,~...~4~~ Is 100 fe ) .(,, :." .... ,..,e?~ .: :.. ~ 8000 .... ?~:: '' . I I I- "1' ' i '1 .... i ~0 ... 0 . ~0 1600 2400 3~00 4000 4800 5600 6400 7200 8000 8800 9600 ' tO400 II200 l~O0 ~2800 13600 <- NEST ' EAST -> ~]ii kl:~ ~34p2 3.~.06 ~1:14 AN PJ .................... ID · FIELD & POOL ADMINISTRATION , i , , WELL PERMIT CHECKLIST COMPANY WELL NAME/~'~"~-._~ PROGRAM: exp 0 d edrll 1:3 serv 13 wellbore seg [] ann. disposal para req [] GEOL AREA ~=~'~/3 UNIT# ,/~,, ,~, ON/OFF SHORE d~/~ ') 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number ................ 4. Well located in a defined pool ................. 5. Well located proper distance from ddg unit boundary ..... 6. Well located proper distance from other wells ......... 7. Sufficient acreage available in drilling unit. .......... 8. If deviated, is wellbore plat included .............. 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............ 11. Permit can be issued without conservation order ...... DATE ? 12. Permit can be issued wi~out administrative approval .... ~,/..~/.~' 13. Can permitbe approved before 15-daywaiL ........ ENGINEERING REMARKS 14. Conductor string provided .................. ;~)N 15. Surface casing protects ail known USDWs ......... L~,~N 16. CMT vol adequate to circulate on conductor & surf csg . . . _L.~ ~ A /? ~ --/~-----" 17. CMT vol adequate to tie-in long string to surf csg ..... 18. CMT will cover all known productive horizons ....... Casing designs adequate for C, T, B & permafrost. ..... [Y_JN ~'~/~ , 19. Adequate tankage or reserve pit. ............... ~N ,,c~r- ~'~ / 20. 21. If a re-drill, has a 10-403 for abndnmnt been approved.. 22. Adequate wellbore separation proposed ............ (.~Y~N 23. If diverter required, is it adequate ................ ~,,N ~'J,-- 24. Ddlling fluid prOgram schematic & equip list adequate .... ~,,N, 25. BOPEs adequate ........................ 26. BOPE press rating adequate; test to ~ psig.(~N 27. Choke manifold complies w/APl RP-53 (May 84) ....... Y(.,~N 28. Work will occur without operation shutdown .......... d_,~N 29. Is presence of H2S gas probable ............... ~ N ' G~OLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N/ o. ove re ,e ....... 32. Seismic anaiysis of shaiiow gas zones ............. 33. Seabed condition survey (if off-shore) ........... ~. Y N 34. Contact name/phone for weekly progress reports .... /.. Y N Iexp~oratorr only] GEOLOGY: ENGINEERING: COMMISSION: B EW~/o///ro DW~ JDH ,~ JDN TAB Comments/Instructions: HOW/lib- A.'~OR~ rev 4~6 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. RECEIVED DEC 1 5 1995 * ALASKA COMPUTING CENTER * * . *__ ............. . * ....... SCHLUMBERGER ....... . . ............................ . COMPANY NAME : B.P. EXPLORATION WELL NAME : MPK-34 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22712-00 REFERENCE NO : 96377 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-DEC-1996 15:48 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/12/10 ORIGIN . FLIC REEL NAME : 96377 CONTINUATION # : PREVIOUS REEL : CORR4~a~T : B.P. EXPLORATION, MILNE POINT MPK-34, API #50-029-22712-00 **** TAPE HEADER **** SERVICE NA2iE : EDIT DATE : 96/12/10 ORIGIN : FLIC TAPE NAME : 96377 CONTINUATION # : 1 PREVIOUS TAPE : COf~4~IVT : B.P. EXPLORATION, MILArE POINT MPK-34, API #50-029-22712-00 TAPE HEADER MILNE POINT MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPK-34 500292271200 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES lO-DEC-96 1ST STRING 2NDSTRING BIT RUN1 BIT RUN2 BIT RUN3 ........................... 96377 96377 96377 BOSSE BOSSE BOSSE ANGLEN ANGLEN ANGLEN 3 12N liE 3577 1954 57.30 57.30 27.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ................................ 12.250 20.000 112.0 8.500 9.625 8459.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-DEC-1996 15:48 3RD STRING PRODUCTION STRING Well drilled 07-NOV through 17-NOV-96 with CDR/ADN. Ail data was collected in three bit runs. ADN curves in LDWG are as follows: ROMB= max. rotational bottom quadrant density, ROBB/ROBU/ROBL/ROBR = bottom, upper, left, and right quadrant density, DRHB/DRHU/DRHL/DRHR= quadrants as above for delta rho, PEB/PEU/PEL/PER = quadrants as above for PEF, HDIA/VDIA = horizontal and vertical hole diameters. Also, ROBB=RHO1, ROBU=RH02, ROBL=RH03, ROBR=RH03. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 96/12/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENOY4~ER: 1 EDITEDMERGEDI~WD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0. 5000 FILE S~4MARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH ..................... 4992.5 14671 . 5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH MWD ..................... 88888.0 88899.5 8351.0 8362.5 8335.0 8347.0 8317.5 8329.0 8292.5 8303.5 8290.0 8300.0 8283.5 8295.5 8239.5 8252.0 8168.0 8179.0 8131.0 8143.0 8084.5 8097.0 8039.5 8052.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8031.5 8007.0 7986.5 7955.0 7907.5 7889.0 7883.5 7865.5 7844.0 7820.5 7800.5 7779.5 7767.5 7743.0 7737.0 7731 0 7712 5 7693 0 7678 0 7672 0 7652 0 7620 5 7584.0 7564.5 7551.5 7543.5 7539.5 7507.0 7486.0 7476.0 7474.0 7462.5 7424.0 7407.5 7397.5 7394.0 7380.5 73 69.5 7303.0 7286.0 72 63.0 7256.5 7250.0 7228.0 7212.0 7201.0 7192.0 7187.5 7176.5 7159.5 7158.0 7144.0 7134.0 7123.5 7111.0 8043.5 8017.5 7995.5 7963.5 7916.0 7897.5 7892.5 7875.0 7853.0 7828.5 7808.0 7788.5 7776.5 7750.5 7745.0 7738.5 7721.5 7701.5 7686.0 7680.5 7660.5 7628 0 7594 5 7573 5 7557 5 7551 0 7548 0 7515 5 7494 0 7484 5 7483.0 7472.5 7433.0 7417.5 7407.0 7402.5 7389.5 73 78.0 73 09.5 7293.5 7271.5 7264.5 7258.0 7234.5 7219.5 7209.0 7199.5 7194.5 7183.0 7166.5 7165.0 7149.5 7139.5 7132.0 7121.0 10-DEC-1996 15:48 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 7102 7061 7042 7019 6977 6959 6945 0 6935 5 6925 0 6899 5 6891 5 6877 5 6864.5 6858.5 6811.5 6798.5 6744.5 6742.5 6727.5 6723.0 6705.0 6691.0 6689.0 6662.5 6643.5 664 O. 5 663 O. 0 6619.0 6616.5 6595.5 6585.0 6572.5 6570.5 6562 5 6556 0 6544 0 653 6 0 6525 5 6515 5 6504 0 6489.5 6484.5 6466.5 6444.5 6430.5 6419.5 6396.0 6383.5 6362.5 6356.0 6340.5 6326.0 631 O. 5 6271.5 6260.5 7112.5 7071.5 7049.5 7026.5 6982.0 6965.0 6947.0 6939.5 6928.5 6906.0 6896.5 6885.5 6871.5 6863.5 6819.0 6807.5 6753.0 6750.5 6735.0 673 O. 5 6712.0 6698.0 6695.5 6670.0 6651.5 6647.0 6637.5 6622.0 6618.5 6601.5 6592.0 6580.0 6577.0 6569.5 6563.5 6551.5 6541.5 6530 0 6520 0 6510 0 6497 0 6491 5 6474 5 6453 5 6440.5 6425.5 6401.0 6388.0 6366.5 6360.0 6347.5 6333.0 6315.5 6277.0 6265.5 10-DEC-1996 15:48 PA GE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 6255 6197 6113 6080 6068 6054 0 6049 5 6037 0 6025 0 6016 0 6005.0 5987.5 5972.5 5958.0 594 O. 5 5910.5 5902.5 5875.5 5857.5 5850.0 5832.5 5826.5 5819.5 5810.5 5801.5 5780.0 5768.0 5744.5 5740.0 5734.0 5715.0 5682.5 5674.5 5666.5 5644.5 5629.0 5610.0 5598.5 5589.5 5556.5 5548.5 5532.5 5521.5 5511.0 5507.5 5485.5 5477.5 5470.5 5469.0 5461.5 5456.5 5444.0 5425.5 5408.5 5387.5 6260.5 6202.5 6119.0 6086.5 6068.5 6057.5 6053.5 6041.5 603 O. 0 6019 5 6007 5 5991 0 5975 5 5961 0 5944 0 5911 0 5905 0 5879 0 5861 0 5854 5 5835.0 5829.0 5822.0 5815.0 5803.5 5781.0 5770.0 5746.5 5744.0 5737.5 5720.0 5689.0 5679.0 5669.5 5647.0 5632.0 5610.0 5599.5 5593.5 5561.0 5552.0 5536.5 5523.5 5512.5 5510.5 5488.0 5481.5 5472.5 54 69.5 5464.0 5459.0 5447.5 5429.5 5413.5 5393.0 10-DEC-1996 15:48 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-DEC-1996 15:48 PAGE: 5363.0 5337 0 5324 5 5294 5 5268 0 5249 5 5231 0 5223 0 5210 5 5199 0 5161 5 5154 5 5118 0 5064 5 5023.0 5001.0 4985.5 4980.0 4974.5 4971.5 4963.0 4956.0 4947.0 4937.5 4923.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE RENARKS: 53 67.0 5338.0 5326.5 5295.0 52 69.0 5251.5 5233.5 5225.0 5212.5 5200.5 5164 5 5158 5 5122 5 5069 5 5027 0 5003 0 4988 0 4982 5 4979 0 4976 0 4967 0 4959 5 4950 5 4942 0 4926.0 103.0 BIT RUN NO. MERGE TOP MERGE BASE 1 4992.5 6533.0 2 6533.0 8481.0 3 8481.0 14671.5 The depth adjustments shown above reflect the MWD GR to the CBT GR logged by SWS. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-DEC-1996 15:48 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUPIB SAMP ELEM CODE (HEX) DEPT FT 039016 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 039016 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0H~I039016 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OH~ff4 039016 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OHdVk4039016 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OHM~I 039016 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OHFiM 039016 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 039016 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 039016 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB MWD G/C3 039016 O0 000 O0 0 1 1 1 4 68 0000000000 RHO1 I~WD G/C3 039016 O0 000 O0 0 1 1 1 4 68 0000000000 RH02 MWD G/C3 039016 O0 000 O0 0 1 1 1 4 68 0000000000 RH03 MWD G/C3 039016 O0 000 O0 0 1 1 1 4 68 0000000000 RH04 MWD G/C3 039016 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 039016 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 039016 O0 000 O0 0 1 1 1 4 68 0000000000 DCALMWD IN 039016 O0 000 O0 0 1 1 1 4 68 0000000000 CALAMWD IN 039016 O0 000 O0 0 1 1 1 4 68 0000000000 CALSMWD IN 039016 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 039016 O0 000 O0 0 1 1 1 4 68 0000000000 TNRAMWD PU-S 039016 O0 000 O0 0 1 1 1 4 68 0000000000 DPHIMWD PU-S 039016 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CBT GAPI 039016 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-DEC-1996 15:48 PAGE: ** DATA ** DEPT. 14671.500 FET.MWD VRA.MWD -999.250 VRP.MWD GR.MWD -999.250 RHOB.MWD RHO3.MWD -999.250 RHO4.MWD DCAL.MWD -999.250 CALA.MWD TNRA.MWD -999.250 DPHI.MWD DEPT. 14000.000 FET.MWD VRA.MWD 3.466 VRP.MWD GR.MWD 106.556 RHOB.MWD RHO3.MWD 2.419 RHO4.MWD DCAL.MWD 1.007 CALA.MWD TNRA.MWD 21.698 DPHI.MWD DEPT. 13000.000 FET.MWD VRA.MWD 2.221 VRP.MWD GR.MWD 105.948 RHOB.MWD RHO3.MWD 2.454 RHO4.MWD DCAL.MWD 0.142 CALA.MWD TNRA.MWD 24.185 DPHI.MWD DEPT. 12000.000 FET.MWD VRA.MWD 2.865 VRP.MWD GR.MWD 72.674 RHOB.MWD RHO3.MWD 2.512 RHO4.MWD DCAL.MWD 0.108 CALA.MWD TNRA.MWD 22.171 DPHI.MWD DEPT. 11000.000 FET.MWD VRA.MWD 3.176 VRP.MWD GR.MWD 81.426 RHOB.MWD RHO3.MWD 2.374 RHO4.MWD DCAL.MWD 0.573 CALA.MWD TNRA.MWD 22.613 DPHI.MWD DEPT. 10000.000 FET.MWD VRA.MWD 2.785 VRP.MWD GR.MWD 71.248 RHOB.MWD RHO3.MWD 2.410 RHO4.MWD DCAL.MWD 0.269 CALA.MWD TArRA.MWD 22.487 DPHI.MWD DEPT. VRA . MWD GR.MWD RH03 .MWD D CAL . MWD TNRA.MWD 9000 000 3 273 63 900 2 352 0 262 22 357 DEPT. VRA.MWD GR.MWD RHO3.MWD 8000.000 3.271 81.377 -999.250 FET. MWD VRP.MWD RHOB. MWD RH04. MWD CALA . MWD D PHI . MWD FET. MWD VRP.MWD RHOB. MWD RH04 .RH~D -999.250 RA.MWD -999.250 DER.MWD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 CALS.MWD -999.250 GRCH. CBT 3 392 4 094 2 543 2 452 9 535 5 000 0.439 3. 340 2.370 2. 441 10. 469 14. 600 O. 519 3.310 2.510 2.508 9. 762 10.200 0.706 3.670 2.484 2.405 10.136 13.200 0.670 3.144 2.406 2.391 9.479 15.100 O. 733 3.305 2. 342 2. 330 10.136 18.300 1.525 3.928 -999.250 -999.250 RA . MWD DER.MWD RH O1. MWD DRHO.MWD CALS . MWD GRCH. CBT RA . MWD DER. MWD RHO1. MWD DRHO.MWD CALS . MWD GRCH. CBT RA . MWD DER.MWD RH O1. MWD DRHO.MWD CALS . MWD GRCH. CBT RA . MWD DER. MWD RH O1. MWD DRHO.MWD CALS . MWD GRCH. CBT RA . MWD DER.MWD RH O1. MWD DRHO. MWD CAL S . MWD GRCH. CBT RA . MWD DER.MWD RH O1. MWD DRHO.MWD CAL S . MWD GRCH. CBT RA . MWD DER.MWD RH O1. MWD DRHO. MWD -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.641 3. 930 2.568 O. 040 9.335 -999.250 2. 051 2. 618 2. 409 O. 039 10. 069 -999.250 2. 764 3. 072 2. 482 O. 017 9. 135 -999. 250 3. 123 3.410 2. 432 O. 026 10. 002 -999.250 2. 700 2. 918 2. 401 O. 004 9.504 -999.250 3.273 3.317 2.348 0.005 10.136 -999.250 3.925 3.715 -999.250 -999.250 RP.MWD ROP. MWD RH02. MWD PEF. MWD NPHI.MWD RP.~WD ROP.MWD RHO2.MWD PEF.MWD NPHI.MWD RP.MWD ROP. MWD RH02. MWD PEF.MWD NPHI. MWD RP.MWD ROP. ~D RH02. MWD PEF.MWD NPHI.MWD RP.MWD ROP.MWD RHO2.MWD PEF.MWD NPHI.MWD RP. MWD ROP. MWD RH02. MWD PEF. MWD NPHI.MWD RP.MWD ROP.MWD RHO2.MWD PEF.MWD NPHI.~D RP.MWD ROP.MWD RHO2.MWD PEF.~D -999.250 121.623 -999.250 -999.250 -999.250 4.115 75.946 2.302 3.257 34.900 3. 625 46. 037 2.448 3.018 42.1 O0 3. 315 110. 437 2. 467 3. 337 36.200 3. 614 191. 476 2. 380 3. 025 37. 400 3.077 178.216 2.427 3.220 37.100 3.342 134.332 2.297 3.131 36.700 3.624 77.920 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-DEC-1996 15:48 PAGE: DCAL.MWD -999.250 CALA.MWD TNRA.MWD -999.250 DPHI.MWD DEPT. 7000.000 FET.MWD VRA.MWD 1.476 VRP.MWD GR.MWD 60.628 RHOB.MWD RHO3.MWD -999.250 RHO4.MWD DCAL.MWD -999.250 CALA.MWD TNRA.MWD -999.250 DPHI.MWD DEPT. 6000.000 FET.MWD VRA.MWD 14.669 VRP.MWD GR.MWD 66.544 RHOB.MWD RHO3.MWD -999.250 RHO4.MWD DCAL.MWD -999.250 CALA.MWD TNR~.MWD -999.250 DPHI.MWD -999.250 CALS.MWD -999.250 GRCH. CBT 0.581 RA.MWD 1.532 DER.MWD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 CALS.MWD -999.250 GRCH. CBT 1.153 RA.MWD 14.077 DER.MWD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 CALS.MWD -999.250 GRCH. CBT DEPT. 5000.000 FET. MWD 0.991 RA.MWD VRA.MWD 4.144 VRP.MWD 4.385 DER.MWD GR.MWD 75.913 RHOB.MWD -999.250 RHO1.MWD RHO3.MWD -999.250 RHO4.MWD -999.250 DRHO.MWD DCAL.MWD -999.250 CALA.MWD -999.250 CALS.MWD TNRA.MWD -999.250 DPHI.MWD -999.250 GRCH. CBT DEPT. 4980.000 FET.MWD VRA.MWD -999.250 VRP.MWD GR.MWD -999.250 RHOB.MWD RHO3.MWD -999.250 RHO4.MWD DCAL.MWD -999.250 CALA.MWD TNRA.MWD -999.250 DPHI.MWD -999.250 RA.MWD -999.250 DER.MWD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 CALS.MWD -999.250 GRCH. CBT -999.250 43.906 1.410 1.475 -999.250 -999.250 -999.250 35.902 11.297 11.913 -999.250 -999.250 -999.250 34.647 4.902 4.833 -999.250 -999.250 -999.250 44.692 -999.250 -999.250 -999.250 -999.250 -999.250 38.471 NPHI.MWD RP.MWD ROP.MWD RHO2.MWD PEF.MWD NPHI.MWD RP.MWD ROP. MWD RH02 . MWD PEF. MWD NPHI.MWD RP.MWD ROP. MWD RH02 . MWD PEF. MWD NPHI.MWD RP.MWD ROP. MWD RH02. MWD PEF.MWD NPHI.MWD -999.250 1.528 417.278 -999.250 -999.250 -999.250 12.111 31.196 -999.250 -999.250 -999.250 4.802 257.161 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION · O01CO1 DATE ' 96/12/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-DEC-1996 15:48 PAGE: 10 FILE HEADER FILE i~JMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SO2vk~IRY VEA~OR TOOL CODE START DEPTH MWD 4980.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 6533.0 17 -NOV- 96 4.0 4.0 MEMORY 14660.0 4990.0 14660.0 60 66.6 68.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... CDR RESIST./GR $ TOOL NUMBER CDR8-044 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : 12.250 112.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10. O0 MUD VISCOSITY (S) : 48.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OPk4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 090 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. 020 MUD CAKE AT (MT): 72.0 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-DEC-1996 15:48 PAGE: 11 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: ******RUN/ CDR ONLY************* DRILLED INTERVAL 4997' - 6533' RES TO BIT: 66.12'; GR TO BIT: 76.70' ******RUN2 CDR ONLY************* DRILLED INTERVAL 6533' - 8481' RES TO BIT: 54.69'; GR TO BIT: 65.27' ******RUN3 CDR/ADN 8481'-14660'** RES TO BIT: 57.86'; GR TO BIT: 68.28' $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATIONRECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 039016 O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 OH~M 039016 O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW1 OH~ff~039016 O0 000 O0 0 2 1 1 4 68 0000000000 ATVR LW! OH~M 039016 O0 000 O0 0 2 1 1 4 68 0000000000 PSVR LW1 OIff4M039016 O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 OH~M039016 O0 000 O0 0 - 2 1 1 4 68 0000000000 ROPE LW1 F/HR 039016 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW! GAPI 039016 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-DEC-1996 15:48 PAGE: 12 ** DATA ** DEPT. 6533. 000 ATR. LW1 -999. 250 PSR. LW1 -999. 250 ATVR. LW1 PSVR.LW1 -999.250 DER.LW1 -999.250 ROPE.LW1 32. 610 GR.LW1 DEPT. 6000.000 ATR.LW1 10.559 PSR.LW1 12.328 ATVR.LW1 PSVR.LW1 12.128 DER.LW1 11.877 ROPE.LW1 35.644 GR.LW1 DEPT. 5000. 000 ATR. LW1 4. 946 PSR. LW1 5.105 ATVR. LW1 PSVR.LW1 4. 901 DER.LW1 5. 047 ROPE.LW1 295. 894 GR.LW1 DEPT. 4980. 000 ATR.LW1 1 . 708 PSR.LW1 O. 636 ATVR.LW1 PSVR. LW1 -999. 250 DER. LW1 O. 733 ROPE. LW1 176. 467 GR. LW1 -999.250 -999.250 12.985 67.729 4.585 77.984 -999.250 46.746 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 96/12/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 6454.5 8481.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-DEC~1996 15:48 PAGE: 13 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (blEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... CDR RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH : MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~4~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) EWR FREQUENCY (HZ) REMARKS: ******RUN 1 CDR ONLY************* DRILLED INTERVAL 4997' - 6533' RES TO BIT: 66.12'; GR TO BIT: 76.70' ******RUN 2 CDR ONLY************* DRILLED INTERVAL 6533 ' - 8481 ' RES TO BIT: 54.69'; GR TO BIT: 65.27' ******RUN 3 CDR/ADN 8481 ' -14660'** RES TO BIT: 57.86'; GR TO BIT: 68.28' 17-NOV-96 4.0 4.0 MEMORY 14660.0 4990.0 14660.0 6O 64.8 7O.O TOOL NUMBER CDR8-044 12.250 112.0 LSND 10.00 48.0 2. 090 72.0 2.020 72.0 20000 LIS Tape Verification Listing Schlumberger Alaska Computing Center !0-DEC-1996 15:48 PAGE: 14 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 66 66 73 66 66 73 65 0 0 32 1 0.5 FT 32 1 2 3 4 5 6 7 8 68 9 65 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NO?4B NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB_ SAMP ELEM CODE (HEX) DEPT FT 039016 O0 000 O0 0 3 1 1 4 68 0000000000 ATR LW2 OHMM 039016 O0 000 O0 0 3 1 1 4 68 0000000000 PSR LW2 OH~M 039016 O0 000 O0 0 3 1 1 4 68 0000000000 ATVR LW2 OP~4M 039016 O0 000 O0 0 3 1 1 4 68 0000000000 PSVR LW2 OH~M 039016 O0 000 O0 0 3 1 1 4 68 0000000000 DER LW2 OH~M 039016 O0 000 O0 0 3 1 1 4 68 0000000000 ROPE LW2 F/HR 039016 O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI 039016 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 8480.500 ATR.LW2 -999.250 PSR.LW2 -999.250 ATVR.LW2 -999.250 PSVR.LW2 -999.250 DER.LW2 -999.250 ROPE. LW2 41.285 GR.LW2 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-DEC-1996 15:48 PAGE: 15 DEPT. 8000. 000 ATR.LW2 PSVR. LW2 3. 124 DER. LW2 DEPT. 7000. 000 ATR. LW2 PSVR . LW2 1. 521 DER. LW2 3. O11 PSR. LW2 3. 062 ROPE. LW2 1.365 PSR. LW2 1.448 ROPE. LW2 3. 092 ATVR. LW2 80. 718 GR.LW2 1.519 ATVR. LW2 53. 413 GR.LW2 DEPT. 6454.500 ATR.LW2 -999.250 PSR.LW2 -999.250 ATVR.LW2 PSVR.LW2 -999.250 DER.LW2 -999.250 ROPE, LW2 -999.250 GR.LW2 2. 959 79,821 1.477 56.483 -999.250 95.516 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE . 96/12/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: O . 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... MWD 8366.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): STOP DEPTH 14660.0 17-NOV-96 4.0 4.0 MEMORY LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-DEC-1996 15:48 PAGE: 16 TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... CDR RESIST./GR ADN NEUT./DENS. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 14660.0 4990.0 14660.0 55 68.0 70.0 TOOL NUMBER ........... RGS-022 ADN-045 12.250 112.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10. O0 MUD VISCOSITY (S) : 48.0 MUD PH: MUD CHLORIDES (PPM) : 800 FLUID LOSS (C3): RESISTIVITY (Otfl~l) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 090 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. 020 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: ******RUN 1 CDR ONLY************* DRILLED INTERVAL 4997' - 6533' RES TO BIT: 66.12'; GR TO BIT: 76.70' ******RUN 2 CDR ONLY************* DRILLED INTERVAL 6533' - 8481' RES TO BIT: 54.69'; GR TO BIT: 65.27' ******RUN 3 CDR/ADN 8481 '-14660'** RES TO BIT: 57.86'; GR TO BIT: 68.28' $ LIS FORMAT DATA 72.0 72.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-DEC-1996 15:48 PAGE: 17 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 112 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 039016 O0 000 O0 0 4 1 1 4 68 0000000000 ATR LW3 OH~M 039016 O0 000 O0 0 4 1 1 4 68 0000000000 PSR LW3 OH~I 039016 O0 000 O0 0 4 1 1 4 68 0000000000 ATVR LW3 Otfl~M039016 O0 000 O0 0 4 1 1 4 68 0000000000 PSVR LW3 OH~4 039016 O0 000 O0 0 4 1 1 4 68 0000000000 DER LW3 OPff~f039016 O0 000 O0 0 4 1 1 4 68 0000000000 ROPE LW3 F/HR 039016 O0 000 O0 0 4 1 1 4 68 0000000000 GR LW3 GAPI 039016 O0 000 O0 0 4 1 1 4 68 0000000000 DPHB LW3 PU 039016 O0 000 O0 0 4 1 1 4 68 0000000000 ROMB LW3 G/C3 039016 O0 000 O0 0 4 1 1 4 68 0000000000 ROBB LW3 G/C3 039016 O0 000 O0 0 4 1 1 4 68 0000000000 ROBU LW3 G/C3 039016 O0 000 O0 0 4 1 1 4 68 0000000000 ROBL LW3 G/C3 039016 O0 000 O0 0 4 1 1 4 68 0000000000 ROBR LW3 G/C3 039016 O0 000 O0 0 4 1 1 4 68 0000000000 DRHB LW3 G/C3 039016 O0 000 O0 0 4 1 1 4 68 0000000000 DRHU LW3 G/C3 039016 O0 000 O0 0 4 1 1 4 68 0000000000 DRHL LW3 G/C3 039016 O0 000 O0 0 4 1 1 4 68 0000000000 DRHR LW3 G/C3 039016 O0 000 O0 0 4 1 1 4 68 0000000000 PEB LW3 039016 O0 000 O0 0 4 1 1 4 68 0000000000 PEU LW3 039016 O0 000 O0 0 4 1 1 4 68 0000000000 PEL LW3 039016 O0 000 O0 0 4 1 1 4 68 0000000000 PER LW3 039016 O0 000 O0 0 4 1 1 4 68 0000000000 TNPH LW3 PU 039016 O0 000 O0 0 4 1 1 4 68 0000000000 TNNA LW3 039016 O0 000 O0 0 4 1 1 4 68 0000000000 DCAL LW3 IN 039016 O0 000 O0 0 4 1 1 4 68 0000000000 HDIA LW3 IN 039016 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-DEC-1996 15:48 PAGE: 18 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) VDIA LW3 IN 039016 O0 000 O0 0 4 1 1 4 68 0000000000 RPM LW3 RPM 039016 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 14660.000 ATR.LW3 -999.250 PSR.LW3 -999.250 ATVR.LW3 PSVR.LW3 -999.250 DER.LW3 -999.250 ROPE.LW3 121 . 623 GR.LW3 DPHB. LW3 -999. 250 ROMB. LW3 -999. 250 ROBB. LW3 -999. 250 ROBU. LW3 ROBL. LW3 -999. 250 ROBR. LW3 - 999. 250 DRHB. LW3 - 999. 250 DRHU. LW3 DRHL.LW3 -999.250 DRHR.LW3 -999.250 PEB.LW3 -999.250 PEU. LW3 PEL.LW3 -999.250 PER.LW3 -999.250 TNPH. LW3 -999.250 TNRA.LW3 DCAL.LW3 -999.250 HDIA.LW3 -999.250 VDIA.LW3 -999.250 RPM. LW3 DEPT. 14000. 000 ATR. LW3 3.317 PSR. LW3 PSVR. LW3 4. 035 DER. LW3 3. 654 ROPE. LW3 DPHB. LW3 6. 500 ROMB. LW3 2. 566 ROBB. LW3 ROBL.LW3 2. 436 ROBR.LW3 2.522 DRHB.LW3 DRHL.LW3 O. 126 DRHR.LW3 O. 036 PEB.LW3 PEL.LW3 3. 703 PER.LW3 2. 979 TNPH. LW3 DCAL. LW3 O. 933 HDIA. LW3 8. 735 VDIA. LW3 DEPT. PSVR . LW3 DPHB. LW3 ROBL. LW3 DRHL. LW3 PEL. LW3 DCAL. LW3 13000 000 ATR.LW3 2 659 DER.LW3 17 200 ROMB.LW3 2 339 ROBR. LW3 0 023 DRHR. LW3 3 023 PER. LW3 0. 241 HDIA . LW3 1. 892 PSR. LW3 2. 454 ROPE. LW3 2. 374 ROBB. LW3 2.314 DRHB . LW3 O. 002 PEB. LW3 2.92 6 TNPH. LW3 9. 351 VDIA. LW3 DEPT. PSVR . LW3 DPHB. LW3 ROBL. LW3 DRHL. LW3 PEL. LW3 DCAL . LW3 12000. 000 ATR. LW3 3. 077 DER.LW3 6. 900 ROMB. LW3 2. 489 ROBR. LW3 O . 051 DRJ{R . LW3 3 . 149 PER. LW3 O. 134 HDIA. LW3 2 883 PSR. LW3 3 000 ROPE.LW3 2 495 ROBB. LW3 2 459 DRHB. LW3 0 043 PEB. LW3 3 097 TNPH.LW3 8 561 VDIA. LW3 DEPT. PSVR. LW3 DPHB. LW3 ROBL . LW3 DRHL. LW3 PEL. LW3 DCAL . LW3 11000. 000 ATR. LW3 3. 449 DER.LW3 12.100 ROMB. LW3 2. 471 ROBR. LW3 O. 065 DRHR.LW3 3.143 PER. LW3 O. 369 HDIA. LW3 2.918 PSR. LW3 3.167 ROPE. LW3 2. 460 ROBB. LW3 2. 445 DRHB. LW3 O. 042 PEB. LW3 3.13 6 TNPH. LW3 9. 602 VDIA. LW3 DEPT. PSVR. LW3 DPHB . LW3 ROBL. LW3 10000. 000 ATR. LW3 5. 858 DER. LW3 14. 600 R OMB . LW3 2. 353 ROBR. LW3 3. 339 PSR. LW3 4. O16 ROPE. LW3 2.417 ROBB. LW3 2.364 DRHB.LW3 3. 895 ATVR. LW3 118 420 GR.LW3 2 543 ROBU. LW3 - 0003 DRHU. LW3 2 833 PEU. LW3 35 1 O0 TNRA. LW3 8 735 RPM. LW3 3. 650 ATVR. LW3 118. 420 GR.LW3 2.367 ROBU. LW3 - O. 002 DRHU. LW3 2.837 PEU. LW3 46. 100 TNRA. LW3 10. O18 RPM. LW3 3. 074 ATVR. LW3 185. 652 GR. LW3 2.53 6 ROBU. LW3 O . 059 DRHU. LW3 3 . 022 PEU. LW3 33. 500 TNRA. LW3 8. 735 RPM. LW3 3.345 ATVR. LW3 113.210 GR.LW3 2. 451 ROBU. LW3 O . 003 DRHU. LW3 3 . 150 PEU. LW3 35. 500 TNRA. LW3 8. 860 RPM. LW3 4. 677 ATVR. LW3 174. 752 GR.LW3 2.409 ROBU. LW3 - O. 008 DRHU. LW3 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.351 118.387 2.355 0.232 4.639 21.782 70.000 1.700 98.386 2.259 0.027 2.800 25.431 60.500 2. 768 82. 153 2. 429 O. 045 2. 956 21.171 59. 000 2.945 85.900 2.437 0.111 3.226 21.913 62.144 4.694 65.237 2.304 0.083 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-DEC-1996 15:48 PAGE: 19 DRHL.LW3 O. 028 DRHR.LW3 PEL. LW3 3.183 PER. LW3 DCAL . LW3 O . 441 HI~IA . LW3 DEPT. PSVR . LW3 DPHB.LW3 ROBL. LW3 DRHL. LW3 PEL. LW3 DCAL. LW3 9000 000 3 511 19 200 2 260 0 120 3 066 0 630 DEPT. 83 65. 500 PSVR. LW3 -999. 250 DPHB. LW3 - 999.250 ROBL . LW3 ~ 999.250 DRHL. LW3 -999. 250 PEL. LW3 -999 . 250 DCAL. LW3 -999. 250 ATR . LW3 DER. LW3 ROMB. LW3 ROBR . LW3 DRHR . LW3 PER. LW3 HDIA. LW3 ATR . LW3 DER LW3 ROMB LW3 ROBR LW3 DRHR LW3 PER LW3 HiDIA LW3 O . O14 PEB . LW3 3.267 TNPH. LW3 9. 335 VDIA. LW3 3. 029 PSR. LW3 3. 291 ROPE. LW3 2.346 ROBB. LW3 2. 322 DRHB. LW3 O . O18 PEB . LW3 3.363 TNPH.LW3 10. 091 VDIA. LW3 -999. 250 PSR. LW3 - 999.250 ROPE. LW3 -999. 250 ROBB. LW3 -999. 250 DRHB. LW3 -999. 250 PEB. LW3 -999. 250 TNPH. LW3 -999. 250 VDIA. LW3 2. 951 PEU. LW3 40. 400 TNRA. LW3 9. 202 RPM. LW3 3.477 ATVR.LW3 169. 812 GR. LW3 2. 333 ROBU. LW3 O . 036 DRHU. LW3 3 . 690 PEU. LW3 38.500 TNRA.LW3 9. 806 RPM. LW3 -999. 250 ATVR. LW3 -999. 250 GR. LW3 -999. 250 ROBU. LW3 -999. 250 DRHU. LW3 -999. 250 PEU. LW3 -999. 250 TNRA. LW3 -999. 250 RPM. LW3 3.064 23.635 87.000 3 360 66 541 2 300 0 139 2 936 22 982 54 052 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 96/12/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/12/10 ORIGIN : FLIC TAPE NAME : 96377 CONTINUATION # : 1 PREVIOUS TAPE : CON~NT : B.P. EXPLORATION, MILNE POINT MPK-34, API #50-029-22712-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 96/12/10 ORIGIN . FLIC REEL NAME : 96377 CONTINUATION # : PREVIOUS REEL : CO~IENT : B.P. EXPLORATIONj MILNE POINT MPK-34, API #50-029-22712-00