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179-011
Regg, James B (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Monday, November 24, 2014 3:54 PM To: Regg, James B (DOA) Cc: Christy Anderson Subject: FW: D -34A TIO plot Attachments: D -34A 90 day TIO.xlsx Here you go, Jim. We'll figure out what to look at next after we check out the tree. Larry From: Christy Anderson Sent: Saturday, November 22, 2014 7:02 PM To: Larry Greenstein Cc: John Lee; Jon Loomis; Stan Golis; Dan Marlowe; Christy Anderson Subject: D -34A TIO plot Larry, D -34A has apparently gotten tubing / casing communication. We changed the gauge on the 9 5/8 casing to find it at 2200 PSI. We bled it down to about 300 PSI and it pressured back up to 1000 PSI in about five hours while the well was still injecting. We shut the well in and as the tubing bled down so did the 9 5/8" casing. The well remains shut in. The MIT was not done. Z Jim Regg has requested a TIO plot on D -34A. If you can get it for him it would be appreciated. Thanks Christy D. Anderson Lead Operator Dolly Varden Platform 776-6840 canderson@hilcorp.com 1 DEC 3 12014 TBUDO34A'[SO.O596.UOJ2l 1000 08/2014 09/2014 10/2014 11/2014 9000 ° 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED SEP 2 4 2014 A0G0C 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate El Other R] Complete Performed: Alter Casing ❑ Pull Tubing0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re-enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑ Exploratory ❑ Stratigraphic❑ Service 2) 179-011 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20225-01 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018729 Trading Bay Unit / D -34A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): McArthur River Field / Hemlock Oil and Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured 11,285 feet Plugs measured None feet true vertical 9,960 feet Junk measured 11,091 & 11,098 feet Effective Depth measured 11,185 feet Packer measured 9,823 feet true vertical 9,872 feet true vertical 8,706 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate 2,080' 13-3/8" 2,080' 2,012' 3,090 psi 1,540 psi Production 10,295' 9-5/8" 10,295' 9,097' 5,750 psi 3,090 psi Liner 1,416' 7" 11,275' 9,963' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.55# / L-80 9,855' (MD) 8,732' (TVD) 9,823' (MD) Packers and SSSV (type, measured and true vertical depth) Tripoint Inj. Packer 8,706' (TVD) SSSV: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A SCW§D OCT 16, 2014 �°°�� 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 1-0 . c - -501--l. 0 Subsequent to operation: 0 0 0 314 2950 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service E] Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ R] WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 314-350 Contact Dan Marlowe Email dmarlowe(cDhilcorp.com Printed Name Dan Marlowe Operations Engineer Signature -fW O.ti yam,Title Phone (907) 283-1329 Date 9/23/2014 Form 10-404 Revised 10/2012 1 0 . ` / ty /�°���y Submit Original Only 11 SCHEMATIC McArthur River Field, TBU Well: D -34A Hilcorp Alaska, LLC As Completed: 08/25/2014 41' RKB Plug Back Depth = 11,185' TD = 11,285' MD/9,963' TVD :mt CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 J-55 Butt 12.515 Surf. 2,080' 9-5/8" 40 N-80 Butt 8.835 Surf. 2,556- 9-5/8" 47 N-80 Butt 8.681 2,556' 81351 9-5/8" 47 P-110 Butt 8.681 8,351 10,295' 7" liner 29 L-80 Butt 6.184 9,859' 11,275' Tubing 4-1/2" 11.6 Bare 12.55 Lined L-80 TLP 4040 (Poly lined) 3.640" Surf 9,855' JEWELRY DETAIL NO. Depth Depth ID Item Amt (MD) (TVD) Phasing G-1 1 9,823 8,706' 5.00 9-5/8" 36-53.5# - Tripoint 5 7/1/2012 72° G-2 Stimtop Injection Packer 2 9,844' 8,723' 2.810" "X" Nipple 3 9,856' 8,733' 3.00" Wireline Guide PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Phasing G-1 9,984' 10,003' 8,840' 8,855' 19 5 7/1/2012 72° G-2 10,022' 10,047' 8,871' 8,892' 25 5 7/1/2012 72° G-3 10,095' 10,128' 8,931' 8,959' 33 5 7/1/2012 72° 10,137' 10,186' 8,966' 9,007' 49 5 7/1/2012 72° G-4 10,249' 10,266' 9,059' 9,073' 17 5 7/1/2012 72° 10,315' 10,340' 9,114' 9,135' 25 5 7/1/2012 72° G-5 10,352' 10,368' 9,145' 9,158' 16 5 7/1/2012 72° G-6 10,426' 10,448' 9,207' 9,226' 22 5 7/1/2012 72° G-7 10,486' 10,493' 9,259' 9,265' 7 5 7/1/2012 72° B-1 10,550' 10,585' 9,314' 9,345' 35' 8 Nov -90 45° 10,610' 10,625' 9,367' 9,380' 15 8 Nov -90 45" B-2 10,611' 10,674' 9,368' 9,423' 63 5 08/21/14 72' 10,640' 10'660' 9,393' 9,411' 20 8 Nov -90 45° 10,740' 10'755' 9,481' 9,494' 15 8 Nov -90 45° B 3 10,788' 10,824' 9,524' 9,556' 36 8 Nov -90 45° B-4 10,834' 10,920' 9,565' 9,642' 86 8 Nov -90 45° B-5 10,950' 11,040' 9,669' 9,750' 90 8 Nov -90 45° Fish ID Description Depth A Retainer & Junk 11,091' B Old Isolation Packer 11,098' Updated by: JLL 09/23/14 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -34A 50-733-20225-01 1 178-011 7/11/14 1 8/25/14 Daily Operations: 07/11/14 - Friday N/D PRODUCTION TREE & HUNG OFF IN WELL BAY. N/U 11" X 5M RISER, BOP'S, & SPACER SPOOLS. INSTALL POLLUTION PANS ON DECK AROUND RISER. 07/12/14 - Saturday HOOK-UP KOOMEY LINES & PRESSURE UP ACCUMALATOR. FUNCTION TEST BOPS. BIND DOWN STACK & HANG POLLUTION PANS. INSTALL BEAMS & FLOOR PLATE. GREASE/WORK ALL VALVES TO BE TESTED. PERFORM GENERAL HOUSEKEEPING AROUND RIG. MODIFY & INSTALL CAT -WALK TO DRILLER SHACK. R/U TEST MANIFOLD. P/U 3-1/2" TEST ASSY M/U TO HANGER & PREP TO PRESSURE TEST CONNECTIONS. PRE-TEST 11" X 5M BOPS & SURFACE EQUIP 250 LOW / 2500 HIGH WHILE WAITING ON STATE REP TO ARRIVE TO WITNESS BOP TEST. SET POWER SWIVEL IN PLACE & INSTALL KELLY VALVES & CROSS OVER SUBS ON SAME. 07/13/14 - Sunday Held safety meeting JSA and did general rig maintenance while waiting on AOGCC rep to arrive. Tested BOP_s ani. manifolds and safety valves to 250 psi low, 2500 psi high on chart for 5 min each test. Tested with 3-1/2" & 4-1/2" tbg. All tests witnessed by Johnnie Hill with AOGCC. R/D test equipment and test jt. P/U power swivel. P/U 4-1/2" landing jt. & M/U same into hanger. Backed out hanger pins & attempted rotate anchor out of packer w/o success, by rotating tbg 15 rds to the right. Worked pipe to a maximum of 25k over P/U wt. while holding 3-4k torque on tbg. R/D power swivel pulled 17K over and pipe in slips. Move power swivel power unit and set EXPRO unit in place & r/u same. Held JSA on cutter with crew & essential personnel, gathered all cell phones and shut down all transmitting devices (radio silence). EXPRO trouble shooting w/I unit, found hydraulic bypass valve open, closed same & attempted to RIH with cutter and could no get through. EXPRO supplied x -over with cutter, (cutter od + 2.75" ID of x -over 2.69"). L/0 cutter broke subs on top of TIW valve. Strip CCL thru & pump in sub and x -over subs cutter and run same in tbg. Lower pack off and subs. M/U same. RIH with chemical cutter & CCL, tagged @ 9,840', logged up to 9,600'. RIH to 9,840' and tagged again. P/U to 9,835' WLM and cut tbg. POOH with a -line and L/O same. Pull hanger to rig floor. 07/14/14 - Monday BREAK OUT HGR AND LAYDOWN SAME. POOH W/4-1/2" 563 PROD TBG LAYING DOWN AND STRAPPING SAME. SERVICE RIG & PERFORM SAFETY COMPLIANCE CHK. CONT' TO POOH & L/D 4-1/2" HYD 563 PROD TBG. CLEANING & STRAPPING SAME. CONT' TO POOH & L/D 4-1/2" HYD 563 PROD TBG. CLEANING & STRAPPING SAME. L/D 331 FULL JNTS PLUS 6.72' CUT JNT. TOTAL LENGTH OF TBG W/ CUT JNT = 9,762.46'. R/D MCCOY TONGS & R/U FOSTER TONGS. SWAP ALL PHE T/ 3- 1/2", DRESSED FOSTERS FOR SAME. CLEAN & CLEAR RIG FLOOR, SET BACK AREA, & PIPE RACK. P/U & M/U 4-3/4" drill collars and 3-1/2" PH -6 work string while waiting on Knight fishing tools, concave mill, cut lip guide with cut rite. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -34A 50-733-20225-01 1 178-011 7/11/14 1 8/25/14 Daily Operations: ` 07/15/14 -Tuesday SERVICE RIG AND SAFETY COMPLIANCE CHECK. M/U (6) 4-3/4" SPIRAL DC'S AND RACK IN DERRICK. STRAP, RABBIT AND CALIPER SAME. M/U 5.938" CONCAVE MILL, (6) 4-3/4" DC'S AND JARS AS PER KNIGHT TOOL REP. TIH W/3-1/2" PH6 AND MILL ASSY. BHA = 5.938" OD CONCAVE MILL, BIT SUB OIL JAR, (6) 4.750" D/C, ACCELERATOR JAR, X -OVER, TOTAL LENGTH OF BHA #1 = 217.44'. CONT' TO TIH OUT OF DERRICK W/ 3-1/2" PH6 & MILL ASSY. CONT' TO TIH P/U SINGLES F/ V -DOOR. STRAP & DRIFT SAME. TAG TOF @ 9,852' DPM. P/U POWER SWIVEL & R/U SAME. GET DRILLING PERIMETERS. P/U=102K, S/0=90K, R/W=92K, TORQ=5500 FT/LBS @ 50 RPM. BROKE CIRC IN REVERSE @ 2 BPM W/170 PSI. MILL DOWN FROM 9,852' TO 9,853', REVERSE OUT 1 WORK STRING VOLUME @ 2 bpm 140 psi. L/D SINGLE & ATTEMPT TO R/D SWIVEL. WELL U -TUBING. M/U SWIVEL TO STRING & CIRC 70 BBLS LONG WAY TO BALANCE FLUID. CHECK WELL FOR U -TUBE "OK". L/D POWER SWIVEL & PREP TO POOH. POOH W/ 3-1/2" PH6 & MILL ASSY. 07/16/14 - Wednesday POOH with 3-1/2" PH -6 work string and milling assy. B/O & L/O BHA # 1 ( JARS & MILL). P/U & M/U BHA #2 5.750" OVER SHOT WITH 4-1/2" GRAPLE, 4.750" OIL JAR (6) 4. 750" D/C, 4.750" ACCELERATOR JAR, 3.50" PH -6 BAX X 3.50" IF PIN X- OVER--- 217.09'. RIH WITH BHA #2 TO 9,352'. SLIP & CUT 100' OF DRILL LINE. RECALIBRATE CROWN-O-MATIC AND TEST SAME. FINISH RIH TO 9,852'. P/U AND R/U POWER SWIVEL. P/U WT. = 98K, S/O WT = 79K, ROTATING P/U = 88K. S/0 TO 9,852' AND TAGGED WITH 19K DOWN ON FISH. P/U TO12K OVER P/U WT ATTEMPTED TO ROTATED 6 AT 8 ROUNDS TO THE RIGHT WHILE WORKING PIPE ATTEMPTING TO ROTATE OUT ANCHOR OF PACKER W/O SUCCESS. JARRED ON FISH WITH 42-45 OVER P/U WT 5 TIMES AND ATTEMPTED TO ROTATE ANCHOR OUT W/O SUCCESS. ATTEMPTED TO ROTATE OVERSHOT FREE BY TURNING TO THE LEFT AND BACKED OUT 3-1/2" PH -6 WORK STRING. WHEN WORK STRING BACKED OUT BLOCK AND POWER SWIVEL JUMPED UP APPROX. 2' THROWING DRILL LINE OUT OF SHEEVE AT CROWN. R/U TO HANG OFF BLOCK AND POWER SWIVEL TO GET DRILL LINE BACK IN SHEEVE. 07/17/14 - Thursday Rig up and pull slack on drill line and put back in sheave. Rig down lines. Slip and cut 900 ft of drill line to remove two bad spots in line. Rigging down hanging lines from block. Cleaning rig and change out starter on power swivel. Break out power swivel and out same. Calibrate setting on draw works and set crown-o-matic with drill line (OK ). Pooh w/ PH -6 work string and racking back in derrick ( strapping pipe ) checking connections on middle breaks. With rig tongs lay btm single ( had bad threads on pin end ). Make up 8-1/8 over shot and x/over w/ 4.75 grapple on 3.5 PH -6. Trip in hole with workstring to 870'. P/u and space out w/ tow 10 ft pups. Tag fish at 894', engage fish and work overshot over same and latch. P/up power swivel, make up same torque string to 6k ft/lbs working pipe up to p/up weight of 98k lay out power swivel and ( 1) 10 ft pup. Held prejob meeting. Rigging up E -line lubricator, attempt to test lubricator to 2500 psi pack off leaking. Rig down lubricator, change out pack off. PM Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -34A 50-733-20225-01 1 178-011 7/11/14 8/25/14 Daily Operations:` 07/18/14 - Friday Continue rigging up E -line and lubricator, unable to get a test on lubricator. Change out pack off, still unable to test to 2500 psi. Rigging up grease head, P/u lub test 2500 psi ( ok ). Ran in hole w/ 1.75 CCL tool string tagging up at 9,856' ELM. Pooh w/ CCL. Make up 1.75 Drill Collar Severing tool w/ CCL. RIH tagging at 9,861' ELM, pick up to string wt - fired cutter had indication of cutter firing but no pipe movement. Work tool string free, pooh, cutter fired. R/d E -line. Pulled 140k several times, jarring at 140k, pipe not free. R/u power swivel torque pipe to 6k and work same f/ 130k to 80k several times with no success. R/D power swivel, jar on pipe at 170k twice pipe came free. Pooh w/ 14 stds and lay out over shot and bad jt. Pooh w/ work string having to brk connections w/ rig tong. 86 std at rpt time. 07/19/14 -Saturday Held JSA, and pre job meeting. Serviced rig. POOH with 3.5 PH6 work string, having to break some connections with rig tongs due to pipe being torqued up. POOH with BHA, layout oil jars and overshot, no recovery of fish. Left hand grapple from overshot was missing, overshot was slightly swollen. Make up BHA #3 6" concave mill w/ 2 boot bskts w/ Double Box Xover w/ Oil jar and 6- 4 3/4" drill collars, accelerator jars, x over, total BHA 227.98'. TIH with 3.5" PH6 work string. Install stripper head and pickup power swivel, mill on fish from 9,853' to 9,856' DPM, 85 SPM, 450 PSI, torque 6500, rev circ two dp vol. - U -tubing. Continue circulating. Check well, static. Rig down power swivel and stripper rubber flange. Start POOH with 3.5 PH6 work string. 07/20/14 -Sunday Service rig and held JSA. Continue pooh w/ 3.5 workstring and 6" mill assembly. Change drag blocks on Foster tongs. Continue pooh w/ milling assembly. Rack back drill collars and lay down mill. Pull wear bushing, make up test plug. Test bops and related surface to 250 psi and 2500 psi w/ 3.5 & 4.5 pipe, held each test 5 minutes. Test made w/ FIW. Witness waived by Mr. Jim Regg on 7-18-14 at 10:08 AM. Rig down test equipment and install wear bushing. Trouble shooting draw works, unable to reset system from being down due to service on engine. Make up 5 3/4" packer burning shoe BHA assy. Start TIH with 3.5" PH6 work string. Power tongs not working properly, change out with foster tongs. 07/21/14 - Monday Held pre -job meeting and service rig. Continue to TIH w/ packer shoe assembly. Change -out back up foster tong dies. Cont. TIW with 3.5" D.P. with 6" packer shoe, tag TOF @ 9,856' DPM. R/U stripper head and P/U power swivel. Establish circ rate and PSI. Layout power swivel to tighten swivel packing due to leaking. Pick up power swivel make connection establish circ rates circ @ 4 BPM 620 PSI rotate and wash down from 9,865' DPM to 9,881' torque 6-7k RPM 60. Cont milling from 9,881' to 9,896' DPM, 1-2 WOB, 3 BPM, 730 PSI, 6500 to 7500 torque, RPM 60. Lay down power swivel. Pump 10 bbls 8.7 down TBG due to U -Tubing with no success. Rev circ while trouble shoot draw works. Reset block weight. Change out power tongs and r/d stripper rubber flange. Start POOH with 3.5 PH6 work string. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-34A 50-733-20225-01 1 178-011 7/11/14 8/25/14 Daily Operations: 07/22/14 - Tuesday Held pre job meeting & JSA. Service rig. Continue pooh w/ workstring, work BHA (SHOE 100% WORN OUT). Made up new shoe and TIH w/ work string tagging at 9,865' top of tbg stump. Rigging up stripper head & picking up power swivel. Working and reaming down over tbg stump f/ 9,865' to 9,890' swapping circ directions due pipe trying to plug. Milling on packer f/ 9,890' to 9,898'. 07/23/14 - Wednesday Cont burning on PKR 9,898' DPM. P/U off bottom & CIRC 315BBL @ 4.5 BPM due to U-Tube. Shut down pump, well static. L/O single. Rig down power swivel & stripper head. POOH with 6" PKR shoe ASSY. Work BHA. Clear and clean rig floor and prep to TIH. Make up over shot BHA with 4.5 spiral grapple ( BHA Overshot w/ 4.5 spiral grapple, oil jar, 6 - 4-3/4 drill collars Acc jars, x/o = 215.80 ). TIH with 3.5 PH work string to 9,840' DPM. Change out elevators & pick up single jt. Attempt to latch onto fish with no success. PU power swivel & attempt to latch fish rotating & setting 25K down on fish several times (no indication of latching to fish no over pull). Lay down power swivel. Start POOH with 3.5 PH6 work string. 07/24/14 - Thursday Service rig and perform safety and compliance check. Cont POOH with 3.5 PH6 workstring, overshot and possible fish. L/O acc jars, rack back drill collars. Recovered 5.3ft, 4.5 prod tubing. Shuck fish and L/O overshot. Clear and clean rig floor and prep to TIH. Make up 6" concave mill assy. TIH with mill assy on 3.5 PH6 workstring. Finish TIH with mill assy on 3.5 PH6 workstring to 9,852' DPM. Make up stripper head flange and pickup power swivel. Tag TOF @ 9,866' DPM, mill down to 9,868' DPM, rev circ 2 drill pipe vol, pump 10 bbls of 9.4 PPG down drill pipe due to u-tubing. Lay down power swivel & stripper head. Start POOH with 3.5 PH6 work string. 07/25/14 - Friday Service rig and perform safety and compliance check. Cont POOH with 3.5 PH6 workstring. L/O acc jars, rack back DC and L/O concave mill assy. Dress overshot with 4.5 grapple. P/U overshot assy and TIH with same on 3.5 PH6 workstring. Change out elevators to 150 ton. P/U single and PUP, tag fish @ 9,868' DPM. Latch fish, pull to 94K, jarred one time, fish started moving. Pull up 10' with 72K over, slacked off, laid out / space out pups, pulled up 28' and lay down single. P/U 15' fish, moving, pick up wt @ 168K, 90K over, pipe sling shot out of hole. The drill line jumped 2 sheaves @ crown. Put drill line back in sheaves @ crown. Change out drill spool and reset crown o matic (ok). Change out drill line in derrick, Superior came and inspected sheaves @ crown (ok). Checking calibration on drill line sensor. PM Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -34A 50-733-20225-01 1 178-011 7/11/14 1 8/25/14 Daily Operations: 07/26/14 - Saturday Latch onto pipe, picked up work string, had weight indicator reading of 21k, minus block weight of 8k =13k string weight. Pooh, recovered 1,739 ft of pipe, pipe was corked screwed and discolored, weight of string should have been 22,433k plus block weight indicator should have read 30,433k when latched onto string. Laid down bad pipe out of derrick in singles. Pick up singles off deck, racking back in derrick while, waiting on replacement string. Called for load cell for drill line anchor. Hang block off and respool drill line. Check draworks hold down bolts & cleaning rig. Waiting on replacement load cell for drill line anchor. 07/27/14 -Sunday Held pre job meeting & JSA. Cleaning rig & decks. Pick up 3.5 work string off deck. Drift, tally, RIH 30 JTS @ a time and pooh racking back same. Pull wear bushing and rig up testing equipment. Test BOP'S & related surface equipment to 250 psi low and 2500 psi high. Test made w/ FIW held 5 minutes. Louis Grimaldi, AOGCC, waived witness @ 09:31 on 7-27-14. Rig down test equipment and install wear bushing. Cont pick up new 3.5" PH6 workstring drifting and tally same. RIH 30jts at a time. POOH racking back in derrick. 07/28/14 - Monday Held pre job and meeting. Continue to pick up 3.5 workstring off deck, racking back in derrick. Hang off block and the replacement load cell for drill line anchor. Received the wrong load cell for the rigs drill line anchor. Omron tech trouble shooting rig computer system. Call for another load cell. Waiting on replacement. Install replacement load cell & Quadco sensor on drill line and calibrate same. PU 8 1/8" overshot BHA with 3.5 basket grapple. TIH with 3.5 PH6 workstring tag @ 1,790' DPM (latch onto fish), pull 45K over several times. Pickup power swivel, attempt to release bottom overshot with 6.5K torque while working pipe with no success. Move equip around on deck and spot a -line. Start rig up same. 07/29/14 -Tuesday Service rig and perform safety and compliance check. PU lubricator and M/U 2.11 gauge ring. Test lubricator @ 250OPSI (pack off leaked). Worked on pack off then retested @ 2500 PSI (ok). RIH with 2.11 gauge ring on a -line tagged FILL @ 9,811' ELM POOH with same. Change 2.11 gauge ring to 2.60 gauge ring. RIH with same tagged @ 9,652' ELM ( TOP OF BHA ). POOH with 2.60 gauge ring, break 2.60 gauge ring and M/U 2.5 jet cutter. Arm and RIH with same, tagged at 9,652' ELM, pull 132K on workstring. Recorrelated and cut pipe at 9,640' ELM. POOH with 2.6 jet cutter on a -line. R/D lubricator and equip. POOH with 3.5 PH6 workstring and fish with 117K pickup. Lay down 8 1/8 overshot and shuck fish from overshot. POOH with damaged 3.5 PH6 workstring and cut jt and laydown same. Load out damaged 3.5 PH6 workstring on work boat. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -34A 50-733-20225-01 1 178-011 7/11/14 1 8/25/14 Daily Operations: 07/30/14 - Wednesday Back load boat w/ work string. Making up 8.125 overshot dressed w/ 3.5 normal catch basket grapple. Continue to make up overshot. Trip in hole w/ pipe out of derrick, finish picking up pipe off rack, drifting same, having to drop bolt on top of rabbit due to scale in pipe. Make up stripper head flange and pickup power swivel. Cont pickup 3.5 PH6 workstring with power swivel and tag fish @ 9641 DPM pick up 119K, s/o 90K. Work down over fish to 9652 DPM, jar on fish 170K 3 times (50K over) fish came free with 10K extra weight, laydown power swivel and r/d stripper head flange. POOH with 3.5 PH6 workstring, slow and easy on and off slips. 07/31/14 - Thursday Lay out overshot, lay out fish ( Recovered the 18 ft ph6 tbg, x/o, jars, 6 drill collars, jars, jars, top bushing overshot & 23 ft of 4.5 tbg), Shuck fish from both overshots and clean decks. M/u BHA ( Flat btm mill, junk basket, junk basket, bit sub, bumper jar, oil jar, 4 drill collars, jar, x./o = 175.73 ). TIH to 9,859' and tagged at 7" liner top- used rig tongs to rotate past TOL. Continued in hole. Stopped at 9,885' and mounted stripping head w/ adapter flange. P/U swivel w/ jt# 313 and installed stripping rubber then M/U to string (122k P/U- 86k S/O). Began circulating in rev at 3 BPM 500#s rotating at 85 RPMs 6200 FPT. Washed 2' of fill before tagging tbg stub at 9,897'- had to rev circ several times when we saw signs of plugging. Milled down to 9,900'. Picked up off btm 2' and reversed two tbg volumes to flush tubing. Shut down pump. Well static. Rigging down power swivel. 08/01/14 - Friday Held pre job meeting and JSA. POOH W/ MILL, having to break out several joints w/ B.J. tongs. Lay out mill. 40% worn, recovered 25 lbs metal and cuttings from boot baskets. Make up packer burning shoe. Making up BHA (4-7/8 rough ID x 6" type D packer shoe, wp ext, top sub, bumper jar, oil jar, 4 drill collars, jar, x./o = 173.38. Trip in hole w/ packer burning assembly and tagged liner top at 9,959'. Laid out single then P/U swivel + single- rotated thru liner top with minimal effort. Established parameters (122k P/U- 86k S/O, 3 BPM @ 420 #s in rev, swivel free torque = 5600 ft#s ). Tagged (cut- over) Baker pkr at 9,897.5' (DPM) to 9,899 ft. 08/02/14 - Saturday Milling on packer to 9900.5 dpm, adjusting weights on shoe f/ 8 to 12k wob adjusting rpm f/ 60 to 80 rpm, (122k P/U- 86k S/O, 3 BPM @ 420 #s in rev, swivel free torque = 5600 ft#s ). Rigging down power swivel and stripper head. Pooh to change out shoe. B/D BHA- burning shoe 100% worn. M/U fresh 6" x 4 7/8" SOD RID 4 -pad pkr type burning shoe. Laid down jar/shoe assembly. Clean and organize rig floor. Began testing all BOP equipment as per HAK & AOGCC procedure (w/ FIW 250/low 2500/high held for 5 mins) Mr. Jim Regg waived Bop test witness on 8-1-2014 10:05 AM. Test made w/ 3.5 & 4.5 pipe. I/ Hilcorp Alaska LLC Well Operations Summary Well Name =API Number Well Permit Number Start Date D -34A LEndCate 50-733-20225-01 178-011 7/11/1425/14 Daily Operations: 08/03/14 - Sunday Rigging down test equipment and install wear bushing. Make up BHA #11 ( Type D packer shoe, wash pipe ext, top bushing, Bumper jar, oil jar, 4 4-3/4 drill collars, acc jars, x.o = 173.32 ). Trip on hole to 9828 ft dpm. Rig up power swivel and stripper head. Establish parameters and Burning over packer at 9900 ft.w/ 80 rpm 5500/ 6000 ft lbs, 2/4 wob, 460 psi at 3 bpm. Varied RPMs, weight and pump rate while trying to re -cut over pkr. Pkr turned loose- followed same downhole to end of jt. Circulated 2 tbg volumes in reverse to clean tbg and check for gas bubble. Pushed pkr downhole another 8' before it stopped going down- set 40k down without moving. Top of pkr at 9,922'. B/O 2- singles and laid down swivel. Removed stripping head and adapter flange. POOH w/ BHA #11 (burning shoe & jarring assembly). 08/04/14 - Monday Held PTSM- Serviced rig and performed safety compliance check. Continued POOH w/ BHA #11 (rotary shoe assembly). B/D BHA- rotary shoe 100% worn. M/U (BHA #12) 5 7/8" Bowen Ovs w/ short cutlip guide dressed w/ 4 7/8" spiral grapple and type 'A' packoff, 3' upper ext, top sub, 4 3/4" x 2 1/4" B & 0 jars, 4 3/4" x 2 1/4" DCs x 4, A jar, xo. TIH to 9,877'- installed stripping head w/ adapter flange and P/U power swivel w/ single. M/U to string (w/ rubber in place). Eased down thru top of liner and started circ down tb @ 2 BPM 170 PSI rotating slowly. Did not find top of fish at 9,922' - continued in hole searching for fish. Tagged at 10,488'- pressured increased to 600#s when overshot covered fish - latched same and picked up on string w/ 8k overpull. Set back down several times to insure latch on fish- pulled 3 jts wet then ruptured pump out disk at 2200#s- laid down swivel. POOH w/ ovs/ jarring assem + fish, easy on/ easy off slips. 08/05/14 - Tuesday Serviced rig and performed safety compliance check. Continued POOH w/ BHA #12 (overshot & jarring assembly + fish). B/D BHA and recovered milled over Baker'S' pkr + tailpipe assembly (52.93' long). Cleared and cleaned rig floor- prepped for next BHA M/U. M/U BHA #13 (8 1/2" Rock bit, M&M scraper f/ 9 5/8", bit sub, xo, magnet, Bowen B & 0 jar, DCs x 4, Bowen Ajar, xo). TIH w/ bit & scraper on 3 1/2" PH6 workstring at 150'/min. Stopped at 8,942' (17' from top of liner - DPM) (P/U 122k S/0 91k) - R/U lines to displace dirty FIW w/ clean FIW in rev to Trading Bay. Eased into pump to 2 BPM 240#s (sending to TB). Setup for caliper log and finished cleaning fluid tanks. V Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -34A 50-733-20225-01 178-011 7/11/14 8/25/14 Daily Operations: 08/06/14 - Wednesday CONT DISPLACE WELL WITH 8.5# FIW @2BPM 235 PSI, UNTIL RETURNS CLEAN. ALL RETURNS GOING THRU PRODUCTION HEADER TO TRADING BAY. TOTAL BBLS PUMPED=745. BLOW DOWN CIRCULATING LINES AND RIG DOWN SAME. POOH W/3-1/2" PH6 AND 9-5/8" SCRAPER ASSY. BREAK AND LAYDOWN BIT/SCRAPER BHA. R/U E -Line w/ full lubricator flanged up to 11" 5. M/U 2 3/4" Multifinger Imaging Tool w/ roller centralizers top & bottom, GR, wt bar, cable head. Pulled inside lubricator and tested against blinds to 500#s. Opened well and TIH to 9,980' (WLM) (300 FPM) w/ Gamma Ray/caliper tool- recorded casing caliper (@50 FPM) to surface. Pulled inside lubricator and closed blinds. R/D ELine. Correction to liner top at 9,859' put TD reached at 9,999'. Removed 11" adapter flange and changed out McCoy tbg tongs to Fosters. M/U 8.25" RTTS pkr and circ valve. TIH w/ test pkr at 30 sec/ stand. 08/07/14 - Thursday Held pre job meeting and JSA. CONT TIH SLOW W/3-1/2 PH6 AND RTTS TO 9,848' DPM. P/U AND R/U POWER SWIVEL. SET RTTS @ 9,850' DPM. SET DOWN 20K. R/U TEST EQUIPMENT AND TEST CASING TO 2500 PSI FOR 30 MINUTES ON CHART DATED 8-7-2014 TOOK 6 BBLS TO PRESSURE UP. MONITOR THE 9-5/8 X 13-3/8 CSG ANNULAS DURING TEST, INITIAL PRESSURE 22 PSI, FINAL PRESSURE 22 PSI. R/D TEST EQUIPMENT/UNSET RTTS AND RIG DOWN POWER SWIVEL. POOH SLOW W/3-1/2" PH6 AND RTTS. B/D L/O RTTS tool and circ sub- all components intact. Slipped and cut 95' of drill line - recalibrate crown-a-matic. M/U BHA #14 (5 3/4" x 4" crippled type 'I' rotary shoe w/ flapper valve (SOD SID), WP ext, top bushing, B. jar, 0. jar, DC x 4, A. jar, WS xo). TIH w/ cripple shoe (107 stands @ 0600 hrs = 6,665'). 08/08/14 - Friday Serviced rig and conducted safety compliance check. Continued TIH w/ Knight BHA #13 (crippled shoe w/ flapper valve and jarring assembly) to 10,412' (DPM). Installed stripping head and P/U power swivel. M/U single w/ stripping rubber and screwed into string. Broke circ and reversed out 1 tbg volume @ 3 BPM 350#s PSI. Rotated and washed down from 10,412' to 10,507' pumping 3 BPM 350#s PSI. 4-5k torque at 10 RPMs circulating now at 4 BPM 700#s PSI (circulated btm's up every 30 mins) - could not get deeper. Reversed out @ 4 BPM 700#s until returns cleaned up. POOH. B/D BHA #13 - recover — 10#s of metal fragments, scale and 6" cement core out of 5 3/4" shoe w/ flapper and extension assembly. M/U BHA #15 (6" x 1.5" 'Chomp' bit, boot baskets x 2, bit sub, B. & 0. jars, DCs x4, A. jar & WS xo). TIH to drill out 25' of cement + EZ Drill CIBP. Depth at rpt 9323 dpm. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -34A 50-733-20225-01 1 178-011 7/11/14 1 8/25/14 Daily Operations: 08/09/14 - Saturday Serviced rig and performed safety compliance check. Continued TIH w/ BHA #15 (chomp bit w/ jarring assembly) to 10,480' (DPM). N/U adapter flange and stripping head assy. P/U power swivel and M/U single + stripping rubber. Screw into string and install rubber. Continued in hole circ 3 BPM 350#s to 10,507'- tagged cement. Drilled out cement from 10,507' to top of CIBP @ 10,554' reversing btm's up every 15' of hole made (70 RPMs, 5-6k torque, 1-3k WOB, 3 BPM 450#s, 100% returns). Circulated at 4 BPM 550#s until returns cleared of all cmt. Turned on EZDrill CIBP at 60 RPMs, 6-7k torque, 2-3k WOB, 3 BPM 350#s making 6" of hole. Decision was made to pull bit when ROP fell to zero (small chips of steel, brass and cast iron in returns). Circulated hole clean @ 4 BPM 550#s. L/D power swivel and 2- singles. N/D adapter flange w/ stripping head. Pulled OOH w/ 166 stands + BHA. Switched to McCoy tongs at 1930 hrs. B/D BHA and cleaned out boot baskets. Recovered — 2#s of CIBP pieces from bit ports and baskets. Cleared and cleaned floor. Pulled wear bushing and installed test plug. Tested BOPE as per AOGCC & Hilcorp procedure. 250#s low/ 2500#s high. Witness waived by James Regg, AOGCC 4:12 PM 8/8/14. 08/10/14 - Sunday Continued testing 11" x 5M BOPs and surface equip as per AOGCC & Hilcorp procedure - 250#s low / 2500#s high charted - tested 3 1/2" & 41/2" pipe sizes. Tested from main and function tested remote. Performed accum drawdown test also. Witness of test waived by Jim Regg, AOGCC 8/8/14 4:12 PM. R/D test equipment and installed wear bushing. M/U 6" Varel rock bit, 5" boot baskets x 2, bit sub, B. & 0. jars, 4 3/4" DCs x 4, A. jar, WS Xo (BHA #16). TIH to 10,503'. Installed 11" x 5M adapter back to stripping head. P/U power swivel w/ single #334 + rubber and M/U to string. Landed rubber. Broke circ (in reverse) at 3 BPM 400#s, started rotating at 60 RPMs 5200 FPT, 137k, P/U 96k S/0. Eased down hole and tagged at 10,554'. Drilled on EZDrill CIBP until it turned loose ( after making — 1 Ft of hole ). Reversed out two tbg volumes to clean tbg and check for gas. Pushed CIBP down to 10,619' (DPM) with no resistance and put 5k wt down. No plug movement. Reversed 11/2 tbg volumes around at 4 BPM 550#s. B/O L/D power swivel and N/D 11" x 5M stripping head adapter. POOH w/ BHA #16 (6" bit & jarring assm)- 22 stands OOH at 0600 hrs = 9,260'. 08/11/14 - Monday Service Rig and held JSA. Continue to pooh w/ 3.5 ph6 work string and 6" bit. Lay out bit and clean floor. Make up 5-3/4 mill, BHA, Trip in hole w/ 5-3/4 mill to 10,598'. Installed 11" x 5M stripping head adapter- P/U power swivel + single w/ stripping rubber. M/U to string and landed rubber. Began rev circ at 3 BPM 420#s and rotating at 80 RPMs 5300 FPT- P/U 131k S/0 98k. Eased down and tagged at 10,619'. Began milling on remainder of EZDrill CIBP. Had to turn circ around several times and work pipe due to plugging. 2225 hrs Kelly down at 10,626' (pushing plug down)- circulated btm's up (rubber, steel & brass in returns). Continued pushing/milling plug downhole to 10,629' where it stopped solid. Turned for 2 hrs at this depth without making hole. Could not stall swivel. Nothing in returns. Picked up off btm and circ hole clean in rev 4 BPM 800#s. B/O L/D power swivel and N/D stripping head adapter. POOH w/ BHA #17 (Piranha mill). 15 of 168 stands OOH at 6 AM = 9,633'. 08/12/14 -Tuesday Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -34A 50-733-20225-01 1 178-011 7/11/14 1 8/25/14 Daily Operations: Serviced rig and performed safety compliance check. POOH w/ BHA #17 (5 3/4" Piranha mill). B/D BHA -mill 40% worn - recovered (possible) pieces of pkr mandrel wedged in mill throat and fiberglass backing from Weatherford casing patch in boot baskets. Clear and clean rig floor. Discuss forward ops w/ Engineers. Added feeler pins inside 5 3/4" rotary shoe. M/U BHA #18 (5 3/4" (slick) x 4 7/8" Pkr type'D' rotary shoe, WP ext, top bushing, B. & 0. jars, DCs x 4, A. jar, xo). TIH to 10,565'. Circulated CFS 520 in rev to end of tbg @ 3.5 BPM 600#s. N/U 11 x 5M stripping head adapter and P/U swivel + single w/ rubber. Screwed into string and landed rubber. Broke circ in rev @ 3 BPM 400 PSI - eased down to 10,629' and began turning on obstruction. Covered 2' and pressure started increasing. Changed direction of circ and continued attempting to make hole. Pressure increased to 1500#s, worked pipe and had 14k over pull - changed circ (rev) and had 100#s increase in pressure at same rate. Decision was made to circ hole clean and POOH to see if pkr was hung inside shoe. Circulating hole clean in reverse. 08/13/14 - Wednesday Service rig & continue pooh w/ 3.5 ph6 workstring and BHA. Work BHA - Recovered 1 ft - 9" piece of the ESVZ plug W/ pieces of slips and small pieces of metal and rubber. Clear and clean floor. Change out, make up dies in KT 5500 power tongs. M/U BHA #19 (same as #18 w/ fresh 5 3/4" x 4 7/8" SOD x RID pkr type 'D'4 -pad rotary shoe w/ feeler pins, WP ext, top bushing, B. & 0. jars, DCs x 4, A. jar, WS xo). TIH to 10,626'. N/U 11 x 5M stripping head adapter. P/U swivel + single w/ rubber and M/U to string. Landed rubber. Started circ in rev at 3 BPM 400#s, rotating 70 RPMs 4100 FPT. Eased down and tagged at 10,631'. Saw torque initially then started easing down hole with little resistance. TD reached was 10,653'. Pressure climbed to 700#s before pulling back up to 10,626' and circ btms up. Eased down and pressure started climbing again. Pulled back up and circ down tbg to clear obstruction @ 1100 PSI. Eased back to 10,648' with pressure climbing again (rev). Pulled back to 10,626' and circ hole clean, but maintained higher than normal pressure. Attempted to blow out obstruction again down tbg but failed. Turned circ around (rev) and went back to 10,653', pushed pkr down to EOJ at 10,655'. Made connection and made V of new hole (put 10k down w/o moving) = 10,656'. Pressure climbing. Decision was made to POOH to see what's has us restricted. Laid out single and R/D swivel. 08/14/14 - Thursday Serviced rig and performed safety compliance check. R/D swivel and N/D stripping head adapter. POOH slowly w/ BHA #19 (5 3/4" shoe & ext). B/D BHA and L/O shoe & extension- recovered — 40#s of metal. Clear & clean rig floor while discussing forward ops w/ engineers. M/U BHA #20 (6" SOD x 4 7/8" RID type'D' pkr rotary shoe, 5 3/4" WP x 1, top bushing, B. & 0. jars, DCs x 4, A. Jar, WS xo) = 195.70'. TIH to 10,584'. N/U stripping head adapter and P/U swivel + single #335 w/ rubber. M/U to string and land rubber. Establish circ in rev at 3 BPM 400 PSI, rotating at 80 RPMS 4100 FPT- 124k P/U 98 S/O. Eased down to EOJ at 10,615'w/ no trouble. M/U #336 and continue circ, rotating down to 10,640'. Worked thru tight spot and eased down to EOJ at 10,646'. M/U #337 and continued circ, rotating to 10,658', taking weight and torque. Pressure increasing, decreased pump rate to stay below 700#s- 0400 hrs at 10,662'. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -34A 50-733-20225-01 1 178-011 7/11/14 1 8/25/14 Daily Operations: 08/15/14 - Friday CONT REV/OUT 1 DPV @3-1/2 BPM 520 PSI (RETURNS CLEAN). R/D POWER SWIVEL AND LAYDOWN SAME. N/D STRIPPER HEAD. POOH W/3-1/2" PH6 AND BURNING SHOE BHA. B/D BURNING SHOE BHA & INSPECT SHOE. SHOE 80% WORN, FOUND 20 LBS OF CASING PATCH AND BODY -LOC -RING FROM SAB -3 PACKER INSIDE SHOE. M/U 6" BURNING SHOE W/4.8875" ID, OIL & BUMPER JARS, (1) JT WASH PIPE, SUPER II INTENSIFIER JAR AND (4) 4 -3/4" DC'S -TOTAL LENGTH OF BHA #21 = 195.64'. TIH W/3-1/2" PH6 AND BHA #21. Continued TIH to 10,649'. N/U stripping head adapter and P/U swivel + single #337 w/ stripping rubber. M/U to string and landed rubber. Established circ in rev at 3 BPM 420 PSI - rotating at 80 RPMs 4200 FPT- P/U 124k S/O 98. Eased down and tagged at 10,662'. Began milling on obstruction. Milled from 10,662' to 10,671' in 30 mins. Tbg plugged, swapped valves and unplugged tbg with 800psi. Attempted to mill deeper w/o success. Reversed hole clean, had a total 120 lbs of metal recovered in returns. B/0 L/D swivel and N/D adapter w/ stripping head. POOH. 08/16/14 -Saturday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH W/3-1/2" PH6 AND BURNING SHOE BHA. BREAK DOWN BHA. LAY DOWN BURNING SHOE AND INSPECT SAME. (70% WORN ). SLIP AND CUT 108' DRILL LINE. RE -CALIBRATE BLOCK & CROWN SAVER. CHECK SAME "OK". WASH/CLEAN RIG FLOOR. M/U 5.875 OVERSHOT DRESSED W/4.750" SPIRAL GRAPPLE, OIL & BUMPER JARS, SUPER II JARINTENSIFIER AND (4) 4-3/4" DC'S. TIH W/3-1/2" PH6 AND OVERSHOT BHA TO 10,623'. N/U STRIPPING HEAD ADAPTER. P/U SWIVEL W/ SINGLE #337 + STRIPPING RUBBER. M/U TO STRING AND LAND RUBBER. BROKE CIRC LW AT 2 BPM 160 PSI- 129K P/U 96K S/0- 2700 FT/LBS TORQUE. EASED DOWN TO 10,653'. M/U #338 AND CONTINUED IN HOLE ROTATING SLOWLY. TAGGED AT 10,671'. PRESSURE INCREASED TO 400#s. P/U AND BUMPED JARS SEVERAL TIMES TO INSURE BITE ON PKR. SET 20K DOWN. P/U AND HAD INTERMITTENT DRAG (AS MUCH AS 11K OVER + 120 PSI EXTRA PUMP PRESSURE). B/O L/D SWIVEL. N/D STRIPPING HEAD ADAPTER. L/D 1 JT OF 3 1/2" PH6 WS. POOH W/ BHA #21 (OVS/JARRING ASSEMBLY). 08/17/14 -Sunday CONT POOH W/3-1/2" PH6, O/S BHA AND FISH. BREAK DOWN OVER SHOT BHA AND LAY DOWN FISH. (TOTAL RECOVERY). STRAP FISH TOTAL= 62.67' (PKR, 2 X -NIPPLES, 1 PUMP OUT SUB, 1 PUP JT & 1 JT OF 3-1/2" TBG). P/U RETRIEVING TOOL AND PULL WEAR BUSHING. SET TEST PLUG AND R/U BOP TESTING EQUIPMENT. TEST 11" X 5M BOPS & SURFACE EQUIP. AS PER HILCORP & AOGCC SPECS, 250 LOW/2500 HIGH. TEST 3-1/2" AND 4-1/2". TEST FROM REMOTE AND FUNCTION MAIN. PERFORM ACCUMULATOR TEST "OK". WITNESS OF TEST WAIVED BY JIM REGG, AOGCC. PULL TEST PLUG, SET WEAR BUSHING. L/D RETRIEVING TOOL. R/D TEST EQUIP. & WASH/CLEAN R/F. M/U BHA #23 (6" X 2 1/4" CROSS -BAR JUNK MILL, 4 3/4" B. & 0. JARS, DCs X 4, 4 3/4" A. JAR, PUMPOUT SUB (SET AT 3800#s), WS XO SUB). TIH W/ BHA ON 3 1/2" 12.95# PH -6 WS. TAGGED AT 10,605'. LAID OUT SINGLE OFF TOP OF STAND. N/U STRIPPING HEAD ADAPTER. P/U SWIVEL W/ SINGLE + STRIPPING RUBBER. M/U TO STRING AND LANDED RUBBER. BROKE CIRC IN REV AT 3 BPM 400 PSI 127K P/U 94K S/0- 80 RPMs AT 4200 FPT. EASED DOWN AND STARTED MILLING AT 10,605'. TOOK 1 HR TO MILL TO 10,610' (METAL IN RETURNS) THEN BROKE THRU TO EOJ AT 10,618'. CIRC BTMS UP, CONTINUED WASHING DOWN TO 10,689' Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -34A 50-733-20225-01 1 178-011 7/11/14 1 8/25/14 Daily Operations: 08/18/14 - Monday ROTATE AND WASH DOWN FROM F/10,689'-10,694' DPM, PUMPING 3 BPM @400 PSI, RPM=70 TORQUE= 5-7K. UNABLE TO WORK DEEPER DUE TO PIPE TORQING UP AND STICKING. P/U TO 15-20K OVER TO FREE PIPE. CONSULT WITH ENGINEER, DECISION MADE TO DISPLACE WELL W/ CLEAN 8.5# F.I.W. & POOH. DISPLACE WELL W/8.5# F.I.W. @ 3 BPM 520 PSI UNTIL RETURNS CLEAN. ALL RETURNS GOING THRU PRODUCTION TO TRADING BAY. TOTAL PUMPED = 800 BBLS. L/D SINGLE, BLOW DOWN CIRC LINES. R/D POWER SWIVEL. LAY DOWN SAME & N/D STRIPPER HEAD. POOH W/3-1/2" PH6 & MILL ASSY BHA. B/O L/0 SAME. MILL HAD ABOUT 10% WEAR. CLEANED RIG FLOOR. HELD JSA. P/U & M/U 4-1/2" 5 SPF TCP ASSY & RA TAG SUB TOTAL LENGTH = 168.07'. _RIH WITH TCP ASSY TO 3,481' AND TAGGED UP WITH 3K DOWN P/U AND CONTINUED IN HOLE TO 3,491' AND TAGGED WITH 4K DOWN. P/U 17K OVER, GUNS CAME FREE. POOH SLOW WITH TCP ASSY. 08/19/14 -Tuesday CONT POOH W/3-1/2" PH6 AND TCP GUN ASSY. BREAK DOWN TCP ASSY AND LAY DOWN SAME. SERVICE RIG. WASH RIG FLOOR AND MONKEYBOARD. REVERSE CIRCULATING FINGER BASKET. M/U 8,125" W/6" ID FINGER BASKET, OIL/BUMPER JARS, SUPER II OIL JAR INTESIFIER & (4) 4-3/4" DCS TOTAL LENGTH = 169.58'. TIH W/3-1/2" PH6 AND JUNK BASKET BHA. TAG @4,059' DPM. P/U AND R/U POWER SWIVEL, MAKE CONNECTION. ROTATE AND WASH DOWN FROM 4,031'- 4,062' DPM, PUMPING 4 BBLS MIN, 500 PS I,RPM=70, TORQUE=2-3K. UNABLE TO WORK DEEPER DUE TO PIPE TORQING UP TO 5-6K. REV/OUT 2 DPV @ 5 BPM 600 PSI. GOT BACK A SMALL ABOUT OF FIBERGLASS COATING OFF OF CASING PATCH. CONT TIH TO 4,156' DPM WITHOUT ROTATING. RIG DOWN POWER SWIVEL. CONTINUED IN HOLE TO 7,447' AND TAGGED WITH 5K DOWN. WORKED THRU TIGHT SPOT AND CONTINUED N HOLE TO 9,830' DPM. R/U KELLY HOSE AND CONTINUE IN HOLE TO 9,859' DPM. REVERSED OUT 2 DPV @ 4BPM. RETURNS CLEAN. R/D KELLY HOSE. POOH SLOW WITH 3-1/2 PH -6 WORK STRING AND BASKET ASSY. 08/20/14 - Wednesday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH W/3-1/2" PH6 & FINGER BASKET ASSY. B/D FINGER BASKET ASSY & INSPECT SAME. NO JUNK RECOVERED. WASH/CLEAN RIG FLOOR. M/U BHA # 25---5.50" JUNK MILL W/SMOOTH O.D. ( 28 JTS ) 3-1/2" PH6 TBG, 8.50" WATERMELON MILL, OIL/BUMPER JARS, SUPER II JAR INTENSIFIER & (4) 4-3/4" DC'S, TOTAL BHA LENGTH = 1,051.92'. CONT TIH W/3-1/2" PH6, JUNK MILL BHA & 8.50" WATERMELON MILL. WORK MILL THRU PREVIOUS TIGHT SPOTS @ 4,059' DPM & 7,447' DPM, SEVERAL TIMES. CONT TIH 10,696.50'. RU KELLY HOSE AND REVERSE OUT 2 DP VOLUMES. RD KELLY HOSE AND POOH WITH BHA # 25. B/D UPPER SECTION OF BHA (STRING MILL, JARS & COLLARS) THEN FINISHED POOH W/ MILL. B/D L/O. DISCUSSED JSA AND M/U 4 1/2" 5 SPF 72* PHASE TCP ASSY - LDD 63'. INCLUDES SAFETY IMPACT MECH, 4- PUPS, PORTED SUB, XOs, 1- STAND PH -6, XO, RA SUB, XO, TIH RUNNING TCP ASSY ON 3 1/2" 12.95# PH -6 WORKSTRING, RABBITING SAME. DEPTH AT 06:00 = 1,987'. Hilcorp Alaska LLC Well Operations Summary Well Name =A11 Number Well Permit Number Start Date End Date D -34A 50-733-20225-01 1 178-011 7/11/14 1 8/25/14 Daily Operations: 08/21/14 - Thursday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT TIH W/3-1/2" PH6 AND TCP ASSY. DRIFTING PIPE OUT OF DERRICK. SPACE OUT TO RIG FLOOR BTM OF ASSY @ 10,675' DPM. R/D POWER SWIVEL UNIT AND HYDRAULIC HOSES. GENERAL RIG MAINTENANCE AND HOUSKEEPING. RU E -LINE AND TEST LUBRICATOR TOM 1500 PSI. SPOT E -LINE EQUIPMENT IN PLACE AND RIG UP SAME. M/U 1-11/16" GAMMA RAY / CCL. TEST LUBRICATOR TO 1500 PSI, OK. RIH W/E-LINE &CORRELATE GUNS ON DEPTH. GUNS 12' SHALLOW. POOH W/E-LINE. M/U PUP JTS AND REPOSITIOIN GUNS AS PER E -LINE LOG. R/U E - LINE. TEST LUBRICATOR TO 1500 P, OK. RIH W/E-LINE & 1-11/16" GAMMA RAY / CCL AND CORRELATE GUNS ON DEPTH. POOH W/E-LINE AND RIG DOWN SAME. DROP BAR & FIRE GUNS. TOP PERFS=10.611', BTMS PERFS=10674', 5 SPF. MONITOR WELL (STATIC). REV/OUT (2) DPV @ 3 BPM 475 PSI TO REMOVE GUN GAS AND DEBRIS. MONITOR WELL (STATIC). RIG DOWN CIRCULATING EQUIPMENT. POOH W/3-1/2" PH6 AND TCP ASSY. LAYDOWN WORKSTRING AND PLACE IN PIPE RACKS. 08/22/14 - Friday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH W/3-1/2" PH6 & TCP ASSY, LAYING DOWN WORKSTRING & PRESSURE WASHING SAME. BREAK DOWN TCP GUN ASSY AND LAY DOWN SAME. TIH W/3-1/2" PH6 AND (4) 4/4-3/4" DCS OUT OF DERRICK. POOH AND LAY DOWN SAME. CHANGE OUT 3 1/2" TBG ELEVATORS W/ 4 1/2" & R/U STABBING BOARD. HELD PJSM & REVIEW JSA ON P/U & TIH W/ 4 1/2" PROD TBG. M/U 8.125" PROD PACKER ASSY. P/U 4 1/2" TLP & TIH W/ 4 1/2" 4040 PROD TBG OUT OF V DOOR & TIH. STRAP & RABBIT SAME. BACK LOADING 3 1/2" PH6 WORK STRING & 4 3/4 " DC & 3 CARGO BAKKETS. CONT TIH W/ 4 1/2" TLP 4040 PROD TBG SLOWLY. 08/23/14 - Saturday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT P/U 4-1/2" TLP 4040 PROD TBG & TIH. STRAP AND RABBIT SAME. SERVICE RIG & COMPLIACE CHECK. CONT P/U 4-1/2" TLP 4040 PROD TBG & TIH. STRAP AND RABBIT SAME. TOTAL OF 311 JTS P/U WITH TOP OF 9 5/8" 36.53.5 # PACKER @ 9,823'. P/U M/U CAMERON 11" 5M DCD HANGER & 4 1/2" LANDING JT. SLACK OF & LANDED 11" 5M HANGER IN CAMERON 11" 5M DCD TUBING HANGER, RAN LOCK DOWN PIN IN 11" 5M CAMERON DCD TUBING SPOOL & INJECTED PLASTIC INTO HANGER VOID, TESTED VOID TO 5200 PSI HELD FOR 10 MIN. TEST OK. UP TO REVERSE OUT. REVERSING OUT W/ 1 TO 2 PERSENT INHIBERTER FLUID. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-34A 50-733-20225-01 1 178-011 7/11/14 1 8/25/14 Daily Operations: 08/24/14 - Sunday CONTINUE DISPLACE WELL WITH 8.54 F.I.W. WITH CORROSION INHIBITOR @ 2BPM 50 PSI TOTAL PUMPED = 583 BBLS DOWN CSG. R/D CIRCULATING HOSES. R/U S-LINE UNIT AND EQUIPMENT. M/U 2.80" GAUGE RING. TEST LUBRICATOR TO 1500 PSI. RIH W/S-LINE TO 9,870' SLM. POOH W/S-LINE. M/U 2.813" PX PLG. RIH W/S-LINE TO 9,829' SLM AND SET PLUG. POOH W/SLINE. M/U PRONG & RIH W/S-LINE TO 9,829' SLM AND SET SAME. PRESSURE UP ON TBG WITH RIG PUMP TO 3100 PSI TO SET 9 5/8'_' 36-53.5# HYDRAULIC PACKER. R/U HOSES TO TEST PKR. PRESS UP ON CSG TO 1500 PSI HELD ON CHART FOR 30 MIN. (NO TEST). LINE UP & PUMP DOWN TBG TO CHECK FOR COMMUNATION BETWEEN TBG & CSG. MADE 4 ATTEMPTS W/O SUCCESS. ALSO BYPASSED ALL MANIFOLDS AND RAN LINES DIRECT TO CSG. NO SUCCESS. PRESSURED UP ON TBG TO 2500, CSG = 120 PSI PRESSURE DROPPED TO 2300 CSG = 160 PSI, 2250 TBG, CSG=170 PSI. POOH W/ E-LINE & R/D SAME. BACK OUT & L/D LANDING JT & SET CAMERON 2 - WAY CHECK VALVE IN 4 1/2" PROD. TBG. P/U M/U TEST JT & TEST EQUIPTMENT. TESTING BOP TO 250 LOW 2500 PSI HIGH. WITNESS OF TEST WAIVED BY JIM REGG, AOGCC. 08/25/14 - Monday FINISH TESTING BOPE AS PER HILCORP & AOGCC SPECS. PULL 2-WAY CHECK. R/U E - LINE. M/U 2.80" PRONG. TEST LUBRICATOR TO 1500 PSI "OK". RIH W/ E-LINE TO 9,829' SLM. R/U TEST HOSES, JUG TEST CSG & TBG TO 2500 PSI FOR 30 MIN. "OK" BLED OFF PRESSURE. REMOVE PUMP LINE FROM TBG & PRESSURE UP ON CSG TO 2500 PSI, NO SUCESS, MADE SEVERAL ATTEMPS. R/D TEST HOSE F/ ALL CIRCULATING LINES & MANIFOLDS. M/U LINES DIRECTLY TO CSG VALVE FROM MUD PUMP, PRESSURE UP TO 2500 PSI ON CHART HELD SAME FOR 30 MIN. BLED BACK 100 PSI. PRESSURE UP TO 2590 PSI ON CHART FOR 30 MIN, BLED BACK APPROX 110 PSI. CONSULT W/ HILCORP ENGINEER WAS DETERMINED THAT TEST WAS GOOD. R/D TEST HOSES & EQUIPTMENT. POOH W/ E-LINE & PRONG. M/U 2.80 PX PLUG RETRIEVING TOOL RIH & RETRIEVE 2.815 PLUG POOH W/ SAME. R/D E-LINE. BACK OUT LANDING JT & INSTALL BACK PRESSURE VALVE IN TBG HANGER. ASSIST ELECTRICIANS TROUBLE SHOOT ELECTRIC MOTOR FOR DRAW WORKS. REMOVE FLOOR PLATES & BEAMS. R/D KOOMLY HOSES. N/D BOPE STACK & RISER. R/D POLUTION PAN. P/U & N/U 4" 11" 5M PROD TREE. SWITCH BACK PRESS VALVE W/ 2 WAY CHECK VALVE. ATTEMPT TO TEST PROD TREE WITH WATER & 2 WAY CHECK LEAK. PULL 2 WAY CHECK & CHANGE SEALS ON SAME. RETEST PROD TREE TO 5000 PSI, HELD TEST FOR 15 MIN TEST GOOD. PREP RIG TO SKID. R/D STAIRS, WALK WAY, V-DOOR & R/U TOP & BOTTOM SKID JACKS. ,, ,,\\ I%%/ g THE STATE ,cz F ' '3 11,11--_ 1 - 333 West Se Tenth ASE sue .A (30V I?R<,OR S I -1i PARNEI E i.l, Anchcrc:r.e, Alaska 99501 35/2 � (BMom 907 270 1433 Dan Marlowe %WV AUG 1 4 2D14 — i ' Operations Engineer �� Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, Trading Bay Unit D-34A Sundry Number: 314-350 Dear Mr. Marlowe: 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, ,a/i/— Daniel T. Seamount, Jr. Commissioner DATED this /l9day of June, 2014. Encl. 4RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 0 3 2014 APPLICATION FOR SUNDRY APPROVALS yy��� �� 29 AAC 25.280 A 1.Type of Request: Abandon 0 Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate© Pull Tubing E Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate 0 Alter Casing❑ Other. Complete E 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC • Exploratory ❑ Development ❑ 179-011 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service E. 6.API Number: Anchorage,AK 99503 50-733-20225-01 • 7.If perforating: n� 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? {o{" .ZaI A y Will planned perforations require a spacing exception? Yes 0 No V Trading Bay Unit/D-34A• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018729 McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): • 11,285 • 9,960 •11,185 •9,872 None None Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate 2,080' 13-3/8" 2,080' 2,012' 3,090 psi 1,540 psi Production 10,295' 9-5/8" 10,295' 9,097' 5,750 psi 3,090 psi Liner 1,416' 7" 11,275' 9,963' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 4-1/2" 12.6#/L-80 9,960 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker SAB-3 Pkr/SSSV:N/A Pkr:9,911'(MD)8,779'(TVD)/SSSV:N/A 12.Attachments: Description Summary of Proposal E / 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch E / Exploratory ❑ Stratigraphic❑ Development❑ Service E 14.Estimated Date for 15.Well Status after proposed work: 7/15/2014 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ E - GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe(a�hilcorp.com Printed Name Dan Marlowe Title Operations Engnieer Signat N one (907)283-1329 Date 6/3/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: K._ �� Plug Integrity ❑ BOP Test / Mechanical Integrity Test)" Location Clearance ❑ Other: U Spacing Exception Required? Yes ❑ No 67. Subsequent Form Required: /©— Lio i-f APPROVED BY /I�O/j Approved by: COMMISSIONER THE COMMISSION Date:(�/ r 9-1 rel,, G ,r 6/41/ CkNr. c' n n ` ( Submit Form and Form 10-403(Revised 10/2012) AppOcRplcrIi4iArp2 months from the date of approval. •.Q1 t� ttachments in Duplicate ���!!! 1 ` L MOMS JUN 2014-4- Well Work Plan Well: D-34A Ililcorp Alaska,LU Date:05/29/2014 Well Name: D-34A API Number: 50-733-20225-01 Current Status: Water Injector Leg: Leg A-1 (NE Corner) Estimated Start Date: July 15, 2014 Rig: HAK#1 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 179-011 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907)777-8420 (0) (985)867-0665 (M) AFE Number: Current Bottom Hole Pressure: —3,800 psi @ 9,531 ND 0.46 psi/ft, (8.8 ppg)at mid perf Maximum Expected BHP: —3,800 psi @ 9,531 ND 0.46 psi/ft. (8.8 ppg) No-new perfs Max.Allowable Surface Pressure: 0 psi Using 0.46 psi/ft SW gradient to surface Well Summary The D 34A was worked over in July of 2012 and is currently completed as a Hemlock injection well.Shortly after the workover the well developed a tubing by casing leak and was shut-in_.This workover will pull the completion and replace the tubing and packer. Procedure: 1. Skid rig and RU HAK Rig 1 over D-34A well slot. 2. Notify AOGCC 48hrs before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250psi LOW and 2,50. 0 psi HIGH. 3. RU E-line. Cut tubing above packer at 9,911'. POOH 4. Pull hanger up to floor height, CBU. POOH laying down tubing. 5. Mill and retrieve packer at 9,911'. 6. Mill and remove CIBP at 10,540'. ' 7. RIH and clean out to-11,090'and circulate clean. 8. RU E-line and run caliper log to just above top perforation at 9,984'. 9. PU 9-5/8" retrievable test packer and RIH to 9,850'. Set packer, test backside to 2,500 psi to confirm casing integrity. Hold for 30 minutes, record with a chart recorder. ✓ 10. RIH with TCP guns and re-perf hemlock zones per program./ 11. PU 9-5/8" injection packer and 4-1/2" plastic lined tubing. RIH, set packer within 200' of top perf ±9,825'. d 12. Land the tubing hanger, and pressure up backside to confirm packer is set. 13. Set BPV. NU tree,test same. �--> j'pu p 14. Place well on injection. 15. Schedule the Initial MIT with AOGCC within 2 weeks of stable injection. Attachments: 1. Well Schematic-Current 2. Well Schematic-Proposed 3. Wellhead Diagram-Current(no change) 4. BOP Stack II McArthur River Field,TBU SCHEMATIC Well: D-34A Hileorp Alaska,LLC As Completed: 07/03/2012 CASING AND TUBING DETAIL All measurements are RKB to top of equipment. SIZE WT GRADE CONN ID TOP BTM. CIW DCB-FBB tbg.Hanger. 410 Stainless steel treated to NACE MR-01-75,3.5"8RD EUE x 3.5" 13-3/8" 61 J-55 Butt 12.515 Surf. 2,080' DSS-OHTC 9-5/8" 40 N-80 Butt 8.835 Surf. 2,556' 9-5/8" 47 N-80 Butt 8.681 2,556' 8,351 9-5/8" 47 P-110 Butt 8.681 8,351 10,295' 7"liner 29 L-80 Butt 6.184 9,859' 11,275' L Tubing 4-1/2" 12.6 L-80 Hydril 563 3.958 Surf 9,960 JEWELRY DETAIL NO. Depth ID Item 1 9,911' 4.5" Baker"S3 Production Packer 2 9,949' 3.813" "X" Nipple 3 9,960' N/A Wireline Guide 4 10,540' N/A CIBP PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Phasing 6-1 9,984' 10,003' 8,840' 8,855' 19 5 7/1/2012 72" 6-2 10,022' 10,047' 8,871' _ 8,892' 25 5 7/1/2012 72° G-3 _ 10,095' 10,128' 8,931' 8,959' 33 5 7/1/2012 72° 2111111 _ 10,137' 10,186' 8,966' 9,007' 49 5 7/1/2012 72° G-4 10,249' 10,266' 9,059' 9,073' 17 5 7/1/2012 72° I ,� cl%tl G-5 10,315' 10,340' 9,114' 9,135' 25 5 7/1/2012 72° 2 _ 10,352' 10,368' 9,145' 9,158' 16 5 7/1/2012 72° G-1 G-6 10,426' 10,448' 9,207' 9,226' 22 5 7/1/2012 72° 3 6-7 10,486' 10,493' 9,259' 9,265' 7 5 7/1/2012 72° B-1 10,550' 10,585' 9,314' 9,345' 35' 8 Nov-90 Isolated =G-2 10,610' 10,625' 9,367' 9,380' 15 Nov-90 Isolated B-2 10,640' 10'660' 9,393' 9,411' 20 Nov-90 Isolated G-3B 3 10,740' 10'755' 9,481' 9,494' 15 8 Nov-90 Isolated 10,788' 10,824' 9,524' 9,556' 36 8 Nov-90 Isolated B-4 10,834' 10,920' 9,565' 9,642' 86 8 Nov-90 Isolated G-a B-5 10,950' 11,040' 9,669' 9,750' 90 8 Nov-90 Isolated G-5 Fish ID Description Depth G-6 A Retainer&Junk 11,091' B Old Isolation Packer 11,098' = G-7 TOC10 14' I t' V 4 ( 1 Note: 8/22/2007 2.5"GR tagged up at 11,052' I i _B 1 \ ® B-2 774 B-3 B-4 A B =B-5 41111% oft Plug Back Depth=11,185' TD=11,285'MD/9,963'TVD Last Updated:7/27/12 by TDF • • • II Proposed McArthur River Field,TBU Well: D-34A Hilcorp Alaska,LLC As Completed: 07/03/2012 CASING AND TUBING DETAIL All measurements are RKB to top of equipment. SIZE WT GRADE CONN ID TOP BTM. CIW DCB-FBB tbg.Hanger. 410 Stainless steel treated to NACE MR-01-75,3.5"8RD EUE x 3.5" 13-3/8" 61 J-55 Butt 12.515 Surf. 2,080' DSS-OHTC 9-5/8" 40 N-80 Butt 8.835 Surf. 2,556' 9-5/8" 47 N-80 Butt 8.681 2,556' 8,351 9-5/8" 47 P-110 Butt 8.681 8,351 10,295' 7"liner 29 L-80 Butt 6.184 9,859' 11,275' d , Tubing 4-1/2" 11.6 L-80 TLP 4040 3.50" Surf ±9,900' (Poly lined JEWELRY DETAIL NO. Depth ID Item 1 ±9,825' 4.5" Baker"S3 Production Packer 2 ±9889' 3.813" "X" Nipple 3 ±9,900' N/A Wireline Guide PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Phasing G-1 9,984' 10,003' 8,840' 8,855' 19 5 7/1/2012 72° S� l''° G-2 10,022' 10,047' 8,871' 8,892' 25 5 7/1/2012 72° 1 E 2 G-3 10,095' 10,128' 8,931' 8,959' 33 5 7/1/2012 72° MIN 10,137 10,186' 8,966' 9,007' 49 5 7/1/2012 72° / G-4 10,249' 10,266' 9,059' 9,073' 17 5 7/1/2012 72° ' 4. 10,315' 10,340' 9,114' 9,135' 25 5 7/1/2012 72° 2 -3 rl/� G-5 10,352' 10,368' 9,145' 9,158' 16 5 7/1/2012 72° G-1 1 G-6 10,426' 10,448' 9,207' 9,226' 22 5 7/1/2012 72° G-7 10,486' 10,493' 9,259' 9,265' 7 5 7/1/2012 72° G-2 B-1 10,550' 10,585' 9,314' 9,345' 35' 8 Nov-90 Isolated 10,610' 10,625' 9,367' 9,380' 15 Nov-90 Isolated B-2 ±10,611' ±10,674' ±9,368' ±9,423' ±6 Future G-3 10,640' 10'660' 9,393' 9,411' 20 Nov-90 Isolated 10,740' 10'755' 9,481' 9,494' 15 8 Nov-90 Isolated B-3 10,788' 10,824' 9,524' 9,556' 36 8 Nov-90 Isolated =G-4 B-4 10,834' 10,920' 9,565' 9,642' 86 8 Nov-90 Isolated EE G-5 Fish ID Description Depth G-6 A Retainer&Junk 11,091' B Old Isolation Packer 11,098' G-7 Note: 8/22/2007 2.5"GR tagged up at 11,052' EE B-1 I B-2 B-3 B-4 A B =B-5 411111111 OBI - L Plug Back Depth=11,185' TD=11,285'MD/9,963'TVD Updated by: JLL 06/03/14 11. Dotty Varden Platform D-34A Current Hanwp 'iJi4ku.IAA. 01/17/2013 D-34A Tubing hanger,CIW- 133/8X95/8X41/2 DCB, 11X4'/:EUE 8rd lift and 4'A CS-CB susp,w/4"type H BPV profile,6 1/4"EN 410SS material BHTA,CIW,w/internal knockup cap,4 1/16 5M FE VAN Valve,swab,WKM-M, 4 1/16 5M FE, HWO, ;i T-26 ri'i 7 , lisomw Tee,stdd,4 1/16 5M X 3 1/8 5M FE,t 0 ' )1 4 0 Valve, master,WKM-M, '- 4, 4 1/16 5M FE, HWO,T-26 l ° " Adapter,CIW-FBB, 11 5M O p O FE X 3 1/8 5M, prepped for Void test good 7"extended neck, 1/2npt 1/17/2013 lit "' _ in control line port 250/5000psiAir ,4 Adapter has bushing back to ..� 111 n��- 6'/d'hanger neck Tubing head,CIW-DCB, „ — let 13 5/8 3M X 11 5M,w/ Valve, CIW-F,2 1/16 5M 2 2 1/16 5M SSO,X- ` « FE, HWO,AA bottom prep w/ m f ort4 1.'1" 1 %VR profile `ie; - II I - I j Void test good ilk ' 3/2012 Casing head,CIW-WF, - 250/2500psi M 13 5/8 3M X 13 3/8"csgal r thrd bottom,w/2-2" LPO I I I III Valve, CIW all weld ball �'\ IM[,,,„.i.% +i� �N valve,2" LPO Hilcorp #1 BOP TestHAK Procedure Hilcorp Alaska,LLC Attachment#1 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Hilcorp HAK #1, Dolly Varden WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and/or corroded and BPV cannot be set with tree on, Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing(test)joint to lift-threads d) NU BOP. Test ROPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test, notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness.As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) Hilcorp HAK#1 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 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 wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-2 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. d) Open C-2. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high,for 5 minutes each,as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test,open same. r Hilcorp HAK#1 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 ii) Valves, 3,4,9. After test,open valves 3 &4. Leave 9 closed. iii) Valves 5, 6, 9. After test,open valves 5& 6, leave 9 closed. iv) Valves, 7,8,9. After test, open all valves. e) Close C-3. This is the HCR(the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test,open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test C-1, C-2, and C-4 on the kill (pump-in) side by pressuring up on tubing.Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW(or Lower Kelly Valve)and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Hilcorp BOP TestHAK Procedure#1 Hilrnrp kiaaka,Iii Attachment#1 Diagram A: Dolly Varden BOP stack and Riser Arrangement—Typical for Single Completion QOf.KCnon <OF.XGnanos s oiDolly Varden Platform *4. o4 a4o 2014 BOP Stack(IIAK#1) • n�r•xonw ra�4�r.set� n1d 01/10/2014 11.1.-I. \I...i 11c. Dolly Varden Platform 2014 Workovers BOP Drawing(HAK 41) Quail Tool Rental Stack 1t1 Ii iii 111'11 111`II 11' 3.42' 111 lil lir iil I• 111111111111 /: 4.54' — • 11 Iii1)i111111 i200' p''� 1rr 1' to :': 111 Kill Side Choke side 1.00'to 2.00' 2 1/16 5M w/HCR and Unibolt line 2 1/16 SM w/HCR and Unibolt line connection - ,1 '1 connection Drill deck Riser 11 SM FE X 16.00' 11 5M FE 111 lit l ll.QT' l/1'1/1 III 11111' 3 00' Spacer spool 11 5M FE X11 SM FE iii iii ;it li' . Hilcorp HAK#1 BOP Test Procedure iiileo.t Alaska Ill Attachment#1 Diagram B: Dolly Varden Choke Manifold To Gas Buster All National type 1 -lliTo Panic line 2 1/16 5M 1502 Union ball valves 1JUltIil J (-3 �d ( 15 m at § // intr c _ "' "' Chokes are 90 degrees off \---1 in drawing in order to show / detail ,, I °71i"il : 5 5 . " " i „ ; ;:11 3 *I Ill ' ! tili Swaco 1 IL, _\i_ ; � '18 I II-ttf 1°I411.11'111 111 III :il From Bop Choke Line 2 1/16 5M Unbolt Flange .. Hilcorp HAK#1 BOP Test Procedure Attachment#1 Hilcorp Alaska,LLC U Util I a X 0 I t 1 C t—i P�! g i> _Q et 1 Er „..;O _ 01111111D_aom a1 ht . • _. U 1 0 W a. r A o J 0 1 LL Z CU x() D t- 0 l 0 z7 . ? p cr L U . s V n' t it oo (-) I 4 1 J ,- W U_ J 0 (0 ,,Ill Qua a a.Jop.i 5 C"-D [11>J 0 --iOZuj �a u_ Zl ct. - 3 0 ce U 4 • Hilcorp HAK#1 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 LI 1 v C S ... f.! 1 :•}----+71,+I .. (..) i rr g.--i•)--1 ::•i I ..,. i• I i :)--••.--' 1 \\1 '- '-'•', .!." C)-I .CI 4 IS II) ... L'... . Tr: . • - I-11-ii 01_ . 11 iLy i • ,.. 2...2. I 0 lT)i- V) ILI 1 CL G. F4- fil ( .41 .........-.--,--s, 1 K L, „r zi U) 5 L. _J D A, z ..„, z- I CD Z t 1 f: 173+- 0 CD 1--: n 5( --,4r4.•1.--C• Y. K C 6 -, IA A ZD:' 0 rn 0 z 0 D i cz U_ Z. F— UJ . - _ _ .5 D 5 i U- Z 0 CD Fl Z -:.) D C.) ce c) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 15, 2012 TO: Jim Regg QQ f ZZ'I SUBJECT: Integrity Tests P.I. Supervisor U ( L Mechanical HILCORP ALASKA, LLC D -34A FROM: John Crisp TRADING BAY UNITD-34A Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name TRADING BAY UNIT D -34A API Well Number 50-733-20225-01-00 Inspector Name: John Crisp Permit Number: 179-011-0 Inspection Date: 8/6/2012 Insp Num: mitJCrl20815101338 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well D -34A Type Inj IW -TVD 5779 IA 570 2350 2350 2350 PTD 1790110 Type Test SPT Test psi 2195 OA 15 15 15 15 Interval TAI- P/F P Tubing 3100 3100 3100 3100 - Notes: post workover initial MIT. SWOD OCT 1 3 2011 Wednesday, August 15, 2012 Page I of 1 - IV - STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMMIAIN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations 0 Perforate:0 Other Performed: Alter Casing ❑ Pull Tubing0 Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdowrn❑ Stimulate - Other ❑ Re -enter Suspended WeIII❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ 179-011 s 3. Address: 3800 Centerpoint Drive, STE 100 Stratigraphic ❑ Service 0 6. API Numbed; Anchorage, AK 99503 50- 733 - 20225 -01 - "CO 7. Property Designation (Lease Number): 8. Well Name and Number, ADL0018729 ° Trading Bay Unit / D -34A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): McArthur River Field / Henlock & Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured 11,285 feet Plugs measured None feet true vertical 9,960 feet Junk measured None feet Effective Depth measured 11,185 feet Packer measured See Below feet true vertical 9,872 feet true vertical See Below feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate 2,080' 13 -3/8" 2,080' 2,012' 3,090 psi 1,540 psi Production 10,295' 9 -5/8" 10,295' 9,097' 5,750 psi 3,090 psi Liner 1,416' 7" 11,275' 9,963' "RE Liner ii ii Perforation depth Measured depth See Schematic feet AU G 0 2 2012 True Vertical depth See Schematic feet /\ O 3CC Tubing (size, grade, measured and true vertical depth) 4 -1/2" L -80 12.6 9,960' (MD) 8,820' (TVD) Packer Baker SAB -3 Packer 9,911' (MD) 8,779' (TVD) Packers and SSSV (type, measured and true vertical depth) SSV N/A N/A N/A ' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A SCANNED MAR 0 4 2013. 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 70 0 Subsequent to operation: 0 0 976 560 3,200 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations 16. Well Status after work: r Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJO 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: 312 -213 Contact Ted E. Kramer Printed Name Ted E. Kramer Title Operations Engineer Signature ,. ra G- Phone 907 - 777 -8420 Date 7/31/2012 REBDMS AUG 0 3 2012 e i �. 6.1 Form 10-404 Revised 11/2011 Submit Original Only II • • McArthur River Field, TBU SCHEMATIC Well: D -34A Hilcorp Alaska, LLC As Completed: 12/27/1990 CASING AND TUBING DETAIL All measurements are RKB to top of equipment. SIZE WT GRADE CONN ID TOP BTM. CIW DCB -FBB tbg. Hanger. 410 Stainless steel treated to NACE MR- 01 -75, 3.5" 8RD EUE x 3.5" 13 - 3/8" 61 J - Butt 12.515 Surf. 2,080' DSS -OHTC 9 -5/8" 40 N -80 Butt 8.835 Surf. 2,556' 9 -5/8" 47 N -80 Butt 8.681 2,556' 8,351 9 -5/8" 47 P -110 Butt 8.681 8,351 10,295' 7" liner 29 L -80 Butt 6.184 9,859' 11,275' L Tubing 4 -1/2" 12.6 L -80 Hydril 563 3.958 Surf 9,960 JEWELRY DETAIL NO. Depth ID Item 1 9,911' 4.5" Baker "S3 Production Packer 2 9,949' 3.813" "X" Nipple ,9 961 ,, ,,- line Guide 4 10,540' N/A CIBP 1 -..1 O N D . . /foe To Btm(MD) Top(TVD) Btm(TVDVAmt SPF Date Phasing 6-1 9,984' 10,003' 8,840' 8,855' 19 5 7/1/2012 72° ,\\ 6-2 10,022' 10,047' 8,871' 8,892' 25 5 7/1/2012 72° f G-3 10,095' 10,128' 8,931' 8,959' 33 5 7/1/2012 72° 10,137' 10,186' 8,966' 9,007' 49 5 7/1/2012 72° 1 G 4 10,249' 10,266' 9,059' 9,073' 17 5 7/1/2012 72° 10,315' 10,340' 9,114' 9,135' 25 5 7/1/2012 72° •� OM. - G -5 10,352' 10,368' 9,145' 9,158' 16 5 7/1/2012 72° I 2 = G - / 3 G -6 10,426' 10,448' 9,207' 9,226' 22 5 7/1/2012 72° G - 10,4 10,493' 9,259' 9,265' 7 5 7/1/2012 72° z G -2 B-1 'I0, ' - 9 35' --- 8�'��tle -g -- ts - O ated 10,610' 10,625' 9,367' 9,380' 15 Nov -90 Isolated B-2 10,640' 10'660' 9,393' 9,411' 20 Nov -90 Isolated G -3 B 3 10,740' 10'755' 9,481' 9,494' 15 8 Nov -90 Isolated 10,788' 10,824' 9,524' 9,556' 36 8 Nov -90 Isolated G - B - 4 10,834' 10,920' 9,565' 9,642' 86 8 Nov -90 Isolated B -5 10,950' 11,040' 9,669' 9,750' 90 8 Nov -90 Isolated G -5 Fish ID Description Depth G - A Retainer & Junk 11,091' B Old Isolation Packer 11,098' G -7 T0C 10 515" 4 Note: 8/22/2007 2.5" GR tagged up at 11,052' El B -1 - ® 8-2 8 -3 B -4 A B _ B -5 MK Plug Back Depth = 11,185' TD = 11,285' MD/9,963' TVD Last Updated: 7/27/12 by TDF • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -34A 50- 733 - 20225 -01 179 -011 6/14/12 7/4/12 Daily Operations: 06/14/12 - Thursday R/U a -line unit. Arm perf /punch guns. Rig up circulating hoses to annulus and tubing on D -34A. Test PESI lubricator @ 2,500 psi. Good test. RIH with tubing punch. Correlate on depth @ 10,335'. Punch 13 ea. 3/8" holes 10,335' - 10,332'. POOH with e -line. All shots fired. R/D a -line. Finish rigging up to pump down tubing and take returns from the tubing to production well clean tank. Test lines to 1,500 psi. AOGCC has been notified and will witness BOP test. 06/15/12 - Friday Finish pressure testing lines to 1,500 psi. Install BPV. Nipple down tree and inspect tubing hanger threads. Threads in good condition. N/U risers, single gate, flow cross, double gate, annular preventer, choke and kill lines and flow nipple. R/U accumulator hoses. Function test BOP's. M/U floor valves and IBOP for testing. M/U test joint and engage tubing hanger. Q Lou Grimaldi (AOGCC) is on board to witness BOP test. 06/16/12 - Saturday Test lower pipe rams, upper pipe rams, choke manifold valves, choke and kill line valves @ 250L / 3,000H. All good tests. Back out 3 -1/2" test joints. Rig down bell nipple. Change out preventer element. Secure annular preventer cap. Re- install bell nipple. 06/17/12 - Sunday Test annular with 3 -1/2" test joint 250L / 3,000H. Change out 3 1/2" test joint for 4 1/2 ". Test annular, upper and lower pipe rams @ 250L / 3,000H with 4 1/2 ". Pull BPV, fill hole and install two -way check. Test blind shear rams @ 250L / 3,000H. Pull two -way check. M/U landing joint and engage tubing hanger. Back out lockdown pins. Pull hanger off seat up to 125K. R/U a -line. RIH with 2" radial torch cutter. Correlate on depth and cut tubing @ 10,365'. Tubing weight dropped from 125K to 80K. POOH and rig down a -line. Pull tubing hanger to work window and lay down same. 06/18/12 - Monday POOH laying down 3 1/2" DSS HTC tubing to 3,000'. R/D tubing tongs. R/U Hawkjaws. Install wear bushing. 06/19/12 - Tuesday RIH with 4" HT38 stands. RIH picking up drill pipe to 5,960'. Continue RIH P/U drill pipe from 5,960' - 10,306'. 06/20/12 - Wednesday RIH and tag TOF @ 10,371' drill pipe depth. Begin milling packer @10,371'. Mill from 10,371' - 10,376'. Continue milling 10,376' - 10,379'. Shut down milling. Attempt to push packer downhole with 15K down weight to no avail. Prepare to pull out of hole. • • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -34A 50- 733 - 20225 -01 179 -011 6/14/12 7/4/12 Daily Operations: 06/21/12 - Thursday POOH. Inspect mill shoe and decide to run second mill shoe as packer did not move downhole. Change out slips to 4 1/2 ". POOH with BHA. P/U M/U BHA. Mill shoe, washpipe, top bushing, bumper sub /oil jars, 4 ea. 4 3/4" drill collars, cross -over to drill pipe. Change slip dies. TIH to 600'. 06/22/12 - Friday TIH from 600' to 9,859' with washpipe /milling assembly. Tag top of liner @ 9,859'. Rotate string to get into liner. Continue TIH to 10,376'. Mill on packer to 10,376'. Begin cycle of dry milling for 10 minutes then while pumping for 20 minutes. Also, attempt to push fish down hole by setting down + -20 K after each to no avail. Not making any progress @ 10,377'. Notified Jim Regg (AOGCC) of weekly BOP test due on Saturday 6 -23 @ 1500 hrs. 06/23/12 - Saturday Continue milling on fish at 10,377 pu and set down 15k on fish at 10,377' - pu set down 1k on fish at 10,376'. No progress with milling. Prep to POOH. POOH to inspect overshot. POOH with work string. Change tong die for BHA and LD / BHA. Confer with Operations Engineer on milling results and plan forward. 06/24/12 - Sunday TIH with work string Tag fish at 10,362' - set down 2k, rotate 1 turn to engage fish set down 2k -pu to 174k -start jarring on fish while increasing weights up to 215k. Fish is moving up to — 3' when pu at 180k weight dropped to 170k and fish moving up hole after 12 jar licks. POOH to inspect overshot for recovery. LD BHA with 3 -1/2 tbg stub, pkr locater sub, splines for latch and seal assy. OD of seal assy is 4" TOF looking up is 4 -3/4" OD. Next fishing run after BOPE test will be with 4 -1/4" id rotary shoe over shot. Pull wear bushing and pu BOPE test tools TIW, IBOP, test jts and plugs. 06/25/12 - Monday Fish RU to test BOPE - install test plug in hanger. Prod increasing water flood to provide test pressure. Pressure tested all BOPE components and support safety equipment as per AOGCC, Hilcorp and CUDD procedures to 250 psi low / 3,000 psi high. Pull test plug and set wear bushing. RD all test equip and clear work area. MU XO on to TIW valves. MU rotary mill shoe on wash pipe on the deck. PU / MU fish BHA #4 - 4- 1 /4(id) mill shoe. RIH with Fish BHA # 4. Cont RIH with BHA #4. • • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -34A 50- 733 - 20225 -01 179 -011 6/14/12 7/4/12 Daily Operations: 06/26/12 - Tuesday Cont RIH w/ Fish BHA #4 - tag fish at 10,376'. Start milling oer pkr. Made 2' hole, PU fish w /5k overpull - work back over pkr at 10k torque - 6k weight. Weight and torque fell back to free spin. Packer now free. CBU - some black pkr rubber to surface. LD kelly /pup jt. PU jt #334 RIH tagat 10,624' csg patch at 10,610' w/ ID of 5.884. Overshot OD at 6 -1/16, pkr OD at 5.687. Suspect pkr fell to btm of hole. Overshot to large to pass thru patch without causing damage. Prep floor to POOH. POOH to pu up smaller overshot to fish recover pkr from btm. LD / BHA recovered a small sleeve inside overshot. Discuss plan forward with Operations Engineer. Decision is to leave pkr on btm. RIH with bit /scraper. 6/27/2012- Wednesday MU 7" scrapper BHA on 4 -3/4" DC ; RIH with 7" scrapper tag csg patch at 10,624'. Begin to POOH with 7" scrapper. 6/28/2012 - Thursday Finish POOH with 7 "scrapper. LD scrapper BHA. RU PESI a -line unit. RIH with 5.75" GR tag at 10,620' top of csg patch. POOH PU 3.8" GR. RIH with 3.8" GR tag up same at 10,618' top of csg patch. POOH PU 3.8" LIB. RIH with 3.8" LIB, work thru TOL at 9,859'- cont RIH set down at 10,620'. Over pull 1k to pull LIB free. POOH with 3.8" LIB. LIB appears to have been inside something -pkr ID 3.998' -csg patch ID 5.884 " -if inside pkr the pkr appears to be hung up in the csg patch at 10,620'. MU Halliburton 7" EZDriII Bridge Plug with setting tool on eline. RIH with 7" EZDriII Bridge Plug set at 10540'. POOH inspect tool. Change out tools. RIH with 7" EZ Drill tie into collars and set plug at 10,540' -check set - PUH RIH tag plug at 10,540'. POOH with setting tool and MU dump bailer w /cement. RIH with #1 - 3 "x 30' bailer — 5' cmt per bailer and dump cmt on top of EZ Drill plug at 10,540'. RIH with #2- #3 - #4 - #5 bailer and dump cement at 10540'- 10516' Type cement used Class H cmt at 17ppg. RD and move Pollard eline unit- PU RTTS tool. Received verbal waiver for witness of BP /Cement test from Jim Regg, AOGCC, at 0850 6/27/12. 6/29/2012 - Friday MU / RIH with RTTS and set RTTS at approx. 10,050'. PT 7" csg and Cement/ EZ Drill to 2,600 psi- held solid for 34 mins - Release pressure and RTTS. Begin to POOH with RTTS. 6/30/2012 - Saturday Cont POOH with RTTS- LD RTTS. PU/ MU TCP Guns. Begin to RIH with 4 -1/2" TCP gun assy. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -34A 50- 733 - 20225 -01 179 -011 6/14/12 7/4/12 Daily Operations: 7/1/2012 - Sunday Cont RIH with SLB - TCP guns. RIH thru liner soft tag cement at 10,514'. RU/ RIH with eline and correlate tie in with Digital Perf Correlation Log. POOH and RD eline. Set pkr at 9,788' P0011. RU to fire guns and RU echo monitor. Cycle firing head, good surface indication guns fired. POOH LD DP. TCP 4.5 "Guns dressed with 5 SPF 4505PJ Omega PURE 72 deg phase. Correlated on depth. Perf'd the following intervals ; G1- 9984- 10003,G2- 10095 - 10128, G3- 10095- 10128,G4- 10137 - 10186, G4- 10249 - 10266, G5- 10315 - 10340, G5- 10352- 10368,G6- 10426 - 10448, G7- 10486 -10493 f/213'. 7/2/2012 - Monday POOH and LD pkr and spent TCP guns. MU TIW vlv. Begin to RIH w/ 4 -1/2" tbg w/ 563 thrd plus BOT "S -3" pkr f /7" csg. 7/3/2012 - Tuesday Continue to RIH with tbg /pkr assy, tag TOL at 9872', continue to RIH to pkr depth 9,911'. MU up hgr on landing jt- rotate tbg to line up hgr pins and land hgr with pkr at 9,911' up wt 114k- do wt 65k. Run in LDS -pump sealant into hgr seals bore. RU to set pkr. Set pkr -hold 15 mins -solid test. RD test lines - RU and to set BPV. Start ND / BOPE 07/04/2012 - Wednesday Finish ND / BOPE. NU and test Tree to 5k - pull BPV. RU lubricator to tree. RIH and retrieve RHC ball /rod setting tool at 9,950' SLM. POOH change tools. RIH and retrieve RHC vlv at 9,960' SLM - POOH. RD slick line and move off deck. Rig Released at 2400 hrs. PNM ilgoita Regg, James B (DOA) From: Larry Greenstein [Ireenstein @hilcorp.com] ei f � l qt-z-- Sent: Friday, August 03, 2012 3:51 PM l To: Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: John Lee; Paul Bartolowits; Ted Kramer; Christy Anderson; Jon Loomis Subject: MIT_Dolly_07 -03 -12 Attachments: MIT_Dolly_07- 03- 12.xls; D -34A MIT chart 7- 3- 12.pdf Attached is the WO MIT for the repaired D -34A injection well performed 7/3/12. Also attached is the scanned chart of the test. An initial MIT will be requested shortly. Larry %WE'D Wig 0 2013 • S • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reggCcD(alaska.qov; doa.aogcc.prudhoe.bayt alaska.gov, phoebe.brooksaalaska.gov OPERATOR: Hilcorp Alaska, LLC �� O ( ( FIELD / UNIT / PAD: McArthur River/Trading Bay Unit/Dolly Varden Platforrr DATE: 07/03/12 OPERATOR REP: Joe McInnis AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well D -34A Type Inj. N • TVD 8,779' Tubing 0 4,500 4,500 4,500 ' Interval 0 P.T.D. 1790110 " Type test P Test psi 2195 Casing 0 2,200 " 2,200 2,200 P/F P Notes: MD of pkr = 9911' / OA Tbg & Csg pressure test done during WO Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey 0 = Other (describe in notes) W = Water D = Differential Temperature Test Form 10 -426 (Revised 02/2012) MIT_Dolly_07 - 03 - 12 I ' 1 : , "' '''V' law, _„ -......-_, -_-__ _ ___ .............„ , ..,' ,,,, , „.w,..„ --,..---,_-_-:- -- _ _ , ds --__--v.„-.0,..._ . N . „..,„ „,,, . ,,, , f t/ ,....\,,,, _, ___ _ ,._,_______ ,,,.?,,, % N 4,1s." \,, \ ■ / i e #i" ' ' ' - - - 7 :- - i -- '' z ' -z. - 4 % , , N -. 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'" �� 0 004 l I , \ \ \ ,, s,,, \ - O O O �, h` ~' ti � � 0006 0 ' X00 01 . �_ ` 4% } ,s 01 • • RECEIVED STATE OF ALASKA AUG 0 2 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LiSeGCC la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class: 20AAC 25.105 20AAC 25.1 TO Development ❑ Exploratory ❑ GINJ ❑ WINJ O WAG ❑ WDSPL ❑ No. of Completions: Service p Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Hilcorp Alaska, LLC Aband.: 4/29/1979 179 -011 3. Address: 6. Date Spudded: 13. API Number: 3800 Centerpoint Drive Suite 100, Anchorage AK 99503 4/1/1979 50- 733 - 20225 -01 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1,210' FWL, 757' FSL, Sec 6- 8N- 13W -SM, Leg A -1, Dolly Varden 4/13/1979 Trading Bay Unit / D -34A Top of Productive Horizon: 8. KB (ft above MSL): 106.2 15. Field /Pool(s): 360' FWL, 1,282' FSL, Sec 5- 8N- 13W -SM GL (ft above MSL): McArthur River Field Total Depth: 9. Plug Back Depth(MD +TVD): Hemlock Oil & Middle Ken G Oil Pools 1,155' FWL, 980' FSL, Sec 5- 8N- 13W -SM 11,185' & 9,872' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 208456.7 y- 2490853.4 Zone- G -1 11,285' & 9,960' ADL0018729 TPI: x- 212681.7 y- 2491239.4 Zone- G -1 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 213354.1 y- 2490952 Zone- Hemlock N/A 18. Directional Survey: Yes ❑ Jo 1g / / 19. Water Depth, if Offshore: 20. Thipk e s of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) Il tt (ft MSL) PI 1A 21. Logs Obtained (List al� Iggs here and submit electronic and printed information per 20AAC25.071): 22.Re -dnl) /Lateral Top Window MD/TVD: 23. N TAt CASING, LINER AND CEMENTING RECORD N WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED i 24. Open to production or injection? Yes p Non If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Phasing 4 -1/2" 9,960' 9,911'/8,779' G -1 9,984' 10,003' 8,840' 8,865' 19 5 72° G -2 10,022' 10,047' 8,871' 8,892' 25 5 72° 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. G -3 10,095' 10,128' 8,931' 8,959' 33 5 72° DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED G -4 10,137' 10,186' 8,966' 9,007' 49 5 72° o elik G-4 10,249' 10,266' 9,059' 9,073' 17 5 72° I - �! G -5 10,315' 10,340' 9,114' 9,135' 25 5 72° G -5 10,352' 10,368' 9,145' 9,158' 16 5 72° G -6 10,426' 10,448' 9,207' 9,226' 22 5 72° G -7 10,486' 10,493' 9,259' 9,265' 7 5 72° 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ NA1 Sidewall Cores Acquired? Yes ❑ Nof If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. `t �1 i) A . U Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE e7/47...._ Submit original only /' ' • • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base 4A Formation at total depth: 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ted E. Kramer Printed Name: Ted E. Kramer Title: Sr. Operations Engineer Signature: s"'_��" Phone: (907) 777 -8420 Date: 8/1/2012 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. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 . II III • McArthur River Field, TBU SCHEMATIC Well: D -34A Hilcorp Alaska, LLC As Completed: 12/27/1990 CASING AND TUBING DETAIL All measurements are RKB to top of equipment. SIZE WT GRADE CONN ID TOP BTM. CIW DCB -FBB tbg. Hanger. 410 Stainless steel treated to NACE MR- 01 -75, 3.5" 8RD EUE x 3.5" 13 - 3/8" 61 J - Butt 12.515 Surf. 2,080' DSS -OHTC 9 -5/8" 40 N -80 Butt 8.835 Surf. 2,556' 9 -5/8" 47 N -80 Butt 8.681 2,556' 8,351 9 -5/8" 47 P -110 Butt 8.681 8,351 10,295' 7" liner 29 L -80 Butt 6.184 9,859' 11,275' L Tubing 4 -1/2" 12.6 L -80 Hydril 563 3.958 Surf 9,960 JEWELRY DETAIL NO. Depth ID Item 1 9,911' 4.5" Baker "S3 Production Packer 2 9,949' 3.813" "X" Nipple 3 9,960' N/A Wireline Guide 4 10,540' N/A CIBP PERFORATION DATA Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Phasing G -1 9,984' 10,003' 8,840' 8,855' 19 5 7/1/2012 72° G -2 10,022' 10,047' 8,871' 8,892' 25 5 7/1/2012 72° G -3 10,095' 10,128' 8,931' 8,959' 33 5 7/1/2012 72° 2>C 10,137' 10,186' 8,966' 9,007' 49 5 7/1/2012 72° L 1 G-4 10,249' 10,266' 9,059' 9,073' 17 5 7/1/2012 72° C G-5 10,315' 10,340' 9,114' 9,135' 25 5 7/1/2012 72° 10,352' 10,368' 9,145' 9,158' 16 5 7/1/2012 72° 2 3 = G - G -6 10,426' 10,448' 9,207' 9,226' 22 5 7/1/2012 72° G -7 10,486' 10,493' 9,259' 9,265' 7 5 7/1/2012 72° G -2 B -1 10,550' 10,585' 9,314' 9,345' 35' 8 Nov -90 Isolated 10,610' 10,625' 9,367' 9,380' 15 Nov -90 Isolated B-2 10,640' 10'660' 9,393' 9,411' 20 Nov -90 Isolated - G - B 3 10,740' 10'755' 9,481' 9,494' 15 8 Nov -90 Isolated 10,788' 10,824' 9,524' 9,556' 36 8 Nov -90 Isolated =-- G • - B - 4 10,834' 10,920' 9,565' 9,642' 86 8 Nov -90 Isolated B -5 10,950' 11,040' 9,669' 9,750' 90 8 Nov -90 Isolated G • -5 Fish ID Description Depth G -6 A Retainer & Junk 11,091' B Old Isolation Packer 11,098' - G -7 TOC 10,515" 4 I 1 e '� Note: 8/22/2007 2.5" GR tagged up at 11,052' B -1 ® B-2 B -3 B -4 A B = B -5 MK 4111111t -.- Plug Back Depth = 11,185' TD = 11,285' MD/9,963' TVD Last Updated: 7/27/12 by TDF . .. ���u �� s Hilcorp ������X^�� U 8 �` ''''-- n ~^^^~~~^^`~ v ~-~~~^ Weekly Operations ^ Summary ^ _ _ » Well Name API Number Well Permit Numbe Start Date End Date D-34A 507333022501 179'011 6/14/12 Daily Operations: � � ' '�'� 06/13/12 - Wednesday No operations to report. 06/14/12 - Thursday R/U e-line unit. Arm perf/punch guns. Rig up circulating hoses to annulus and tubing on D-34A. Test PESI lubricator © 2'S0O psi. Good test. RIH with tubing punch. Correlate on depth @1[l33S'. Punch 13 ea. 3/O" holes 1O,33S''1O,332'. POOH with e-line. All shots fired. R/D e-line. Finish rigging up to pump down tubing and take returns from the tubing to production weH clean tank. Test lines to 1,500 psi. AOGCC has been notified and will witness BOP test. 06/15/12 - Friday Finish pressure testing lines to 1,500 psi. Install BPV. Nipple down tree and inspect tubing hanger threads. Threads in good condition. N/U risers, single gate, flow cross, double gate, annular preventer, choke and kill lines and flow nipple. R/U accumulator hoses. Function test BOP's.K4/U floor valves and )BC`P for testing. M/U test joint and engage tubing hanger. Lou Grimaidi (AOGCC) is on board to witness BOP test. 06/16/12 - Saturday Test lower pipe rams, upper pipe rams, choke manifold valves, choke and kill line valves @ 250L / 3,000H. All good tests. Back out 3-1/2" test joints. Rig down bell nipple. Change out preventer element. Secure annular preventer cap. Re-install bell nipple. O6/17/12'Sunday Test annular with 3'1/2" test joint ZSOL/3,0OOH. Change out 31/3" test joint for 41/2". Test annular, upper and lower pipe rams © 250L / 3,000H with 4 1/2". Pull BPV, fill hole and install two-way check. Test blind shear rams @ 2501 / 3,000H. Pull two-way check. M/U landing joint and engage tubing hanger. Back out lockdown pins. Pull hanger off seat up to1J5K.R/Ue'|ine. RIH with 2" radial torch cutter. Correlate on depth and cut tubing @ 10,365'. Tubing weight dropped from 125K to 80K. POOH and rig down e-line. Pull tubing hanger to work window and lay down same. 06/18/12 - Monday POOH Iaying down 3 1/2" DSS HTC tubing to 3,000'. RIO tubing tongs. R/U Hawkjaws. install wear bushing. 06/19/12 - Tuesday RIH with 4" HT38 stands. RIH picking up driJl pipe to 5,960'. Continue RIH P/U drill pipe from 5,960' - 10,306'. JUL �� �M 3 1Z �,___`~ °°� ~ - • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date D - 34A _ 507332022501 179 -011 6/14/12 Daily Operations: 06/20/2012 - Wednesday RIH and tag TOF @ 10,371' drill pipe depth. Begin milling packer @ 10,371'. Mill from 10,371' - 10,376'. Continue milling 10,376' - 10,379'. Shut down milling. Attempt to push packer downhole with 15K down weight to no avail. Prepare to pull out of hole. 06/21/2012 - Thursday POOH. Inspect mill shoe and decide to run second mill shoe as packer did not move downhole. Change out . slips to 4 1/2 ". POOH with BHA. P/U M/U BHA. Mill shoe, washpipe, top bushing, bumper sub /oil jars, 4 ea. 4 3/4" drill collars, cross -over to drill pipe. Change slip dies. TIH to 600'. 06/22/2012 - Friday TIH from 600' to 9,859' with washpipe /milling assembly. Tag top of liner @ 9,859'. Rotate string to get into liner. Continue TIH to 10,376'. Mill on packer to 10,376'. Begin cycle of dry milling for 10 minutes then while pumping for 20 minutes. Also, attempt to push fish down hole by setting down + -20 K after each to no avail. Not making any progress @ 10,377'. Notified Jim Regg (AOGCC) of weekly BOP test due on Saturday 6 -23 @ 1500 hrs. 06/23/2012 - Saturday Continue milling on fish at 10,377' - pu and set down 15k on fish at 10,377' - pu set down 1k on fish at 10,376'. No progress with milling. Prep to POOH. POOH to inspect overshot. POOH with work string. Change tong die for BHA and LD / BHA. Confer with Operations Engineer on milling results and plan forward. 06/24/2012 - Sunday TIH with work string Tag fish at 10,362' -set down 2k, rotate 1 turn to engage fish set down 2k -pu to 174k -start jarring on fish while increasing weights up to 215k. Fish is moving up to ^' 3' when pu at 180k weight dropped to 170k and fish moving up hole after 12 jar licks. POOH to inspect overshot for recovery. LD BHA with 3 -1/2 tbg stub, pkr locater sub, splines for latch and seal assy. OD of seal assy is 4" TOF looking up is 4 -3/4" OD. Next fishing run after BOPE test will be with 4 -1/4" id rotary shoe over shot. Pull wear bushing and pu BOPE test tools TIW,IBOP, test jts and plugs. 06/25/2012 - Monday Finish RU to test BOPE- install test plug in hanger. Prod increasing water flood to provide test pressure. Pressure tested all BOPE components and support safety equipment as per AOGCC, Hilcorp and CUDD procedures to 250 psi low / 3,000 psi high. Pull test plug and set wear bushing. RD all test equip and clear work area. MU X0 on to TIW valves. MU rotary mill shoe on wash pipe on the deck. PU / MU fish BHA #4 - 4- 1/4(id) mill shoe. RIH with Fish BHA # 4. Cont RIH with BHA #4. 06/26/2012 - Tuesday Cont RIH w/ Fish BHA #4- tag fish at 10,376'. Start milling over pkr. Made 2' hole, PU fish w /5k overpull- work back over pkr at 10k torque- 6k weight. Weight and torque fell back to free spin. Packer now free. CBU - some black pkr rubber to surface. LD kelly /pup jt. PU jt # 334 RIH tag at 10,624' csg patch at 10,610' w/ ID of 5284. Overshot OD at 6 -1/16, pkr OD at 5.687. Suspect pkr fell to btm of hole. Overshot to large to pass thru patch without causing damage. Prep floor to POOH. POOH to pu up smaller overshot to fish recover pkr from btm. LD / BHA recovered a small sleeve inside overshot. Discuss plan forward with Operations Engineer. Decision is to leave pkr on btm. RIH with bit /scrapper. • • Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date D -34A 50- 733 - 20225 -01 178 -011 6/27/12 7/3/12 Daily Operations: 6/27/2012 - Wednesday MU 7" scrapper BHA on 4 -3/4" DC; RIH with 7" scrapper tag csg patch at 10,624'. Begin to POOH with 7" scrapper. 6/28/2012 - Thursday Finish POOH with 7 "scrapper. LD scrapper BHA. RU PESI e-line unit. RIH with 5.75" GR tag at 10,620' top of csg patch. POOH PU 3.8" GR. RIH with 3.8" GR tag up same at 10,618' top of csg patch. POOH PU 3.8" LIB. RIH with 3.8" LIB, work thru TOL at 9,859'- cont RIH set down at 10,620'. Over pull 1k to pull LIB free. POOH with 3.8" LIB. LIB appears to have been inside something -pkr ID 3.998' -csg patch ID 5.884 " -if inside pkr the pkr appears to be hung up in the csg patch at 10,620'. MU Halliburton 7" EZDrill Bridge Plug with setting tool on eline. RIH with 7" EZDrill Bridge Plug set at 10540'. POOH inspect tool. Change out tools. RIH with 7" EZ Drill tie into collars and set plug at 4540' -check set - PUH RIH tag plug at 10,540'. POOH with setting tool and MU dump bailer w /cement. RIH with #1 - 3 "x 30' bailer — 5' cmt per bailer and dump cmt on top of EZ Drill plug at 10,540'. RIH with #2- #3 - #4 - #5 bailer and dump cement at 10540'- 10516' Type cement used Class H cmt at 17ppg. RD and move Pollard eline unit- PU RTTS tool. Received verbal waiver for witness of BP /Cement test from Jim Regg, AOGCC, at 0850 6/27/12. 6/29/2012 - Friday MU / RIH with RTTS and set RTTS at approx. 10,050'. PT 7" csg and Cement/ EZ Drill to 2,600 psi- held solid for 34 mins - Release pressure and RTTS. Begin to POOH with RTTS. 6/30/2012 - Saturday Cont POOH with RTTS- LD RTTS. PU/ MU TCP Guns. Begin to RIH with 4 -1/2" TCP gun assy. 7/1/2012 - Sunday Cont RIH with SLB - TCP guns. RIH thru liner soft tag cement at 10,514'. RU/ RIH with eline and correlate tie in with Digital Perf Correlation Log. POOH and RD eline. Set pkr at 9,788' POOH. RU to fire guns and RU echo monitor. Cycle firing head, good surface indication guns fired. POOH LD DP. TCP 4.5 "Guns dressed with 5 SPF 4505PJ Omega PURE 72 deg phase. Correlated on depth. Perf'd the following intervals ; G1- 9984- 10003,G2- 10095 - 10128, G3- 10095- 10128,G4- 10137 - 10186, G4- 10249- 10266, G5- 10315 - 10340, G5- 10352- 10368,G6- 10426 - 10448, G7- 10486 -10493 f/213'. 7/2/2012 - Monday POOH and LD pkr and spent TCP guns. MU TIW vlv. Begin to RIH w/ 4 -1/2" tbg w/ 563 thrd plus BOT "S -3" pkr f /7" csg. 7/3/2012 - Tuesday Continue to RIH with tbg/pkr assy, tag TOL at 9872', continue to RIH to pkr depth 9,911'. MU up hgr on landing jt- rotate tbg to line up hgr pins and land hgr with pkr at 9,911' up wt 114k- do wt 65k. Run in LDS -pump sealant into hgr seals bore. RU to set pkr. Set pkr -hold 15 mins -solid test. RD test lines - RU and to set BPV. Start ND / BOPE • e • • Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date D -34A 50- 733 - 20225 -01 178 -011 6/27/12 Daily Operations: 07/04/2012 - Wednesday Finish ND / BOPE. NU and test Tree to 5k- pull BPV. RU lubricator to tree. RIH and retrieve RHC ball /rod setting tool at 9,950' SLM. POOH change tools. RIH and retrieve RHCvIv at 9,960' SLM - POOH. RD slick line and move off deck. Rig Released at 2400 hrs. 07/05 /2012 - Thursday No operations to report. 07/06/2012 - Friday No operations to report. 07/07/2012- Saturday No operations to report. 07/08/2012 - Sunday No operations to report. 07/09/2012 - Monday No operations to report. 07/10/2012 - Tuesday No operations to report. �� ^ U Alaska, U � �� H n �n4����k� ��n����n^�� u-u-v~ Weekly Operations Summary �w����n� "����������� � v - , wenmame API Number Well Permit Number Start Date End Date D-34A 507332022501 179-011 6/14/12 Daily Operations:'�� 06/13/12 - Wednesday No operations to report. 06/14/12 - Thursday R/U e-line unit. Arm perf/punch guns. Rig up circulating hoses to annulus and tubing on D-34A. Test PESI lubricator @ 2 psi. Good test. RIH with tubing punch. Correlate on depth @10 Punch 13 ea. 3/8" holes 1O,33S' 10,332'. POOH with e-line. All shots fired. R/D e-line. Finish rigging up to pump down tubing and take returns from the tubing to production well clean tank. Test lines to 1,500 psi. AOGCC has been notified and will witness BOP test. 06/15/12 - Friday Finish pressure testing lines to 1,500 psi. Install BPV. Nipple down tree and inspect tubing hanger threads. Threads in good condition. N/U risers, single gate, flow cross, double gate, annular preventer, choke and kill lines and flow nipple. R/U accumulator hoses. Function test BOP's. M/U floor valves and IBOP for testing. M/U test joint and engage tubing hanger. Lou Grimaidi (AOGCC) is on board to witness BOP test. 06/16/12 - Saturday Test lower pipe rams, upper pipe rams, choke manifold valves, choke and kill line valves @ 250L / 3,000H. All good tests. Back out 3-1/2" test joints. Rig down bell nipple. Change out preventer element. Secure annular preventer cap. Re-install bell nipple. 06/17/12 - Sunday Test annular with 3'1/2" test joint %SOL/3,OOUH. Change out 31/2" test joint for 41/Z" Test annular, upper and lower pipe rams @ 250L / 3,000H with 4 1/2" Pull BPV, fill hole and install two-way check. Test blind shear rams @ 250L / 3,000H. Pull two-way check. M/U landing joint and engage tubing hanger. Back out lockdown pins. Pull hanger off seat up to12SK. R/U e-Une. RIH with 2" radial torch cutter. Correlate on depth and cut tubing @ 10,365'. Tubing weight dropped from 125K to 80K. POOH and rig down e-line. Pull tubing hanger to work window and lay down same. 06/18/12 - Monday POOH Iaying down 3 1/2" DSS HTC tubing to 3,000'. R/D tubing tongs. R/U Hawkjaws. Install wear bushing. 06/19/12 - Tuesday RIH with 4" HT38 stands. RIH picking up drill pipe to 5,960'. Continue RIH P/U drill pipe from 5,960' 10 JUL � �O1� 4- 2 - ' • Post Office Box 244027 Anchorage, AK 99524 -4027 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Phone: 907 /777 -8300 Hilcorp Alaska, LLC Fax: 907/777. -8301 PrD /79 -of/ June 15, 2012 Guy Schwartz State of Alaska RECEIVED Alaska Oil & Gas Conservation Commission 333 West 7 Avenue, Suite 100 JUN 18 2012 Anchorage, Alaska 99501 AOGCC Re: Sundry for RWO on D -34A SCANNED} MAY 0 7 2013 Dear Guy: Y This letter is in response to your e-mail of June 12, 2012 regarding the above workover. Item 1: Addresses the need of conducting a pressure test on the cast -iron bridge plug of 2500 PSI for 30 min. to verify that the Hemlock zone is isolated. Response: That item has now been added to the workover procedure a copy of which is attached. Item 2: Conduct an assessment of the D -34A 7 inch liner cement job from an applicable cement bond log. Response: An assessment of the cement bond log for the 7 inch liner in well D -34A was conducted by myself and Kerry Richards from Baker Atlas on June 13, 2012. Utilizing a dresser Atlas CBL ran on April 16, 1979 the following was found: The D34A contains 140 feet of well bonded cement above the top planned G -zone perf located at 9984 feet to the top of the G zone. Looking at the base, the D34A well has over 90 feet of well bonded cement below the bottom perforation at 10,486 feet to the base of the G zone. Therefore, Hilcorp believes that the G zone in this well bore is well isolated and that water injected water will be contained to the G zone reservoir. Item 3: Provide an area review of 1/4 mile of all wells impacted by this injector. Provide a map of bottom hole locations (BHL) and Adjacent wells in the '/4 mile area. Mr. Guy Schwartz • • June 15, 2012 Page 2 of 3 Response: A map of the BHL and adjacent wells is attached for the 1/4 mile area surrounding D -34A. A review of the five wells in the 'A area surrounding D -34A for cement integrity is in the table below: Well CBL CBL Results Cement Comments (Y/N) Review D -4 N N/A 2 Stage Circ. Out 900 sxs. cement job. Pumped 1600sx class g followed by 900sxs. Class g D -4RD Y Very good Cement bond from 800 sxs. 8200' down to PBTD at 12,089' Class g (G -zone 10,628— 11,262') D -17 N N/A 1167 No Bond log across the Sxs. g -zone. There was one Class g higher which showed very good cement bond down to 8,200 feet. D -17RD Y Very good Cement bond from 900 sxs. 8800' down to PBTD at Class g 10,676'. (G -zone 9,500— 10,040') D -2ARD Y Very good cement bond from 1,100 Good containment 11,250 up to 10,380 ft. There is sxs. above the G -zone. a section of pipe that is approx.. Class g 70% bonded intermixed with good bonded pipe from 10,380 up to 10,160'. Very good cement bond from 10,160 up to 10,000'. (G -zone is from 10,201 to 10,679) Based on the volume of cement pumped and the results of the cement bond logs, Hilcorp believes that the G -zone surrounding the D -34A well is contained and isolated from the rest of the well interval and that the injected fluid will stay in zone. • • • Mr. Guy Schwartz June 15, 2012 Page 3 of 3 Sincerely, E �r 1 7 Ted E. Kramer Senior Operations Engineer HILCORP ALASKA, LLC Attachments: Updated Procedure (Ver. 3) Map of 'A mile radius surrounding D -34A -n • • Well Work Plan Well: D -34A Hilcorp Alaska, LLC Date: 06/07/2012 Ver. 3 Well Name: D -34A API Number: 50- 733 - 20225 -01 Current Status: Water Injector Leg: A -1 Northwest Crnr Estimated Start Date: June 14, 2012 Rig: Cudd Hydraulic Workover Unit Reg. Approval Req'd? June 14, 2012 Date Reg. Approval Rec'vd: Regulatory Contact: Appropriate Reg. Tech Permit to Drill Number: 179 -011 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Mike Dunn (907) 777 -8382 (0) (907) 351 -4191 (M) AFE Number: Pending Current Bottom Hole Pressure: 3,800 psi @ 9,531 TVD (mid pert of 10,795 MD). Based on Offset Well D -31 RD from the 2009 Redoubt Shut In Maximum Expected BHP: 3800 psi @ 9,531 TVD Max. Allowable Surface Pressure: 0 psi (Using 0.435psi /ft to surface) Well Summary The D 34A is currently completed as a Hemlock injection well. In March of 2012 this well - developed tubing to casing communication and the well was shut in. Further investigation into the bottom hole location identified that this well was better suited for a G Zone injector. Procedure: 1. MIRU CUDD Hydraulic Workover Unit. 2. RU E -line, RIH with tubing punch to 10,335' and punch tubing. 3. Reverse circulate one tubing volume of FIW. 4. Shut down pump for one hour. Kick in pump and record number of barrels to catch fluid. a. Note: Well will not flow to surface. 5. Calculate fluid loss rate (Bbls. / Hour). If Loss is greater than 20 bph, mix graded rock salt pill in FIW. 6. Pump pill and recalculate fluid loss. If acceptable, continue to step 6. Otherwise repeat step 4. 7. ND wellhead and NU BOP stack. Pressure test BOP to 250 psi. low / 3,000 psi high. Note: notify AOGCC 48 hours in advance of test for the opportunity to witness bop test. 8. RIH with tubing cutter on E- line to ( + / -) 10,372' and cut tubing. 9. RD E-Iine. 10. POOH laying down 3 -1/2" tubing string. 11. Rig up circulating system with Magnets for possum belly. 12. PU overshot mill and down hole motor on 4" HT -38 work string and RIH to Baker SAB -3 Packer at 10,375'. Mill up and remove same. 13. PU bit and scraper and RIH to 10,550ft. POOH with same laying down 4" HT -38 work string. 14. RU E -line. RIH with CIBP to 10,540'. 15. Dump bail 20' of cement on top. 16. WOC 24 hours. 17. PU test packer on work string and RIH to 10,510'. 18. Set Test packer and test cement plug to 2,500 psi for 30 minutes. 19. POOH with test packer. .n • • Well Work Plan Well: D -34A Hilcorn Alaska, LLC Date: 06/07/2012 20. RU Schlumberger perforating unit and pert the following G -zone intervals: Note: Use landing joint with large cross -over in stack crossed back over to Bowen head connection for well control. Bench To . MD Btm. MD Feet G1 9,984 10,003 19 .............................................................................................................................................................. ............................... G2 10,022 10,047 25 G3 10,095 10,128 33 G4 10,137 10,186 49 .......................................................................................................................................................................................... ............................... G4 10,249 10,266 17 G5 10,315 10,340 25 .............................................................................................................................................................................................. ............................... G5 10,352 10,368 16 G6 10,426 10,448 22 G7 10,486 10,493 7 Total .......... ............................... 213 ........................... . 21. RD E -line. 22. PU Hydraulic set injection packer and RIH on 4 -1/2" completion string. 23. Circulate packer fluid and Set Packer at 9899' + / -. 24. ND BOP, NU Well head. 25. Perform initial MIT test. 26. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematics • 139,086 . ,193 12/97 /3/12 — I -05RD 10/06 / 10/0 71 129 0 0 '° 02A �`"° 5,45613 a W • W 746,079 s e D -24 39 _ l4 . co °o ° b -24 co co ` 3 1 , � q , W "cP 67 IR D-17RD 34A : • ' t • 7 8 Syr. 0 11/7 t • % 1 -17 o co 7/79 1 63,26 2 / D -Q o 5/69 12/87 , 8 c G b 11 %81 8 194,293 0 `° 3/12 / 3/12 D-04 D co to F i9 e r -�- D -25RD m ^ D - 09' D o° _ HILCORP ALASKA, LLC W 1,140,6 : 7 111D-09 % co , - - -D -25 10/77 MCARTHUR RIVER FIELD 12/86 G 20,E STRWTRE 40 ° O ° D -34A Base Map 0 4o m co ° A. o -9. 4" y �o 1 000 ■ ilk 445,601 �� CP FEET ■ 0 1/12 / 3/12 • 3 r I ^� 37 Co *-0- y 9‘ �� POSTED WELL DATA 0 0 0 y .g , co T o rn ° o 0 975, D- 4 �y o 9/01' . Well Label top L 1. D - 3/12 /3/12 PD CUM - M IDDLEKENAIG O (BBL) 2 9 52 D -12RD D_C UM - MIDDLEKENAIG1W (BBL PdCum -TO DATE TBU GZN - NET_PAY[MJF] ' -D -12 ' : 80 WELL SYMBOLS co?'" 121,594 • Oil Well 12/11 / 12/11 4. Dry Hole 1 Injection Well co _08R 11 Plugged & Abandoned C i o crt .c. 0 Converted Water -Input Vv o Abandoned Water Inject o \ / Shut-in Oil Well June 8, 2012 PETRA 6/62012 7.30 AM Page 1 of 2 Schwartz, Guy L (DOA) From: Ted Kramer [tkramer@hilcorp.com] Sent: Friday, June 15, 2012 10:37 AM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Cc: Tom Fouts - (C); Regg, James B (DOA) Subject: RE: Sundry for D34A ( PTD 179-011) Attachments: Sundry 312-213 for D -34A RespLtr-06-15-12.pdf Guy, In answer to your Email below, please open the attachment. It includes an updated procedure that includes the pressure test, the area review of the cement bond for D -34A and the surrounding wells, and a map of the % mile radius. A hard copy of this information has been put in the mail for your files. Respectfully, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 SCMNED From: Schwartz, Guy L (DOA) [mailto:guy.schwa rtz@alaska.gov] Sent: Tuesday, June 12, 2012 9:23 AM To: Ted Kramer; Ferguson, Victoria L (DOA) Cc: Tom Fouts - (C); Regg, James B (DOA) Subject: RE: Sundry for D34A ( PTD 179-011) Ted, As per our discussion you have verbal approval to start the RWO on D -34A. I have reviewed the procedure and a couple of changes are needed: 1) After step 12 ( setting the CIBP and dumping cement) the plug (and casing ) needs to be pressure tested to 2500 psi./30 min to verify the Hemlock is isolated. 2) Before perforating the G -zone oil pool an assessment of the 7" liner cement bond must be done and submitted to the Commission. There may have been a CBL run in 1990 during the conversion to injector but I don't have a copy here in the Commission's records. If this log was not run an assessment of the 7" liner cement should be based on the original cementing records. 3) As a new Pool is being perforated a '/4 mile review (Area of Review) should be done also for impacted wells around the injector. Please provide a map of the BHL and adjacent wells in the %4 area. Thanks, 6/15/2012 Page 2 of 2 Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ted Kramer [mailto:tkramer@hilcorp.com] Sent: Tuesday, June 12, 2012 7:36 AM To: Ferguson, Victoria L (DOA); Schwartz, Guy L (DOA) Subject: Sundry for D34A Victoria and Guy, The rig on the Dolly platform is moving faster than even we anticipated. Therefore we will be moving to the D - 34A sometime today. I wanted to see if there was a way this sundry could e expedited or if a verbal could be given so we could proceed with the BOP nipple up and test. I am in Kenai today but can be reached on my cell Phone to discuss if necessary. Thanks, Ted Kramer Senior Operations Engineer Hilcorp - Alaska Office 907-777-8420 Cell 907-867-0665 6/15/2012 .lune 15, 2012 Guy Schwartz State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry for RWO on D -34A Dear Guy: Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 100 Anrhorage, AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 This letter is in response to your e-mail ol'Junc 12, 2012 regarding the above workovcr. Item 1: Addresses the need of conducting a pressure test on the cast-iron bridge plug of 2500 PSI for 30 min. to verify that the Hemlock zone is isolated. Response: That item has now been added to the workover procedure a copy of which is attached. Item 2: Conduct an assessment of the D -34A 7 inch liner cement job tram an applicable cement bond log. Response: An assessment of the cement bond log for the 7 inch liner in well D -34A was conducted by myself and Kerry Richards from Baker Atlas on June 13, 2012. Utilizing a dresser Atlas CBL ran on April 16, 1979 the following was found: The D34A contains 140 feet of well bonded cement above the top planned G -zone pert located at 9984 feet to the top of the G zone. Looking at the base, the D34A well has over 90 feet of well bonded cement below the bottom perforation at 10,486 feet to the base of the G zone. Therefore, Hilcorp believes that the G zone in this well bore is well isolated and that water injected water will be contained to the G zone reservoir. V- Item 3: Provide an area review of %4 mile of all wells impacted by this injector. Provide a map of bottom hole locations (Bill.) and Adjacent wells in the'/4 mile arca. Mi. (,uy Schwartz June 15, 2012 Page 2 of 3 Response: A map of the BHL and adiacent wells is attached for the 1/4 mile area surrounding D -34A. A review of the five wells in the 'A area surrounding, f3 -34A for cement integrity is in the table below: (`131. Results Cement Well CBT. Comments (Y N N/A Review Circ. Out 900 sxs. D-4 2 Stage cement job. Pumped 1600sx class g followed by 900sxs. Very good Cement bond from Class g D-4RD Y 800 sxs. 8200' down to PBTD at 12,089' Class g (G -zone 10,628— 11,262') D-17 N N/A 1167 No Bond log across the Sxs. g -zone. There was one Class g higher which showed very good cement bond Very good Cement bond from 900 sxs. down to 8,200 feet__ 1)-171ZU Y 8800' down to PBTD at Class k 10,676'. (G -zone 9,500 10,040' D-2ARD Y Very good cement bond from 1,100 Good containment 11,250 up to 10,380 ft. There is sxs. above the G -zone. a section of pipe that is approx.. Class g 70% bonded intermixed with good bonded pipe from 10,380 up to 10,160'. Very good cement bond from 10,160 up to 10,000'. (G -zone is from 10,201 to 10,679) Based on the volume of cement pumped and the results of the cement bond logs, I lilcorp believes that the G -zone surrounding, the: D -34A well is contained and isolated from the rest of the well interval and that the injected fluid will stay in zone. Mr. Guy Schwartz June 15, 2012 Page 3 of 3 Sincerely, Ted E. Kramer Senior Operations Engineer IIILCORP ALASKA, LL,C Attachments: Updated Procedure (Ver. 3) Map of `A mile radius surrounding D -34A I H leil.oaa llu-6a, 1.1! Well Work Plan Well: D -34A Date: 06/07/2012 Ver. 3 Well Name: Current Status: Estimated Start Date: D -34A API Number: 50-733-20225-01 Leg: A-1 Northwest Crnr Rig: Cudd Hydraulic Workover Unit Water Injector June 14, 2012 _ Reg. Approval Req'd? June 14, 2012 Appropriate Reg. Tech Date Reg. Approval Rec'vd: 1 Permit to Drill Number: 179-011 Regulatory Contact: First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Mike Dunn (907) 777-8382 (0) (907) 351-4191 (M) AFE Number: Pending Current Bottom Hole Pressure: 3,800 psi @ 9,531 TVD (mid pert of 10,795 MD). Based on Offset Well D-31 RD from the 2009 Redoubt Shut In Maximum Expected BHP: 3800 psi @ 9,531 ND Max. Allowable Surface Pressure: 0 psi (Using 0.435psi/ft to surface) Well Summary The D 34A is currently completed as a Hemlock injection well. In March of 2012 this well-developed tubing to casing communication and the well was shut in. Further investigation into the bottom hole location identified that this well was better suited for a G Zone injector. Procedure: 1. MIRU CUDD Hydraulic Workover Unit. 2. RU E -line, RIH with tubing punch to 10,335' and punch tubing. 3. Reverse circulate one tubing volume of FIW. 4. Shut down pump for one hour. Kick in pump and record number of barrels to catch fluid. a. Note: Well will not flow to surface. 5. Calculate fluid loss rate (Bbls. / Hour). If Loss is greater than 20 bph, mix graded rock salt pill in FIW. 6. Pump pill and recalculate fluid loss. If acceptable, continue to step 6. Otherwise repeat step 4. 7. ND wellhead and NU BOP stack. Pressure test BOP to 250 psi. low / 3,000 psi high. Note: notify AOGCC 48 hours in advance of test for the opportunity to witness bop test. 8. RIH with tubing cutter on E- line to (+/-) 10,372' and cut tubing. 9. RD E -line. 10. POOH laying down 3-1/2" tubing string. 11. Rig up circulating system with Magnets for possum belly. 12. PU overshot mill and down hole motor on 4" HT -38 work string and RIH to Baker SAB -3 Packer at 10,375'. Mill up and remove same. 13. PU bit and scraper and RIH to 10,550ft. POOH with same laying down 4" HT -38 work string. 14. RU E -line. RIH with CIBP to 10,540'. 15. Dump bail 20' of cement on top. 16. WOC 24 hours. 17. PU test packer on work string and RIH to 10,510'. 18. Set Test packer and test cement plug to 2,500 psi for 30 minutes. 19. POOH with test packer. Ifily rp kla.ka. LLC Well Work Plan Well: D -34A Date: 06/07/2012 20. RU Schlumberger perforating unit and perf the following G -zone intervals: (Vote: Use landing joint with large cross-over in stack crossed back over to Bowen head _connection for well control. RPnrh Top Mp Btm.IVID (Feet G 1 9,984 10,003 19 G210,022 __.__—_...___..._...._..___...._..._ 10,047 ..............__.___ 25 ......_................... - _ G3 10,095 _ 10,128 ........___.___.._ 33 _._._.---.._. G4 10,137 10,186 49 G41 .. 10,266.............__..._ G5 10,315 I 10,340 25 G5 10,352 I 10,368 16 G6 10,426 10,448 22 G7 10,486 10,493 7 Total 21. RD E -line. 22. PU Hydraulic set injection packer and RIH on 4 112" completion string. 23. Circulate packer fluid and Set Packer at 9899' 24. ND BOP, NU Well head. 2.5. Perform initial MIT test. 26. Turn well over to pruduction. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematics 139,086 193 -05RD 7 c 129 i \ • c ° D-02A �5,456 136/r 746.079 ;12(D-24 � \ 39 r Q ao C N '5-24 ti �. 34A ej 4. • aD-05 78 0 i `\ Co 653.26 I ,.3 ----------------- 194.293 0 D-04 RD D-25RD g 1t #'VO C-09�D D-25 �S HILCORP ALASKA, LLC 1 ,140,627iV fi ! MCARTHUR RIVER FIE-D ...ae. 00 t 445.601v//`b FEET I ! D-r 3 vc. yam- "C' ?OS'=D .'JELL DATA l m 975,3'• D-46' �� "ell Label ./� Ozone :oF � �D-09 52 D 12RD t/ Po COM-MIDDLE. „dL, 3 ` D D TBU�CsZN AIY MJFGOW IBBL 1 t it e� it WELL SYMBOLS •�' 121,594 f % • DII 'Nell ` Dry Ho!e i r Ineccon Well 0 13 / Pra37ed & Abandoned Gi )Ff, Ccn+erted Water-Input Abandoned Water Inject ` + Smut-m Oct Well { ,:une 8 23'2 P AWW?017 I'M NAM ;i Y • • riA r@ [LA �, SEAN PARNELL, GOVERNOR L ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVA COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Ted E. Kramer Sr. Operations Engineer — 0 I Hilcorp Alaska, LLC 1 ( I 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock & Middle Kenai G Pool, TBU D -34A Sundry Number: 312 -213 Dear Mr. Kramer: SigAtiNED JUL 6 20 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. r Commissioner DATED this e- day of June, 2012. Encl. 1 1 . c r12 RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 0 8 2012 APPLICATION FOR SUNDRY APPROVALS iAOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrtll ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations V Perforate B. Pull Tubing 0 • Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Recomplete p • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Development ❑ Exploratory ❑ 179 -011 • 3. Address: Stratigraphic ❑ Service EI v 6. API Number. 3800 Centerpoint Drive, Suite 100, Anchorage, AK 99503 50 -733- 20225 -01 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership cianges: Spacing Exception Required? Yes ❑ No 0 Trading Bay Unit / D-34A • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0018729 • McArthur River Field / Hemlock & Middle Kenai G Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): r Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 1 yid 9,963 11,185 9,872 None None Casing •6 r L ength Size MD TVD Burst Collapse Structural Conductor Surface Intermediate 2,080' 13 -3/8" 2,080' 2,012 3,090 psi 1,540 psi Production 10,295' 9 -5/8" 10,295' 9,097 5,750 psi 3,090 psi Liner 1,416' 7" 11275' 9,963 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,550 - 10,585 9,314 - 9,345 3 -1/2" L -80 9.3 10,437 10,610 - 10,625 9,367 - 9,380 10,640 - 10,660 9,393 - 9,411 10,740 - 10,755 9,481 - 9,494 10,788 - 10,824 9,524 - 9,556 10,834 - 10,920 9,565 - 9,642 10,950 - 11,040 9,669 - 9,750 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker SAB -3 Packer / N/A 10,375 / N/A 12. Attachments: Description Summary of Proposal C 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch el Exploratory ❑ Development ❑ Service El 14. Estimated Date for 15. Well Status after proposed work: 6/15/2012 Commencing Operations: 011 ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: 4•IZ - I L WINJ 0 • GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: Sc A.c., /I -L._ GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing and correct to the best of my knowledge. Contact Ted E. Kramer Printed Name Ted E. Kramer Title Sr. Operations Engineer Signature � I Phone (907) 777 -8420 Date 6/7/2012 // COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5 r22 13 Plug Integrity ❑ BOP Test M Mechanical Integrity Test I Location Clearance ❑ Other: lie_ 3600 p S ` ' ;1- Subsequent Form Required: /0 6' /0 APPROVED B Y Approved by � COMMISSIONER T MISSION Date: 6 7;27/ '' se 1m1R� tlUI1R0 0 u mit u1 Duplicate \ ! L " � i L�14 4,./z l jL • • Well Work Plan Well: D -34A Hilcorp Alaska, LLC Date: 06/07/2012 Well Name: D -34A API Number: 50- 733 - 20225 -01 Current Status: Water Injector Leg: A -1 Northwest Crnr Estimated Start Date: June 14, 2012 Rig: Cudd Hydraulic Workover Unit Reg. Approval Req'd? June 14, 2012 Date Reg. Approval Rec'vd: Regulatory Contact: Appropriate Reg. Tech Permit to Drill Number: 179 -011 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Mike Dunn (907) 777 -8382 (0) (907) 351 -4191 (M) AFE Number: Pending Current Bottom Hole Pressure: ` 2,679 psi @ 8,848 TVD (mid pert of 10,333 MD). Based on Offset Well M -31 from the 2009 Redoubt Shut In Maximum Expected BHP: 2,700 psi @ 8,848 TVD - Max. Allowable Surface Pressure: 0 psi (Using 0.435psi /ft to surface) Well Summary The D 34A is currently completed as a Hemlock injection well. In March of 2012 this well developed tubing to casing communication and the well was shut in. Further investigation into the bottom hole - location identified that this well was better suited for a G Zone injector. Procedure: 1. MIRU CUDD Hydraulic Workover Unit. 2. ND wellhead and NU BOP stack. Pressure test BOP to 250 psi. low / 3,000 psi high. Note: notify AOGCC 48 hours in advance of test for the opportunity to witness bop test. 3. RIH with tubing punch and punch tubing ( + / -) 40 feet above the Baker SAB -3 packer. 4. Reverse circulate one tubing volume of FIW. 5. Shut down for 1 hour and monitor fluid loss. Kick in pumps and measure number of barrels top catch fluid. Calculate fluid loss to formation. Adjust loss to acceptable level by pumping graded rock salt (or other acceptable fluid loss material) pill in FIW. Note: Well will not flow to surface. 6. RIH with tubing cutter on E- line to ( +1 -) 10,360' and cut tubing. 7. RD E -line. 8. POOH laying down 3 -1/2" tubing string 9. PU overshot mill and down hole motor on 4" work string and RIH to Baker SAB -3 Packer at 10,375'. Mill up and remove same. 10. PU bit and scraper and RIH to 10,550ft. POOH with same, RU E -line. RIH with CIBP to 10,540'. �-� & P2� f 12. Dump bail 20' of cement on top. Tf�SS 4CS c-5> 4 2--c6 c /?6D . . • • Well Work Plan Well: D -34A Hilcorp Alaska, LLC Date: 06/07/2012 13. RU Schlumberger perforating unit and pert the following G -zone intervals: Bench Top MD Btm. MD Feet G1 9,984 10,003 19 G2 10,022 10,047 25 G3 10,095 10,128 33 G4 10,137 10,186 49 G4 10,249 10,266 17 G5 10,315 10,340 25 G5 10,352 10,368 16 G6 10,426 10,448 22 G7 10,486 10,493 7 Total 213 14. RD E -line. 15. PU Hydraulic set injection packer and RIH on 4 -1/2" work string. 16. Circulate packer fluid and Set Packer at 9899' + / -. 17. ND BOP NU Well head. 18. Perform initial MIT test. 19. Turn well over to production. �- Wo F /C n /O - f�� r V/ vie -ss r .� A 1 f q �t �- `7 Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematics • i McArthur River Field, TBU Well: D -34A As Completed: 12/27/1990 Hilcorp Alaska, LLC ASBUILT CASING AND TUBING DETAIL All measurements are RKB to top of equipment. SIZE WT GRADE CONN ID TOP BTM. CIW DCB -FBB tbg. Hanger. 410 Stainless steel treated to NACE MR- 01 -75, 3.5" 8RD EUE x 3.5" 13 - 3/8" 61 J - Butt 12.515 Surf. 2,080' DSS -OHTC 9 -5/8" 40 N -80 Butt 8.835 Surf. 2,556' 9 -5/8" 47 N -80 Butt 8.681 2,556' 8,351 1 9 -5/8" 47 P -110 Butt 8.681 8,351 10,295' L 2 7" liner 29 L -80 Butt 6.184 9,859' 11,275' 3 Tubing 3 -1/2" 9.3 L -80 555- HTC;IPCw/ 2.992 TK -69 Surf 10,437' JEWELRY DETAIL NO. Depth ID Item 1 307' 2.88" Otis Flow Coupling 2 313' 2.813" Otis "X" Nipple/ MCX injection safety valve w/ 58/64" port and equalizing sub 3 314' 2.88" Otis Flow Coupling 4 10,373' Baker KC -22 Anchor 5 10,375 3.25 Baker SAB -3 Pkr 4.5" LTC box dwn; Baker Mill out ext. 4.5" LTC PxP XO 4.5" LTC B x 3.5" DSS -HTC P 6 10,396' 2.813" Otis "X" Nipple 7 10,431' 2.75" Otis "XN" Nipple x .MK 8 10,437' Baker Ball Catcher Sub/ WL Entry Guide L 4 S. PERFORATION DATA :%K 5 Accum. Date 9,291 Zone Top Btm Amt Last Phasing SPF O P r. 6 B -1 10,550' 10,585' 35' 8 11/90 45 10,610' 10,625' 15 11/90 CMT Squeezed B -2 10,640' 10'660' 20 11/90 CMT Squeezed 8 10,740' 10'755' 15 8 11/90 45 B -3 B 1 10,788' 10,824' 36 8 11/90 45 B -4 10,834' 10,920' 86 8 11/90 45 B -5 10,950' 11,040' 90 8 11/90 45 Eg ® B Fish ID Description Depth B -3 A Retainer & Junk 11,091' = B Old Isolation Packer 11,098' = B -4 = B -5 A B Note: 8/22/2007 2.5" GR tagged up at 11,052' Plug Back Depth = 11,185' TD = 11,275' MD/9,963' TVD Last Updated: 6/5/12 by TDF • • McArthur River Field, TBU Well: D -34A As Completed: 12/27/1990 Hilcorp Alaska, LLC PROPOSED CASING AND TUBING DETAIL All measurements are RKB to top of equipment. SIZE WT GRADE CONN ID TOP BTM. CIW DCB -FBB tbg. Hanger. 410 Stainless steel treated to NACE MR- 01 -75, 3.5" 8RD EUE x 3.5" 13 -3/8" 61 J - Butt 12.515 Surf. 2,080' DSS -OHTC 9 -5/8" 40 N -80 Butt 8.835 Surf. 2,556' 9 -5/8" 47 N -80 Butt 8.681 2,556' 8,351 9 -5/8" 47 P -110 Butt 8.681 8,351 10,295' 7" liner 29 L -80 Butt 6.184 9,859' 11,275' L Tubing 4 -1/2" 12.6 L -80 Hydril 563 3.958 Surf ±9,909 JEWELRY DETAIL NO. Depth ID Item 1 ±9,899' 4.5" Packer 2 ±9,910' 3.813" "X" Nipple 3 ±9,911' N/A Wireline Guide 4 ±10,540' N/A CIBP PERFORATION DATA Accum. Date Zone Top Btm Amt Phasing Op r. Last O r. G -1 ±9,984' ±10,003' 19 5 Pending 72° F G -2 ±10,022' ±10,047' 25 5 Pending 72° L 1 G -3 ±10,095' ±10,128' 33 5 Pending 72° ±10,137' ±10,186' 49 5 Pending 72° G -4 2 3 = G -1 ±10,249' ±10,266' 17 5 Pending 72° ±10,315' ±10,340' 25 5 Pending 72° G -5 G -2 ±10,352' ±10,368' 16 5 Pending 72° G -6 ±10,426' ±10,448' 22 5 Pending 72° G -3 G -7 ±10,486' ±10,493' 7 5 Pending 72° B - 1 10,550' 10,585' 35' 8 Nov - 90 Isolated = G - 4 10,610' 10,625' 15 Nov -90 Isolated B -2 10,640' 10'660' 20 Nov -90 Isolated G -5 10,740' 10'755' 15 8 Nov -90 Isolated B -3 10,788' 10,824' 36 8 Nov -90 Isolated 0-6 B -4 10,834' 10,920' 86 8 Nov -90 Isolated _ B -5 10,950' 11,040' 90 8 Nov -90 Isolated = G -7 TOC 10,515" Fish ,, I I ID Description Depth - B-1 A Retainer & Junk 11,091' ® B -2 g. B 3 B Old Isolation Packer 11,098' B-4 A B = B -5 Note: 8/22/2007 2.5" GR tagged up at 11,052' Plug Back Depth = 11,185' TD = 11,275' MD/9,963' TVD Last Updated: 6/8/12 by TDF • • • Dolly Varden Platform 2012 BOP Stack 05/15/2012 %t.,.t..,. t.t,t. Dolly Varden D -34A Recomplete and Perforate 4.54' • Hydril ' GK 13 518 -5000 Iii ;I 1111.1111 •11 111 111 111 I/1 4.67' Cjt 2 7/8 -5 variables - RI Boosterbon,tsonbotto i — Bl Shear 111 111 11111111111 w 1!1 111111 M I!1 2.00' II∎.I1:®11f: jI : 1i, • 1i1 111 111III I!I I11 I!1 III II) 2.83' . — 2 7/8 -5 variables i1. ,11 III tII 111 1.17' I! 111 111 111 1111 Drill deck Riser 13 5/8 5M FE 14.20' X 13 5/8 5M FE 111 1111111111.1 tit 111 111 111 111 Spacer spool 2.16' 135/85MFEX 135/85M III III I PlII lit FE Illl lil I!' 111 111 Spacer spool 2.00' 135/85MFEX 135/85M 111 1.1 .II i1. III FE UOCD 1!1. U i 1 I!I Crossover spool 1.41' 1227 ,;; ;, ,;,,;, 13 5/8 5M FE X 11 5M FE Page 1 of 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, June 12, 2012 9:23 AM To: 'Ted Kramer'; Ferguson, Victoria L (DOA) Cc: 'Tom Fouts - (C)'; Regg, James B (DOA) Subject: RE: Sundry for D34A ( PTD 179 -011) Ted, As per our discussion you have verbal approval to start the RWO on D -34A. I have reviewed the procedure and a couple of changes are needed: 1) After step 12 ( setting the CIBP and dumping cement) the plug (and casing ) needs to be pressure tested to 2500 psi. /30 min to verify the Hemlock is isolated. 2) Before perforating the G -zone oil pool an assessment of the 7" liner cement bond must be done and submitted to the Commission. There may have been a CBL run in 1990 during the conversion to injector but I don't have a copy here in the Commission's records. If this log was not run an assessment of the 7" liner cement should be based on the original cementing records. 3) As a new Pool is being perforated a 1/4 mile review (Area of Review) should be done also for impacted wells around the injector. Please provide a map of the BHL and adjacent wells in the % area. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Ted Kramer [mailto:tkramer @hilcorp.com] Sent: Tuesday, June 12, 2012 7:36 AM To: Ferguson, Victoria L (DOA); Schwartz, Guy L (DOA) Subject: Sundry for D34A Victoria and Guy, The rig on the Dolly platform is moving faster than even we anticipated. Therefore we will be moving to the D -34A sometime today. I wanted to see if there was a way this sundry could e expedited or if a verbal could be given so we could proceed with the BOP nipple up and test. I am in Kenai today but can be reached on my cell Phone to discuss if necessary. Thanks, Ted Kramer Senior Operations Engineer Hilcorp - Alaska Office 907 - 777 -8420 Cell 907 - 867 -0665 6/12/2012 Regg, James B (DOA) Pn I1'/O!(o From: Larry Greenstein [Ireenstein @hilcorp.com] Sent: Friday, March 23, 2012 2:02 PM � 3, z Z�i z To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: Michael Dunn ✓ Subject: RE: Dolly D -34A (PTD# 179 -011) - RTI procedure request - Update Per your request, Jim. Appears the tree is not the cause the pressure communication (step 1 of RTI plan). We plan to run the baseline temp survey in this well when the equipment becomes available (step 2). Would be good to talk about the validity of a CMIT vs temp survey comparison with TIO plot for prove up on casing integrity before we get too far along this path. I want to make sure we are all comfortable with the process of getting a well back on injection once communication has been detected. Larry From: Clint Chanley Sent: Thursday, March 22, 2012 2:47 PM To: John Lee; Larry Greenstein; Jon Loomis; Christy Anderson Cc: Chris Myers; Paul Mazzolini Subject: 34A Wellhead integrity 9 ' hiiNE ) MAR all Gents Results of testing hanger voids on wellhead. Looks like everything is okay for injection on the wellhead. Will not cause any casing pressure issues. Tubing hanger void: Test good 250 /5000psi. Still had good test oil in void, no sign of any leakage in the past. Casing crossover void (9 5/8 X 13 3/8): Test good 250/2500psi. Did leak at first, had water in void. Recharged X bushing secondary seal with plastic injection, retested, everything ok. This leak would have not ever caused any issues, primary seal on slip type hanger still had full integrity. Thanks Clint Chanley Wellhead Specialist Hilcorp Alaska Work 907 - 776 -6881 Cell 907 - 252 -8219 1 PM I Olio Regg, James B (DOA) From: Regg, James B (DOA) �� Sent: Wednesday, March 21, 2012 10:58 AM ( ' 21 I To: 'Larry Greenstein' Cc: Schwartz, Guy L (DOA); Michael Dunn Subject: RE: Dolly D -34A (PTD# 179 -011) - RTI procedure request The diagnostic plan does not require AOGCC approval, but results will be necessary as supporting documentation for AOGCC decision about allowing well to return to injection. I would also encourage you to consider mechanical integrity testing (MITT, MITIA, CMIT TxIA) as appropriate, and either include results with other diagnostics or provide an explanation /justification as to why Hilcorp believes MIT(s) represent an unacceptable step in the effort to return TBU D -34A to injection. You mentioned planned work on TBU injectors — that is welcome news and hole Hilcorp will follow through to restore the mechanical integrity of at least the important water injectors in the field. Priorities /schedules — to the extent you can share them — would be useful information in support of an Admin Approval request. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 '1 MAR 8 'LUIZ Anchorage, AK 99501 907 - 793 -1236 From: Larry Greenstein [mailto:Igreenstein@ hilcorp.com] Sent: Wednesday, March 21, 2012 9:35 AM To: Regg, James B (DOA) Cc: Schwartz, Guy L (DOA); Michael Dunn Subject: Dolly D -34A (PTD# 179 -011) - RTI procedure request Hi Jim, As reported Monday (see attached), the Dolly D -34A well now appears to have tubing x casing communication and has been shut -in. We would like to return this well to injection through the Administrative Approval (AA) process, so we request your approval to begin the process. Our plan would be to: 1) Confirm the tree is not the communication conduit 2) Run a baseline temperature survey while the well is shut -in - 3) Return the well to injection for 2 -3 weeks to establish a solid downhole temperature profile - 4) Run another temperature survey to prove up on fluid containment by overlaying with the baseline survey 5) Provide you with an AA request for a RTI with the required back -up documentation attached - Assuming success at the first four steps, the fifth step would be the approval needed to return this well to injection. If this plan meets with your approval, please let me know and we'll proceed. Larry 1 • • i4 -(c�� PrtiqqO M TRADING BAY UNIT WELL D -34A COMPLETED 12/27/90 All measurements are RKB to top of equipment. CIV DCB -FBB tbg, hanger. 410 stainless steel treated to NACE MR- 01 -75, 3.5' 8RD EUE X 3.5' DSS -HTC, 307' Otis Flow Coupling (2.88' ID). 313' Otis 'X' Nipple (2.813' ID). Otis MCX injection safety valve w/ 58/64" port and equalizing sub instolled in X nipple. 314' Otis Flow Coupling (2.88" 10). 2080' 13 -3/8', 62#, J -55 Csg. • Completion String 0'- 10,437' a5', 9.311, L -80 DSS -HTC flog. IPC w/ TK -69 10,295' 9 -5/8', 40, 4711, N -80 & 47 #, P -110 Butt Csg. 10,373' Baker KC -22 Anchor. 10,375' Baker SAB -3 Pkr 4.5' LTC Box Down (3.25' ID). Baker Mill Out Ext 4.5' LTC PxP. c=3 X0 4.5' LTC B x 3.5' DSS -HTC P. 10,396' Otis 'X' Nipple (2.813' ID) 10,431' Otis 'XN' Nipple (2.75' ID) 10,437' Baker Ball Catcher Sub/ VL Entry Guide. = B -1 HEMLOCK PERFORATIONS Zone Interval, a SPF • Phasing late 0-1 10,550'- 10,585' 35 8 45 B -2 B -2 10,610'- 10,625' 15 Cmt Squeezed 11/90 10,640'- 10,660' 20 Cnt Squeezed 11/90 B -3 10740'- 10,755' 15 8 45 11/90 10,788' - 10,824' 36 8 45 11/90 H -3 0-4 10,834'- 10,920' 86 8 45 11/90 0-5 10,950' - 11,040' 90 8 45 11/90 Averoge Deviation = 28.0' w - HOMCO Steel liner csg patch covers the cmt sqzd B -2 perfs - reduces csg I.D. by 0.3' B-4 9859'- 11275' 7', 29 #, N -80 Butt Csg. 8/22/07: 2.5" B - (iR lagged up Retainer & Junk 2 11,091' Revision Date. 10/1/93 at 11052'. Old isolation pkr pushed to 11,098' Revised By' JCM /evo PBTD @ 11,185' Reason. Update nefrA ?�� ) )1/3/9 TD 2 11,275' , Previous Revision. 2/91 Prb , 1 1!0 Regg, James B (DOA) From: Larry Greenstein [Ireenstein @hilcorp.com] Sent: Monday, March 19, 2012 9:04 AM To: Regg, James B (DOA) Subject: Dolly Varden Injection Well D -34A (PTD #179 -011) is shut -in Attachments: D -34A TIO plot.xls Morning Jim, Last night, just before midnight, the D -34A 9 5/8" casing pressure spiked up to the injection pressure of 2800 #. The pressure would not bleed down, so the well was blocked in from the injection system and the 9 5/8" pressure was bled off. The well will remain shut -in while we explore the options for the well. In the meantime, the tree will be serviced to make sure the pressure increase wasn't a surface issue. Per the attached plot, besides a few injection upsets, there wasn't any indication that there were any casing pressure issues expected on this well. Larry 1 • • SiIVZa1 z, pm I 79 al - Plot Pressure & Rate vs Time - Well D -34A 3000 ‘14//14..‘1 Mr - • - 6000 —9 5/8" •I 13 3/8" — Tubing 2500 —Vol 5000 2000 II • 4000 E tn J N CO L 1500 -- -- 3008 1000 2000 500 1000 0 — 0 N N N N N I N N N N N N W I n N W N cn n a N O �- n n n n n n MEMORANDUM To: Jim Regg P.I. Supervisor ~~ ~C'IZ~('lii~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, June 18, 2010 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA D-34A TRADING BAY UNIT D-34A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprvyi ~~ Comm Well Name: TRADING BAY iJN1T D-34A API Well Number: 50-733-20225-01-00 Insp Num: mitCS100618084654 Permit Number: 179-011-0 Rel Insp Num: Inspector Name: Chuck Scheve Inspection Date: 6/10/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. D-34A~i- --- . Well Type Ind. 1790110 P.T.D~ ypeTest -I-- w ~ TVD SPT Test psi / 9164 2291 __ IA 100 QA 15 , .~ 2390 15 2370 2370 15 15 ~ Iriterval 4YRTST p~F, P Tllbing 2400 2400 _ i 2400 2400 NOtes: pre-test pressures were observed and found stable. Friday, June 18, 2010 Page 1 of 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical lrrtegrity Test --~' Email to:jim.regg@alaska.gov; phcebe.brooks@alaska.gov; tom.maunder~aMaska.gov; doa.aogcc.prudhce.bay~alaska.gov OPERATOR:. FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC 'REP: Union. Oi Company of California. McArthur River Field 1 TBU /Dolly Platform 06/10/10 Jason Sulley Chuck Scheve • Packer Depth Pretest Initial 15 Min 30 Min. Well D-29RD Type Inj. W TVD 8,460' Tuning 2,475 2,450 2,450 2,450 Interval 4 P.T:D.' 185003{3 Type test P Test psi: . 2915 Casing ~ 2:240 2,230 2,230 PIF P Notes: OA 160 160 160 160 -- t)-34x4 _ T Iri. W TVD 9,164' T 2,400. 2,400 2,400 2,400. Interval. 4 P.T.D. 1790110 Type test P Test psi 2291 Casi 100 2,390 2,370 2,370 P/F P Notes: OA 15 15 15 15 11Vell' D-41 Type tnj. W TVD 9,146' Tubing 2,500 2,500 2,500 2,5330 Interval 4 P.T.D. 1790830 Type test P Test psi 2287 Casing 390 2,370 2,350 2,350 P/F P Notes: OA 150 150 150 150 Well T pe Inj. TVD Tubing lrrteryal P.T.D. Type test Test psi Casing PIF Notes: OA Well Type Inj. TVD Tubing (ntenral P.T.D. Type test Test psi Casing P/F Notes: OA 'TYPE INJ Codes D =Drilling Waste G =Gas 1 =Industrial Wastevrater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D = DitfereMial Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) .r<<, - ~,ir'._ * '" ;„ ~ ~'~„a t .. ~. MIT Report Form Revised: 06!19/02 MIT Dolty_Varden_ 06-10-10.~ds rake -i v~ ~ 1 • Ma~~d~r, ~~oc~as E {DMA) __ From: Martin, J. Hal jHal.Martin@chevron.com] Sent: Wednesday, June 02, 2010 4:08 PTVI To: Maunder, Thomas= (DOA) Cc: Greenstein, Larry P; Agler, Brit G; Loomis, Jon • Anderson, Christy Subject: RE: State witnessed MIT on Dolly Varden D-29, D-34 D-41 Q'' Tom, 1~~ ~ As we discussed earlier today and to continue the thread below... The Dolly waterflood injection was shut-in in April 2009 due to surface piping issues. On 5/26/10, waterflood injection on the Dolly was restarted. We are monitoring all injectors as before the shut-in. Three wells (D-29RD, D-34A, and D-41 -see below) were due for their state witnessed 4-year Standard MIT test in November 2009, but were deferred since waterflood was down per AOGCC preference. Injection in these wells was restarted on 5/26/10 as well and appear to still have integrity. As we discussed, the Dolly folks will schedule to have a state representative come out next week and witness the MIT test on these three wells. Question -Will the 4-year MIT clock be reset as of )une 2010 or will it be from November 2009? Let me know your thoughts and if you have any questions. Thanx, Hal From: Regg, lames B (DOA) jmailta:jim.regg@alaska.goV] Sent: Friday, February 05, 2010 9:27 AM To: Martin, ]. Hal Subject: RE: State witnessed MiT on Dolly Varden D 2g, D 34 & D-41 Sorry to bother you about this; should have checked our well files before sending message based solely on a query of our MIT database for tests due. The correspondence was in our well files. No change to plan as stated previously - we will continue to monitor and defer MITs until wells put on injection. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 __. -From: Martin, J. Hal jmailto:Hal.Martin@chevron.com] Sent: Thursday, February 04, 2010 4:3b FM 6/11/2010 • • Page 1 Oe Regg, James B (DOA) From: Martin, J. Hal [Hal.Martin @chevron.com] II 1 1�? Sent: Tuesday, November 24, 2009 10:20 AM 1 To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Aubert, Winton G (DOA); Greenstein, Larry P; Lee, John R; Anderson, Christy D Subject: RE: State witnessed MIT on Dolly Varden D -29, 0& D -41 Jim, 6 0 9 54A Thanks for the reply. D -29RD and D -41 are shut -in and will remain so until waterflood injection is restored. D -34A has been on nominal effluent injection (generally less than 100 BFPD) over the last 2.5 weeks due to a rig workover that is now complete, but is now shut -in and will remain so until waterflood injection is restored. These wells will be put in the monthly waivered injection well report. Thanx, Hal From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, November 24, 2009 9:43 AM NED DE 2 2009 To: Martin, J. Hal Cc: Maunder, Thomas E (DOA); Aubert, Winton G (DOA) Subject: RE: State witnessed MIT on Dolly Varden D -29, D -34 & D -41 If shut in (zero injection), we will wait until wells are put back on injection to witness the MIT. In the meantime, the wells (D -29RD, D -34A, and D-41) should be included in the monthly waivered injection well report until put on injection. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: Martin, J. Hal [mailto: Hal. Martin @chevron.com] Sent: Wednesday, November 11, 2009 1:13 PM To: Regg, James B (DOA) Cc: Anderson, Christy D; Greenstein, Larry P; Lee, John R Subject: RE: State witnessed MIT on Dolly Varden D -29, D -34 & D -41 Jim, A point of clarification that I need to make and then also understand from you. You mentioned below that you would have an inspector contact the platform about 11/24/2009 Page 2p� conducting the MITs. I want to make sure you know that these wells are now shut -in and have been since mid - October. Since I thought you preferred having the wells on injection and stable before conducting the standard MIT test, let me know if you want to wait until injection is restored (sometime next year) or if you want to conduct an MIT test. Thanx, Hal From: Martin, J. Hal Sent: Wednesday, November 04, 2009 11:53 AM To: 'Regg, James B (DOA)' Cc: Bartolowits, Paul D; DOA AOGCC Prudhoe Bay; Anderson, Christy D; Greenstein, Larry P; Lee, John R; Johnson, Wayne E; Cole, David A Subject: RE: State witnessed MIT on Dolly Varden D -29, D -34 & D -41 Jim, Thanks for the reply. Sorry about misreading your e-mail concerning the issue about conducting an MIT following the "shut -in ". Now that I look back at it I see where you were coming from. I've got a few other issues I'm dealing with at the moment, but maybe next week sometime I'd like to give you a call and discuss a couple of the regulations that I'm not clear on and the scheduling of MITs for mutual benefit and the impact on the due dates. Thanx Hal From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Wednesday, November 04, 2009 10:06 AM To: Martin, J. Hal Cc: Bartolowits, Paul D; DOA AOGCC Prudhoe Bay; Anderson, Christy D• reenstein, Larry P; Lee, John R; Johnson, Wayne E; Cole, David A Subject: RE: State witnessed MIT on Dolly Varden D -29, D -34 & -41 Thank you for clarifying that these wells are not shut in, but j t isolated from the injection pumps and are still connected to the treated effluent system, and that small v me injection is continuing. You are correct that our 4 preference is to witness the MIT while on injection; we normally only deviate from that practice when it cannot be avoided. I will have an inspector contact the platform abo witnessing MITs on these 3 wells. TBU D -29RD (PTD 1850030) TBU D -34A (PTD 1790110) TBU D-41 (PTD 1790830) 1 did not suggest that you perform e MIT "prior to the volcanic eruption ". What I said in my email note was that - based on our injection records - nion had opportunity to perform the MITs in September or October. That statement appears to be con stent with the clarification provided. The variance I refer to.4 not related to loss of well integrity. It enters the picture when you go beyond the due date for conducting an MIT. Further, my comment was to understand why you would not (could not) test prior to I ' 11/24/2009 • Page 1 of 4 • Regg, James B (DOA) ~~ ~~~ _ _ __ _ __ _ _ _ ~.__. . From: Regg, James B(DOA) ~C,; ~~~I AI ~~~ Sent: Wednesday, November 04, 2009 10:06 AM ~ To: Martin, J. Hal Cc: Bartolowits, Paul D; DOA AOGCC Prudhoe Bay; Anderson, Christy D; Greenstein, Larry P; Lee, John R; Johnson, Wayne E; Cole, David A Subject: RE: State witnessed MIT on Dolly Varden D-29, D-34 & D-41 Thank you for clarifying that these welis are not shut in, but just isolated from the injection pumps and are still connected to the treated effluent system, and that small volume injection is continuing. You are correct that our preference is to witness the MIT while on injection; we will normally only deviate from that practice when it cannot be avoided. I will have an inspector contact the platform about witnessing MITs on these 3 wells. TBU D-29RD 1850030) TBU D-34A PTD 179011 ~ TBU D-41 (PTD 1790 I did not suggest that you perform the MIT "prior to the volcanic eruption". What I said in my email note was that - based on our injection records - Union had opportunity to perForm the MITs in September or October. That statement appears to be consistent with the clariflcation provided. The variance I refer to is not related to loss of well integrity. It enters the picture when you go beyond the due date for conducting an MIT. Further, my comment was to understand why you would not (could not) test prior to shutting in the injectors if you were planning work that would cause the injectors to be SI. Successful testing would restart the compliance clock; in this case, providing another 4 years until the next MIT is due, barring some loss of inechanical integrity. One last observation - the Commission witnessed safety valve system tests on Dolly Varden on 9/4/09; that would have been a good time to do the MITs. There may have been reasons not evident to us that prevented these MITs from being done on 9/4. Please ask your field operators to make an effort in the future to combine tests whenever possible. I hope you can appreciate that taking advantage'of~opportunities like this ensures we are best using the limited inspection resources we have. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 `~'"`~'~~~~~°1 '~'{~ `/ '~ ~~oU~ Anchorage, AK 99501 907-793-1236 From: Martin, J. Hal [mailto:Hal.Martin@chevron.com] Sent: Wednesday, November 04, 2009 8:38 AM To: Regg, James B (DOA) Cc: Bartolowits, Paul D; Noble, Robert C(DOA); Anderson, Christy D; Greenstein, Larry P; Lee, John R; Johnson, Wayne E; Cole, David A Subject: RE: State witnessed MIT on Dolly Varden D-29, D-34 & D-41 ]im, Below is the reply from Christy Anderson on the Dolly as he sent to us by a separate e- maiL 11 /4/2009 • • Page 2 of 4 Jim Niy confusir~n on terrninolo~~t so k misst~t~d that they wer~ SIL Th~~e thr~~ wel(s are isolat~d frarn aur injectior~ ~;um~~s ~c~r s~~rfac~ ~i~?~ r~placement. (This is why i s~id they v~~ere shut in.) ~he v~~ells ar~ still connected to ihe pi~ain~ s~r tiur treated e~ffuent syst~m an~ th~refore still shovd that they are Gc~iv~. They have shawn v~ry law vo(um~s af irj~ctian ~~,ring tl~~~ ~~st f~w ~nanrhs ~eca~.~~~ only i~ha freated eff(u~t~t t~~~s ~aeen going to them ar~d ntit water;lood. The ~Ic~ck v~lves o,=1 D-23, C-3~ & D-41 wer~ stiut on 1C~-12-2t~~9 roufing aIl the treated effiuent down ~-14RD in pr~par~;tic~~~~ ~~r mor~ ~~p~ re~lacement, The MIT c~n stil{ b~ done on thes~ weli's to keep in com~iiance. ~.et m~ Ync~w ~nd l.ve ~vilV s~:~ ur> a~ay to get them done. C~rist}r I~. l~rztic:i~s~n 1,eacl Opf~rat.or l3ollyr V~.al~cte~~ I'tatforr~~. PIi{.>ne 77E~-6~34Q i^a~; 77G-~"7€~20 In addition, I wouid like to add the following comments. 1. Christy's comments point to the fact that during the shut-in period following the volcano Chevron had some internal accounting issues regarding a well's designation of being on/off and the corresponding capture of minimai effluent injection volumes. The monthly reports you have show that the wells were shut-in between April and August, but in actuality small volumes of effluent injection as you observed in September were happening during this time also. For the three wells in question, there was not a long-term shut-in as it appears on the monthly reports. 2. The surface piping repair plan began in April/May of this year. Following the volcano eruption, surface piping inspection was conducted and found spot(s) with thin wall piping. This combined with the significant expenditure constraints placed on us resulted in a plan to do the repair work by reducing the spend, slawing down the time frame and get a good product by having the Dolly production personnel themselves plan/supervise/manage a lot of the work as they are able - it is actually quite a statement about the desire and willingness of the folks out there to find a way to manage their field expense funds and "get it done" without a lot of overhead process and cost. 3. There may have been opportunity for us to do MITs prior to the volcanic eruption, but we didn't know about the thin wall sections until we inspected the piping. Besides, the November MIT due date was a long way off and we expected to be back on waterflood injection by then. 4. I am not sure about "seeking a variance to the regulations" comment. We were ready to have the integrity of the well's tubing/packer/casing tested and witnessed by the AOGCC during a stable shut-in period which in my mind is similar to a stable injection period. However, since you prefer to conduct the MIT during active injection, we are certainly willing to schedule the tests once the wells have been returned to injection and reach thermal stability. Let me know if you have questions or need additional information. Thanks, Hal Martin 11/4/2009 ~ Page 3 of 4 ~ From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, October 30, 2009 4:14 PM To: Anderson, Christy D; Greenstein, Larry P Cc: Martin, J. Hal; Bartolowits, Paul D; Noble, Robert C(DOA) Subject: RE: State witnessed MIT on Dolly Varden D-29, D-34 & D-41 TBU D-29RD (PTD 1850030) TBU D-34A (PTD 1790110) TBU D-41 (PTD 1790830) Checked our well records; MITs are due 11/3/2009. You mention the wells are currently SI for replacement of surface piping from the injection pumps and that could take 6 months. Injection records show Union commenced injecting in September after a long SI - presumably tied to Redoubt eruption. There were 30 days injection for each well in September; unknown number of days each well injected in October. Realty begs the question - when was the surface piping repair planned? And, why were the wells not tested after commencing injection following the long Redoubt SI. Appears based on info we have that there was opportunity to do MITs prior to SI so that Union could remain in compliance without seeking an variance to the regulations. An explanation would be appreciated. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Anderson, Christy D [mailto:andercd@chevron.com] Sent: Thursday, October 29, 2009 6:53 PM To: Regg, James B(DOA); Greenstein, Larry P Cc: Martin, J. Hal; Bartolowits, Paul D Subject: RE: State witnessed MIT on Dolly Varden D-29, D-34 & D-41 Jim These wells are shut in at the present time because we are replacing the surface piping fram our injection pumps. It may be six months (hopefully less) before we are done and can bring the wells back on. The plan is that they will be brought back on when the piping is replaced. Bob Noble was scheduled to corne out Friday morning has been put on hold until you decide to da the MIT or not. Thanks Christy D. Anderson Lead Operator Dolly Varden Platform Phone 776-6840 Fax 776-6820 From: Regg, )ames B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, October 29, 2009 5:38 PM 11 /4/2009 . ~ ~ Page 4 of 4 , To: Anderson, Christy D; Greenstein, Larry P Subject: RE: State witnessed MIT on Dolly Varden D-29, D-34 & D-41 Understand these wells are SI. Is that long term? Our normal preference would be to wait for welis to be back on line before witnessing MIT Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Anderson, Christy D [mailto:andercd@chevron.com] Sent: Wednesday, October 28, 2009 3:03 AM To: Regg, James B (DOA) Cc: Bartolowits, Paul D; Lee, John R Subject: State witnessed MIT on Dolly Varden D-29, D-34 & D-41 Jim We would like to do the Dolly Varden MIT's that are due on D-29, D-34 & D-41 on Friday October 30th Let me know if this wili work. Thanks Christy D. Anderson Lead Operator Dolly Varden Platform Phone 776-6840 Fax 776-6820 11 /4/2009 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission . TO' ~~~< í<.~ I,/t~ -~;: ~ª:~;~;~~;~:5-\1- q-~ -01 J FROM: John Crisp TRADING BAY UNIT D-34A Petroleum Inspector Src: Inspector Reviewed By: P.I. SuprvSß12..- Comm Well Name: TRADING BAY UNITD-34A API Well Number 50-733-20225-01-00 Inspector Name: John Crisp Insp Num: mitTCr051111072804 Permit Number: 179-011-0 Inspection Date: 11/3/2005 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I D-34A Type Inj. I w j TVD I 9164 IA I 20 , 2425 ! 2425 I 2425 i ! I I P.T. 11790110 TypeTest I SPT I Test psi I 2291 OA i 290 310 I 310 ¡ 310 I i Interval 4YRTST P/F P Tubing ¡ 2600 2600 I 2600 I 2600 I I Notes The IA pressures recorded for the two previous days prior to M1T were 22 & 10 psi. NON-CONFIDENTIAL 5~Jt~~E[ ø ...ç t( .... Wednesday, November 16, 2005 Page 1 of 1 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us g reenstei n Ip@chevron.com; trod riguez@chevron.com OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: Unocal Alaska McArthur River Field I TBU / Dolly Platform 11/03/05 Pat King/Norman Fahnholz John Crisp Sr weill D-29RD I Type Inj. P.T.D. 185-003 Type test Notes: Packer Depth TVD I 8,460' Test psi 2115 Tubing Casing OA W P weill D-34A I Type Inj. P.T.D. 179-011 Type test Notes: I TVD I 9,164' Test psi 2291 Tubing Casing OA W P weill D-41 I Type Inj. W I TVD I 9,146' Tubing P.T.D. 179-083 Type test P Test psi 2287 Casing Notes: OA weill Type Inj'l I TVD I Tubing P.T.D. Type test Test psi Casing Notes: OA weill Type Inj. I TVD I Tubing P.T.D. Type test Test psi Casing Notes: OA TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test MIT Report Form BFL 911/05 Pretest 2525 160 510 Initial 2525 2140 520 4 P 15 Min. 30 Min. 2525 2525 Interval 2140 2140 P/F 515 515 2600 2600 2600 2600 Interval 4 20 2425 2425 2425 P/F P 120 325 325 325 2600 2600 2600 2600 Interval 4 0 2350 2350 2350 P/F P 290 310 310 310 Interval P/F Interval P/F INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) 5CA\N\NIEJD ~O\~ 0 8 2005 MIT _Dolly-11-03-05-1.xls 0\ \ ,.('C/ \ STATE OF ALASKA ALA~ OIL AND GAS CONSERVATION COMMIS~'~N 0 R REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown __ Stimulate __ Plugging __ Perforate Pull tubing __ Alter casing m Repair well m 2. Nam. e..o.f..(~p. Qrator ~L 5. Type of Well: UNUCAL (Marathon Oil - Sub Operato ) Development__ I Exploratory __ 3. AddrCs. s0. Box 190247 Anchorage AK 99519~ StratigraphiC__service ~ Leg A-1 Cond #10 Dolly Varden Platform FWL, Sec. 6 -8N-13W-SM 4. Location of well at surface 757' FSL, 1,210' At top of productive interval 1,080' FSL0 820' At effective depth FWL, Sec. 5 -8N-13W-SM 1,013' FSL, 1,040' FWL, Sec. At total depth 980' FSL, 1~155' FWL~ Sec. 5 12. Present well condition summary Total depth: measured 11,285 ' true vertical 9,960 ' Effec!ive depth: measured 11 185 ' true vertical ' 9,872' Casing Length Structural Conductor Surface Intermediate 2,080 ' Production 10,295 ' Liner 1,416' Perforation depth:measured 13 9 5 -8N-13W-SM -SN- 13W-SM Size feet feet feet feet Plugs (measured) Junk (measured) Cemented 3/8" 5/8" See 2,000 sx 2,480 sx 300 sx Attachment #1 IGilVA true vertical Tubing (size, grade, and measured depth) 3-1/2" 9.3# N/L-SO DSS - HTC Packers and SSSV (type and measured depth) Bi~ker SAB3 packer (IP£ w/ PA 13. Stimulation or cement squeeze summary Intervalstreated(measured) Cement squeezed Bench 2, casing patches across the Treatment description including volumes used and final pressure 10,605' - squeezed Squeezed w/ 14. Prior to well operation Subsequent to operation Other __~O r ko Ve r 6. Datum elevation (DF or KB) 106' KB above MSL ¢,Urct, or Pro..perty,rla~Q aolng uay un 1~: 8. Well number D-34A 9. Permit number/approval number 10. APl number $~33-20225-01 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 11. Field/Pool Hemlock None None Measured depth 2,080' 10,295' 11,275' RECEIVED True vertical depth 2,007' 9,092' 9,945' 10,665' and placed Homco intervals. 125 sx cmt, final pressure, 3600 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 227 161 1159 1100 3450 100 Service 16. Status of well classification as: Oil ~ Gas ~ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ ~¢~ Title ~:~. R' '06/1c'~-'-~ ~ ' Form 10-404 feet ~si Tubing Pressure 130 3400 Water Injection Date q - 8,-~ ~ SUBMIT IN DUPLICATE Attachment #1 TBU WELL D-34A Perforations Hemlock B-1 MD 10,550' - 10,585' TVD 9,312' - 9,342' B-3 10,740' - 10,755' 10,788' - 10,824' 9,480' - 9,493' 9,522' - 9,555' B-4 10,834' - 10,920' 9,563' - 9,641' B-5 10,950' - 11,040' 9°668' - 9,746' \docs\dvp\d34A. doc Attachment #2 TBU Wel 1 D-34A Daily Operations Summary 12/03/90 Skid rig to Well D-34A. Rig up wireline and pulled wireline retrievable SCSSV. RIH with lock out for safety valve. RIH with bottomhole pressure survey. Bled down casing pressure. 12/04/90 Reverse circulated to well clean tank. Perforated tbg 10,306' - 10,308'. Circulated to well clean tank. Well dead. RU Otis to set W/L plug. 12/05/90 Attempted to set W/L plug at 10,398' without success. Set BPV. ND tree & NU BOPE. Tested BOPE. RU to pull tbg. 12/06/90 Pull seals out of packer. Bullhead 20 bbls. Circulate down tbg to well clean tank. POOH w/ 4-1/2" & 3-1/2" tbg. PIJ pkr retrieving tool. 12/07/90 RIH w/ pkr retrieving tool to 10,400'. CBU - 1200 units gas on BU Monitor well, flowing. Hole taking fluid while circ. Tagged pkr ~t 10,429' DPM. Milled on packer & pushed down hole to 10,890'. Circ and raised Wt 8.4+ppg - 8.7 ppg. SD pump, well flowing. Circ & raised Wt to 8.8+ppg. 12/08/90 Monitored well, still flowing. Circ & raised Wt. to 9.0 ppg. Monitored well - stable. POOH. Recovered packer. RIH w/ mill. Tagged fill 10,882'. Lost power. Restored power. Washed fill from 10,882' - 10,938'. Milled on pkr at 10,938'. 12/09/90 Pkr fell free. Circ high visc sweep. Unable to POOH without circ. Circ high visc sweep. POOH while circ. LD singles. Stuck at 10,660' Circ & worked pipe. Hole packed off. Work/jar pipe. Ran freepoint tooi- free above jars. RIH w/ string. Shot & backed off at 10,618'. TBU Well D-34A ~ -~' Daily Operations Summary Page 2 12/10/90 POOH. RIH with washpipe. Washed over fish from 10,618' - 10,633'. Hole packed off & stuck washpipe. Worked pipe & jarred free. Washed to 10,639' & stuck again. Pulled free. CBU. Start POOH - wash pipe hanging up. POOH to liner top while circ& LD singles. POOH. 12/11/90 Ran bit and scraper to top of fish at 10,618' washing and working through liner. POOH. RIH w/ screw-in assembly. Screw into fish, jarring and working fish. 12/12/90 Jarred fish loose. Pump out to top of liner. POOH. Full recovery of pkr milling assembly. RIH w/ spear. Tag pkr tailpipe assembly at 10,949'. Push to 11,098'. POOH to liner top. CBU. POOH, no recovery. 12/13/90 Test BOPE 250/3000 psi, annular, 250/1500 psi. RIH w/ spear w/ larger grapple. POOH. 12/14/90 No recovery. RIH w/ bit and scraper. Wash to 11,093' DPM. CBU. POOH. RIH w/ cement retainer and set at 10,700'. POOH. 12/15/90 Set cmt retainer ~ 10,497'. Test casing and liner lap to 2300 psi Establish injection rate into perfs 1BPM ~ 3600 psi- Mix & pump ~25 sx cmt. Squeeze 31 sx into csg & 2.5 sx into perfs. Reverse out & POOH. Set storm pkr. ND & raise stack to inspect tbg spool. NU stack & test to 3000 psi. RIH to retrieve stom pkr. 12/16/90 Retrieve storm pkr. WOC. RIH with 6" bit. Drilled cement and retainer 10,473' - 10,600' Test csg to 1500 psi. Drilled cmt to 10,700'. Test to 1500 psi. Drill ~etainer & push junk to 11,091' Circ. 12/17/90 POOH w/ cleanout assembly. RIH w/ 9-5/8" scraper to liner top. Reverse circ & displace hole w/ filtered fluid. POOH. PU 7" csg scraper. 12/18/90 RIH w/ bit & scraper. Cleaned pits. Circ & filtered brine. TBU Well D-34A -~ ~-~' Daily Operations Summary Page 3 12/19/90 POOH. RIH w/ TCP guns. RU Schlumberger. RIH w/ GR-CCL. 12/20/90 Correlated guns. Set packer. Attempted to fire guns. No jolt felt but had strong blow to bubble bucket. Flowed for I hr. Killed well. POOH. Guns did not fire. Set storm packer at lg98'. POOH. Prepared to ND stack. 12/21/90 Changed out tbg spool. NU. Tested BOP's. Retrieved storm packer. 12/22/90 POOH w/ storm packer. RIH w/ TCP assembly. Correlate guns. Set packer. Fired guns & flowed well. Perforated B-3, 10,740' - 10,755' and 10,788' - 10,824'; B-4, 10,834' - 10,920'; B-5, 10,950' - 11,040'. Killed well. POOH. 12/23/90 POOH. LD TCP assembly. E-line perforated B-l, 10,550' - 10,585'. RIH w/ bit & scraper. Reversed out fill from 11,065' - 11,088'. POOH. 12/24/90 POOH w/ scraper. RIH w/ csg patch. RU Schlumberger & correlate depth. Set csg pa~ch 10,605' - 10,665' DIL. POOH. Lay down 3-1/2" DP & 4-3/4" drill collars. 12/25/90 Rigged up and RIH with packer and 3-1/2" tubing. 12/26/90 MU hanger. Circulated inhibited fluid. Landed tbg hanger. Attempted to test hanger. Repacked hanger. Retested hanger from top to 3000 psi. Set packer at 10,375'. Set "XN" plug at 313'. ND BOP. NU tree. Attempted to test void to 5000 psi. Failed. ND. 12/27/90 Replaced seals on hanger. Landed hanger. Nippled up tree. Tested void area to 5000 psi. Volume tested tree to 5000 psi. RIH with slickline and pulled "XN" plug at 313'. Released rig. \docs\dvp\d34A.doc Attachment #3 MARATHON OIL COMPANY TRADING BAY UNIT WELL D-34A COMPL£T£D 12/27/90 Ail measurements are RKB to top oF equipment. CI~ DCB-FBB tbg. hanger. 410 stainless stee( treated to NACE NR-Ol-75, 3.5' B~D EUE X 3.5' ~SS-HTC. ~07' O~ls F~o~ CoupLing <2.BB' I~>. ~1~' Ot;~ 'X' NippLe (2.813' IDA 31~' O~ls FLo~ CoupLing <2.BB' Comp(e~lon String: 0'-10,437' 3.5~ 9.38, L-80 ~SS-HTC Tbg. IPC w/ TK-69 2080' 13-3/8', 62#, J-55 Csg. 10,295' 9-5/8; 40, 47#, N-80 & 47ff, P-IlO Butt B-1 B-2 B-3 B-4 10,373' 10,375' 10,396' 10,431' 10,437' Baker KC-22 Anchor. Baker SAB-3 Pkr 4.5' LTC Box Down (3.25' ID). Baker Hill Out Ext 4,5' LTC PxP. XO 4.5' LTC ]~ x 3.5' DSS-HTC P. Otis 'X' N;pple (2.813' ID) Otis 'XN' N;pp[e (2.75' ID) Baker Bail Catcher Sub/ %/L Entry Guide. HEMLDCK PERFORATIONS Zone Interv&[ Ft SPF ' Phesmg Date B-1 10,550'-10,585' 35 8 45 B-2 10,610'-10,685' 15 Cmt Squeezed ~ 11/90 10,640'-10,660' 20 Cmt Squeezed 11/90 B-3 10,740'-10.755' 15 8 45 11/90 10,788'-10,824' 36 8 45 11/90 B-4 10,834'-10,920' 86 8 45 11/90 B-5 10,950'-11,040' 90 8 45 11/90 Average Deviation = 28.0' · - HOMCO Steel liner csg patch covers the cmt sqzd B-2 perPs - reduces cs9 I.D. by 0.3' 9859'-1L8:75' 7; 89#, N-BO Butt Csg. ? B-5 ' Reta;ne~ & Junk @ 11,091' Revision D~%e~ ;~/91 ~ nLd ;solar;on pkr pushe~ to 1~098' Revised By, JCM/evo Reos~, Conversi~ - . _~ PBT9 8 11,185' · ~ev~us Rev~ ~A .~~ STATE OF ALASKA '"~LASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ COR vert to Alter casing __ Repair well __ PluggingITime extension __ Stimulate m Change approved program __ Pull tubing N Variance __ Pedorate m Other,Y,_H eml cc k I nj ect¢ ,, 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL (Marathon 0il Co - Sub 0perat~m) Development__X 106' KB above MSL feet Exploratory ~ 3. Address Stratigraphic ~ 7. Unit or Property name P.0. Box 190247 Anchorage AK 99519 Service__ Trading Bay Unit , 4. Location of well at sudace Leg A-I Cond #10 Dolly Varden Platform 8. Wellnumber 757' FSL, 1,210' FWL, Sec. 6 -8N-13W-SM D-34A At top of productive interval 9. Permit number 1,080' FSL, 820' FWL, Sec. 5 -8N-13W-SM 79-11 At effective depth 1'0. APl number 1,013' FSL, 1,040' FWL0 Sec. 5-8N-13W-SM $o-733-20225-01 11 Field/Pool Att°~c~ePt~SL, 1,155' FWL, Sec. 5-8N-13W-SM H~mlock 12. Present well condition summary ! 1,285 ' Total depth: measured feet Plugs (measured) NOlle true vertical 9,960 ' feet Effective depth: measured 11,185 ' feet Junk (measured) Nolle true vertical 9,872 ' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface Intermediate 2,080' 13 3/8" 2°000 sx 2,080' 20007' Production 10,295' 9 5/8" 2,480 SX 10,295' 9,092' Liner 1,416' 7" 300 sx 11,275' 9,945' See Attachment #1 RECEIVED Perforation depth: measured true vedical DEC - 3 199~ Tubing (size, grade, and measured depth) ~Jas~Jr~,_ .0il & Gas Cons. C0mmissi0lt 4 1/2" N-80 e 9,818', 3 1/2" N-80 ~ 9,818' - 10,502' ~l~lrlchorag8 ~n(~,~][$ , ~is WD packer ~ 10,930', Otis TRBV @ 322' 13. Attachments 2 ~ .'3, Description summary of proposal .Z_ Detailed operations program __ BOP sketch _.Z. .4 & 5 14. EstimatecJ' date for commencing operation 15. Status of well classification as: ,qecember 1, 1990 16. If proposal wa~'verbally approved Oil X__ Gas N Suspended ~ Name of approver Date approved Service 17. I hereby/c~rtify ~hat the foregoing is true and correct to the best of my knowledge. Signed/1/~ J~ ~_~. .~ ~{¢',. ' e_~, , , ~L.,R ¢" Date {[ 2.. T,tle ~ ~ ¢-~,:,,_ . - - / FOR COMMI~ION US~NLY Conditions ~ ~ppr~v~l'. Notify Commission so representative may witnessI Approve,No. ?O Prug integrity __ BOP.Test i Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10-,_ ~ · order oft O~6\l'[IkL' · Approved Copy Approvedby he..Commission~.0~,Cr. O $~F~B . R~eturp~d~ Commissioner Date ic::~]~/ r Form 10-403 Rev 06/15/88 ~ ~ SUBMIT IN TRIPLICATE Attachment #1 TBU WELL D-34A Perforations Hemlock B-1 MD 10,550' - 10,585' TVD 9,312' - 9,342' B-2 10,610' - 10,625' 10,640' - 10,660' 9,365' - 9,378' 9,391' - 9,409' B-3 10,740' - 10,755' 10,788' - 10,820' 9,480' - 9,493' 9,522' - 9,551' B-4 10,834' - 10,920' 9,563' - 9,641' B-5 10,950' - 10,960' 10,996' - 11,006' 11,016' - 11,040' 9,668' - 9,677' 9,710' - 9,719' 9,728' - 9,750' docs\ dvp\d34A, doc REEEIVED DEO- ~ i990 AiasEa Oil & Gas Cons. CommiSsion ~chorage Attachment #2 Procedure Well D-34A Objective: Convert from a Hemlock producer to a Hemlock injector. 1. Fill tubing and casing with FIW + 3~ KCL. Perforate circulating holes in tubing at 10,420'. Circulate to kill well. 2. Set BPV. ND tree. NU and test BOPE to 3000 psi. 3. POH and LD tubing. 4. RIH and mill-up/recover packers at 10,419' and 10,930'. 5. Cement squeeze the following perfs: 10,550' - 10,585' 10,610' - 10,625' 10,640' - 10,660' 6. Mill up cement to top of retainer and pressure test the squeezed perfs to 2500 psi. 7. Run cement bond log. 8. RIH with TCP system and (re)perforate: 10,740' - 10,755' 10,788' - 10,820' 10,834' - 10,920' 10,950' - 11,040' 9. Run 60' casing patch to cover 10,605' - 10,665'. 10. RIH with electric line and perforate 10,550' - 10,585'. 11. RIH with new completion equipment and set packer at 10,400'. Test annulus to 1000 psi for 30 min. 12. ND BOPE. NU and test tree. NOTE: Maximum anticipated SBHP is 4100 psi. \docs\oe53\D34A.doc RECEIVED DEC - ~ 1990 Alas Oil & Gas Cons. (;omm'~ss'to~ Anchorage Attachment #3 ,.~ MARATHIIN FIIL CDMPANY TRADING BAY UNIT WELL D-34A Proposed CompleJ;Ion 2080' 13-3/8; 6P4L J-55 Csg. g-4 10,295' g-5/8'~ 40, 47#, N-80 & 47#, P-IlO Itut~ Csg. 9859'-11.275' 7: 291f, N-80 But:~c Csg. 10,400' Baker KC-22 Anchor`. Itaker SAB-3 Pkr 4.5' LTC Itox l]own (3~5' Baker I~[1 Du~ Ex~ 4.5' LTC PxP. X[i 4.5' LTC It x 3.5' IISS-HTC P. iO,4L:q_' 10,455' 10,462' D~ 'X' N~ople (;~.813' Dt~$ 'XN' N~ple (2.75' TO). Beaker Bedt C~cher. Sub w WL Entry Guide. PRDPD~E9 HENLDCK PERFORATIONS[ Zo. ne ]ni:er'vq:! Fi: SP.F. ° Ph~slno_ B-1 1(~550'-10~585' 35 8 45 B-~ 10,610'-10.6P5' 15 Cm-t Squeezed 10,640'-10.~60' 20 C~ Squeezed It-3 11~740'-10,755' 15 8 45 10,788'-10,8~0' 3:~ 8 45 B-~ 10, B34'-10,920' 86 8 45 B-5 10,950'-11,040' 90 8 45 Average Dev, a,lon = ~3.0' RECEIVED Alaska Oil & Gas L;0ns, uummiss't0~ Armh0rago PBTD E 1L185' TO @ tLE~5' Revision ]]c~(e, 11/90 Reviced By: JCH/neF Re~son~ Conver~on Pr,evlous Revision: N/A MARATHON OIL COMP Y DOLLY VARDEN PLATF~F~M BOP STACK I . Flowllne U -. Annular Preventer DEC - 3 1990 Alas~.Oji & Gas Cons. ~mfttissio,. /b~ch0rage °I o ~ Clamp Connector Drill Deck Floor ~ Spool Pie~ea Io _ Caeinghead (~) 3' Howco Lo Torque 5000 pal Valve All Flanges are 3' 5000 pal Remote AdJuiJ[able Choke ' P[IllUra $inlor Manual Rig Floor CHOKE MANIFOLD 3' Vent Line .3' I 1/2' Manual Choke 3' Valve Open) Plug 2' Blind Flange 6' to Shaker Choke Line 3' 5000 psi " /-~ L, L,d ~J [ III1~ r I I., ~0 DOLLY VARDEN ~.ATFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) ,- LUBRICATOR RECEIVED DEC - 3 i99t~ Gas Cons. Commission ~chorage · 4' ::11~.:6'-g.. 5000 psi CHISTMAS TREE POSITIVE CHOKE ~ 2' 5000 ]~)._.- 2' 3000 psi ,,. 13 3/8' CASING · ,..__~ STATE OF ALASKA '--.-" O ALASKA' OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate __ Plugging __ Pull tubing __ Alter casing ~ Repair well __ 2. Name of Operator ! 5. Type of Well: UNOCAL (Marathon 0il - Sub 0perato~[) Development X.~_ ~ Exploratory __ ..... ,~,/ nn~n! Stratigraphic ~ 3. Addrcs.%. Box 190247 Anchor-dgu ~r~ ~:~3z~ Service. 4. Location of well at surface Leg A-1 Cond //10 Dolly Varden Platform 757' FSL, 1,210' FWL, Sec. 6-SN-13W-SM At top of productive interval 1,080' FSL, 820' FWL, Sec. 5 At effective depth 1,013' FSL, 1,040' FWL, Sec. At total depth 980' FSLf lf155' FWL~ Sec. 5 12. Present well condition summary Total depth: measured 11,285 ' true vertical 9,960 ' Perforate ~ Other __ Effective depth: measured 11 185 ' true vertical ' 9,872' Casing Length Structural Conductor Surface Intermediate 2,080 ' Production 10,295 ' Liner 1,416' Perforation depth: measured Size -8N-13W-SM 5 -8N-13W-SM -8N- 13W-SM 13 3/8" 9 5/8" 7" feet feet feet feet Plugs (measured) Junk (measured) Cemented 6. Datum elevation (DF or KB) 106' KB above MSL feet See 2,000 sx 2,480 sx 300 sx Attachment #1 U itorPr erty am T7i'aSlng ~y Onl~ 8. Well number D-34A 9. Permit numbedapproval number 90-774 10. APl number 5o/-33-20225-01 11. Field/Pool Hemlock None None Measured depth 2,080' 10,295' 11,275' True vertical depth 2,007' 9,092' 9,945' true vertical Tubing (size, grade, and measured depth) 4 1/2" N-80 ¢ 9,818', 3 1/2" N-80 ¢ 9,818' Packe[s aOC.,SS~V (type an,,d OtiS WU vacl<er L" lO,419"Potis WD packer measur_edde th) - 10,502' 10,930', Otis TRBV 0 322' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure NOV 1 4 1990 o;I & 6as cam. 14. Representative Daily Average ProduCtion or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 10/22/90 Subsequent to operation 11/5 / 9 0 Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 172 283 902 1080 120 313 106 1108 1100 140 Service 16. Status of well classification as: Oil ~ Gas_ Suspended Date SUBMIT IN DUPLICATE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ned (~~/~ S, ~)~ Title ~.~. ~¢~.~, Form 10-404 Rev Attachment #1 TBU WELL D-34A Perforations Hemlock B-1 MD 10,550' - 10,585' TVD 9,312' - 9,342' B-2 10,610' - 10,625' 10,640' - 10,660' 9,365' - 9,378' 9,391' - 9,409' B-3 10,740' - 10,755' 10,788' - 10,820' 9,480' - 9,493' 9,522' - 9,551' B-4 10,834' - 10,920' 9,563' - 9,641' B-5 10,950' - 10,960' 10,996' - 11,006' 11,016' - 11,040' 9,668' - 9,677' 9,710' - 9,719' 9,728' - 9,750' RECEIVED NOV 1 ~ 1990 ~mchora~ \docs\dvp\d34A. doc Attachment #2 TBU Well D-34A Daily Operations Summary 10/22/90 RU E-Line and PT equipment and lubricator to 2500 psi. RIH w/ 1-11/16" dummy gun and tag fill ~ 10,809§' WLM, POOH. Make three runs using 1~11/16" Enerjet II perf guns, 4 SPF, phasing and reperforate HB-4 ~10,851 - 10,881'; 10,834' - 10,849'; 10,788' - 10,820' DIL. Flowed well for 15 min after each run to clean up. POOH, secure well. 10/23/90 RU E-Line and PTe__quip, and lubricator to 2500oPSi. Make three perforating runs using 1-11/16" Enerjet II guns, 4 SPF, 0 phasing and reperforated HB-3 ~ 10,740' - 10,752'; HB-2 @10,610' - 10,625'; and HB-1 ~ 10,550' - 10,585' DIL. POOH, RD. \docs\oe53\D34A. doc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 4. Location o~f well at surface 757 FSL, 1,210' FWL, Sec. 6 At top of productive interval 1,080' FSL, 820' FWL, Sec. 5 At effective depth 1,013' FSL, 1,040' FWL, Sec. At total depth 980' FSL, 1,155' FWL, Sec. 5 -8N- 13W- SM -8N- 13W- SM 5 -8N- 13W-SM -8N- 13W-SM 8. Well number D-34A 9. Permit number 79-11 10. APl number 5(7-33-20225-01 11. Field/Pool Hemlock 12. Present well condition summary Total depth: meas'ured true vertical 11,285' 9,960' feet Plugs (measured) feet None Effective depth:measured 11,185 ' true vertical 9,872 ' feet Junk (measured) feet None Casing Length Structural Conductor Surface Intermediate 2,080 ' Production 10,295 ' Liner 1,416' Perforation depth:measured 13 3/8" 2,000 sx 2,080' 2,007' 9 5/8" 2,480 sx 10,295' 9,092' 7" 300 sx 11,275' 9,945' Size Cemented true vertical Tubing (size, grade, and measured depth) 4 1/2" N-80 e 9,818', 3 1/2" N-80 e 9,818' - 10,502' Pa'q~ej'sa°d'S%SV(tyPeaO'd~ts~.e¢'d?P~cis WD packer @ 10,930' Ul:lS wu racker La , See Attachment #1 Measured depth True vertical depth Otis 13. Attachments 1, 2 &3 14. Estimated date for commencing operation ~ 15. Status of well classification as: September' 1990 16. If proposal was verbally approved Oil ~ Gas __ Suspended __ Name of approver Date approved Service 17. I hereby c/e, rtify that the foregoing is true and correct to the best of my knowledge. Signedj'~k~~(.~ C'~ %' (~)'J'-~ FOIT:Ii~I~OM%ISe~I~)Nt~JuC'S?~NLY~A"~r- ' Conditions oflaCpro~a~l¢. Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance ~ '¢,~,'¢ Mechanical Integrity Test ~ Subsequent form required 10-. ORIGINAL SIGNED BY Description summary of proposal X Detailed operations program __ BOP sketch Date I Approval NO.¢ ~ .- .,~ ~¢ Approved by order of the Commission LONNIE C. SMITH Form 10-403 Rev 06f15/88 Approved Copy Returned Commissioner SUBMIT IN TRIPLICATE 1. Type of Request: Abandon __ Suspend __ Operation shutdown ~ Re-enter suspended well ~ Alter casing ~ Repair well ~ Plugging ~ Time extension __ Stimulate ~ Change approved program __ Pull tubing ~ Variance ~ Perforate X Other ~ 2. Name of Operator J 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL !Marathon_ Oil - Sub .Operatot) DevelopmentX~Exploratory__ 106' KB above MSL 3. ~' ~ Stratigraphic __ 7. Unit or Property name P.O. Box 190247 An.chor?g.e A_K .99..5_19j ._ Service__ Trading Bay Unit Leg a-J. k, onu FJ.U uol ly Varden PlaLfur'm,, Attachment #1 TBU WELL D-34A Perforations Hemlock B-1 MD 10,550' - 10,585' TVD 9,312' - 9,342' B-2 10,610' - 10,625' 10,640' - 10,660' 9,365' - 9,378' 9,391' - 9,409' B-3 10,740' - 10,755' 9,480' - 9,493' B-4 10,788' - 10,820' 10,834' - 10,920' 9,522' - 9,551' 9,563' - 9,641' B-5 10,950' - 10,960' 10,996' - 11,006' 11,016' - 11,040' 9,668' - 9,677' 9,710' - 9,719' 9,728' - 9,750' \docs\dvp\d34A.doc Attachment #2 1) 2) 3) 4) 5) 6) 7) OBTAIN A 24-HOUR WELL TEST WITH A MINIMUM OF FOUR (4) WC'S. RU WIRELINE UNIT. HOOK UP COMMUNICATION SYSTEM IN UNIT. PRESSURE TEST LUBRICATOR AND BOPE TO 2500 PSI. BLOCK IN CONTROL LINE FOR SCSSV AT MANIFOLD PANEL. SI LIFT GAS AND LET WELL DIE. CLOSE MANUMATIC AND CHOKE. RIH WITH X-LOCK RUNNING/PULLING TOOL DRESSED TO PULL WLR-DKX ~ 322'. LATCH INTO DKX AND POOH. NOTE: CONTROL LINE PRESSURE WILL BE LOST AND TRBV WILL CLOSE DUE TO FAULTY LOCK OPEN DEVICE. PRESSURE TBG WITH WATER FLOOD TO ENSURE TBG EQUALIZED ABOVE AND BELOW SCSSV. RIH WITH OTIS DUMMY CHOKE VALVE TO 322'. PURGE CONTROL LINE AND SET. PRESSURE CONTROL LINE TO 3500 PSI AND MONITOR FOR LEAK OFF. RD WIRELINE UNIT. OPEN WELL TO PRODUCTION TO ENSURE TRBV IS OPEN. APPLY 4000 PSI CONTROL LINE PRESSURE TO THE TRBV (SCSSV) WITH A HAND PUMP AND MONITOR FOR ANY LEAK OFF PRIOR TO RIH. HAND PUMP TO BE LOCATED NEAR LOWER WELLROOM ENTRY DOOR. RU E-LINE UNIT. HOOK UP COMMUNICATION SYSTEM IN UNIT. PRESSURE TEST LUBRICATOR AND BOPE TO 2500 PSI. NOTE: PRIOR TO RIH MAKE SURE WELL IS PINCHED BACK TO ONE OR TWO TURNS OPEN ON CHOKE; KEEP WELL PINCHED BACK UNTIL THE DUMMY GUN OR PERFORATING GUN IS BELOW THE TUBING TAIL. MAKE A DUMMY GUN RUN TO 10,900' (MAXIMUM PERF GUN INTERVAL 35'). TAG FILL. PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN HOLE NOTIFY LOGISTIC SUPPORT AND ESTABLISH COMMUNICATIONS BLACKOUT. RIH WITH 2-1/8" STRIP GUNS, 4 SPF, O-PHASING, OFFSET 300 AND PERFORATE THE FOLLOWING INTERVALS UNDERBALANCED (WELL FLOWING). OPEN CHOKE AND STABILIZE FLOW PRIOR TO PERFORATING. RUN BENCH INTERVAL DIL FOOTAGE I HB #4 10,851'-10,881' 30' 2 HB #4 10,834'-10,849' 15' 3 HB #4 10,788'-10,820' 32' 4 HB #3 10,740'-10,752' 12' 5 HB #2 10,610'-10,625' 15' 6 HB #1 10,550'-10,585' 35' **FLOW WELL FOR CLEAN-UP APPROXIMATELY 15-20 MINUTES AFTER PERFORATING EACH INTERVAL. PRIOR TO POOH, PINCH WELL BACK AGAIN. SHUT IN WELL TO POOH (AND RIH) IF HEADING APPEARS TO BE A PROBLEM. Well D-24A Procedure~-~ Page 2 8) RD E-LINE. FLOW WELL TO GROUP SEPARATOR AT A REDUCED RATE SLOWLY OPENING THE CHOKE COMPLETELY OVER ABOUT 4 TO 6 HOURS. FLOW WELL IN GROUP SEPARATOR FOR 12 TO 24 HOURS OBTAINING WC's EVERY FOUR HOURS. MONITOR SEPARATOR SCREEN FOR PERFORATING DEBRIS. SI LIFT GAS TO KILL WELL. CLOSE MANUMATIC AND CHOKE. RU WIRELINE UNIT. HOOK UP COMMUNICATION SYSTEM IN UNIT. PRESSURE TEST LUBRICATOR AND BOPE TO 2500 PSI. RIH WITH X-LOCK RUNNING/PULLING TOOL AND RETRIEVE DUMMY CHOKE VALVE. POOH. PRESSURE TUBING WITH WATER FLOOD TO ENSURE TUBING IS EQUALIZED ABOVE AND BELOW SCSSV. REDRESS DKX AND RIH TO 322'. PURGE CONTROL LINE AND SET DKX. POOH. MONITOR CONTROL LINE FOR ANY LEAK OFF. RD WIRELINE UNIT. OPEN WELL TO PRODUCTION. 10) PERFORM STEP RATE TEST WHILE OBTAINING FIRST 24-HOUR TEST. PLACE WELL IN 24-HOUR TEST AT OPTIMUM GAS LIFT RATE. TURN WELL OVER TO PRODUCTION. Note: Maximum anticipated SBHP is 4100 psi. \docs\oe52\25. doc b~LLY VARDEN PL~'FORM Wireline Lubricator w/Associated BOPE - GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP · 4'~.1JJ,6~,'5000 psi CHISTMAS TREE .~ [~~Z_.___._~.--- ~ 2" 5000 psi -- ~ ]~~::~_-- 2" 3000 psi 13 3/8' CASING Unocal North Americ~ Oil & Gas Division '~-~/ Unocal Corporation P.O. Box 190247 Anchorage. Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL- Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, G u Regional Drilling Manager GSB/lew APR 2 197 DOLLY DISTANCE & DIRECTIONS FROM SE CORNER SEC. 6, TSN, R13W CON'DUCTOR "Y" COORD. "X" COORD. WELL # FSL LEG #A-1: LAT: 60°48' 28.272" LONG :151°37' 57.620" 2,490,836.22 208,461.20 757.5 1 2 3 4 5 6 7 8 9 lO ll 12 2,490,836.95 208,454.55 D-27 758.1 2,490,840.99 208,456.66 D-28 762.1 2,490,842.79 208,460.79 D-29 764.0 2,490,841.51 208,465.11' D-32 762.9 · 2,490,837.76 208,467.60 D-4D 759.2 2,490,833.28. 208,467.10 D-41 754.7 2,490,830.18 208,463.83 D-26 751.5 2,490,829.90 208,459.34 D-25 & RD 751'.1 2,490,832.58 208,455.72 753.7 2,490,835.56 208,458.66 D-24 & 34A 756.8 2,490,838.66 208,462.17 D-31 & RD 760.0 2,490,834.00 208,462.61 D-24A 755.3 LEG ~A- 2' 2,490,835.42 208,381.20 754.7 1 2 3 4 5 6 7 8 9 l0 ll 12 2,490,836.16 208,374.66 D-1 755.3 2,490,840.19 208,376.67 D-17 759.4 2,490,842.00 208,380.80 D-11 761.3 2,490,840.72 208,385.11 D-7 & RD 760.1 2,490,836.97 208,387.60 D-9 756.4 2,490,832.49 208,387.10 D-19 751.9 2,490,829.39 208,383.84 D-23 748.8 2,490,829.11 208,379.34 D-21 748.4 2,490,831.78 208,375.72 ' D-5 & RD 750.9 2,490,834.77 208,378.66 D-15 & RD.& 2 754.0 2,490,837.86 208,382.17 D-3 & RD 757.2 2,490,833.21 208,382.61 D-13 752.5 LEG #B- l' LAT = 60o48' 27.485" LONG =151°37' 57.564" 2,490,756.22 208,462.00 " 677.5 1 2 3 4' 5 6 7 8 9 lO ll 12 2,490,755.48 208,468.53 D-8 & RD 677.0 2,490,751.45 208,466.53 D-6 672.9 2,490,749.65 208,462.40 D-14 & RD 671.0 2,490,750.92 208,458.08 D-20 672.1 2,490,754.67 208,455.59 D-16 675.8 2,490,759.15 208,456.10 D-22 680.3 2,490,762.25 208,459.36 D-2 & A & RD 683.5 2,490,762.53 208,463.85 D-4 683.9 2,490,759.86 208,467.48 D-10 681.3 2,490,756.87 208,464.53 D-12 & RD 678.3 2,490,753.78 208,461.02 D-18 675.1 2,490,758.43 208,460.58 D-30 & RD 679.7 LEG #B-2' 2,490,755.43 208,382.00 674.8 (Reserved for Compressors) FHL 1212 0 1205.5 1207.4 1211.5 1215.8 1218.4 1218.0 1'214.8 1210.3 1206.7 1209.5 1213.0 1213.5 1132.1 1125.5 1127.4 1131.5 1135.9 1138.5 1138.1 1134.9 1130.4 1126.7 1129.6 1133.0 1133.6 1214.8 1221.4 121'9.5 1215.4 1211.1 1208.5 1208.9 1212.1 1216.5 1220.2 1217.4 1213.9 1213.4 1134.9 STATE OF ALASKA AI..'~KA OIL AND GAS CONSERVATION COMMfb-SION r~ REPORT OF SUNDRY WELL OPERATIONS"' 1. Operations pedormed: Operation shutdown __ Stimulate m Plugging ~ Pull tubing __ Alter casing m Repair well __ 2. Name of Operator ! 5. Type of Well: Development _~ UNOCAL (Marathon 0il - Sub 0berate ) Exploratory__ 3. Address ' I Stratigraphic __ P.O. Box 190247 Anchorage AK 995191 Service__ 4. Location of well at surface Leg A-1 Cond #10 Do]'ly Varden Platform 757' FSL, 1,210' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,080' FSL, 820' FWL, Sec. 5-8N-13W-SM At effective depth 1,013' FSL, 1,040' FWL, Sec. 5-8N-13W-SM At total depth 980' FSL, 1,155' FWL, Sec. 5-8N-13W-SM Perforate ~ Other __ 6. Datum elevation (DF or KB) 106' KB above HSL 12. Present well condition summary Total depth: measured true vertical 11,285' feet 9,960' feet Plugs (measured) 7. Unit or Property name Tradin9 Baj/ Unit 8. Well number D-34A feet 9. Permit numbedapproval number 9-947 10. APl number 50/33-20225-01 11. Field/Pool Hemlock None Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate 2,080 ' Production 10,295' Liner 1,416' Perforation depth:measured 11,185' feet 9,872' feet 13 9 true vertical Tubing (size. grade, and measured depth) pa4cke~ ~'~ &-sSv~tyl~e ~rfoar~;sbre3d 13. Stimulation or cement squeeze summary Size Junk (measured) Cemented None Measured depth True vertical depth . - 3/8" 2,000 sx 2,080' 2,007' 5/8" 2,480 sx 10,295' 9,092' 7" 300 sx 11,275' 9,945' See Attachment #1 gECL?/. VE N-80 ~ 9,818' - 10,502' Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 11/14/89 112 34. 275 1020 120 Subsequent to operation 12/06/,39 116 37 554 1070 140 15. Attachments 2 Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas_ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (..~-z.'d~'z--~-L_- ~-7~.,_~z-J~9'~"'r'L~ (~ Title Environmental Analyst Form ~0-404~ov0~l~518~- ) Date 1 / 1 2/90 SUBMIT IN DUPLICATE ¢' Attachment TBU WELL D-34A Perforations Hemlock B-1 MD 10,550' - 10,585' TVD 9,312' - 9,342' B-2 10,610' - 10,625' 10,640' - 10,660' 9,365' - 9,378' 9,391' - 9,409' B-3 10,740' - 10,755' 9,480' - 9,493' B-4 10,788' - 10,820' 10,834' - 10,920' 9,522' - 9,551' 9,563' - 9,641' B-5 10,950' - 10,960' 10,996' - 11,006' 11,016' - 11,040' 9,668' - 9,677' 9,710' - 9,719' 9,728' - 9,750' \docs~dvp~d34A. doc Attachment #2 TBU Well D-34A Daily Operations Summary 12/1/89 Perfora t i on RU E-line. SI well. RIH w/ 30~ strip guns. Tag fill @ 10,910~ DIL. Flow well, correlate and perforate 10,881~ - 10,911~ (30~ B-4). POH. RIH w/ 30~ strip guns. Flow well, correlate and perforate 10,851~ - 10,881~ DIL (30~ B-4). POH. Produce well. 12/2/89 RU E-line. Perforate (3 runs) the following intervals with well flowing: 10,834~ - 10,849~ DIL (15~) 10,788~ - 10,820~ DIL (32~) 10,740~ - 10,752~ DIL (12~) 10,610~ - 10,625~ DIL (15~) RIH w/ 35~ guns, flow well and correlate perforate at 10,550~ - 10,585~ DIL (35~). POH. All shots good. RD. 12/3/89 Clay Stabilizer RU pumping equipment. PT line to 3000 psi. Pump 1000 gal 15% HC1. Displace to EOT w/ 60 bbl FIW w/ 2% NH4CL. Final injection pressure 1600 psi @ 3 BPM. Flow back acid. 12/4/89 Clay Stabilization RU pumping equipment. PT line to 3000 psi. Pump 4000 gal 2% NH4CL w/ 0.1% Lowsurf 300 and 0.6% Cla-Sta XP. Overflush w/ 6000 gal 2% NHaCL w/ 0.1% Lowsurf 300. Displace to EOT w/ 95 bbls 2% NH4CL. Final inj6ction rate 2 BPM @ 2500 psig. RD and unload well. ~docs\dvp~d34A. doc STATE OF ALASKA , )1L AN D'GAS .CONSERVATION COM M lSSl ON APPLICATION FOR SUNDRY APPROVALS 61 1, Type of Request: 2. Name of Operator " j 5. Type of Well: . UNOCAL (Marathon Oil - Sub Operator) De..vel.°pm.entx j ' ,-xploratory __ 3. Address /' Stratigraphic_ P.O. Box 190247 Anchorage AK 99519| Service__ L~g A-i Cu[,d #iO Gully 'v'~['d~n Fi,~lfur., Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plbggi~g __ Time extension __ Stimulate __ Change approved program __ Puli tubing __ Variance __ Perforate .~_ Other 4. Loca~%j~Tqf well at su rfac , FS[, '1,~10 FWL, Sec. 6 -8N-13W-SM At top of productive interval 1,080' FSL, 820' FWL, Sec. 5-8N-13W-SM At effective depth 1,013' FSL, 1,040' FWL, Sec. 5.-8N,t3W~S~<,i?,' ~ At total depth 980 FSL, 1,155' FWL, Sec. 5-8N-13W-SM. 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Un. it or Property name Trading Ba.y Unit D8.- ~z~,~number : 9. Permit number 79-11 10. APl number 5~-33-20225-01 JJ. Field/Pool emlocE 12. Present well condition summary Total depth: measured true vertical 11,285 ' feet Plugs (measured) 9,960' feet None Effective depth: measured 11,185 ' feet Junk (measured) true vertical 9,872 ' feet Casing Length Size Cemented Structural Conductor Sudace Intermediate 2,080' 13 3/8" 2,000 sx Production 10,295' 9 5/8" 2,480 SX Liner 1,416' 7" 300 sx P~rf~)~ti~l~e~lR:me~;~j~a~u~ed true vertical None ~as'~Jred depth True vertical depth 2,080' 2,007' 10,295' 9,092' 11,275' 9,945' RECEIVED OCT 2 ? ]989 Tubincl (size, arade, and measured depth) 4 I/2" h-80 e 9,818', 3 1/2" N-80 e g,818' - 10,502' ~S~..~ P~r~a~oS~SaV~8~a~§a,s~'d, eP~is WD packer ~ 10,930', Otis TRBV @ 322' 13. Attachments 2 & 3 Description summary of proposal X Detailed operations program __ BOP sketch X 14. Estimated date for commencing operation 115. October 30, 1989 I 16. If proposal was verbally approved Oil X Gas __ Name of approver Date approved Service 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~......~/"~o /~:?,~ C~,tle Environmental En, ineer Li~ ~OR,COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test ~ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- ~off_ Original Signed By ApprovedbyorderoftheCommissi~vid W. Johnston Status of well classification as: Suspended Approved OoP¥ Returned,,, Commissioner Date 10/26/89 lAppr°val N°' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 TBU WELL D-34A Perforations Hemlock B-1 MD 10,550' - 10,584' TVD 9,312' - 9,342' B-2 10,610' - 10,625' 10,640' - 10,660' 9,365' - 9,378' 9,391' - 9,409' B-3 10,740' - 10,755' 9,480' - 9,493' B-4 10,788' - 10,820' 10,834' - 10,920' 9,522' - 9,551' 9,563' - 9,641' B-5 10,950' - 10,960' 10,996' - 11,006' 11,016' - 11,040' 9,668' - 9,677' 9,710' - 9,719' 9,728' - 9,750' MDC / em/46 / Sundry Attachment #2 Well D-34A Reperf Procedure · · RU slickline, PT to 2500 psig. Shut in Well· Retrieve 4-1/2" DKX ball valve from 322'. RIH w/2.70" GR to PBTD. POOH. RD slickline. Adjust gun length if significant fill covering lower interval. RU E-line, PT to 2500 psig. With well flowing RIH with 2-1/8", 4 SPF, 0° phased expendable carrier guns. Be very careful not to get blown up hole. If necessary, choke back well until on bottom (if still having difficulties shut in well until on bottom). Perforate the following intervals: BENCH INTERVAL (DIL) FOOTAGE B-1 10,550' - 10,585' B-2U 10,610' - 10,625' B-3 10,740' - 10,752' B-4 10,788' - 10,820' 10,834' - 10,920' 35' 15' 12' 32' 86' TOTAL 180' · POOH. R/D E-line. Place well on production, gradually increasing rate. Monitor well in test for 24 hours after reperf and obtain another test within 3 days. Note: Maximum anticipated SBHP is 3000 psi. docs~oe42\40, doc COMM COMM ,,~ RES :NG I t ,ENG 75-E~}-L ASST~ ] _ STAT 'FE C~_t FILE ,~OLLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) LUBRICATOR · 4' :--1/~:6'-'.. '5000 pal CHISTMAS TREE POSITIVE CHOKE 3/8' CASING STATE OF ALASKA ~< · · ALASKa, OIL A~D GAS CONSERVATION CoM;r~,",51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator UNOCAl, (Marathon Oil - Sub O~erator) Anchorage AK 99519 Leg A-I Cond #lO Dol±y Varden ~Aat FWL, Sec. 6 -8N-13W-SM 5 -SN-13W-SM 5 -8N-13W-~M -8N-13W-SM 3. Address P.O. Box 190247 4. Location of wellatsurface 757' FSL, 1,210' Attop of productiveinterval 1,080' FSL, 820' FWL, Sec. Ateffective depth 1,013' FSL, 1,040' FWL, Sec. Attotaldepth 980' FSL, 1,155' FWL, Sec. 5 5. Datum elevation(DF or KB) 106' KB above MSL 6. Unit or Property name 8. Approval number 8-65 9. APl number 50-- 733-20225-01 10. Pool Hemlock Feet 11. Present well condition summary Total depth: measured true vertical 11,285' feet Plugs (measured) None 9,960' feet Effective depth: measured 11,185 ' true vertical 9,872' Casing Length Size Structural Conductor Surface Intermediate 2,080' 13 3/8" Production 10,295' 9 5/8" Liner 1,416' 7" Perforation depth: measured See Attachment #1 true vertical feet Junk (measured) None feet Cemented Measu. red depth 2,000 sx 2,080' 2,480 sx 10,295' 300 sx 11,275' True Vertical depth 2,007' 9,092' 9,945' Tubing (size, grade and measured depth) 4 1/2" N-80 @ 9,818', 3 1/2" N-80 @ 9,818' - 10,502' Packers and SSSV (type and measured depth) Otis WD Packer @ 10,419', Otis WD packer @ 10,930', 12. Stimulation or cement squeeze summary Otis TRBV @ 322' Intervals treated (measured) Treatment description including volumes used and final pressure APR 1 5 Alask.~ 0il & Gas Cons. Co 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation - 95 30 240 1036 psi 245 34 522 1040 123 psi 120 psi 14. Attachments: (/2 Daily Report of Well Operations i~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed R~ D. Rbberts ~A Title Environmental Engineer Form 10-404 Rev. 12-1-85 Submit In Duplicate Attachment #1 TBU WELL D-34A Perforations Hemlock B-1 10,550' - 10,584' TVD 9,312' - 9,342' B-2 10,610' - 10,625' 10,640' - 10,660' 9,365' - 9,378' 9,391' - 9,409' B-3 10,740' - 10,755' 9,480' - 9,493' B-4 10,788' - 10,820' 10,834' - 10,920' 9,522' - 9,551' 9,563' - 9,641' B-5 10,950' - 10,960' 10,996' - 11,006' 11,016' - 11,040' 9,668' - 9,677' 9,710' - 9,719' 9,728' - 9,750' MDC/em/46/Sundry Attachment # 2 TBU Well D-34A Daily Operations Summary 3~7/88 RU E-line and pressure test lubricator to 2500 psi. OK. RIH w/10' sinker bar, CCL, 2-5/8" through tubing guns, 4 SPF, 0° phasing. Correlate to DIL, flow well and perforate Bench 2 from 10,610' to 10,625', POH, put well in test. 3/8/88 RU E-line and PT to 2500 psi. OK. RIH w/CCL, sinker bar, 30' 2-5/8" through tubing guns, 4 SPF, 0~ phasing. Correlate to DIL, flow well and perforate Bench 3 from 10,740' to 10,750' and Bench 2 from 10,640' to 10,660'. POH and bring well on slowly for cleanup. Put well in test. 3/9/88 RU E-line and PT to 2500 psi. OK. Made four perforating runs with CCL, sinker bar, 2-5/8" through tubing guns, 4 SPF, 0~ phasing. Perforated under drawdown Bench 4 from 10,890' - 10,920', 10,860' - 10,890', 10,834' - 10,860'; and Bench 1 from 10,550' _10,580,. Made fifth perforating run w/ 2-1/8" silver jet perf guns, 4 SPF, 0° phasing on upper Bench 4 from 10,790' - 10,820' DIL. POOH, RD, flow well for cleanup and place well in test. 46/Sundry A?[i i 5 Gas Cons, Oommiss[o~ ~qch~rage STATE OF ALASKA ALASKa_OIL AND GAS CONSERVATION COMM~...~'ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown '~ Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~: Other [] 2. Name of Operator UNOCAL (Marathon Oil Company Sub-operator) 3. Address P.O. Box 190247 Anchorage AK 99519 4. Location of wellatsurface Leg A-I Cond #tO Do±±y Varden Miatt 757' FSL, 1,210' F-~CL, Sec. 6 -8N-13W-SM Attop ofproductiveinterval 1,080' FSL, 820' FWL, Sec. 5 -8N-13W-SM Ateffective depth 1,013' FSI,, 1,040' FWL, Sec. 5 -8N-13W-SM Attotaldepth 980' FSL, 1,155' FWL, Sec. 5 -8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit °r'~- W~)II._~ ber 8. Permit number 79-11 9. APl number 50-- 733-20225-01 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical 11,285 ' feet 9,960 ' feet Plugs (measured) None Effective depth: measured 11,185 ' true vertical 9,872' feet feet Junk (measured) None Casing Length Size Structural Conductor Surface Intermediate 2,080' 13 3/8" Production 10,295' 9 5/8" Liner 1,416 ' 7" Perforation depth: measured See Attachment ¢/1 true vertical ~bing(size, grade and measured depth) 4 1/2" N-80 @ 9,818', 3 1/2" N-80 @ 9,818' Packers and SSSV(type and measured depth) Otis WD Packer @ 10,419' Cemented 2,000 sx 2,480 sx 300 sx Measured depth True Vertical depth 2,080' 2,007' 10,295' 9,092' 10,502' , Otis WD packer @ 10,930', Otis TRBV @ 322' 12.Attachments: ¢/2 Description summary of proposal I~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation February 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby ce.r~ify that t~e.fore, going is true and correct to the best of my knowledge Signed R~D. R~berts Title Ez'zv-i_~or~z~a_l Enqineer Commission Use Only Date2/1/88 Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Approved Copy Returned ORIGINAL SIGNED BY Approved by LONNIE C. SMITH Form 10-403 Rev 12-1-85 No. Commissioner feet by order of c~ --~//' -'~'~ ~ the commission Date ,¢~.~_~ / submit in triplicate~ Attachment #1 TBU Well D-34A Perforations Hemlock B-1 B-2 B-3 B-4 B-5 MD 10,550' - 10,584' 10,610' - 10,625' 10,640' - 10,660' 10,740' - 10,755' 10,788' - 10,820' 10,834' - 10,920' 10,950' - 10,960' 10,996' - 11,006' 11,016' - 11,040' TVD 9,312' - 9,342' 9,365' - 9,378' 9,391' - 9,409' 9,480' - 9,493' 9,522' - 9,551' 9,563' - 9,641' 9,668' - 9,677' 9,710' - 9,719' 9,728' - 9,750' MDC/em/46A/Sundry Attachment #2 D-34A Procedure 1. RU wireline unit. Pressure test lubricator to 2500 psi. e RIH with 2.50" gauge ring, cut scale as necessary. Try to work through WD packer at 10,930'. Tag bottom. Work up to 2.72" gauge ring, if possible. POOH. 3. RD wireline. 4. RU E-line unit. Pressure test to 2500 psi. . Perforate underbalanced the intervals listed beow with 2-5/8" or 2-1/8" perforating guns 4 SPF 0° phasing. Gun size will depend on gauge ring runs. Clean up well after each gun run. 1 B-5 2 B-5 3 B-4 4 B-4 5 B-4 6 B-4 7 B-3 8 B-2 9 B-2 10 B-1 10,996' - 11,006' 10' 10,950' - 10,960' 10' 10,890' - 10,920' 30' 10,860' - 10,890' 30' 10,834' - 10,860' 26' 10,790' - 10,820' 30' 10,740' - 10,750' 10' 10,640' - 10,660' 20' 10,610' - 10,625' 15' 10,550' - 10,580' 30' May not be able to per- forate B-5 due to obstruction in isolation packer. 6. RD E-line. 7. Test well for 2-3 days. 8. RU wireline, pressure test and RIH with dual gauges. 9. Obtain a FBHP at 10,728' WLM (9,450 TVD). 10. RD wireline. NEF/em/46A/Sundry STATE OF ALASKA ALASI'..,_~31L AND GAS CONSERVATION COMI~ ~ION REPORT OF SUNDRY WELL OP[I:tATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate~ Pull tubing [] Alter Casing [] Other [] 2. Name of Opera[or UNOCAL 3. Address P.O. Box 190247 4. Location of well at surface 757' FSL, 1,210' FWL, Sec. 6-8N-t3W-SM At top of productive interval 1,080' FSL, 820' FWL, Sec. 5-8N-13W-SM At effective depth 1,013' FSL, 1,040' FWL, Sec. 5-8N-13W-SM At total depth 980' FSL, 1,155' FWL, Sec. 5-8N-13W-SM Anchorage AK 99519 Leg A-I Uond #i0 ooiiy v'arden Plat1 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit We L%r ber 8. Approval number 165 9. APl number 50-- 733-20225-01 10. Pool Hemlock Fee?~ ! / 11. Present well condition summary Total depth: measured true vertical 11,285 ' feet Plugs (measured) 9,960' feet Effective depth: measured 11,185 ' feet Junk (measured) true vertical 9,872' feet None None '--, 1 198 oc :w Casing Length Size Cemented Structural Conductor Surface Intermediate 2,080' 13 3/8" 2,000 sx Production 10,295' 9 5/8" 2,480 sx Liner 1,416' 7" 300 sx Perforation depth: measured See Attachment #1 true vertical Tubing(size, grade and measured depth) 4 1/2" N-80 @ 9,818', 3 1/2" N-80 @ 9,818' Packers and SSSV(type and measured depth) Otis WD Packer @ 10,419', Otis WD packer @ 10,930' Measured depth True Vertical depth - 10,502' 2,080' 10,295' 11,275' 2,007' 9,092' 9,945' J 0 1986; Alaska 0it & Gas Cons. Anchorage , Otis TRBV @ 322' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 6/23/86 140 141 210 1,000 psig Subsequent to operation 7/4/86 230 77 497 1,100 psig_ Tubing Pressure 140 psig 150 psig 14. Attachment~ #2 Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify th. at t~oing is true and correct to the best of my knowledge * Mara]~n Oil ~ppany, Sub-Operator Signed Rov Roberts Title Enviro~nental Enqineer Form 10-404 Rev. 12-1-85 Date lfl/o/o~Ii submit in b~'~l'i'c~ate )OD Attachment #1 TBU'WELL D-34~ Perforations Hemlock B-1 MD 10,550' - 10,584' TVD 9,312' - 9,342' 10,610' - !0,625' 10;640' ~ i0,660' 9,365' - 9,378' 9,391' - 9,409' B-3 10,740' - 10,755' 9,480' - 9,493' B-4 10,788' - 10,820' 10,834' - 10,920' 9.,522' - 9,551' 9,563' - 9,641' B-5 10,950' - 10,960' 10,996' - 11,006' 11,016' - 11,040' 9,668' - 9,677' 9,710' - 9,719' 9,728' - 9,750' .~.,T 0 ~ 1986 Anchorage MDC/em/46/Sundry ATTACHMENT #2 WELL D-34A Perforating Operations On July 2, 1986, Marathon perforated the well with 2 1/8" guns, 4 SPF, 0° phasing under drawdown at the following intervals: Bench 2 Bench 2 Bench 3 MD TVD 10,610' - 10,625' 10,640' - 10,660' 10,740' - 10,755' 9,365' - 9,378' 9,391' - 9,409' 9,480' - 9,493' A!aska Oil & Gas Cons. Anchorage MDC/em/46/Sundry STATE OF ALASKA ALASKA'OiL AND GAS CONSERVATION COMMIL~=YON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon iq Suspend ~.' Operation Shutdown ~ Re-enter suspended well [] Alter casing [] Time extension El. Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other [] 2. Name of Operator UNOCAL 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surface 757' FSL, 1,210' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 1,080' FSL, 820' FWL, Sec. 5- 8N- 13W- SM At effective depth 1,013' FSL, 1,040' FWL, Sec. 5- 8N- 13W- SM At total depth 980' FSL, 1,155' FWL, Sec. 5 - 8N - 13W - SM 5. Datum elevation (DF or KB) KB 106 6. Unit or Property name Trading Bay Unit 7. Well number D-34A 8. Permit number 79-11 9. APl number 50-- 733-20225-01 10. Pool ' Hemlock feet 11. Present well condition summary Total depth: measured true vertical 11,285 ' feet 9, 960 ' feet Plugs (measured) Effective depth: measured true vertical 11,185 ' feet 9,872 ' feet Junk (measured) Casing Length StJuctural Conductor Surface Intermediate 2,080' Production 10,295' 1,416' Liner Perforation depth: measured Size Cemented 33" 13 3/8" 2,000 sx 9 5/8" 7" 300 sx See Attachment #1 true vertical Measured depth True Vertical depth 2,080' 2,007' 10,295' 9,092' 11,275' ~,~45 ' RFcF!V J U N 0 9 i986 Tubing (size, grade and measured depth) 4 1/2", N-80 @ 9,818' 3 1/2", N-80 @ 10,502' Packers and SSSV (type and measured depth) WD - Packer @ 10,419' TRBV @ 322' Alaska 0~t ~ (~as Cons. Commissior~ Anchorage - WD - Packer @ 10,930' 12.Attachments Description summary of proposal ffl Detailed operations program ~ BOP sketch [] 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date ?p. proved 15. I hereby certify that the foregoing is true and correct to the best of my knowledgeL,~'v~k- ~ S i g n ed,~¢,~_/"~. Roy D. Roberts Title Environmental Engineer Date 6/9/86 Commission Use Only Approved by Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP T~st ~.l. qei~t, icn clearancel / ~:~ ~f [~ ~' ~'~ Commissioner the commiSsion Date Form 10-403 Rev 124-85 Submit in triplicate Attachment #1 TBU WELL D-34A Perforations Hemlock B-1 10,550' - 10,584' TVD 9,312' - 9,342' B-4 10,788' - 10,820' 10,834' - 10,920' 9,522' - 9,551' 9,563' - 9,641' B-5 10,950' - 10,960' 10,996' - 11,006' 11,016' - 11,040' 9,668' - 9,677' 9,710' - 9,719' 9,728' - 9,750' WJL/em/081/LAV Attachment #2 WELL D-34A Procedure It is Marathon's intention to perforate the well with 2 1/8" guns, 4 HPF, 0° phasing, under drawdown as follows: 1. RU lubricator and pressure test to 2,000 psi. e RIH with guns and perforate: B-2 10,610' - 10,625' DIL 10,640' - 10,660' DIL 3. POH, return well to production. WJL/em/080/LAV Union Oil and Gas '~:'dsion' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 unl,o n DOCUMENT TRANSMITTAL November 4, 1983 Hand Carried TO: William Van Alen FROM: R.C. Warthen LOCATION: 3001 Porcupine Drive LOCATION: Alaska District Anchorage, Alaska 99501-)192 ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting: One (1) tape and verification listing each of the following wells: TBU D-25RD - Run 1 and 2 '/ TBU D-25RD - Run 2 '" ;'' ' TBU D-34A Deepen TBU D-15RD ?:''''' ; -': ...... '] -''] ' ' : " '-- TBU D-15RD #2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMZTTAL. THANK YOU. RECEIVED BY: DATED' TBUS WELL D-34A On June 15, 1974, Hemlock Water Injection Well D-24, Conductor #10, Leg A-1 (NE), on the Dolly Varden Platform stopped taking water. In August, 1974, the rig was moved over this well and found the 9-5/8" casing collapsed at 7343'MD. Attempts to repair the casing damage and salvage this wellbore as a Hemlock injector were unsuccessful. On September 12, 1974, the well was shut-in and temporarily abandoned with a cement ret~°ih~e~r and a 200-sack cement plug at 7140'. In order to utilize this conductor, we re-entered the well on October 13, 1975, to begin drilling Well D-34A as a Tyonek G Zone water injector. Realizing that the 9-5/8': casing could not be repaired at 7343', a free-point indicator was run and the 9-5/8'~ casing was cut at 2214'MD. Fifty-five joints of 9-5/8", 47#, N-80 casing (2161'Net) was pulled. A section was milled in the 13-3/8'~ casing from 2080' to 2158' and a cement plug set across the window. The old wellbore was sidetracked at 2090' and drilled to a new total depth of 10,295' The 9-5/8I' casing was run as follows: 9-5/8~ CASING DETAIL Item Length From To KB to Cutoff & slips 61 jts 40#, Butt, N-80 74 jts 47#, Butt, N-80 Baker Model J Stage Collar 56 jts 47#, Butt, N-80 23 jts 47#, Butt, P-110 Baker Model JB Stage Collar 23 jts 47#, Butt, P-110 Baker Model G Diff Fill Clr 1 jt 47#, Butt, P-110 Baker Model G Diff Fill Shoe 41.20 -0- 2514.44 41.20 3321.96 2555.64 1.75 5877.6O 2471.32 5879.35 944.04 8350.67 1.75 9294.71 952.56 9296.46 1.90 10,249.02 41.48 10,250.92 2.60 10,292.40 41.20 2555.64 5877.6O 5879.35 8350.67 9294.71 9296.46 10,249.02 10,250.92 10,292.40 10,295.00 The 9-5/8" casing string was cemented as follows: 1. First Stage: Cemented with 630 sx of class G neat with 1% D-31 & 0.31% R-5. Bumped plug to 1500 psi. Opened stage collar at 9296'. 2. Second Stage: Cemented with 1000 sx of class G with 4% gel, 1% D-31, & 0.3% R-5 followed with 150 sx class G neat with 1% D-31 & 0.3% R-5. Bumped plug to 2800 psi. Stage collar did not hold, so held pressure for 3 hrs. 3. Third Stage: Opened stage collar at 5879' and pressured up to 3200 Psi- Could not pump in. Second stage cement across third stage collar at 5879'. Job completed 11-22-75. On 12-01-75, perfs 4 holes from 4030' - 4031' and cemented w/ 850 sx of class G with 4% gel, 1% D-31 and 0.3% R-5 (15.2#/gal slurry) followed with 200 sx class G with 1% D-31 and 0.3% R-5 (16.5#/gal slurry). Had returns to surface. Drilled out and tested to 4600 psi--OK. On 11-27-75, perforated in the G Zone with 4 holes from 10,138' to 10,139' and cement squeezed for zone isolation with 150 sacks of class G neat with 1% D-31 and 0.5% R-5 (15.0#/gal slurry). Final squeeze pressure was 4500 psi. On 12-09-75, squeezed perforations 10,138' to 10,178' with 150 sacks of class G cement (15.7#/gal) to 4500 psi. Squeezed to stop injection water from going down behind pipe. PERFORATION RECORD Date 12-04-75 12-11-75 12-15-75 12-29-75 Net Interval Ft Perfd Gun HPF 10,138' - 10,178' 40' 4" Carrier 3 (Bench 4) (These perfs were cmt squeezed to stop zone communication.) 10,138' - 10,178' 40' 4" Carrier 3 (Bench 4) 10,100' - 10,122' 22' 4" Carrier 3 (Bench 3) 10,027' 10,042' (Bench :~) 15' Capsule 3 TUBING RECORD 01-o6-76 O1-07-76 O1-08-76 Set lower permanent packer at 10,O73' (10,065'WLM) with a 21-foot x 7"OD extension crossed-over to 3½" tubing with a profile nipple at 10,090'(WLM). This will enable separation of Benches 3 and 4 from Bench 2. Set top permanent packer at 9981' (9973'WLM). Ran 347 jts of 3½:'OD, 9.2#, N-80 tubing with dual seal assemblies to sting packers at 9981' and 10,073'. Released rig 01-09-76. NOTE: Since putting Well D-34A on injection on 01-12-76, the casing pressure was observed at 3700 psi. An impression block was run on wireline and indicated that the lower seal assembly was not stung into the packer at 10,073'. .When the rig and crews are available, the tubing will be re-spaced to properly seal the tubing in the packers and thus remove annulus pressure. TREATING RECORD 12-05-75 12-13-75 12-16-75 12-25-75 Interval 10,138' to 10,178' Treated with 300 gals of 12-6 MCA acid. A tracer survey showed fluid to be going down behind pipe. Cement squeezed on 12-09-75. (Bench 4) Interval 10,138' to 10,178' Treated with 150 gals of 12-6 MCA acid ahead of 1600 gals 5% HC1 & 3000 gals 12-6 MCA w/ 400# of ammonium chloride, followed with 1600 gals 5~ HC1 and 100 gals 15% HC1. Maximum rate 1¼ BPM @ 3500 psi. Re-treated on 12-15-75 with 275 gals of 5% HC1 with 400# of diverter and displaced with injection water. (Bench 4) Interval 10,100' to 10,122' Treated with 900 gals 5% HC1 ahead of 1600 gals of 12-6 MCA with 250# of ammonium chloride and followed with 500 gals of 5% HC1. Spaced with 2000 gals of water and followed with 100 gals 15% HC1. (Bench 3) Frac-treated Benches 3 and 4 Perfs (10,100' - 10,1221 and 10,138' - 10,178I) with 37,925 gals gelled water with 74,500# of 20/40 sand (concentration from 2/3 to 5#/gal sand). Maximum pressure 6000 psi @ 14 BPM. ISIP was 5000 psi and bled to 2700 psi in 1 hour. Der,_ lesearch Center Marathon OilCompany P.O. Box 269 Littleton, Colorado 80160 Telephone 303/794-2601 September 23, 1983 Mr. R. C. Warthen District Development Geologist Alaska District Union Oil Company 909 West 9th Avenue Anchorage, AK 99501 Dear Bob, Please find enclosed duplicate copies of 5 digital well log tapes that you requested recently. They are from the following wells' CTBU D-3 Redrill (Dresser Atlas) ~TBU D-15 Redrill # i & 2 2 TBU D-25 Redrill ~TBU D-34A Deepened W. A. Dulin WAD/vm An Equal Opportunity Employer February 4, 19U3 Mr. tlobert T. Anderson District Land Manager Union Oil Company of California P. O. Box 7247 Anchorage, Alaska 99502 Dear Mr. Anderson: The Alaska Oil and Gas Conservation ComMission has recently checked the records of wells completed since January i, 1979. This revie~ has revealed that the digitized data for certain logs run in a ~el! is not on file with the Co~ission. The Oil. and Cas Regulations require the operator to file, within 30 days after completion, suspension, or abandonment of a drilling %~ell, thc digitized data, if available, for copying, for all logs run in the well except velocity surveys, experi~nenta.1 logs and dip- meter surveys. We ~ould request that' you check your records to see if the data has been submitted to the Commission and, if not, that you co~ply ,~rith the regulation with-regard to the following ~'ells: Trading Bay Unit No. D-34A Trading Bay Unit No. D-15 RD Tradino~ Bay Unit ~o. 5-3~. RD Trading Bay Unit ~o. D-25 RD Trading Bay Unit ?!o. ~-2i RD Trading Bay Unit No. K-24 Tungak Creek No. 1 Tra~ing Bay St. No. A-17 RD Cannery Loop Unit I~o. 1 Cannery Loop" ' on~t No. 2 Cannery Loop Unit ~o. 3 Kenai Tyonek Unit No. 43-6X Thank you ~or your cooperation in this m...att~ Yours very truly, Harry ~7. Kugler Com,...?,ni s s ioner ORDER OF Tt~ STATE OF ALASKA ALASKt~..~IL AND GAS CONSERVATION C~..~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL D0 OTHER [] 2. Name of Operator 7. Permit No. Union Oil Company of California* 79-11 3. Address 8. APl Number P. 0. Box 6247, Anchorage AK 99502 50-733-20225-01 4. Location of Well Surface' Leg A-l, Cond #12, Dolly Varden Platform 757'FSL, 1210'FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL I 6 . Lease Designation and Serial No. ADL-18729 12. 9. Unit or Lease Name Tradinq Bay Unit 10. Well Number D-34A 1-1. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) · Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On December 18 and 19, 1982, the well was reperforated w/ 2-1/8" Sl imkone guns, 4 HPF, 0° phasing, 30° offset. Bench 1 Bench 4 Bench 5 10,550 -10,580 10,790 -10,820 10,834 -10,920 10,950 -10,960 10,996 -11,006 11,016 -11,040 DIL DIL DIL DIL DIL DIL Production before reperforating' 480 BFPD, 68% WC, 154 BOPD, 326 BWPD RECEIVEO Production after reperforating' 883 BFPD, 54% WC, 406 BOPD, 477 BWPD. JAN 0 6 1983 Alaska Oil & Gas Cons. Oommissio. Anchorage * Marathon Oil Company Sub-operator best my 14. I hereby certify.that the foregoing is true and correct to the of knowledge. Signed Ti The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA-~-~,L AND GAS CONSERVATION G._~iMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~( OTHER [] 2. Name of Operator Union 0il Company of California* 3. Address P.O. Box 6247, Anchorage, AK 9~502 4. Location of Well Surface: Leg A-l, Cond //12, Dolly Varden Platform 757'FSL, 1210'FWL, Sec. 6-SN-1~3W-SH 5. Elevation in feet (indicate KB, DF, etc.) KB 106' Above MSL 12. I 6 . Lease Designation and Serial No. ADL-18729 7. Permit No. 79-11 8. APl Number s0- 73.3-20225-01 9. Unit or Lease Name. Tradin9 Bay Unit 10. Well Number D-34A 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other I--I Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is Marathon's intention to reperforate the well with 2-5/8" perforating guns, 4 HPF, 30© offset, under drawdown.. Bench 5 11,016'-11,040' DIL' 10,996'-11,006' DIL 10,950'-10,960' DIL **Bench 4 10,834'-10,920' DIL 10,790'-10,820' DI'L **Bench 1 10,550'-10,580' DIL The September, 1982, production averages were: 541 BFPD, 50% WC, 268 BOPD, 273 BWPD. **Benc[Pes ~4 and 1 will be reperforated if Bench 5 does not significantly increase p rod Oct i on. Subsecluem~ Wo~'k ~eportec] * Marathon 0il Comp_any Suboperator ~~o/~:~_~~~~ 14.I hereby certif~~to the best of my knowledge. Signed ~ ~~ ~ ~ ~ Title District Engineer Date 11/30/g2 lh.~o~, b.~ow fo~ Com~i~ion.~ C. H. CASE Conditions of Approval, if any: By Order of Approved by , COMMISSIONER the Commission Date Form 10-403 Rev. 7-1.80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA O~T'L AND GAS CONSERVATION CO'r~nVllSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL :lO( 2. Name of Operator 7. Permit No. Union Oil Company of California* 79-11 3. Address 8. APl Number P.O. Box 6247, Anchorage, AK 99502 5o- 733-20225-01 4. Location of Well Surface: Leg A-l, Cond #12, Dolly Varden Platform 757'FSL, 1210'FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) KB 106' Above MSL 12. I 6 . Lease Designation and Serial No. ADL-18729 OTHER 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-34A 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is Marathon's intention to reperforate the well with 2-5/8" perforating guns, 4 HPF, 30© offset, under drawdown. 11,016'-11,040' DIL I ECEIVEB' 10,950'-10,960' DIL - Bench 5 **Bench 4 10,8341-10,920' DIL 10,790'-10,820' DIL **Bench 1 10,5501-10,580' DIL The September, 1982, production averages were: 541 BFPD, 50% WC, 268 BOPD, 273 BWPD. **Benches 4 and 1 will be reperforated if Bench 5 does not significantly increase production. * Marathon Oil Company Suboperator 14. I hereby certify that/~:~fore.~oir~g)is true and correct to the best of my knowledge. Signed ~ ~' Title District Engineer Thespace below for Commission use C. H. CASE Date. 1 1/.'~0/82 Conditions of Approval, if any: Approved by Form 10403 Rev. 7-1-80 By Order of CQMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name ~ Operator 7. Permit No. Union Oil Company of California* 79-11 3. Add~ 8. APl Number P.O. Box 6247, Anchorage, AK 99502 50-733-20225-01 4. Loca~ ~f Well Surface: Leg A-1 Comd. 12 Dolly Varden Platform 757' FSL, 1210' FWL, Sec 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) KB 106.2 Above MSL 6. Lease Designation and Serial No. ADL 18729 A-926 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-34A 11. Field and Pool McArthur River Field 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). -. On 11/i2-13/81 the well was reperforated with 2-1/8" enerjet gun w/ 4 Hps as follows: Bench 5: Bench 4: 11,016'-11,040' DIL 10,950'-10,960' DIL 10,834'-10,900' DIL 10,788'-10,820' DIL 10,554'-10,584' DIL Production Test: Before reperf: After Reperf : 440 BFPD, 40% WC, 176 BWPD, 264 BOPD 1115 BFPD, 68% WC, 758 BWPD, 357 BOPD RECEIVED *Marathon Oil Company - Sub-operator Alaska 0il & Gas Cons. C0mmJssJ0,~ Anchorage 14.1 ~eby omr~.~ raat the foregoing is true and correct to the best of my knowledge. S igne~ ~/'~ ~ (/~~/~'~ Title D I ST [:)RLG S UPT /, The space~3eltc~,~ for Commission use Date 12/9/81 Condilion. s of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate STATE OF ALASKA ALASKA'OiL AND GAS CONSERVATION C~:rf~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Union Oil Company of California* 79-11 3. Address 8. APl Number P.O. Box 6247, Anchorage, Alaska 99502 50- 733-20225-01 4. Location of Well Surface; Leg A-i, Cond 12, Dolly Varden Platform 757' FSL, 1210' FWL, Sec 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106.2' KB above MSL 12. 6. Lease Designation and Serial No. ADL-18729 A-926 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-34A 11. Field and Pool McArthur River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate E~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans. [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We are requesting approval to reperforate selected intervals of Benches 1, 4, and 5 using a 2-1/8" enerjet gun with 0© phasing at 4 HPF as follows: 1. RU wireline & pressure test to 2500 psi. 2. RIH, locate on depth, correlate with CCL. 3. Reperforate well under drawdown conditions at the following intervals Bench 1 10,554'-10,584' Bench 4 10,788'-10,820' 10,834'-10,920' Bench 5 10,950'-10,960' 11,016'-11,040' 4. Produce well to separator to clean up well. 5. POH, RD wireline. Estimated Startup: November 4, 1981 on Fo~ No. 4~ WMarathon 0il Company - Sub-Operator ' £C£1vEO OCT .~ d I98i 14. I herel~y c~ertify that the/~rego~ is true and correct to the best of my knowledge. Signed Title DIST D:RZ~ SUt:~ The s~c/C'belovv for Commission use Cond~tqons of Approval, if any: ~tC~rag~ '~'aro/s$iot Date 10/29/81 ORIG!I~IAI' SIGNED' BY I. OH:~IEC. SMITH Approved by COMMISSIONER Approved Copy Returned By the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA-~IL AND GAS CONSERVATION C~--MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Union 0il Company of California* 3. Address P. O. Box 6247, Anchoraqe AK 99502 4. Location of Well Dolly Varden Platform, Leg A-l, 757'FSL, 1210'FWL, Sec 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) _ 106.2' KB 12. 6. Lease Designation and Serial No. AlII -18729 A-976 7. Permit No. 79-11 8. APl Number 50- 733-20225-01 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-34A il. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Perforate Stimulate Repair Well Pull Tubing NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) ~ Alter Casing [] ~ Perforations [] Altering Casing ~ Abandon [] Stimulation [] Abandonment [] Change Plans [] Repairs Made [] Other [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We are requesting approval to both reperforate selected intervals in Hemlock Zone, Benches 4 & 5, through the tubing, and then treat the well with TUrbo Chemical's "Turflo" treatment to stabilize the clays and fines. Estimated date of start-up: 04-30-81 A description of proposed procedures is attached. *Marathon Oil Company - Sub-Operator RECEIVED APR - ? ]981 Alaska 0ii & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed b~~ (~. C~~~L~"~ I~.~g Title DiSt.Drlg. Supt, The space w for Commission use ~- {~ Date 4/6/81 Conditions of Approval, if any: Approved by [~' -~'-~"~']'/ti ~-~'L~ COMMISSIONER Form 10-403 ~/ Lk,,J Rev. 7-1,80 I~pprowd '"oTM By Order of the Commission Date Submit "I ntentions" in Triplicate and "Subsequent Reports" in Duplicate Attachment to Sundry Notice Well D-34A REPERFORATING AND TREATING WELL D-34A WITH TURFLO 1. RU A-frame. MU CCL, 24' of DA 2-5/8" Slim-kone gun loaded 4 SPF, 0° phasing, with magnetic decentralizer. Attach DA greasehead and BOPT to MRO lubricator, RU & press test to 2500 psi. 2. SI wel I & RIH. Locate to perforate 11,016' - 11,040'DIL. 3. Obtain + 400 psi drawdown & perforate. 4. Flow well to clean up perfs. SI well & POH. 5. Repeat steps 2 thru 4 as above, perforating the following intervals: a. 10' gun: 10,950' - lO,960'DIL b. 30' gun: 10,890' - lO,920'DIL c. 30' gun: 10,860' - lO,890'DIL d. 26' gun: 10,834' - 10,860'DIL e. 32' gun: 10,788' - lO,820'DIL 6. RD DA. 7. Mix 13,425 gals (320 bbls) 3% KCI solution in 500 bbls tank. Add Turflo concentrate & mix. Add J237 diverter & mix. 8. Press up tbg of D-34A using lift gas. Shut off lift gas & bleed annls. Monitor TP for communication between tbg & csg. Repress annls w/ lift gas. 9. RU Dowell lines to both the tbg & csg of D-34A. Press test line to 4500 psi. RU to record annls press. 10. Fill tbg w/ Turflo. Note volume required. Pump all fluids thru 5 micron filters going in well. 11. Pump 17,900 gals Turflo (less volume required to fill tbg) at 2500 psi of 2 BPM max. 12. Displ w/ 149 bbls diesel at 2500 psi or 2 BPM max. 13. SI well for 4 hrs. RD Dowell. 14. Return well to production. RECEIVED APR - ? Alaska Oil & Gas Cons. Commission Anchorage Form 10-403 REV. 1-10-73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) [ GAS E~ OWL%L WE LL OT H E R 2. NAME OF OPERATOR Union Oil Company of California* 3. ADDRESS OF OPERATOR P. O. Box 6247~ Anchoraqe AK 99502 4. LOCATION OF WELL At surface Le9 A-l, Do l ly Varden Platform 757~FSL, 1210~FWL, Sec 6-8N-13W-SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 106.2'KB 5. APl NUMERICAL CODE 50- 133-20225-01 6. LEASE DESIGNATION AND SERIAL NO. ADL-18729 A-926 7. IF INDIAN, ALLOTTEE OR TRIBE NAME ---- 8. UNIT, FARM OR LEASE NAME tradin.q Bay Un it 9. WELL NO. D-34A (Deepen) 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 5, T8N, R13W, SM 12. PERMIT NO. 79-11 14. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I=ertlnent ¢letalls, and give pertinent dates, including estimated date of starting any proposed work. On 04-04-80, perfd following Hemlock interval under drawdown: Bench 5: 10,950'-10,960'DIL 4 HPF Bench 5: 11,016'-11,040'DIL 4 HPF 2-5/8" DA 2-5/8" DA 0° Slim Kone gun 0° Slim Kone gun Production Test: Before Perfs: 703 BFPD 26% WC After Perfs: 1691BFPD 12% WC Verbal approval to perforate received from Russ Douglass to Tony Swan on 04-02-80. *Marathon Oil Company - Sub-Operator 16. Ihereby~_that the~l~ue and correct (T~a~e for State office use) Dist. Drlg. Supt. ~COMMISSIO'~:~ DATE 4/21/80 APPROVED BY TITLE DATE See Instructions On Reverse Side Alaska 0il and Gas Conservation C~mmission File April 2, 1980 Russell A. Douglass Marathon TBU D34A Tony Sw~nn called this a.m. 4-2-80 to discuss perforating operations of Marathon's D34A. Reperfora~g opara~ h~d taken place in this well late last year with negative results. Fluid production ~as reduced and ~ter cut increased. Due to reperforating operations that are to be perfo~ in other wells on the platfozm, Marathon has decided to perforate bench 5 in D34A. Since the paperwork must go thru Union as field operator Tony requested verbal approval for the perforating operations. Bench 4 is perforated frc~ 10,788' to 10,920', Marathon proposes to shoot new perforations frcm 10,950'-10,960' and 11,016' to 11,040'. I gave verbal approval to Tony and asked for a subsequent P-3 outlining the operations and noting verbal approval of this Form 10-403 REV. 1-10~73 Submit "Intentions' in Triplicate & "Subsequent Reports" in Duplicate '-~.~ STATE OF ALASKA 0IL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT-J' for such proposals.) WELL OTHER 2. NAME OF OPERATOR Union 0il Company of California* 3, ADDRESS OF OPERATOR P. O. Box 6247, Anchorage AK 99502 4. LOCATION OF WELL At surface Dolly Varden Platform, Leg A-l, 1210'FWL, 757'FSL, Sec 6-8N-13W-SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 106.2'KB MLLW 14. CheCk Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO-' 5. APl NUMERICAL CODE 50-133-20225-0:1 6. LEASE DESIGNATION AND SERIAL NO. ADL-18729 A-926 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Tradinq Bay Unit 9. WELL NO. D-34A (Deepen) 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC,, T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 5, T8N, R13W, SM 12. PERMIT NO. 79-11 )ort, or Other Data 'SUBSEQUENT REPORT OF: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* CHANGE PLANS (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all Pertinent details, and give pertinent dates, including estimated date of starting any proposed work. 11-20-79: Reperforated following intervals under drawdown: Bench 1: lO,550'-10,584'DIL 4 HPF Bench 4: 10,788'-10,820'DIL 4 HPF Bench 4: 10,834'-10,920'DIL 4 HPF 2-5/8" DA 180° Phased Carrier Gun 2-5/8" DA 180° Phased Carrier Gun 2-5/8" DA'lBO° Phased Carrier Gun Production Test: Test Before Perforations: Test After Perforations: 1152 BFPD, 9% WC 860 BFPD,'26.7% WC *Marathon Oil Company - Sub-Operator 16, I hereby//cer~ifv that the~re~lng I, true and correct (ThI~ ~ for State ~flce u~) Dist. Drlg. Supt. TITLE DATE 12/5/79 APPROVED BY TITLE CONDITIONS OF APPROVAL, IF ANY~ ~ Imtrumiom On R~e~ ~ DATE INSTRUCTIONS General: This form is designed for submitting proposals to perform certain well operations, and reports of such operations when completed, as indicated, on all types of leases and lands in Alaska. Item 15: Proposals to abandon a well and subsequent reports of abandonment should include reasons for the abandonment; data on any former or present productive zones, or other zones with present significant fluid contents not sealed off by cement or otherwise; depths (top and bottom) and method of placement of cement plugs; mud or other material placed below, between and above plugs; amount, size, method of parting of any casing, liner or tubing pulled and the depth ~to top of any left in the hole; method of closing top of well; and date well site conditioned for final inspection looking to approval of the abandonment. Forn; No, P-4 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I. OIL r~ GAS [] Water Injector WELL WELL OTHER 2. NAME OF OPERATOR Union Oil Company of California* ' 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage AK 99502 4. LOCATION OF WELL 755'FSL, 1213'FWL, Conductor //12, Leg A-l, Dolly Varden Platform, Sec, 6, T8N, R13~/, SM 5. APl NUMERICAL CODE 50-133-2022,5-01 6. LEASE DESIGNATION AND SERIAL NO. ADL-18729 7. IF INDIAN.ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. D 2 -r/'~ 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 5, T8N, R13W, SM 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. JUNE REPORT OF WORKOVER OPERATIONS 06-19 13,600'TD 13,542' PBTD Moving rig eqp~nt --f rom rig 77 to rig 76 RU. 06-20 13,600'TD 13,542'PBTD Moving rig eqpmt. Chgd DC power . CO mud tanks, loaded out Dowell eqpmt. RU. 06-21 13,600'TD 13,542'PBTD Activating rig 76. RU drlg eqpmt. RU Swaco Super-Choke. 06 -22 13,600'TD 13,542' PBTD 06-23 13,600'TD 13,542'PBTD Fin activating rig 76. Instld BPV & ND Xmas tree. NU BOP, chgd rams, & prep to test same. Tstd BOP. Tstd 7" x 3½" annls to 2100 psi for 30 min--OK. Pulled seal assy out of pkr @ 1-2,390'WLM. Circ hole clean. POH w/ 3½" tbg. Rec all tbg & Baker seal assy & muleshoe. 06-24 13,600'TD 13,542'PBTD PU DC's & 3½" DP & RIH. Tagged Baker Model F pkr @ 12,412'. Circ hole clean. POH. MU pkr picker. 06-25 13,600'TD 13,542' PBTD Fin RIH w/ pkr picker. Worked into Model F pkr @ 12,412' & milled to 12,414'. Pkr came free. POH. 06-26 13,600'TD POH w/ pkr picker. Rec Model F pkr. RIH w/ bit & boot basket. 13,549'PBTD Rec additional junk from pkr. RIH w/ bit & scraper to PBTD (DPM) 13,549'DPM. RU WL unit, tstd lub, & RIH w/ 6" gauge ring & JB. D~ that the,~~s true and correct 14. I here NO?~/~l~eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the V oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. *Marathon Oil Company - Sub-Operator Monthly Report of Workover~O~-Perations - June Page 2 O6-27 06-28 06-29 O6-30 13,600'TD 13,549'PBTD (DPM) 13,600'TD 13,549'PBTD (DPH) 13,600'TD 13,549' PBTD (DPH) 13,600'TD 13,549' PBTD (DPM) POH w/ WL JB & gauge ring. Set BP @ 12,980'WLM & cmt rtnr @ 12,890'WLM. RIH w/ stinger on DP & estab rate. Sqzd FIW holes @ 12,905' & 12,965'WLM w/ 50 sx Cl G to 3500 psi. Rev out 3-4 sx of cmt. Fin POH w/ cmt stinger. WOC. RIH & drld cmt rtnr @ 12,909'DPM (12,890'WLM). Drld cmt to 13,003'DPM (12,984'WLM). Circ hole clean. With pipe rams closed, press 7" to 3500// & bled to 2000// in 3 min thru Bench 1 & 2 perfs. Bled to 0// in 30 min. POH w/ //1RR bit. RIH w/ Baker Retrievamatic & set @ 12,904'DPM. Test sqz to 2000//. Bled off to 250 psi in 15 min. Set pkr @ 12,915'DPM, press to 2000//. Bled off to 600 psi in 5 min. Set @ 12,997'DPM & press to 2000 psi on BP @ 13,004'DPM. No loss. Set @ 12,944'DPM. & press to 2000//. Bled off to 800 psi in 5 min. POH. Set cmt rtnr @ 12,885'¥JLM. RIH w/ Baker sqz tool. RIH w/ Baker sqz tool to l'2,885'WLM. Rev circ hole clean. RU HOWCO. Took breakdwn @ 1 BPM.@' 3500 psi. Mixed 10¼ bbls 15.6// slurry: 50 sx C1 G w/ .75% CFR-2 & .5% Halad 22A. P! slurry followed by 5 bbls fresh wtr. Displ to 100' short of tool & stabbed into cmt rtnr. Sqzd in 6 bbls cmt w/ press to 1800//. CIP @ 1300 hrs. Press to 1700// in 30 min. WOC 30 min. Press to 3500//. No press loss for 30 min. PU 10' & circ approx 10 bbls cmt. POH. WOC. SLM DP in hole to 12,885'. WOC. Drld cmt rtnr & WOC. GEOPHYSICAL/GEOLOGICAL DATA~. TRANSMITTAL LIST FROM: DE:PT, MARATHON OIL COMPANY J SENDER EXPLOARTIO~ DICK ATCHISO~ TO: COMPANY IDATE June 7,1979 Mr. H. W. Kugler Union Oil Co. ADDRESS ADDRESS P. o. Box 2380 FORWARD TO STATE Anchorage, Alaska 99510 VIA IDATE SHIPPED QUANTITY Blue Line Sepia lea. lea. DIL 2" & 5" lea. lea. Sonic 2" & 5" 1 1 FDC 5" 1 1 Saraband 5" 1 1 RFT 1 1 1 1 DESCRIPTION 1 1 ~E,~SE REruRI~ ONE SIGNED COPY TO THE ABOVE ADDRESS Gyro Survey, Tangential, & RC FDC-CNL 5" WELL D--7RD Saraband ( - :. ,.: ~ /; WELL D-28.... ~ '~ Saraband (Recomputed) 5" ..... -~:'- RECEIVED BY ~ No. P-4 STATE OF ALASKA svs~rr n~ mmt, c,,~ ~. B- I-T0 ~A~I N~IE~C~ ~ODE OIL AND GAS CONSERVATION CO~I~EE 50-~33-20225-0~ CO~~ MONTHLY REPORT OF DRILLING ~ ~s~ ~s:o.~o~ ~-~ s~,~ ~.,~ j ] ENg I AND WORKOVER OPERAT~NS ADL- ~ 8 7 2g WiLL W~LL -- -- J. N~E ~F OP~TOR ~ & ~ ' Union Oil Company of California* '~.~ ~.", ...... ~ J 2GEOL ~. ~gg~ss o~ o~o~ ' T' y.~' {~- -/~ Trading Bay Unit .~. P O Box 6247, Anchorage AK 99502 ~ ';r,.~[~, ~ ~f~i~ · · '~"~. D-34A (Deepen) ~[ STAIIEC 4. ~c~o~ o~ w~ ~, ~?. ~¥5. - /-~ ~.-;p,. ,-- _ McArthur River 840'FWL, 1070'FSL, See. 5, T8N, R13W, SM %%" n S~..T..~..~..(~O~O~ %; o~ F[LF: Sec. 5~ TSN~ ~3~ ' '~ 1~. P~IT NO. 7g-~l 13. REPORT TOTAL DEPTH AT END OF MONTH. CYIA~NGF_.S IN HOLE SIZE. CASING AND CEMF~'~IiIqNG JOBS INCLUDING DEPTH SET AND VOLU1VIES USED. PER~ORATIONS. TESTS AND RESULTS FISHING JOB~ JU/2tK L~I HOLE AND SIDE-Tlq~CKED HOLE A~D ANY OTHEt{ SIGNIFICANT CHANGF,~ IN HOI~ ~ITIONS. 04-01 10,295'TD 10,200'PBTD APRIL REPORT OF DRILLING AND WORKOVER oPERATIONS RU WL & opened circ slv@ 10,021' in Well D-34A. Set BPV, ND tree, & NU BOPE. 04-02 10,295'TD 10,200'.PBTD Fin NU & testing BOPE. PU tbg string to position circ slv above top pkr @ 9973'. C&C mud building volume. " 04-03 10,295'TD 10,200'PBTD C&C mud to 9.6 ppg around. POH & LD 3~" tbg, seal assy, & XA sly. 04-04 10,295'TD 10,200' PBTD RIH w/ burnover shoe #1. PU 5" DP. Milling over Baker F-1 pkr @ 9984'DPM. 04-05 10,295'TD 10,200'PBTD Cont to mill _o-ver Baker F-1 pkr @ 9984'DPM. POH. Rec pkr. Tstd BOPE. RIH w/ burnover shoe #2 & milled over Otis WB pkr @ 10,074'DPM. POH. Indications are that the Otis WB pkr has been milled .over & "picked." 04-06 10,295'TD 10,200' PBTD POH. Rec Otis WD pkr, pkr bore ext, & Otis T:"nipple. LD fishing tools & RIH w/ bit. Tagged hard fill @ 10,180'. Drld fill to rtnr @ 10,222'DPM. Drld on rtnr 3 hrs. POH. RIH w/ bit to fin drlg rtnr. 04-07 10,310'TD Drld rtnr @ 10,200', FC @ 10,249', & flt shoe @ 10,295'. Drld new hole to 10,310'. POH. RIH w/ locked drlg assy. Tagged csg perfs @ 10,100'. Reamed from 10~100' - 10,147'. hereby ~rtl£~ that the fori~oir~"~ true ~ ~ s~a~.,r~-g ~. ~~~~ Dist Drlng Superintenden~_~ May 7, 1979 I f -/I I I I II rl I II ..... (-~OTE --Regor! on this form ie required for ~3ch calend.r month% regardless ~ the JtoSus of operatio.s, o.d must ~ filed Jn duplicate with the oil and gal conlervat~n commi~ee by the 15~ of the succ~diflg ~n~, ~le~ otherwise directed. *Marathon 0il Company - Sub-Operator April Report of Drilling Operations Well TBU D-34A (Deepen) Page 2 04-08 10,389'TD 04-09 10,539'TD 04-10 10,841'TD 04-11 11,093'TD 04-12 11,178'TD 04-13 11,285'TD 04-14 11,285'TD 04-15 11,285'TD 04-16 11,285'TD 11,185'PBTD 04-17 11,285'TD 11,185'PBTD 04-18 11,285'TD 11,185'PBTD POH. Removed locked drlg assy (LD roller reamer.) RIH w/ bit & 1 stabilizer 120' above bit. Reamed csg perfs from 10,100' - 10,174'. POH. RIH w/ locked drlg assy. Reamed csg from 10,100' - 10,174'. Cont in hole to 10,310'. Performed'14 ppg mud equiv leak off test. Drld from 10,310' -10,389'. Drld from 10,389' - 10,486'. POH. Chgd BHA & RIH. Drld to 10~539'. Drld from 10,486' - 10,841'. POH for new bit. RIH to 10,100'. Replaced low drum chain. RIH to 10,841' & drld to 11,093'. Drld from 11~093' - 11,178'. Made wiper trip to 9-5/8" shoe @ 10,295'. C&C hole for logs. POH. RU Schl & started running logs. Fin logging. RD Schl. RIH w/ 8~" bit. Drld from 11,178' - 11,285'. POH. RU Schl. RIH w/ Schl RFIT & meas BHP in Benches 1, 2, 3, 4, 5, & 6 of Hemlock Zn. RD Schl. RIH to cond hole for 7" lnr. Recorded BHP as follows: Bench Depth BHP 1 .... 10,560.' 3278 psi 10,569' 3277 psi 2 .... 10,619' 3745 psi 10,667' 3763 psi 3 .... 10,701' 3626 psi 10,749' 3560 psi 10,751' 3536 psi Bench Depth BHP 4 .... 10,801' 3378 psi 10,865' 3349 psi 5 .... 10,984' 3454 psi 11,021' 3458 psi 6 .... 11,119' 3820 psi RIH to TD @ 11,285'. C&C hole for 7" lnr. POH. RU & ran 33 jts 7", 29#, N-80, Butt csg. MU BOT lnr hgt. RIH w/ 7" lnr on 5" DP. Set lnr w/ tie-back slv@ 9859'-, top of hgr @ 9864', LC @ 11,185', & shoe @ 11,285'. HOWCO cmtd w/ 300 sx C1 G w/ 1% CFR-%.3%Halad 22-A, .3% Kci, & 1/4 #/sec Flocel.preceded by 12 bbls mud flush. Bumped plug w/ 2500 psi--held OK. POH 15 stds & circ to clean 5" DP. Circ @ 8460' to clean DP. POH. LD BOT lnr setting toOls. LD HWDP from derrick. RIH w/ 8~" bit. Broke circ@ 8900', 9500', 9742'. Tagged cmt @ 9812'. Started drlg cmt. Drld hard cmt from ~812' - top of 7" lnr @ 9859'. Tstd 9-5/8" csg to 2000#--OK. POH. RIH w/ 6" bit. Drld hard cmt from 9859' - 9864'. CO cmt stringers to 9900'. RIH to 11,029' & tagged cmt. Drld cmt from 11,029' - landing clr@ 11,185'. Tstd 9-5/8" csg & 7" lnr to 2000# OK. Fin POH. RU DA. Ran CBL/GR log from 11,165' - 9800' and from 4000' - 100'. Ran Scientific gyro surv from 11,180' - 9500'. Started MU DST tools for dry test of lnr lap~ RIH w/ Johnston DST tools for dry test of lnr lap. Set pkr @ 9790'. Tool open i hr & SI 2 hrs. Lnr lap tstd dry. POH. BHP charts confirmed dry test. RIH w/ bit & scraper to 11,185'. Displ mud in hole w/ FIW. POH. LD DP. April Report of Drilling Operations Well TBU D-34A (Deepen) Page 3 04-19 11,285'TD ll,185'PBTD 04-20 11,285'TD 11,185'PBTD 04-21 11,285'TD 11,185'PBTD 04-22 11,285'TD 11,185'PBTD 04-23 11,285'TD 11,185'PBTD 04-24 11,285'TD 11,185'PBTD 04-25 11.,285'TD ll,185'PBTD 04-26 11,285'TD ll,185'PBTD 04-27 11,285'TD 11,185'PBTD 04-28 11,285'TD 11,185'PBTD 04-29 11,285'TD ll,185'PBTD Fin LD DP. RU DA. Set Otis WD pkrs @ 10,930' g 10,419'DIL. RD DA. RU to run 4~" prod tbg g started running same. Cont RIH w/ 4~" prod tbg. Attempted g failed to sting into Otis WD pkr @ 10,419'. RU DA for depth measurement. ~ RIH w/ DA CCL to determine location of seal assy w/ respect to perm pkr. Found Ijt of tail RiRe thru pkr. POH. Stood tbg in derrick. Chgd over-sized tbg coUPllng'below seal assy% RIH w/ 4~" prod tbg, Gator-Hawking to 5000 psi. Spaced out g landing tbg. Landed 4%" prod tbg. ND BOPE. NU Xmas tree & tstd to 5000#. Prod crew installing manifold $ flowline for D-34A. Cont to install new manifold in A~I well room. Also 'fabricating flow line for D-34A. Performed maintenance on rig eqpmt. Cont to install prod manifold & flow liDe~ Maintained rig eqpmt & moved some ~rig eqpmt to rig 77 for redb~ll Of D-3. Fin installing flow line & GL line. Unloaded FIW from well. RU DA. Perfd Bench 4, Hemlock, w/ 2-1/8" jet from 10,890' 10,920'DIL w/ 4 HPF. DA perfd Bench 4, Hemlock, from 10,890' 10,834'DIL w/ 2-1/8" jet (4 HPF). Placed well thru test sep.~ Well prod @ rate of 2368 BFPD @ 0.6% WC (2354 BOPD). Cont flowing lower Bench 4 @ 2638 BFPD @ 0.6% WC. RU DA. Perfd upper Bench 4 from 10,788' - 10,820'DIL w/ 2~1/8'' jet, 4 HPF. Flowed. well @ 3048 BFPD @ 6% WC (2865 BOPD). RU Camco for BU surv using HP gauge.' RIH w/ gauge. Now stah. ilizing well. Compl running PBU surv $ POH. RD Camco. RU DA & tstd lub to 2500#. Perfd Bench I w/ .2-1/8" carrier gun (4 HPF) from 10,584' - 10,564' and from 10,564' - 10,550'. RD DA. Flowing well for clean-up. 24-hour test on D-34A: 3074 BFPD, 4.2% WC (2945 BOPD, 129 BWPD). Released rig from D-34A @ 0700 hfs, 04-29-79. FINAL REPORT. _= ~:~'JSTATE OF ALASKA SUBMIT IN x, OIL AND GAS CONSERVATION COMMITTEE .rE* reverse side: la. TYPE OF WELL: b. TYPE OF COMPLETION: NEW ~ VV O R I(. ~ V~' E L L[~ OVER ~ WELL COMPLETION OR RECOMPLETION REPORI%&ND WELL WELL ,.' .' DRY Other DEEP- ,~ PI. UG .~ DIFF. ~_ EN BACK P.E SV R. ~,, Other 2. NAME OF OPERATOR Union Oil Company of California* 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage AK 99502 4. LOCATION Ob' wELL (Report location clearly and in accordance with any State requirements)* At s~u~rface ' ~.o 1210'FWL, 757'FSL, Sec 6-SN-13W-SM, Leg A-l, Dolly Varden Al; top prod. interval reported below 820'P~/L, 1080'FSL, Sec 5-SN-13W-SM At total depth l155'FWL, 980'FSL, Sec 5-8N-13W-SM i3. D_~T-E SPUDDED [14. DATE T.D. I:LE~CIR]BD [15.'DAT~I GOB~P SUSP O1~ ABAN-D. 116. ELEVATIONS iDF, RKB. 04-01-79 [ 04-13-79 [ 04-29-79 ] KB 106.2' MSL 11,285' MD ! 11,185 ' aow ~'n~N¥. ~OT^~ rOO~.~ 9;qfiO'TVD | 9:g72'TVD -- Ail 22. PRODUCING !NTE!RVAL(S), OF THIS COMPLETION--TOP, BOTTOM, NA!%IE (MD AND TVD)· Top of Hemlock: 9311'TVD; 10,500'MD Btm of Hemlock: -9637'TVD; 10,920'MD 24. TYPE ELECTRIC YLND OTHEFt LOGS RUN Sec. 5, T8N, R13W, SM 12. PEltI~IIT NO. ) 79-11 .RT, GR, ~'I'C)* 117. EI_~V, CASINGIIEAD 62 'MSL INTER%'ALS DR(LI,ED BY CABI,E T00I,S 23. WAS DIRECTIONAL , SUHVEY MADE Ye8 1 SP-DIL-GR, BHC/SOniC;, CNL-FDC, CBL/GR, Gyro 25. . CASING RECORD (Report all strings set in well) 13-3/8" 20807MD t 9-5/8" 10,295,'MD i 26. LINEit I:LEC ORD SIZt!I ~ TOP (AID) [ I~OTTOIvi (I'ID) t SA. Ct(S CE.MEXT* 7I' t ~= 9859'I 11,,275' 300 si 28. PERFORATIONS Op~_~N TO PRODUCTIOiNI (interval, size and number) Bench 1: 10,550'-10,584' 4 HPF Bench 4: 10,788'-10,820' " Bench 4: 10,834'-10,920' " PRODUCTION CI~tlENTING RECOtLD Existing Existing 29. i FtP, 'IOUNT PULLED 27. TUBING !REC GILD 4!~x2~'~ 10,948~ 10;930~ & ~, 10.419~ ACID, si:eT, FilAZ2 URE, CF.",iENT SQUEEZE, ETC. D~]Pl~Ii INTEI~VAL (MD) A?dOUN£ ~'~ND I'~!ND OF MA'iEYLIAL US'ED DATE FIRST P~ODUCTION [ rfP, eDUCTION MEIIiOD /Fiov:i~*g, gas lifi, pumpimg--size and type of pump, 04-30-79 [ Gas Lift DATE OF T~ST. ~OL~S ?ms~ -Icxaoxm SIZE ]PROD':q FOR OI~BBL. GA~AiCF. 05-02-? 24 [ I3010 I 673 ~X(', ~:BING CAkhNG P~S~E ICAL~~ OI~BBL. ~ss. 180 l~--~ov~ ~ I I3°1° I 673 - 31. DISP08ITION OF GAS (8Old, u~ed for 7uel, vented, etc.) Lift Gas and Sales I V, };LL G'I-ATUS i Producing or Producing \V/dfER--BBL. ] GAS-OIL II.'~TIO 129 ] ·223 WATER--BBL. ] OILGRAVITY-AP1 (COil.It.) 1 I 129 35° _. _ t TES] WITNESSED BY · R. McClellan 32. LIST OF ATTACHMENTS Well History, Tubing Details 33. I hereby celsgffv that the foregoi~ and attached information is complete and correct as determined from all-available records SIGNED .~'~"2f~- ~~-.~~~TITLE DisC Drlng Superintendent DATE May 4, 1979 *(See Instructions and Spaces For Additional Data on Reverse Side) *Marathon Oil Company - Sub-Operator INSTRUCTIONS C~eneral: This forr'r~ is designed for subr~.~tt~r~g a complete and correct well completion report end Ia.c] all types of lanJs and leases ~n Alaska. item: 16: Indicate which elevation ~s used as reference (whe. e nor oti~erw~se sho,~'n) for depth measure- merits g~ven ~n ether sF)aces on Th~s forr~ ar'~¢J ,n any atl,]:-!~:~er'~ts Items 20, end 22:: If ti~s well ~s completed for sef')~r?.t~ !)rcctuc~Jor-, fro"~ ,"~ore than age ~nterval zone (muJl~ple complet~or~), so state ~n rten~ ~0. ,]nd ~r~ ~te"~ ?? show tho p~c:]~(',~l ~nte:rval, or ~te~vals, top(s), bottom(s) and name (s) (if any) for only the interval! re[.)orted Ir~ ~te~ 30 Submit a separate report (page) on th~s form, ade,quately ~dentif~ed, for each add~t,o~al ~r~t~,val to be seperately produce, J, show- ing the additional data pertinent to such ~nterval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cemor~ting and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). , , 34. SUMMARY OF FOi~MATION 'l'~2g'l'S 1N('LLIDIN(; INTEH. VA1L, TE.qTEF). I'ltE.'qSUI2E I')ATA A_N'D '~q. lgCOVEltlF~~, OF ()1I, GAS. 35. G ]DOL, OG I C M A R KIKI:~q WATT2II AND MUD NAME .. .... , , ,, , ,,, ,,, ~ ,, ., ,,,,, , , - ............... 3fl, CORE DATA, A'I'I'ACII BIIlE~' D~_.~Cb~'iPI'I*ION.q OF LITIIOI,OG¥, DOTIO.qlTY, F[IAC'I'URES, AND 'D'~T~C'T~I,) gliOWS OF' (')IL, GAS O11 I L il Il I Ill I Ill I Ill I I I I Il I i , ,, · . , .............. Union Oil and Gas Di,'~sion· Western Region Union Oil Company 0,'t'~alifornia P.O. Box .6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 union March 25, 1976 Mr. Hoyle Hamilton Division of Oil & Gas . State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 RE: ~ - ~-DEN PLATFORM Dear Mr. Hamilton: Enclosed for your files are two (2) copies of [he Well Histories for each of the above captioned wells. Very truly yours, Callender ~ ' District Drilling Supt. sk Encl. (4) cc: Marathon Oil Company Atlantic Richfield Company Amoco Production Company (D-5 only) Phillips Petroleum Company (D-5 only) Skelly Oil Company (D-5 only) Standard Oil Company (D-5 only) USGS-Rodney Smith DATE: C) '~- OW-.. "/.(w .. MAr. RTHIDN OIL COi~P~ 'NIY' FIELD McArthur'RiVer HIS'~)RY OF OIL OR GAS WELL NO.._[L~.4.,~ LEASE Trading Bay Unit PARISH Kenai STATE Alaska COUNTY Peninsula Borough BLOCK SEC. § TWP. 8N .. R.,, 13W Surf Loc: Conductor #10 Leg A-1 {NE) 7S6.8'FSL & 1209.5' FWL /ToP OF OIL STRING EL£V M£ASURE~.' £~,-S , I ToP OF ROTARY TABLE ELEV. TAKEN FROM ~ [GRO. OR MAT, ELEV._ HISTORY PR£PAR[D BY K · A. Thoma_:. TITL£ Drilling Engineer ... It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations ot the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, sur~eys, all tests, all completion operations and procedure, etc. DATE 1975 i0-09 .0-10 0-11 0-12 0-13 '0-14 0-15 0-16 .0-17 !0-18 :0-19 ,0-Z0 !0-21 .0-22 WELL HISTORY - D-34A, REDRILL (Marathon AFE 4545) NOTE' Report is to 7 AM for previous 24 hours operaL~i,~i~i;: :,.,.~, :.;:.~, ~;:i;_; :i_-!:!~!; Re]eased rig #76 from well D-2S to D-34 @ 9 PM, 10-08-75. Rigging down to move rig. Have off-loaded 3½" DP & 3 pipe racks. Moving rig from Leg B-1 to A-1, Installed BPV. Removed Xmas tree· Installing BOPE. "Rig Engineer" out of service. Wait on boat to off-load pipe racks & mud tanks. "Husky" arrived @ DV @ 3PM, 10-10-75 & off-loaded 3 pieces. (Winds 25 knots.) Began skidding rig from Leg B-1 to A-1. Rig skidded to Leg A-l, 10 AM, 10-11-75. Set 2 mud tanks. Tied do~m rig. NU riser. Winterizing rig. RUR. Finished rigging up @ 3 PM. Tested BOPE to 3000 psi. Pulled & laid down tb g. Flanged up & tested BOPE. PU bit & six 6¼" DCs. RIH. Circ to cond mud wt & risc. Circ & build mud wt. Made up 9-5/8" csg spear. RU Dia-log. Worked 9-5/8" csg to 350,000#. Pulled slips. Ran FPI. 9-5/8" csg free @ 2000'. Worked pipe. Re-ran FPI. Free point worked down to 2225'. Pulled free point. Set slips. Finished hooking up kelly. Laid down spear. Flanged up BOPE. Tested to 1500 psi. PU 9-5/8" csg cutter. RIH to 2220'. Attempted to cut csg Broke knife POH Changed tools RIH Cut 9-5/8" @ °2t4' · · · · · /- · POH. Laid do~m cutter· Worked & circ 9-$/8" csg. Preparing to pull 9-5/8" csg. Repairin~ rotary while circ w/ 700#. Press incr to 3700# & hyd q-$/8" csg up 4]'. ' Inspected derrick--all OK. Cleaned & magnaflux elevators· Kelly bails all OK. Engaged 9-5/8" csg w/ spear. Pulled $5 jts 9-5/8" 47# csg. Overall length 2161'. ~. o · ~.. Laid do~m 6¼" DC. PU 12¼" drlg assy. RIH tO 2204'. Circ & cond mud. POH. PU 13-3/8" Servco section mill. RIII. Milled 2080' - 2090'. Milled 13-3/8" csg from 2090' - 2105' w/ mill #1. Circ. POH. Change blades &RIII w/ mill #2. blilled-from 2105' - 2113'. POlt. Changed blades & RI}I w/ mill #3. blilled from 2113' - 2120'. ~a'¢ll History - D-34A, Redri.~., ._~ Page 2 10-23 Milled 13-3/8" csg from 2120' - 2125' w/ mill #3. POH. Made CO run w/ diamond point bit. POH. RIH w/ mill #4 & milled to 2143'. POH. 10-24 10-25 .10-26 Finished trip--changed knives. Milled from 2143' - 2153'. Trip to change out knives. Milled 2153' - 2158'. Laid down milling tools. The window in 13-3/8" is from 2080' - 2158'. Ran open end 5" DP to 2190'. Cond hole to set plug. Circ & cond mud'. Mixed 200 sx class G 14% sand, 16# slurry. POH. Placed 200# on plug for 6 hrs. Drld plug. Poor cmt. Drld out to hard cmt @ 2150'. Circ clean. POH. RIH w/ OEDP to 2150'. Cond hole for plug #2. Set kick-off plug w/ 200 sx class G 10% sand, 17.5# slurry @ 2150'. WOC 6 hrs. Drld hard cmt 2010' - 2090'. POH. PU DD & BttA. RIH to 2090'. Orient DD 10-27 Drld & surveyed from 2090' - 2175'. POH. Changed BHA. RIH. Reamed Dyna-drilled hole from 2090' - 2175'. Drld & surveyed from 2175' - 2744'. 10-28 Drld & surveyed 2744' - 3339'. Trip for new bit. Changed BHA. Drld surveyed from 3339' - 4060'. 10-29 Drld & surveyed from 4060' - 4172'. Trip for new bit. RIH. Drld & surveyed from 4172' - 4914'. 10-30 t0-31 Drld & surveyed to 5130'. Made trip. Changed bit. RIH. Drld & surveyed from 5130' - 5381'. POH for bit chg. Completed POH @ 5581' to chg bit. RIH. Drld & surveyed to 6032'. POH for bit chg. !!-0! Finished trip to chg bit & BHA. Cut drlg line. Drld to 6216', surveyed. Drld to 6263', POH to chg BHA. RIH. 1-02 1-03 Drld to 6431'. Circ & surveyed. Drld to 6480'. POH to chg bit. RIH & drlg 12¼" hole. Drld & circ for survey @ 6620'. Drld to 6625'. POH & changed BHA. RIH. Reamed 67' to bottom. Drld 6756'. Surveyed & drlg ahead. 1-04 ~1-05 Drld to 7015'. Surveyed. POH to check BHA. Changed bit. RIH. Drld to 7340'. Circ. Survey & POH. Completed trip for new bit. RIH. Drld to 7720'. Rig failure @ 4 PM, 7 PM, & 8 PM. -,1-06 :1-07 Drld from 7720' - 7756'. Circ & surveyed. POH for bit. RIH. Drld from 7756' - 7990'. POH w/ bit #1'3. Ran bit #14. .Drld from 7990' - 8327'. :1-08 11-09 Drld to 8338'. Surveyed & POH. RIH & drld to 8412'. POH for bit. RIH. Drlg. Drld 12~" hole from 8415' - 8595'. POH. Changed bit & RR. RIH. Drld from 8595' - 8610'. i1-10 Drld from 8610' ~ 8869'. POH to chg bit. 1-11 1-12 Finished TIH. Drld to 8881'. Ran survey. Drld to 9133'.~ POH. Check BHA. Changed bit. RIH w/ bit #19. Drld to 9348'. Survey. POll to chg bit. 1-13 Changed BHA. Rill. Drld to 9592'. Dropped survey. POH. 1-14 POll. Test BOP & ~iydril. RIH. Slipped drlg li'ne. Drld to 9720'. Ran survey. POll. Well History - D-~ , Redrill · Page 3 11-12 11-15 11-14 11-15 11-16 11-17 11-18 11-19 11-20 11-21 Drld to 9348'. Survey. POH to chg bit. Chg BHA. RIH. Drld to 9592'. Dropped survey. POH. POH. Test BOP & Hydril. RIll. Slipped drlg line. Drld to_ 9720'. Ran survey. POH. Made trip for bit #22. Measured in OK. Drlg 12¼" hole. Drld to 9933'. Ran survey. POH. Chg BHA. Cut drlg line. RIH. Drlg 12¼" hole. Drld to 10,074'. Circ. Ran survey. Trip for bit. Drlg 12¼" hole. Drld to 10,203'. Circ. Ran survey. POH. Chg bit. RIH. Drlg 12¼" hole. Drld 10,252' - 10,275'. RU Schlumberger. Logged w/ DIL, BHC-Sonic, GR Cal, FDC from 10,250' - 2080'. Schlumberger finished logging well. RIH w/ new bit. Drld 10,275' 10,295'. Circ clean. POH. Chg rams. RU to run 9-S/8" csg. Now r.unning csg. (Drld 10,275' - 10,295'~-O.) Ran 9-5/8" csg to 10,295'. Stage clr #1 @ 9296' stage clr #2 @ 5879'. Circ hole. Cmtd w/ 630 sx class G neat ~mt, 1% D-31, .03 R-5. Bumped plug w/ 1500 psi. Held OK. Open stage clr @ 9296'. Circ hole. Cmt w/ 1000 sx class G 4% gel, 1% D-31, .03 R-5, 150 sx class G, 1% D-31, .03 R-5. Bumped plug w/ 2800 psi. Tool shifted. Released pressure on stage clr. Did not hold. Hold pressure for 2 hrs. 9-5/8" CASING DETAIL Item Len. g?h Fro.re. To KB to' Cutoff & slips 61 jts, OD, 40#, Butt, N-80 74 jts, OD, 47#, Butt, N-80 Baker Model J Stage Collar 56 jts, OD, 47#, Butt, N-80 23 jts, OD, 47#, Butt, P-110 Baker Model JB Stage Collar 23 its, OD, 47#, Butt, P-il0-' Baker Model G Diff Fill Clr 1 jt, OD, 47#, Butt, P-110 Baker Model G Diff Fill Shoe 41.20' -0- 41.20' 2514.44' 41.20' 2555.64' 3321.96' 2555.64' 5877.60' 1.75' 5877.60' 5879.35' 2471.32' 5879.35' 8350.67' 944.04' 8350.67' 9294.71' 1.75' 9294.71' 9296.46' 952.56' 9296.46' 10,249.02' 1.90' 10,249.02' 10,250.92' 41.48' 10,250.92' 10,292.40' 2.60" 10,292.40' 10,295.00 11-23 11-24 11-25 11-26 11-27 WOC. Skidded Rig #76 to Well D~26 to repair ball valve. WOC. Repairing ball valve on well D-26. Rig released from D-26 @ 10 AM, 11-24-75. Moved rig on lOcation 4 PM. Flanged up & tested BOP. Laid down 8" DC. PU 6¼" DC. RIH. Placing rubbers on DP. RIH to 5880,. Test csg to 3000 psi. Drld out stage cir.- Tested to 3000 psi--held OK. RIH to 8960'. Drld cmt & stage clr@ 9296'. Tested to 3000 psi--held OK. Drld hard cmt from 10,230' - 10,249'. POH. RU DA. RIH w/ csg bond log, GR, clr locator. DA tool failed. Finished running DA csg bond log. Poor bond over all sections. RU ran Sperry-Sun gyro from 2000' - 10,200' in 100-ft intervals. RU DA csg gun to perf 4 holes from 10,138' - 10,139'. POll. RU & running Baker model K cmt ret. 11-28 11-29 11-30 12-01 12-02. 12-03 12-04 12-05 12-06 12-07 12-08 12 -09 12-10 Well l-list@fy - D-3'.,~-~, Rcdrill Page 4 RIH w/ Baker Model K cmt ret. Set @ 10,047'. Breakdown press 3800 psi @ 1.75 BPM. Annulus press incr 200 psi. POH. PU pkr. Checked stage clrs & csg to 4000 psi--held OK. RIH. Sqz cmt perfs 10,138' - 10,139' w/ 150 sx class G cmt w/ 1% CFR-2, 0.5 R-5, 15# slurry· Breakdown press 3800 psi, rain sqz Press 3500 psi @ 2 BPM. Max sqz press 4500 psi. CIP @ 7·30 9uM. ClP a 7·30 AbI POH RU DA Perf w/ csg gun from 10,018' - 10,019' 4 HPF. PU Baker Model K 9-5/8" cmt ret. RIH. Ret stopped @ 7779'. Started out of hole. Lost ret @ 7403'. POH. PU bit. RIH. Pushed ret to 10,142'. POH. RU DA. Ran junk basket & gauge ring. RIH w/ junk basket & gauge ring· Stopped @ 9998'. POH. RIH w/ bit scraper & junk basket to 10,040'. Circ clean. POH. RIH w/ gauge ring & junk basket. Ran Baker Model K ret to 9858'. Ran cmt tools. Press to 5000 psi. Would not take fluid. Surged perfs. Would not take fluid @ 5000 psi. POH. Finished POH. RU DA, perf 4 HPF 4030' - 4031'. Ran gauge ring & Baker cmt ret. Set cmt ret @ 3918'. Circ mud out of annulus. Cond hole. Cmt w/ 850 sx class G 4% gel, 1% D-31, 0.3% R-5, 15.2# slurry. Followed w/ 200 sx class G 1% D-31, 0.3% R-5, 16.5# slurry, 80% returns. Job compl @ 10. PM. WOC. Stab into ret @ 3918'. Press to 5000 psi. No break down. POH w/ cmt tools. RIH w/ bit. Drl ret & cmt. POH. Ran Baker Retrievamatic pkr to 3934'. Tested to 4600 psi for 30 min--OK. POH, Laid down pkr. RIH to 9158'. Drlg on ret. Drld ret @ 9858'. RIH to 10,040' Trip for new bit. Drld ret & cmt to 10,180'. RIH to 10,250'. Circ hole clean. Displ hole w/ filtered Inlet wtr. POH. Removed drlg nipple· Flanged o I ~or. *~o~ . ~ ~. man ~v/ csg gun. Perf w/ csg up lubr:-~+ ~o~ to 3000 psi. ~" ~ ~"-- gun 3 HPF 10,138' - 10,178'. POH. RD DA. Flanged up drig nipple. Cut drlg line. RIH w/ bit & csg scraper. Finished running bit & scraper. POH. Ran Baker pkr to 10,047'. RU Dowell. Started injection test. Would not take fluid @ 3500 psi. Spot 300 gal 12.6 MCA over perfs. Re-set pkr. Held acid on perfs for 2 hrs w/ 3500 psi. Started taking fluid @ ½ BPM @ 3700 psi. Cont to pump acid. Released pkr. Flushed w/ 20 bbls wtr. Re-set pkr @ 10,010'. Inject @ 3500 psi 3/4 BPM. Injected 710 bbls filtered Inlet wtr @ 3/4 BPM @ 3500 psi. RU Go Int'l to run tracer survey. Finished RU Go Int'l. Tested lubricator. RIH w/ tracer while injecting @ 3500 psi. After running tracer, released pkr. Re-set below perfs to confirm no water going out bottom. Checked OK. POH. Preparing to sqz cmt. --- PU Baker Model K cmt ret. Ran on WL to 9950'. Would not set. POH. Ran ret on DP. Set @ 9950'. Sqz cmt w/ 150 sx 15.7# slurry. Min press 3500 psi @ 3/4 BPM, sqz press 4500 psi @ -'a BPM. Locked up w/ 9 bbls outside perfs. Rev out 5 bbls cmt. Job comp @ 1'15 PM. PO~l. WOC. POH. Laid down Baker cmt tools. RIH w/ 8~" bit. W0C to 3 PM. Drld ~ 43 ' POH RU out to bottom of cmt @ 10,185'. Circ out to 10,~ . . lubricator. RU D:\. RU DA. Tested lubricator to 1500 psi. RIH w/ 20' csg gun, 3 HPF. ?0' 3 HPF Perf 10,138' Perf 10,158' - 10,178'. POH. RIH w/ gun #2, . ., . to 10,158'. RU & ran Howco DST tools to clean fro. Ran 1000' wtr cushion & 1000# gas cushion. Open tool 10 min- NO flow. Bled off gas cushion to 475--no flow. Shut-in 5 min. .Open tool 1 hr. Fair . blow. Final shut-in 5'45 AM. PreParing tO rev out. - Well ~listory- D-mA, Rcdrill Page 6 ' . 12-22 12-23 12-24 12-25 12-26 12-27 12-28 12-29 12-30 12-31 Waited on Go Int'l, RU lubricator & tested to 6000 psi. RIH w/ tracer ~ GR. Ran base log. Injected 6 BPP. I @ S900 psi for 12 min, 73 bbls injected. Shut down pumps, shot. tracer @ 10,135', RIH to 10,190'. Pumped 6 BPbl @ 5900 psi. Tracer'passed GR in 3 min. Set for 30 min 6 remained hot. Ran log up 10,200' to 10 040'. Hot spots '(10,164' 10,190'). Pulled tracer tools to 10,100'. Stopped pumping. Shot tracer off @ 10,100', RIH to 10,200'., waited for tracer to come by. No RA material showed up. Logged up. Hot @ 10,164' - 10,190' w/ some RA material @ 10,138'. No RA material into Bench #3 @ 10,100' 10,122'. POH & RD Go Int'l. RU for frac job. Moving Dowell frac equip on-location to frac Benches 3 & 4. Off-load Dowell equip. Mixed 4000 gal gel water. Mixed gelled water Dowell YF 60 FC frac fluid, 2% HCL, 60#/1000 gal J-30, 20#/1000 gal J-115, 3#/1000 gal J-218 (40,000 gal total-fluid). Press annulus to 3000 psi. Tested lines to 8000 psi. Pumped' 134 bbls 5617 gals fluid loss pad 189 bbls 7919 gals w/ 0.64 g/gal 20/40 sand 5,074# 136 bbls 5702 gals w/ 1.28 #/gal 20/40 sand 7,305# 203 bbls 8530 gals w/ 2.65 #/gal-20/40 sand 21,856# 2'17 bbls 9119 gals w/ 3.84 #/gal 20/40 sand 35,048# 24 bbls 1018 gals w/ 5.13 #/gal 20/40 sand 5,217# 74,500# Max press 6000 psi Displ w/ 189 bbls (7938 gals)w/ lilt Inlet wtr. @ 14 BPM. Min press 5650 psi @ 15½ BPM. Instant shutin 5000 psi, 1 hr 2700 psi. Connected up to inject @ 4000 psi--flow rate too low to measure. POH w/ pkr. PU bit & RIH. Tagged sand @ 10,130'. CO to 10,200' w/ rev circ. PU 9-5/8" Baker pkr & RIH to 10,045'. Set pkr. Press annulus to' 2500 ps~. ~o~,~ted .... up wtr injection system. Press up +'~o 4000 psi. Injection rate too low to register on 3" turbine meter--less than 1500 BWPD. Injecting filtered Inlet wtr. RU Go Int'l to run GR. Ran GR from 10,200' - 10,045'. Indications are that sand went in @ 10,166'. RD Go. RU BJ. Pumped 140 bbls injection wtr @ 4000 psi @ 1.4 BPM. Hook up wtr injection system & test Bench 4. Injected filtered Inlet wtr w/ injection system @ 1.4 BPM. Spotted 31 sx 20/40 sand. Tag sand @ 10,127'. Set pkr @ 10,045'. Pkr leaked. POH & RIH w/ new pkr to 10,045'. Press up Bench 3 to S000 psi--would not take fluid. RD BJ. RU Dowell. Tested lines to 7500 psi. Injection rate 7500 psi @ 15 BPM. Injection rate 4000 psi @ .9-BPM. RU Go Int'l. Perfd from 10,027' - 10,042' w/ 3 HPF. Pulled pkr-. RIH w/ csg scraper & bit. RIH w/ 9-5/8" csg scraper to 10,210'. POH. PU press bomb on Baker RBP & Baker EA pkr. RIH. Set BP @ 10,090'. Pkr @ 10,080'. Tested BP--held OK. Set pkr @ 9962'. Dowell injected 450 bbls filtered Inlet wtr. Rate: 3/4 BPbl @ 4000 psi 2½ BPM @ 4550 psi S¼ BPM @ 5000 psi 7-3/4 BPM @ 5500 psi 10 BPM @ 6000 psi Pull pkr. Laid down ret head. RIH. Set Pkr @ '9962'. Running Go Int'l tracer. Rill w/ Go Int'l inj tracer 0 10,000'. While pumping 1/3 BPM, log indicated wtr going into zone 3 10,052'. RD Go. Inject w/ filtered Inlet wtr 1 BPM ~ 4000 psi. POtt w/ pkr. PU ret head. blade trip. Ret BI'. Press bomb under BP showed no corem between Benches 2 & 3. Ran bit & scraper. Found sand fill @ 10,125'. CO to 10,200'. Circ to clean up. Well History - ~--34A, Redrill Page 7 1976 01-01 01-02 01-03 01-04 01-05 01-06 01-07 01-08 CO to 10,200'. Rev circ. Laid. down DP. RU DA. Ran junk basket gauge ring to I0,100'. POH. -PU pkr. blade up assy in mouse.hole. Started in hole. Line came out of rope socket. PU-fishing tools. PU 5" DP. RIH w/ OS.. Dressed w/ 3¼" grapple. RIH. Top of fish @ 10,137' pkr ~ 10 145' Engage fish POH Rec cable hd, ro.oe , ' · · · ~, socket, and clr locator. Preparing to fish Baker setting tool. RIH w/ OS. Rec Baker setting t°ol. Ordered WP [ mill. Could not- .. get tools to platform because of weather. ;"- blade 'up mill #1 & fishing tools. Milled on pkr @ 10,143' to 10,144.5'. Drld mill #1. POH. Blade up new mill shoe. RIH. Milling @ 10,144.5'. Milled over pkr. POH. Laid down tools. RIH w/ ret tool. POH w/ fish. RIH w/ bit & scraper. Finished Rill w/ bit & scraper to 10,208' Rev circ hole clean. POH. RIH w/ WL junk basket & gauge ringl POH w/ WL. Cut drlg line. PU Otis type "WR" pkr w/ tail assy. RIH on 5" DP to 10,073'. RIH w/ GR on DA WL. Couldn't record thru DP. POH w/ DA WL. Set pkr @ 10,073'DPM (10,065'WLM). POH w/ DP. RIH w/ junk basket & gauge ring to locate. RIH w/ Baker Model F pkr (9-5/8") & set @ 9973'WLM. POH w/ WL & RD DA. RIH w/ DC's & laid down.' RIH w/ DP & POH. Laying down. Laid down DP. Chg BOP rams. RU to run tbg. PU seal assy. Ran 347 jts 3!~" Buttress, N-80, 9 2# IPC tbg. Ran Gator Hawk press test on every j t. TUBING DETAIL Item Length From To ~ , , KB to Tbg Hgr Tbg Hgr X-over 8rd to SL 2 jts 9.2#, SL, N-80, 4'Pup Jts 345 jts, 9.2#, SL, N-80 X-over Sub Bkr to SL Locator & Bkr Seal assy in Bkr F-1 perm pkr w/ X@ Bkr to SL 1 jt, 9.2#, SL, N-80 Otis XA circ sleeve w/ 2 XO's Otis to SL 1 jt 9.2#, SL, N-80 Locator Sub w/o Locator Otis Seal Assy in Otis WB Perm Pkr Mule Shoe Baker Model F-1 Perm Pkr set @ 9973.50'WLbI. Otis Model WB Perm Pkr set 0 lO,060'WLM w/ following equip below' 7" Extension jt X-over 7" Butt. to 3:.~" EUE 8rd 3½" EUE 8rd Pup jr' Otis T Nipple Profile w/ X-over Bell Nipple 40.2~' -0- 40.20' .75' 40.20' 40.95' 1.50' 40.95' 42.45' 8.00' 42.45' 50.45' 9,918.57' 50.45' 9,969.02' 1.00' 9,969.02' 9,970.02' 22.02' 9,970.02' 9,992.04' 29,31' 9,992.04' 10,021.35' 4.72' 10,021.35' 10,026.07' 29.68' 10,026.07' 10,055.75' .75' 10,055.75' 10,056.50' 20.38' 10,056.50' 10,076.88' · 85' 10,076.88' 10,077.73' 21.17' 10,064.27' 10,085.44' .92' 10;085.44' 10,086.36' 3.61' 10,086.36' 10,089.97' 1.80' 10,089.97' 10,091.77' · 64' 10,091.77' 10,094.41' 01-09 01-10 01-15 01-14 01-16 01-18 01-19 .. Well History -'~34A, Redrill' ' ~" Page 8 Finished running & landed 3'-"..~ tbg, hooked up & tested sliding valve w/ 1000 psi. Installed BPV. Removed BO?E & installed Xmas tree. Tested to SOO0 psi--OK. Moved DP to Rig #77. Now RD & moving BOPt. Move drlg equip from Rig #76 to #77. Released rig @ 2400 hrs. Inj 1714 bbls water @ 4050 psi. Inj 2157 bbls water @ 4050 psi. Inj 3076 bbls water @ 4000 psi. Inj 2679 bbls water @ 3800 psi. Inj 2063 bbls water @ 4000 psi. Average rate (5 days) 2338 BPD @ 4000 psi. Well llistory - D-3~-A, Redrill Page 12-12 12-15 12-14 12-15 12-16 12-17 12-18 12-19 12-20 12-21 Rev out DP. Rec 16 bbls mud & wtr. POH. Lay down test tools. PU Baker pkr & set ~ 9975'. Injection test ~ BPM @ 3400 psi. Pulled pkr to 9000'. Test DP--had communication. POH. Found 'washed out pin. POH. Checking D?. Found 1 bx washed out & pkr rubbers rough. RIH w/ 120' 3½" stinger below Baker pkr. Set pkr @ 10,040', tail pipe to 10,160'. RU Dowell & tested lines to 3500 psi. Unseated pkr & spotted acid on perfs. 151 gals 12-6 MCA, 1600 gals S% HCL w/ additives & mutual solvent, 3000 gals 12-6 MCA w/ 400# ammonium chloride, 1600 gals 5% HCL w/ additives & mutual solvent, 100 gals 15% HCL. Displ w/ filtered Inlet wtr. Rates while acidizing: initial 1 BPM @ 3300 psi, 1½ to 1¼ BPM @ 3500 psi. Displ @ ½ to 2/3 BPM @ 3500 psi. Total displ @ 7 ~u\I, 642 bbls. Displ acid w/ filtered Inlet wtr @ .8 BPM @ 3500 psi. Total displ 1810 bbls. RIH w/ Go Int'l tracer @ 10,100' & traced while injecting filtered Inlet wtr. Entering fm @ 10,138' ~ 10,178' & some wtr going out & down to 10,220' POH. RD Go. Pump in 6½ bbls 5% HCL w/ 400# diverter. Spot w/ 165 gbls filtered Inlet wtr. Set pkr w/ 1500# on annulus. Rate 1-3/4 BPM @ 4200 psi. Inject 390 bbls filtered Inlet wtr. Laid down lubricator & released pkr. POH. RU DA--perf Bench 3, 3 HPF, 10,122' - 10,100' (22'). Finished displ acid & filtered Inlet wtr into Bench 4. RD DA & 7" lubricator, RIH w/ bit & csg scraper to 10,240'. POH. PU Baker RBP & retrievamatic pkr w/ press recorder below bridge plug. Attempted to test in blank between Benches 3 and 4 (10,123' - 10,137')--not able to get a test--blank was too short. Set RBP @ 10,126'. Set pkr @ 10,080' Fm broke down @ 0.3 BPM @ 3500 psi. Spotted 900 gals 5% HCL w/ addi- tives & mutual solvent, 1600 gals 12-6 MCA w/ 250# ammonium chloride, 500 gals 5% HCL w/ additives & mutual solvent, 2000 gals filtered Inlet wtr w/ 100 gals 15% HCL, followed w/ 50 bbls filtered Inlet wtr. Set pkr 1500 psi on annulus, 3500 psi on DP @ 3/4 BPM. 231 bbls displ as of 7 AM. Finished pumping 900 bbls filtered Inlet wtr @ 3/4 BPM @ 410-0 psi. Released pkr @ 10,080'. RIH to 10,126'. Released BP & RIH to 10,191'. Set BP & POH to 10,080'. Set pkr. Injected filtered Inlet wtr @ 3/4 BPM @ 4100 psi, 140 bbls. Released pkr & RIH to BP & retrieved. POH w/ tools. Retrieved BP & press recorder. WOO 5 hrs. RIH w/ pkr, set @ 10,085'. Injected filtered Inlet wtr @' 4000 psi @ 3/4 BPM, 4250 psi @ 1 BPM, 4500 Psi @ 1-1/16 BPM, and 4800 psi @ 1-1/16 BPM. RU Go. Ran tracer log--indicated wtr going out @ 10,176' & down tot10,224' POH w/ WL. Unseated pkr. RIH to 10,130'. Pkr would not se . POH ~'v/ pkr. POt{ w/ pkr, metal gauge on pkr rubbers & On body of pkr. RIH w/ csg scraper. POH. RU 7" lubricator & test. to 2500 psi. RIH w/ DA cso gun. Perf 4 holes, 10,209' - 10,210'. POH w/ DA. RU gauge ring junk basket. RIH to 10,215'. POH. Rec piece of pkr rubber. RIH w/ Baker Model K ret & set @ 10,200'. POH. RD DA. RU cmt stinger & Rill. RIH w/ stinger to 10,206'DPM. Set into ret & attempted to press up & break fm down. Press up to 5000 psi & could not pump into perfs 3 10,210'. Annulus press would bleed off slowly @ 2000 psi. POH & PU Baker pkr. RIH to 10,045'. Set pkr & press up to the following: BPM @ 4700 psi, 1~'~ BPM @ 4900 psi, l:a BPM ~ 4900 psi, 1¼ BPM 0 5000 psi, 2'~ BPM @ 5700 psi, w/ rate deer. RU WL lubricator & RIH w/ press recorder to 6000'. Pumping @ 5000 psi ~ 1 BPM. Will stabilize rate & run press fall off curve. Finished inj O 5200 psi for 4 hrs & started press fall off test. Compl press fall off & waited on Dowell turbine pump equip. RU Dowell & inj into well @ 5200 psi 1:-~ BP,Xl for 1 hr, 3 BFM @ 5600 psi, 4 BPM O 6000 psi, 5 BPM @ 6150 psi, 6 BPM O 6200 psi for 20 min w/ no break. Reduced press to 4000 psi. & checked rate @ ;~ BPM. Called out Go to run POX tracer @ higher press. IVIA ATHON OIL I::OMP. MY HISTORY Of OIL OR GAs W~LL FIELD McArthur River WELL NO._~Z-~ LEASE Trading Bay Unit PARISH Kenai STATE .Alaska- COUNTY Peninsula Borough KB *='kEv. 1 0 6. 2 ' 'TOP OF OIL STRING ~ ELE¥.~ MEASURE','E','S . FROM IToP OF ROTARY TABLE ELEV. TAKEN ! [gna. OR MAT ELEV. ~ BLOCK SEC. 6 TWP 8N r.. 13W' Surf Loc: Conductor #10 Leg A-1 {NE) 7S6.8'FSL & 1209.5' FWL h,s~o.Y P.EP^~EO BY K. A. Thoma T,T'E DrillinR En%ineer It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1975 10-09 10-10 .0-11 0-12 0-13 .0-14 '0-15 0-16 L0-Z7 [0-18 ;0-19 ~0-20 ~0-.21 -. ._ 10-22 WELL HISTORY - D-54A, REDRILL (Marathon AFE 4545) NOTE' Report is to 7 AM for previous 24 hours opera~!~n~:~ ~;/ ~:-C ::i':r','~.' ~/:<!: Re]eased rig #76 from well D-25 to D 34 @ 9 PM, 10-08-75. Rigging down to move rig. Have off-loaded 5~" DP ~ 3 pipe racks. Moving rig from Leg B-1 to A-1. Installed BPV. Removed Xmas tree. Installing BOPE. "Rig Engineer" out of Service. Wait on boat to off-load pipe racks & mud tanks. "Husky" arrived @ DV @ 3PM, 10-10-75 & off-loaded 3 pieces. (Winds 25 knots.) Began skidding rig from Leg B-1 to A-1. Rig skidded to Leg A-l, 10 AM, 10-11-75. Set 2 mud tanks. Tied down rig. NU riser. Winterizing rig. RUR. Finished rigging up @ 3 PM. Tested BOPE to 3000 psi. Pulled & laid down tb g. Flanged up & tested BOPE. pU bit & six 6¼" DCs. RIH. Circ to cond mud wt & risc. Circ & build mud wt. Made up 9-5/8" csg spear. RU Dia-log. Worked 9-5/8" csg to 350,000#. Pulled slips. Ran FPI. 9-5/8" csg free @ 2000'. Worked pipe. Re-ran FPI. Free point worked down to 2225'. Pulled free point. Set slips. Finished hooking up kelly. Laid down spear. Flanged up BOPE. Tested to 1500 psi. PU 9-5/8" csg cutter. RIH to 2220'. Attempted to cut csg. Broke knife. POH. Changed tools. RIH. Cut 9-5/8" @ 2214'. POH. Laid do~,~ cutter. Worked &circ 9-5/8" csg. Preparing to pull 9- 5/8" csg. Repairing rotary while circ w/ 700#. Press incr to 3700# & hyd 9-$/8" csg up 41'. Inspected derrick--all OK. Cleaned & magnaflux elevators. Kelly bails ail OK. Engaged 9-5/8" csg w/ spear. Pulled 55 its 9-5/8" 47# csg. .Overall. length 2161'. Laid do~,m 6'a" DC. PU 12¼" drlg assy. RIH to 2204'. Circ &cond mud. POH. PU 13-3/8" Servco section mill. Rill. Milled 2080' - 2090'. Milled 13-3/8" csg from 2090' - 2105' w/ mill. #1'. Circ. POH. ChaR_ge blades &RIII w/ mill #2. Milled from 2105' - 2113'. POll. Changed blades & Rill w/ mill #3. Mill. ed from 21113' - 2120'. History - D-34A, Redri~' Page 2 10-23 Milled 13-5/8" csg from 2120' - 2125' w/ mill #3. POH. Made CO run w/ diamond point bit. POH. RIH w/ mill #4 ~ milled to 2143'. POH. 10-24 Finished trip--changed knives. Milled from 2145' - 2155'. Trip to change out knives. Milled 2153' - 2138'. Laid down milling tools. The window in 13-5/8" is from 2080' - 2138'. Ran open end 5" DP to 2190'. Cond hole to set plug. 10-25 Circ & cond mud. Mixed 200 sx class G 14% sand, 16# slurry. POH. Placed 200# on plug for 6 hrs. Drld plug. Poor cmt. Drld out to hard cmt @ 2150'. Circ clean. POH. RIH w/ OEDP to 2150'. Cond hole for plug #2. 10-26 Set kick-off plug w/ 200 sx class G 10% sand, 17.5# slurry @ 2150'. WOC 6 hrs. Drld hard cmt 2010' - 2090'. POH. PU DD & BHA. RIH to - 2090'. Orient DD I0-27 Drld & surveyed from 2090' - 2175'. POH. Changed BHA. RIH. Reamed Dyna-drilled hole from 2090' - 2175'. Drld & surveyed from 2175' - 2744'. [0-28 Drld & surveyed 2744' - 3339'. Trip for new bit. Changed BHA. Drld surveyed from 3339' - 4060'. L0-29 Drld ~ surveyed from 4060' - 4172'. Trip for new bit. RIH. Drld & surveyed from 4172' - 4914'. £0-30 Drld & surveyed to 5130'. Made trip. Changed bit. RIH. Drld & surveyed from 5130' - 5381'. POH for bit chg. [0-31 Completed POH @ 5581' to chg bit. RIH. Drld & surveyed to 6032'. POH for bit chg. l!-0! Finished trip to ~g bit & ~u~ Cut drlg line Drld to 6216' surveyed Drld to 6263' POH to chg BHA. RIH · , - ~1-02 Drld to 6431'. Circ & surveyed. Drld to 6480'. POH to chg bit. RIH & drlg 12¼" hole. '1-03 Drld & circ.for survey @ 6620'. Drld to 6625'. POH & changed BHA. RIH. Reamed 67' to bottom. Drld 6756'. Surveyed. & drlg ahead. '1-04 'l-OS Drld to 7015'. Surveyed. POH to check BHA. Changed bit. RIH. Drld to 7340'. Circ. Survey & POH. Completed trip for new bit. RIH. Drld to 7720'. Rig failure @ 4 PM, 7 PM, & 8 PM. ]1-06 Drld from 7720' - 7736'. Circ 5 surveyed. POH for bit. RIH. Drld from 7736' - 7990'. 1-07 POH w/ bit #13. Ran bit #14. Drld from 7990' - 8527'. .1-08 Drld to 8338'. Surveyed & POH. RIH & drld to 8412'. POH for bit. Rill. Drlg. 1-09 Drld 12~" hole from 8415' - 8595~. POH. Changed bit & RR. RIH. Drld from 8595' - 8610'. 1-10 Drld from 8610' - 8869'. POH to chg bit. 1-11 1-12 Finished TIH. Drld to 8881'. Ran survey. Drld to 9133'. POH. Check BHA. Changed bit. RII-I w_/ bit #19. Drld to 9348'. Survey· POll to Chg bit. -. 1-13 Changed BHA. Rill. Drld to 9592'. Dropped survey· POH. 1-14 POll. Test BOP & llydril. RIH. Slipped drlg line. Drld to 9720'. Ran survey. POll. Well History- D-,~.k, Redrill Page 3 11-12 11-13 11-14 11-15 11-16 11-17 11-18 11-19 11-20 11-21 Drld to 9348'. Survey. POH t° chg bit. Chg BHA. RIH. Drld to 9592'. Dropped survey. POH. POH. Test BOP & Hydril. RIH. Slipped drlg line. Drld to 9720'. Ran survey. Made trip for bit #22. Measured in OK. Drlg 12¼" hole. Drld to 9933'. Ran survey. POH. Chg BHA. Cut drlg line. RIH. Drlg 12¼" hole. Drld to 10,074'. Circ. Ran survey. Trip for bit. Drlg 12¼" hole. Drld to 10,203'. Circ. Ran survey. POH. Chg bit. RIH. Drlg 12¼" hole. Drld 10,252' - 10,275'. RU Schlumberger. Logged w/ DIL, BHC Sonic, GR Cal, FDC from 10,250' - 2080'. Schlumberger finished logging well. RIH w/ new bit. Drld 10,275' - 10,295'. Circ clean. ?OH. Chg rams. RU to run 9-S/8" csg. Now running csg. (Drld 10,275' - 10,295'rD.) Ran 9-5/8" csg to 10,295'. Stage clr #1 @ 9296', stage clr #2 @ 5879'. Circ hole. Cmtd w/ 630 sx class G neat cmt, 1% D-31, .03 R-5. Bumped plug w/ 1500 psi. Held OK. Open stage clr @ 9296'. Circ hole. Cmt w/ 1000 sx class G 4% gel, 1% D-31, .03 R-5, 150 sx class G, 1% D-31, .03 R-5. Bumped plug w/ 2800 psi. Tool shifted. Released pressure on stage clr. Did not hold. Hold pressure for 2 hrs. 9-5/8" CASING DETAIL Item Leng?h Fro.m.~ To KB to Cutoff & slips 61 jts, OD, 40#, Butt, N-80 74 jts, OD, 47#, Butt, N-80 Baker Model J Stage Collar 56 jts, OD, 47#, Butt, N-80 23 its, OD, 47#, Butt, P-110 Baker Model JB Stage Collar 23 jts, OD, 47#, Butt, P-11~ Baker Model G Diff Fill Clr 1 jr, OD, 47#, Butt, P-110 Baker Model G Diff Fill Shoe 41.20' -0- 41.20' 2514.44' 41.20' 2555.64' 3321.96' 2555.64' 5877.60' 1.75' 5877.60' 5879.35' 2471.32' 5879.35' 8350.67' 944.04' 8350.67' 9294.71' 1.75' 9294.71' 9296.46' 952.56' 9296.46' 10,249.02' 1.90' 10,249.02' 10,250.92' 41.48' 10,250.92' 10,292.40' 2.60' 10,292.40' 10,295.00 11-25 11-24 11-25 11-26 11-27 WOC. Skidded Rig #76 to Well D--26 to repair ball valve. WOC. Repairing ball valve on well D-26. Rig released from D-26 @ 10 AM, 11-24-75. Moved rig on location 4 PM. Flanged up & tested BOP. Laid down 8" DC. PU 6¼" DC. RIH. Placing rubbers on DP. RIH to 5880'. Test csg to 3000 psi. Drld out stage clr. Tested to 3000 psi--held OK. RIH to 8960'. Drld cmt & stage clr ~ 9296'. Tested to 3000 psi--held OK. Drld hard cmt from 10,230' - 10,249'. POll. RU DA. RIH w/ csg bond log, GR, clr locator. DA tool failed. Finished running DA csg bOnd log' Poor bond over all sections. RU & ran Sperry-Sun gyro from 2000' - 10,200' in 100-ft intervals, RU DA csg gun to perf 4 holes from 10,138' - 10,139'. POlt. RU & running Baker model K cmt ret. Well History - D-~A, Redrill Page 4 11-28 11-29 11-30 12-01 12-02 12 -03 12-04 12-05' 12 -06 12-07 12-08 12 -09 12-10 !2-11 RIH w/ Baker bi@del K cmt ret. Set @ 10,047'. Breakdown press 3800 psi @ 1.75 BPbI. Annulus press incr 200 psi. POH. PU pkr. Checked stage clrs & csg to 4000.psi--keld OK. RIH. Sqz cmt perfs 10,138' - 10,139' w/ 150 sx class G cmt w/ 1% CFR-2, 0.5 Rr5, 15# slurry· Breakdown press 3800 psi, rain sqz press 3500 psi @ 2 BPM. Max sqz press 4500 psi. CIP @ 7'30 ~u%l. · CIP @ 7'30 AbI POH RU DA Perf w/ csg gun from 10,018' - 10 019' · * · ~ , 4 HPF. PU Baker Model K 9-5/8" cmt ret. RIH. Ret stopped @ 7779'. Started out of hole. Lost ret @ 7403'. POH. PU bit. RIH. Pushed ret to 10,142'. POH. RU DA. Ran junk basket ~ gauge ring· ' RIH w/ j.unk basket & gauge ring. Stopped @ 9998'. POH. RIH w/ bit scraper & junk basket to 10,040'. Circ clean. POH. RIH w/ gauge ring & junk basket. Ran Baker Model K ret to 9858'. Ran cmt tools. Press to 5000 psi. Would not take fluid. Surged perfs. Would not take fluid @ 5000 psi. POH. Finished POH. RU DA, perf 4 HPF 4030' - 4031' Ran gauge ring & Baker cmt ret. Set cmt ret @ 3918'. Circ mud out of annulus. Cond hole. Cmt w/ 850 sx class G 4% gel, 1% D-31, 0.3% R-5, 15.2# slurry. Followed w/ 200 sx class G 1% D-31, 0.3% R-5, 16.5# slurry. 80% returns. Job compl @ 10. PM. WOC. Stab into ret @ 3918'. Press to 3000 psi. No break down. POH w/ cmt tools. RIH w/ bit. Drl ret & cmt. POH. Ran Baker Retrievamatic pkr to 3934'. Tested to 4600 psi for 30 min--OK. POH. Laid down pkr. RIH to 9158'. Drlg on ret. Drld ret @ 9858'. RIH to 10,040'. Trip for new bit. Drld ret & cmt to 10,180'. RIH to 10,250'. Circ hole clean. Displ hole w/ filtered Inlet wtr. POH. Removed dr!g nipple. Flanged up lubricator. ~o+~o~ ~ 3000 psi.. RU DA. RIH w/ csg gun. Perf w/ csg gun 3 HPF 10,138' - 10,178'. POH. RD DA. Flanged up drlg nipple. Cut drlg line. RIH w/ bit & csg scraper. Finished running bit & scraper. POH. Ran Baker pkr to 10,047'. RU Dowell. Started injection test. Would not take fluid @ 3500 psi. Spot 300 gal 12.6 MCA over perfs. Re-set pkr. Held acid on perfs for 2 hrs w/ 3500 psi. Started taking fluid @ ½ BPM @ 3700 psi. Cont to pump acid. Released pkr. Flushed w/ 20 bbls wtr. Re-set pkr @ 10,010'. Inject @ 3500 psi 3/4 BPM. Injected 710 bbls filtered Inlet wtr @ 3/4 BPM @ 3500 psi. RU Go Int'l to run tracer survey. Finished RU Go Int'l. Tested lubricator. RIH w/ tracer while injecting @ 3500 psi. After running tracer, released pkr. Re-set below perfs to confirm no water going out bottom. Checked OK. POH. Preparing to sqz cmt. --- . PU Baker Model K cmt ret. Ran on WL to 9950'. Would not set. POH. Ran ret on DP. Set @ 9950'. Sqz cmt w/ 150 sx 15.7# slurry. Min press 3500 psi @ 3/4 BPbl, sqz press 4500 psi @ '-~ BPM. Locked up ~/ 9 bbls outside perfs. Rev out 5 bbls cmt. Job comp @ 1:15 PM. POH. WOC. POH. Laid dOwn Baker cmt tools. RIH w/ 8%" bit WOC to 3 PM. Drld out to bottom of cmt @ 10,185'. Circ out to 10,243'. POH. RU lubricator. RU DA. RU DA. Tested lubricator to 1500 psi. RIH w/ 20' csg gun, 3 HPF. Perf 10,158' - 10,178'. POll. RIH w/ gun #2, 20', 3 HPF. Perf'10,138' to 10,158'. RU & ran Howco DST tools to clean fro. Ran 1000' wtr cushion & 1000# gas cushion. Open-tool 10 min. No flow. Bled off gas cushion to 475--no flow. Shut-in 5 min. Open tool 1 hr. Fair blow. Final shut-in 5:45 AM. Preparing to rev out. Well History - D-S4A, Redrill 12-12 12-13 12-14 12-15 12-16 12-17 12-18 12-19 12-20 12-21 - Rev out DP. Rec 16 bbls mud & wtr. POH. Lay down test tools. PU Baker pkr fi set 3 9975'. Injection test k BPM @. 3400 psi. Pulled .pkr to 9000'. Test DP--had communication. POH Found washed out pin. POH. Checking DP. Found 1 bx washed out & pkr rubbers rough. RIH w/ !20' 3½" stinger below Baker pkr. Set pkr @ 10,040', tail pipe to 10,160'. RU Dowell & tested lines to 5500 psi. Unseated pkr & spotted acid on perfs. 151 gals 12-6 MCA, 1600 gals 5% HCL w/ additives & mutual solvent, 3000 gals 12-6 MCA w/ 400# ammonium chloride, 1600 gals 5% HCL w/ additives & mutual solvent, 100 gals 15% HCL. Displ' w/ filtered Inlet wtr. Rates while acid!zing: initial 1 BPM @ 3300 psi, 1½ to l~a BPM @ 3500 psi. Displ 0 ½ to 2/3 BPM 0 3500 psi. Total displ @ 7 /h\l, 642 bbls. Displ acid w/ filtered Inlet wtr @ .8 BPM 0 3500 psi. Total displ 1810 bbls. RIH w/ Go Int'l tracer @ 10,100' & traced while injecting filtered Inlet wtr. Entering fm @ 10,138' , 10,178' & some wtr going out & down to 10,220' POH. RD Go Pump in 6½ bbls 5% HCL w/ 400# diverter. Spot w/ 165 gbls filtered inlet wtr. Set pkr w/ 1500# on annulus. Rate 1-3/4 BPM @ 4200 psi. Inject 390 bbls filtered Inlet wtr. Laid down lubricator & released pkr. POH. RU DA-*perf Bench 3, 3 HPF, 10,122' - 10,100' (22'). Finished displ acid & filtered Inlet wtr into Bench 4. RD DA & 7" lubricator, RIH w/ bit & csg scraper to 10,240'. POH. PU Baker RBP & retrievamatic pkr w/ press recorder below bridge plug. Attempted to test in blank between Benches 3 and 4 (10,123' - 10,137')--not able to get a test--blank was too short. Set RBP @ 10,126'. Set pkr @ 10,080' Fm broke down @ 0.3 BPM @ 3500 psi. Spotted 900 gals 5% HCL w/ addi- tives & mutual solvent, 1600 gals 12-6 MCA w/ 250# ammonium chloride, SO0 gals 5% HCL w/ additives & mutual solvent, 2000 gals filtered Inlet wtr w/ 100 gals 15% HCL, followed w/ 50 bbls filtered Inlet wtr. Set pkr 1500 psi on annulus, 3500 psi on DP @ 3/4 BPM. 231 bbls displ aS of 7 AM. · Finished pumping 900 bbls filtered Inlet wtr @ 3/4 BPbI @ 410-0 psi. -. Released pkr @ 10,080'. RIH to 10,126'. Released BP & RIH to 10,191'. Set BP & POH to 10,080'. Set pkr. Injected filtered Inlet wtr @ 3/4 BPM @ 4100 psi, 140 bbls. Released pkr & RIH to BP & retrieved. POH w/ tools. Retrieved BP & press recorder. .WOO 5 hrs. RIH w/ pkr, set @ 10',085'. Injected filtered Inlet wtr 0: 4000 psi @ 3/4 BPM, 4250 psi @ 1 BPM, 4500 psi @ 1-1/16 BPM, and 4800 psi @ 1-1/16 BPM. RU Go. Ran tracer log--indicated wtr going out @ 10,176' & down to 10,224-' POH w/ WL. Unseated pkr. RIH to 10,130'. Pkr would not set. POH (~/ pkr. POH w/ pkr, metal gauge on pkr rubbers & on body of pkr. RIH w/ csg scraper. POH. RU 7" lubricator & test. to 2500 psi. RIH w/ DA csg gun. Perf 4 holes, 10,209' - 10,210'. 'POH w/ DA. RU gauge ring & junk basket. RIH to 10,215'. POH. Rec piece of pkr rubber. RIH w/ Baker Model K ret & set @ 10,200'. POH. RD DA. RU cmt stinger &RiH. RIH w/ stinger to 10,206'DPbI. Set into ret & attempted to press up & break fm down. Press up to 5000 psi & could not pump into perfs .3 10,210'. Annulus press would .bleed off slowly @ 2000 psi. POH & PU Baker pkr. RIH to 10,045'. Set pkr & press up to the following: BPM @ 4'700 psi, 1'~ BPM @ 4900 psi, 1:~ BPM ~ 4900 psi, 1¼ BPM ~ 5000 psi, 2~ BPM @ 5700 psi, w/ rate.decr. RU WL lubricator & RIH w/ press recorder to 6000'. Pumping @ 5000 psi 3 1 BPM. Will stabilize rate & run press fall off curve. Finished !nj 0 5200 psi for 4 hrs& started press fall off test. Compl press fall off & waited on Dowell turbine pump. equ'ip. RU DoWell & inj into well 0 5200 psi lt~ Bt'.Xl for I hr, 3 BFM.O 5600 psi, 4 BPM @ 6000 psi, 5 BPM @ 6150 psi, 6 BPM q 6200 psi for 20 rain w/ no break. Reduced- press to 4000 psi & checked rate 0 !~ BPbl. Called out Go to run RA tracer @ highe,' press. ' Well llistorM- D-34A, Redrill Page 6 12-22 12-23 12-24 12-25 12-26 1~.- 27 12-28 12-29 12-30 12 -31 Waited on Go Int'l, RU lubricator & tested to 6000 psi. RIH w/ tracer ~ GR. Ran base log. Injected 6 BP~.I @ 5900 psi for 12 min, 73 bbls injected. Shut down pumps, shot tracer @ 10,135', RIH to 10,190'. Pumped 6 BPbl @ 5900 psi. Tracer passed GR in 3 min. Set for 30 min ~ remained hot. Ran log up 10,200' to 10 040' Hot spots (10,164' - 10,190'). Pulled tracer tools to 10,100'. Stgpped pumping. Shot tracer off @ 10,100', RIH to 10,200', waited for tracer to come by. No RA material showed up. Logged up. Hot @ 10,164' - 10,190' w/ some RA material @ 10,138'. No RA material into Bench #3 @ 10,100' - 10,122'. POH & RD Go Int'l. RU for frac job. Moving Dowell frac equip on location to frac Benches 3 & 4. Off-load Dowell equip. Mixed 4000 gal gel water. Mixed gelled water Dowell YF 60 FC frac fluid, 2% HCL, 60#/1000 gal J-SO, 20#/1000 gal J-liS, 5#/1000 gal J-218 (40,000 gal total fluid). Press annulus to 5000 psi. Tested lines to 8000 psi. Pumped' 134 bbls 5617 gals fluid loss pad 189 bbls 7919 gals w/ 0.64 #/gal 20/40 sand 5,074# 136 bbls 5702 gals w/ 1.28 #/gal 20/40 sand 7,305# 203 bbls 8530 gals w/ 2.65 #/gal 20/40 sand 21,856# 217 bbls 9119 gals w/ 3.84 #/gal 20/40 sand 35,048# 24 bbls 1018 gals w/ 5.13 #/gal 20/40 sand 5,217# 74,500# Max press 6000 psi Displ w/ 189 bbls (7938 gals)w/ filt Inlet wtr. @ 14 BPM. Min press 5650 psi @ 15½ BPM. Instant shutin 5000 psi, 1 hr 2700 psi. Connected up to inject @ 4000 psi--flow rate too low to measure. POH w/ pkr. PU bit & RIH. Tagged sand @ 10,130'. CO to 10,200' w/ rev circ. PU 9-S/8" Baker pkr & RIH to 10,045'. set pkr. Press annulus to ' "~ ~-~ 4000 ps 2500 psi. Connected up wtr inject'~on sys+~ Press ~v -~ Injection rate too low to register on 3" turbine meter--less than 1S00 BWPD. Injecting filtered Inlet wtr. RU Go Int'l to run GR. Ran GR from 10,200' - 10,045'. Indications are that sand went in @ 10,166'. RD Go. RU BJ. Pumped 140 bbls injection wtr @ 4000 psi @ 1.4 BPM. Hook up wtr injection system & test Bench 4. Injected filtered Inlet wtr w/ injection system @ 1.4 BPM. Spotted 31 sx 20/40 sand. Tag sand @ 10,127'. Set pkr @ 10,045'. Pkr leaked. POH & RIH w/ new pkr to 10,045'. Press up Bench 3 to 5000 psi--would not take fluid. RD BJ. RU Dowell. Tested lines to 7500 psi. Injection rate 7500 psi @ 15 BPM. Injection rate 4000 psi @ .9 BPM. RU Go Int'l. Perfd from 10,027' - 10,042' w/ 3 HPF. Pulled pkr. RIH w/ csg scraper & bit. RIH w/ 9-S/8" csg scraper to 10,210'. POH. PU press bomb on Baker RBP & Baker EA pkr. RIH. Set BP @ 10,090'. Pkr @ 10,080'. Tested BP--held OK. Set pkr @ 9962'. Dowell injected 450 bbls filtered Inlet wtr. Rate: 3/4 BPM @ 4000 psi 2½ BPM @ 4550 psi S¼ BPM @ 5000 psi 7-3/4 BPM @ 5500 psi 10 BPM @ 6000 psi Pull pkr. Laid down ret head. RIH. Set pkr @ 9962'. Running Go Int'l tracer. Rill w/ Go Int'l inj tracer @ 10,000'. While pumping 1/3 BPM, log indicated wtr going into zone 9 10,052'. RD Go. Inject w/ filtered Inlet wtr 1 BPM .'2- 4000 psi. POt-I w/ pkr. PU ret head. blade trip. Ret BP. Press bomb under BP showed no corem between Benches 2 & 3. Ran bit & scraper. Found sand fill @ 10,125'. CO to 10,200'. Circ to clean up. Well History- D-54A, Redrill Page 7 1976 · 01-01 01-02 01-03 01-04 01-05 01-06 01-07 01-08 CO to 10,200'. Rev circ. Laid down DP. RU DA. Ran junk basket & gauge ring to !0,100'. POH PU pkr. blade up assy in mouse hole. Started in ko!e. Line came out of rope socket. PU fishing tools. PUS" DP. RIH w/ OS. Dressed w/ 3¼" grapple. RIH. Top of fish @ 10,137', pkr .~'~ 10,145'. Engage fish. POH. Rec cable hd, ro,~e socket, and clr locator. Preparing to fish Baker setting tool. RIH w/ OS. Rec Baker setting tool. Ordered WP & mill. Could not get tools to platform because of weather. blade up mill #1 & fishing tools. Milled on pkr @ 10,143' to 10,144.5'. Drld mill #1. POH. Made up new mill shoe. RIH. Milling @ 10,144.5'. Milled over pkr. POH. Laid down tools. RIH w/ ret tool. POH w/ fish. RIH w/ bit & scraper. Finished RIH w/ bit & scraper to 10,208'. Rev circ hole clean. POH. RIH w/ WL junk basket & gauge ring. POH w/ WL. Cut drlg line. PU Otis type "WR" pkr w/ tail assy. RIH on 5" DP to 10,073'. RIH w/ GR on DA WL. Couldn't record thru DP. POH w/ DA WL. Set pkr @ 10,073'DPM {10,065'WLM). POH w/ DP. RIH w/ junk basket & gauge ring to locate. RIH w/ Baker Model F pkr (9-5/8") & set @ 9973'WLM. POH w/ WL & RD DA. RIH w/ DC's & laid down. RIH w/ DP & POH. Laying down. Laid down DP. Chg BOP rams. RU to run tbg. PU seal assy. Ran 347 jts 3'-"-~ Buttress, N-80, 9.2# IPC tbg. Ran Gator Hawk press test on every j t. 3½" TUBING DETAIL Item Length From To KB to Tbg Hgr Tbg Hgr X-over 8rd to SL 2 jts 9.2#, SL, N-80, 4'Pup Jts 345 jts, 9.2#, SL, N-80 X-over Sub Bkr to SL Locator & Bkr Seal assy in Bkr F-1 perm pkr w/ X@ Bkr to SL 1 jt, 9.2#, SL, N-80 Otis XA circ sleeve w/ 2 XO's Otis to SL 1 jt 9.2#, SL, N-80 Locator Sub w/o Locator Otis Seal Assy in Otis WB Perm Pkr Mule Shoe Baker Model F-1 Perm Pkr set @ 9973.50'WLM. Otis Model h'B Perm Pkr set @ 10,060'WLM w/ following equip below' 7" Extension jt X-over 7" Butt.. to 3'~" EUE 8rd 3'~" EUE 8rd Pup j t Otis T Nipple Profilc w/ X-over Bell Nipple 40.20' -0- 40.20' .75' 40.20' 40.95' 1.50' 40.95' 42.45' 8.00' 42.45' 50.45' 9,918.57' 50.45' 9,969.02' 1.00' 9,969.02' 9,970.02' 22.02' 9,970.02' 9,992.04' 29.31' 9,992.04' 10,021.35' 4.72' 10,021.35' 10,026.07' 29.68' 10,026.07' 10,055.75' .75' 10,055.75' 10,056.50' 20.38' 10,056.50' 10,076.88' · 85' 10,076.88' 10,077.73' 21.17' 10,064.27' 10,085.44' ~92' 10,085.44' 10,086.36' 3.61' 10,086.36' 10,089.97' 1.80' 10,089.97' 10,091.77' .6,1' 10,091.77' 10,09'l.41' Well History - D-34A, Redrill Pa ge 8 01-09 01-10 Finished running & landed 3;.~" tbg, hooked up & tested sliding valve w/ 1000 psi. Installed BPV. Removed BOPE & installed Xmas tree. Tested to S000 psi--OK. Moved DP to Rig #77. No~ RD & moving BOPE. Move drlg equip from Rig #76 to #77. Released rig @ 2400 hrs. 01-13 .01-16 01-18 01-19 Inj 1714 bbls water @ 4050 psi. Inj 2157 bbls water @ 4050 psi. Inj 3076 bbls water @ 4000 psi. Inj 2679 bbls water 0 3800 psi. Inj 2063 bbls ~,'ater @ 4000 psi. Average rate ($ days) 2338 BPD @ 4000 psi. DATE 05-03-79 MARATHON OIL COMPANY HISTORY OF OIL OR GAS WELL FIELD McArthur River D-34A WELL NO. Deepen LEASE Trading Bay PARISH Kenai Penin- Alaska STATE COUNTY sul~ Borough __ ELEV. __ ToP OF OIL STRING ELEV__ MEASUREMENTS~TOP OF ROTARY TABLE ELEV. TAKEN FROM f -- -- / [GRD. OR MAT. ELEV. BLOCK SEC. 5 TWP 8N R.. 13.W HISTORY PREPARED bY L. G. Haywood TITLE Secretary It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1979 03-27 03-28 03-29 03-30 03-31 04-01 04 -02 04-03 04-04 04-05 04-06 04-07 04-08 10,295 ' TD 10,200' PBTD 10,295'TD 10,200 ' PBTD 10,295 ' TD 10,200 ' PBTD 10,295'TD 10,200' PBTD 10,295'TD 10,200' PBTD 10,295 ' TD 10,200 ' PBTD 10,295' TD 10,200 ' PBTD 10,295 ' TD 10,200' PBTD 10,295 ' TD 10,200' PBTD 10,295'TD 10,200 ' PBTD 10,295 ' TD 10,200 ' PBTD 10,310' TD 10,389 ' TD TBU WELL D-34A DEEPEN AFE 4639 Rec'd rig @ 1400 hrs, 03-26-79. Removed & loaded pipe racks onto "Rig Engineer." Cleaned & loaded mud tanks onto "Rig Engineer." Skidded rig from'B-1 well room to A-1 well room. RU service lines to rig. ~ RU. RU. Cont to RU while prep to acidize Well D-ii. Cont to RU while prep to acidize Well D-Ii. Fin acid job on Well D-il. RU WL & opened circ slv@ 10,021' in · Well D-34A. Set BPV, ND tree, & NU BOPE. Fin NU BOPE. PU tbg string to position circ sly above top pkr @ 9973". C&C mud, bldg volume. C&C mud to 9 6 ppg around POH & LD 3~'' tbg, · · 2 seal assy, & XA slv. RIH w/ burnover shoe #1, PU 5" DP. Milling over Baker F-1 pkr @ 9984' DPM. Cont to mill over Baker F-1 pkr @ 9984'DPM. POH. Rec pkr. Tstd BOPE. RIH w/ burnover shoe #2 & milled over Otis WB pkr @ 10,074'DPM. POH. Indications are that the WB pkr has been milled over & "picked." POH. Rec Otis WB pkr, pkr bore ext, & Otis T nipple. LD fishing tools. RIH w/ bit. Tagged hard fill @ 10,180'. Drld fill to rtnr @ 10,222'DPM. Drld on rtnr 3 hrs. POH. RIH w/ bit to fin drlg rtnr. Drld rtnr @ 10,200', flt clr @ 10,249', & flt shoe @ 10,295'. Drld new hole to 10,310'. POH. RIH w/ locked drlg assy. Tagged csg p-~rfs @ 10,100'. Reamed'from 10,100' - 10,147' POH. Removed locked drlg assy~ (LD roller reamer). RIH w/ bit & 1 stab 120' above bit. Reamed csg perfs from 10,100' - 10,174'· POH. RIH w/ locked drlg assy. Reamed csg from 10,100' - i0,174'.. Cont in hole to 10,310'. Performed 14#/gal mud equiv leak off test. Drld from 10 310' - 10 389' , , . t i Well History - TBU Well D-34A (Deepen) Page 2 04-09 04-10 04-11 04-12 04-13 04-14 10,539'TD 10,841'TD ll,093'TD ll,178'TD 11,285'TD 11,285 ' TD Drld from 10,389' - 10,486'. POH to chg BHA. RIH & drld to 10,539'. Drld from 10,486' - 10,841'. POH for new bit. RIH to 10,000'. Replaced low drum chain. RIH to 10,841'. Drld to 11,093'. Drld from 11,093' - 11,178'. Made wiper trip to 9-5/8" shoe @ 10,295'. C&C hole for logs. POH. RU Schl & started logging. Fin logging. RD Schl. RIH w/ 8½" bit. Drld from 11,178' - 11,285'. POH. RU Schl. RIH w/ RFIT & meas BHP in Benches 1, 2, 3, 4, 5, & 6 of Hemlock Zn. RD Schl. RIH to cond hole for 7" lnr. Recorded BblP as follows: Bench Depth Bt{P 1 ..... 10,560' 3278 psi 10,569' 3277 " 2 ..... 10,619' 3745 psi 10,667' 3765 " 3 ..... 10,701' 3626 psi 10,749' 3560 " 10,751' 3536 " Bench Dep.th. BHP 4 ..... 10,801' 3378 psi 10,865' 3349 " 5 ..... 10,984' 3454 psi 11-,021' 3458 " 6 ..... 11,119' 3820 psi RIH to 11,285'TD. C&C hole for 7" lnr. POH. RU & ran 33 jts 7", 29#, N-80, Butt lnr. MU BOT lnr hgr. RIH w/ 7" lnr on 5" DP. Set lnr w/ tie-back slv@ 9859', top of hgr @ 9864', landing clr@ 11,185', & shoe'@ 11,275'. Halliburton cmtd w/ 300 sx C1 G w/ 1% CFR-2, .3% Halad 22-A, .3%-KC1, & 1/4#/sec Flocel preceeded by 12 bbls mud flush. Bumped plug w/ 2500 psi--held OK. POH 15 stds & circ to clean 5" DP. 7" LINER DETAIL Item Length From To KB to top of lnr 9858.60' BOT tievback slv 5.74' BOT hyd hgr 9.84' Stabilizer & XO 2.12' Plug holder bushing .75' 31 jts 29#, Butt, N-80 lnr 1307.96' Landing clr 1.00' 1 jt 39#, Butt, N-80 lnr 42.81' Catcher sub .97' 1 jt 29#, Butt, N-80 lnr 43.35' Float shoe 1.86' 0' 9,858.60' 9,858.60' 9,864.34' 9,864.34' 9,874.18' 9,874.18' 9,876.30' 9,876.30' 9,877.05' 9,877.05' 11,185.01' 11,185.01' 11,186.01' 11,186.01' 11,228.82' 11,228.82' 11,229.79' 11,229.79' 11,273.14' 11,273.14' 11,275.00' 04-15 04-16 04-17 04-18 04-19 11',285'TD 11,285'TD ll,185'PBTD 11,285'TD ll,185'PBTD 11,285'TD ll,185'PBTD 11,285'TD ll,185'PBTD Circ @ 8460' to clean DP. POH. LD BOT lnr setting tools. LD ~DP from derrick. RIH W/ 8~" bit. Broke circ @ 8900', 9500', & 9742'. Tagged cmt @ 9812'. Started drlg cmt. Drld hard cmt from 9812' - top of lnr @ 9859'. Tstd 9-5/8'' csg to 2000 psi--OK. POH. RIH w/ 6" bit. Drld hard cmt from 9859' - 9864'. CO cmt stringers to 9900'. RIH to 11,Q29' & tagged cmt. Drld cmt from 11,029' - landing clr @ 11,185'. Tstd 9-5/8" csg & 7" lnr to 2000 psi--OK. POH. Fin POH. RU DA. Ran CBL/GR log from 11,165' - 9800' and 4000' - 100'. Ran Scientific gyro surv from 11,180' - 9500'. Started MU DST tools for dry test of lnr lap. RIH w/ Johnston DST tools for dry test of lnr lap. Set pkr @ 9790'. Tool open 1 hr, SI 2 hrs. Lnr lap tstd dry. POH. BHP charts confirmed dry test. RIH w/ bit & scraper to 11,185'. Displ mud in hole w/ FIW. POH LD DP. Fin LD DP. RU DA & set Otis WD pkrs @ 10,930' & 10,419'DIL. RD DA. RU to run 4½" tbg & started running same. Well History - TBU Well D-34A (Deepen) Page 3 04-20 04-21 11,285'TD 11,185' PBTD 11,285 ' TD 11,185'PBTD Cont RIH w/ 4½" prod tbg. Attempted & failed to sting into Otis WD pkr @ 10,419'. RU DA for depth measurement. RIH w/ DA CCL to determine location of seal assy w/ respect to perm pkr. Found 1 jt of tail pipe thru pkr. POH. Stood tbg in derrick. Chgd over-sized tbg coupling below seal assy. RIH w/ 4½" prod tbg, Gator-Hawking to 5000 psi. Spaced out & landing tbg. 4½" TUBING DETAIL Item Length From KB to tbg hgr 41.20' CIW 4~" EUE top x 4½" Butt btm tbg hgr 4½" Butt X ASL XO 1 j t 4½" ASL pup 8 jts 12.6#, N-80 tbg 1 jt 4~" ASL pup 4~" ASL x EUE XO Otis Retrievable "DC" Ball Valve (3. 813"ID) 4½" EUE x ASL XO 1 j t 4½" ASL pup 61 jts 12.6#, N-80 tbg 1 4½" ASL x Butt XO Otis RL mandrel (3.99"ID) w/ Macco CM2-RC Valve #1 4½" Butt x ASL XO 34 its 12.6#, N-80 tbg 4~" ASL x Butt XO GLV #2, as #1 above 4½" Butt x ASL XO 30 jts 12.6#, N-80 tbg 4½" ASL x Butt XO GLV #3, as #1 above 4~" Butt x ASL XO 28 jts 12.6#, N-80 tbg 4½" ASL x Butt XO GLV #4, as #1 above 4~" Butt x ASL XO 24 jts 12.6#, N-80 tbg 4~" ASL x Butt XO GLV #5, as #1 above 4½" Butt x ASL XO 21 its 12.6#, N-80 tbg 4½" ASL x Butt XO GLV #6, as #1 above 4½" Butt x ASL XO 22 its 12.6#, N-80 4½" ASL x Butt XO GLV #7, as #1 above 4½" Butt x ASL XO 19 jts 12.6#, N-80 tbg 4½" ASL x Butt XO GLV #8, as #1 above 4~-~'' Butt x ASL XO 14 jts 12.6#, N-80 tbg 4½" ASL x Butt XO GLV #9, as #1 above 4½" Butt x ASL XO 13 jts 12.6#, N-80 tbg 4½" ASL x Butt XO GLV #10, as #1 above To 0' 41.20' 1.00' 41.20' 42.20' 3.45' 42.20' 45.65' 8.10' 45.65' 53.75' 263.6~' 53.75' 317.39' 3.97' 317.39' 321.36' .80' 321.36' 322.16' 7.90' 322.16' 330.06' .70' 330.06' 330.76' 4.10' 330.76' 334.86' 1964.23' 334.86' 2,299.09' 4.25' 2,299.09' 2,303.34' .9.15' 4.05' 1098.47' 4.25'o 9.15'' 4.05' 964.76' 4.25' 9.15' 4.05' 909.34' 4.20' 9.15' 4.00' 762.84' ~4.20' 9.15' 4.05' 677.64' 4.25' 9.15' 3.45' 706.50' 4.20' 9.15' 4.05' 618.12' -4.25' 9.15' 4.'05 ' 442.31' 4.20' 9.15' 3.45' 417.87' 4.20' 9.15' '2,303.34' 2,312.49' 2,312.49' 2,316.54' 2,316.54' 3,415.01' 3,415.01' 3,419.26' 3,419.26' 3,428.41' 3,428.41' 3,432.46' 3,432.46' 4,397.22' 4,397.22' 4,401.47' 4,401.47' 4,410.62' 4,410.62' 4,414.67' 4,414.67' 5,324.01' 5,324.01' 5,328.21' 5,328.21' 5,337.36' 5,337.36' 5,341.36' 5,341.36' 6,104.20' 6,104.20' 6, I08.40' 6'108.40' 6,117.55' 6,117.55' 6,121.60' 6,121.60' 6,799.24' 6,799.24' 6,803.49' 6,803.49' 6,812.64' 6,812.64' 6,816.09' 6,816.09' 7~522.59' 7,522.59' 7,526.79' 7,526.79' 7,535.94' 7,535.94' 7,539.99' 7,539.99' 8,158.11' 8,158.11' 8~162.36' 8,162.36' 8,171.51' 8,171.51' 8,175.56' 8,175.56' 8,617.87' 8,617.87' 8,622.07' 8,622.07' 8,631.22' 8,631.22' 8,634.67' 8,634.67' 9,052.54' 9,052.54' 9,056.74' 9,056.74' 9,065.89' Well History - TBU Well D-34A (Deepen) Page 4 04-22 04-23 04-24 04-25 04-26 04-27 04-28 04-29 11,285'TD ll,185'PBTD 11,285'TD ll,185'PBTD 11,285'TD ll,185'PBTD 11,285'TD ll,185'PBTD 11,285'TD ll,185'PBTD 11,285'TD ll,185'PBTD 11,285'TD ll,185'PBTD 11,285'TD ll,185'PBTD 4~" Butt x ASL XO 11 jts 12.6#, N-80 tbg 4~" ASL x Butt XO GLV #11, as #1 above 4½" Butt x ASL XO 10 jts 12.6#, N-80 tbg 4!~" ASL x Butt XO GLV #12, as #1 above 4½" Butt x ASL XO 1 jt 12.6#, N-80 tbg 4½" ASL x 3%" ASL XO 9 its 3~" 9.3#, N-80 tbg 3~' ASL x Butt XO Otis RW Mandrel (2.99"ID) w/ Macco CM1-BK-PB Valve #13 3%" Butt x ASL XO 8 jts 3~", 9.3#, N-80 tbg 3~" ASL x Butt XO Mandrel and Orifice Valve #14 3!~'' Butt x ASL XO 1 jt 3~", 9.3#, N-80 tbg 3~" ASL x Butt XO Otis "XA" sleeve (2.75"ID) 3~" Butt x ASL XO 1 jt 3%", 9.3#, N-80 tbg~ 3%" ASL x EUE XO Otis Locator (3" ID) Otis seals (4"OD, 3"ID) 3~" 10RD x ASL XO 1 3~" ASL pup Otis "X" nipple (2.75"ID) 1 j t 3~" 9.3#, N-80 tbg Mule shoe guide 4.00' 359.71' 4.25' 9.15' 4.05' 320.81' 4.20' 9.15' 4.05' 32.96' .80' 273.28' 2.02' 7.05' 2.00' 245.01' 4.17' 6.95' 4.10' 30.54' 4.10' 4.00' 4.20' 30.37' .78' 1.20' 20.20' :66' 11.50' 1.10' 30.11' .76' 9,065.89' 9,069.89' 9,069.89' 9,429.60' 9,429.60' 9,433.85' 9,433.85' 9,443.00' 9,443.00' 9,447.05' 9,447.05' 9,767.86' 9,767.86' 9,772.06' 9,772.06' 9,781.21' 9,781.21' 9,785.26' 9~785.26' 9,818.22' 9,818.22' 9,819.02' 9,819.02' 10,092.30' 10,092.30' 10,094.32' 10,094.32' 10,101.37' 10,101'37' 10,103.37' 10,103.37' 10,348.38' 10,348.38' 10,352.55' 10,352.55' 10,359.50' 10,359.50' 10,363.60' 10,363.60' 10,394.14' 10,394.14' 10,398.24' 10,398.24' 10,402.24' 10,402.24' 10,406.44' 10,406.44' 10,436.81' 10,436.81' 10,437.59' 10,437.59' 10,438.79' 10,438.79' 10,458.99' 10,458.99' 10,459.65' 10,459.65' 10,471.15' 10,471.15' 10,472.25' 10,472.25' 10,502.36' 10,502.36' 10,503.12' Landed 4%" prod tbg. ND BOPE. NU Xmas tree & tstd to 5000#. Prod crew installing manifold & flowline for D-34A. Cont to install new manifold in A-1 well room. Also fabricating flow line. Performed maintenance on rig eqpmt. Cont to install prod manifold and flow line. Maintained rig eqpmt & moved some rig eqpmt to rig 77 for redrill of D-3. Fin installing flow line & GL line. Unloaded FIW from well. RU DA. Perfd Bench 4, Hemlock, w/ 2-1/8" jet from 10,890' - lO,920'DIL (4 HPF). DA perfd Bench 4 of Hemlock Zn from 10,890' - lO,834'DIL w/ 2-1/8" jet (4 HPF). Placed well thru test sep. Well prod @ rate of 2368 BFPD @ 0.6% WC (2354 BOPD). Cont flowing lower Bench 4 (Hemlock) perfs @ 2638 BFPD @ 0.6% WC. RU DA. Perfd upper Bench 4 from 10,788' - 10,820'DIL w/ 2-1/8" jet (4 HPF). Flowed well @ 3048 BFPD @ 6% WC (2865 BOPD). RU Camco for PBU surv using HP gauge. RIH w/ gauge. Now stabilizing well. Compl running PBU surv & POH. RU DA & tstd lub to 2500#. Perfd Bench 1, Hemlock Zn, from 10,584' - 10,564' and 10,564' - 10,550'. RD'DA. Flowing well for clean-up. 24-hour flow test: 3074 BFPD w/ 4.2% WC (2945 BOPD, 129 BWPD) Sep Lift Fm Gas GOR GLR 2633 1905 728 237 622 Released rig from D-34A @ 0700 hrs, 04-29-79. FINAL REPORT T-t:EM?&. / 64k-S47N4. ' DETAIL 7" WELL NO.: DATE: z-//l,-l'/7~i _ BY' ..T~-/V q-/~ C. 0 tem Description ' Set Jts Size Wt Thread Grade Range Condition Length From To .. , , ._ ~-o41r ~N~,~ /. ~g IID72.1 ff [/~7~. O0 . .., ~ .._ _ Remarks: · TUBI,NG/CASING DETAIL · . WELL NO.: DATE: BY: Item Description Set Jts Size Wt Thread Grade Range, Condition Length From To .qf;. ,~A,,~ ,. e,/o.¥~':,¢[ ] £~. 7.( "/~g A-SL ,,4: ~VF_. X,o . ~o 3;,21.3g.3~;2. ....... (~T[s/vA,,,4¢. ,,~aT.,C.,/ B,4.:c/,/A.~,: $.8I~Y.D 7. qO 3,,12./B 5! .'-/~ /2. g ,4& /v~o/ ... ,2 ./.%¢;3 ~3¥.e~ -~'~. .... 0~ qL/~!''='~ , ¥ ~: By r~ X >~ Xo ~-lo,/ ~/~. V? ~-81~. ~¥ ,,, .3 Remarks: TUBI, NG/CASI_NG DETAIL WELL NO.: DATE' ~'///;//7'9 -' BY' Itam Description Set _Jts Size Wt Thread Grade Range Condition L_eng t h Fro_m_ To _ .. . ............. .... ~_ _ gYz ~o~~ ~sz ;cO .... ~/os~ dn~d~ d/~/.~ ...... _ ....... ..... --_ _ ~/7Z 4SL ;~ ~or~ Xo ~o 7g~,g9 7~g. 71 =/ qX &Trix ~Z XO gS6/ glT/.dl I - . . Remarks: TUBI, NG/CASING DETAIL · . WELL NO.- L)---gS",,,q-D DATE- BY: Item Descri tion Set Jts Size Wt Thread Grade Range. Condition Length From To ...... . ,. , ,, / .... ~/7a /~:,~ ~L ~o _/ A. 32. 9~ ~75f.~ .... .. ~ 3~ 9.3 ~s~ ~eo ! 4 - ~ v~/ lo/~. 7 Remarks: TUBI.!,~G/CASING DETAIL · . . WELL NO ' DATE-'.-//~z//77 BY: Item Descri tion Set Jts Size Wt Thread Grade Range, Condition Length From To . , . .................. .~_ OT~_S~,3 ~"0~ 2"~ .. ~O. ao /o~. 77 / 3 F~ ?.3 ASL N~o I ~ ~.. //~vT~ ~ /o~o~.~ .. .... __ ~ ~ ~ , , _ _. FOR M ~, r? ~ .rap ..'-,r,': (;TT SURVEY DEPTH: FROM 2000 FT, TO LEAgE: ~.~ adS..nF .~a~/ Unit. COUN'P¢tPARISH }(cnaS_ Per,,irs~]ia qorouF_-h DATE OF SURVEY. '~- .... :" JOB NO. OFFICF' /~u,"hor'a;' ' /~: 27h · ~, ,.~, : ,'..~ s ka -(}6?(; STATE ...... 'SPERRY-SUN WELL SURVEYING COMPANY ...................... -- PAGE MARATHON OIL ¢OMPA~IY ANCHORAGE~ ALASKA ................................................................................................................................................... DATE OF SURVEY NOVEMBER 26~ 1975 TRAOING BAY lJ2,!IT NO. D-3~A CO~PUTATION OATE SURWEL GYROSCOPIC MULTiSHOT SURVEY MCARTHUR RIVER ............. .:~ ................................................................ NOVEF!BER 28, ~975 ..................................... ~OB NUMBER 'SU3-1G'O3G ALASKA .................. KELLY BUSHING ~LEV. = 106.EO ~T. .................... ~ ................... . ..................... , TRUE SUB-SEA COURSE COURSE DOG-LEG T~TAL MEASURED V~RTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL .... I DEPTH - DEPTH ......... DEPTH .............. BEG ........ MIN ......... = .... DE~REES"'~?'-""DE~/IO0 ..... NORTH/SOUTH ........ "-'=-'E~'$T/WEST ................. SECTION'- 2000 ~936~1 1830~20' 28 0 N 83. 0 E . 0,o00 ~8oaO N' 3~9o26 E ) ....... 2100 ............ 2025 2~ ........... 1919 '0~ ................. 26 ........... B1 .............. '.'N'""78i ..... 0 .... E ........... : .......... 2';G~ "73,~3,.,..N, '39B;52 ..... E ........ : .......... 399,18 ......... 2200 2115,~3 2009°23, 2~ 30 N 7~. 0 E 2,78 8~.71 t~t ~o~ E ~1.79 2300 220~,39 2J. 00o19 2~ 37 N 7~, 0 E 0,12 95.17 N 47~,38 E o~82.5~ ............... 2~00 .......... 2297,25 ........... 2191o05 ..................... 28 ....... ~5 ............. ~ ?~, ..... O E'-;---~"'~'O';I~-T~?-':l'06,68'-.~-~ ........ 51'8,52 ..... E ........... 523,~9 2500 2388.05 2281.85 2~ ~7 N 75, 0 E ' 0.~2'"":"'"":':::'"" .... ll? 87 N 556 89 E . . 56~ 6~ 2600 2~78.75 2372°55 25 2 N 75. 0 E ' ' · ........ 0,25 .128.77 N 597,57 E ' ~06 O? .......... 2700 2569.28 ........ 2~65.08 ................. 25 ..... 15 ...... ~ ...... N"'?5;'":-'O .... E ......... z--'0;.22 .......... :-'-139,77'"'N ...... -6~8.61 ...... ~-- ............ g~7' 87 ...... 2800 2659,71 2553,5~ 25 ~7 N 75° 0 E 0,06 ~50,82 N 679,8~. E 689!86 2900 2750.11 26~3.91 ~5 20 N 76, 0 E 0,43 161,52 N 721.22 E 731.98 ........ 3000 .... 28~0e50 ........... 273~.30 ............... 25 ....... 19 .......... N'-'76. ....... O".E~:F.~3~V.-.O;o~ ......... ~?~'~71,87 ....~ ...... 792'~75 ..... ~ ........ 77~.19 51'00 2930,89 282%.69 25 20 N 77, 0 E ' 0,%~ i81 85 N. 80~,32 E 816 ~5 ~200 3021,23 2915,05 25 27 N 76, 0 E ' · ............ 3300 3111,65 ...... ~005,~5 ................ 25 ....... 7 ................... ~,I 76,-0-E ............... 0;'33" --L--202'20'''N---L- .... 887~%5-"E ......... 900,97 ~600 3202o0! 5095o81 25. 36 N 7~, O E 0,98 215 28 N 928 81E 9~ 09 3500 5292,23 ~166,0~ 25 30 N 75, 0 E ' · ....... 0,44. 22~ 81 ~ 970 37 E 985 ~5 ............... 3&O0 5382o37 3276,17 .............. 25--49 ................. N 75','--0-E ...........0,52 ......... 236[02' N'"=~='lO12:2O--E ....... ~028 05 .... ) ~700 3~72.5~ ~366.3~ 25 $0 N 75, 0 E 0,32 2~7,22 N &05~.02 E ~070!65 5800 3562,67 3~56.q. 7 25 ~6 N 76, 0 E O,5Z 258,05 N ~895.90 E Z&&3,2? ............ 3900 ....... $652,6! ...... 35~6,~ .......... 26 ......... ~ ......... N'?7.--O E -0~53 .... 268.25-.N ...... &~58.~0 .... E ..... ~000 ~7~2,2~ 363~,0~ 2~ 35 N 77, 0 E 0o5~ 278,2~ ~! &~81.6~ E &200,3~ ~100 ~83~,7~ ~725.5~ 26 2~ N 77, 0 E 288.26 N &225o07 E '-~ ............ ~aoo ..--392~z4--. ........ 38~.9~ ............... 29 .... 50 ....... ~-N---?8, o-'E .. o,62 ~oo ~o~o ~0 . ~SO~,io 27 '0 :.,N 78. 0 E' · !" 0.i7 ~qO0 ~099.29 3993.09 ' 27 i7 N 7'8, 0 E'.' 0,28· ......... ~500 ~88,0~ ......... ~081,8~-' 27 ...... ~1 ...... ~ ...... N'-'79,'-'0 E ~600 427G.6~ ~170,q~ 27 29 F.t 79, 0 E 0,20 ~700 q$65,ql ~259,21 27 20 N 79, 0 E ........ waOu ........ ~54,'08 ........ a5~7.88 ............27 ...... qS'"~----N 79,...0. E. ..... .. .... ~900 ~5~2.55 ~36,33 27 52 N 80. 0 E 0.~8 , , 5000 ~630.59 ~52~ ~9 28 ~2 N 8~o 0 E . · . ...... 297,96 .... N~"--Z268,81--E ...... ~288,8G ....... '~07.37 N ~31~ 09 E ~333.7~ 31~.85 N ' 1357o71 E 1579.00 526,05'"N .... 1~02;95"~'~-'1~2~,82 ..... 35~.89 N 1~8.39 E ~70.8~ 5~.67 ~ 1495.57 E ~5~$ 5~ · $52.~9"N----."15~8 96'"'E 1562.55 · · 360,99 N 158~,83 E 1608.96 ....... 0~95 568,81 N 1&31,56 E 1656,i7 ..................... . ............................. ~ ~ G _ ' SPERRY-SUN WELL SURVEYING COMPANY ]PAGE 2 ................................................................................................................................. ANCHORAGE~ ALASKA ...................................... MARATHON OIL CONPANY DATE OF SURVEY NOVENBER 26, 19~5 TRADING BAY UNIT NO. D'3~4 ' COMPUTATION DATE SURWEL GYROSCOPIC MULTISHOT SURVEY MCARTHUR RIVER ..................................................................... NOVEMBER"28~"'~;19757~~;~" dOB:'NUMBER"~SU~'I'60~G ALASKA KELLY BUSHING ELEV, '- lOG.20 .... ,. TRUE SUB-SEA COURSE COURSE DOG-LEG TOTAL MEASURED VERTICAL VERTICAL INCLINATION DIREC'TION SEVER'ITY RECTANGULAR COORDINATES VERTICAL DEPTH ...................DEPTH "' DEPTH ................DEG MIN ........... DEGREES .......... :.':.'"DES/lO0 ...... .:TNORTFI/SOUTFi ................. EAST/WEST ......... SECT%ON ............. 5100 ~718.~7 ')5200 ........... 4806.21 5~00 4894,19 5~00 q982.29 .................. 5500 ................... 5070,62 56O0 5159.15 5700 52~7.70 ................ 5800 5900 5~2~,91 6000 551~.~3 ............... 6100 ............. 5601,52 6200 5~?0.0~ 6500 5778.99 6500 595~.18 6600 6058,88 ......... 6700 .......... 6122 ') 6800 6205 6900 6287 ...... 7000 ....... 6370 7100 6~53 7200 6535 .......7500 ....... 6617 7600 6700 7500 6782 ...... 7600 ........ 686~ 77OO 69~5 7800 7026 7900 ......... 7108 8000 7190 8100 7272.~1 ~612.16 28 33 N 81. 0 4700.01 ................... 28 .....52 ..................... N"-'8&~ 0 ~787.99 28 1~ N 82. 0 ~876.09 '28 1~ N 81, 0 ~964.~2 ..................... 27 .... ~";'~'~:~--N""61';"::'O .... 5052o9~ 27 ~7 N 81. 0 51~i,50 27 55 N 82° 0 5250.1~ .................. 27 '36 .............. N 82, .... O' 55i8o71 ~7 82 N 85, 0 5~07.1~ 28 0 N 85, 0 5~95.32 .................. 28 .... 15 ........... ?'N'""Sff, 0 558~.8~ 27 12 N 85. 0 5672.79 27 10 N 85° 0 5761.22 .................. 28 "50 ............. N 85, 0"' 58~7.98 51 7 N 86, 0 5952,~8 ~5 5 N 86, 0 .33 ..........6016.15 .................55 ........ ~7 ........ F,; 87. ,17 .75 .'~1 ..... ,00 .89. - ,12 ,77 0 6098.97 3~ 20 N 87. 0 6181.55 3~ 20 N 88, 0 6264.21 .... ; ...... 5~--I0 ............ N '90.-'0' 63q6.80 3~ 28 N 90, 0 6~29.25 ~ 28 N 90, 0 '6511.~9 ~.q. '-'-28'~--'N-$0, -0" 659~.08 5~ ~5 S 89, 0 667~.!9 ~5 2 S 89, 0 6757,~2 ............. 55 .....20 ...... -'-S'89,'"0 6859.~5 55 ~0 S 90, 0 6920.57 55 ~0 S 90, 0 ,20 ...... 7002,00 ......... 35 ....... 18 ......... S 90,'0 .13 7083.93 .5~ '~0 S 89. 0 7166.21 0.16 576.30 N 1678.88 0'.05 ................... 583,78"U .................. 0,56 390.81 N 1773.08 0.~7 397,80 N 1819.87 0,11 ~12o41 N 1912.14 0~52 ~19.28 N 1703.95 1751'.59 1799.01 18q6.21 1892.96 1985.69 E ......................... 0~07 .................. ~25;72'"'N .......... 2005,90 ..... E ........ 2051,90 ............ E . 0.47 ~31.77 N 2049.91E 2078'.25 E 0,30 %$7.~7 N 2096.27 E 2124.93 ' 'N, .. ~145. E 1.i4 447~27 N E 0 0'5 2.66 ~59,20 N 2330.98 E 1.96 462.91 N 2383.98 E ...................... 0.89 ........ ~&6.27 N ............... 243a. ST"E 0,55 ~69,20 N ~'*:~,~0 E 0.~6. 471.66 N ~551.25 E .............. I;15 ............ ~72.6~ 'N ......... 2607,51 .... E 0,50 ~72,66 N 2663,88 E 0,05 %72.64 N 2720.48 E 0.05 ..... ~72.6% N'-'~ ....... 2777'.07:E ....... 0.58 ~72.15 N 2a33o74 E 0.45 ~71.15 N 2890.8i E 0,67 -~69.6~ N 3006,~9 E 0.06 ~69.6~ N 30~Q,80 E E .......... 0,57 ............ ~ ~' 14 N 3180,17 r 0,85 35 S 88, 0 E 0,57 '~67.66 ............ · .......... ......... L...;_L~ ......................... . .................................... 2360.63 2413.76 2q. 68.Sa ............. 2524.&2 2581.17 2637.33 ....... 2693,52 27~9'.92 2806.33 ........ 2862.77 29~9.58 2976.91 3034.7~ 3092.66 3150.71 $207.8! . © SPERRY-SUN WELL SURVEYING COMPANY PAGE .................................................. ' ............................ : ....................................................... ANCHORAGE9 ALASKA ................................. ~ARATHON OTL COI'"'IPAI',Jy DATE OF sURwEY NOVEMBER 26,~ 1975 TRADING P, AY UNIT NO,,. D~Sq./~ COMPUTATION DATE SURWEL GYRoscoPIC MULTISHOT SURVEY "'MCARTHUR' RIVER ........ . ......................................................................... NOVEMBER 28'~."1975" ..... ':-?~'?: .......... dOB"NUP1BER' S~3,.,,,.%,S036r. ALASKA · ' KELLY BUSHING ELEV. = 106.20 ............... ' 3>':' ' .'i ' ". · ................................................. .................................................................... ,..._. TRUE SUB-SEA COURSE COURSE DOG-LEG TOTAL MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR ,COORDINATES VERTICAL '-DEPTH ..................... DEPTH .................... DEPTH ................DEG" :'MIN ........... OE,,,-,REES ........... :DEG/IOO. I~JO,-,,TH/SOUTH,-- EA'ST/I,.JEST ....................... SECTIO~\I' ..... 8200 735q. o 92 ' ) .... 8300 ............. 7q.,37.62 8qO0 7520.63 8500 ?603.59 .................. 8900 ............. 7656.27 8700 7768.97 8800 ................ 8900 ................ 9000 9100 7851.59 793%.09 8016.50 8099.05 9200 .......... 6181.70 9300 626q,q6 9500 ............ 8430.33 9600 85~3.76 9700 6597.7~ ........... 9800 .......... 66~1.67 9900 876~.99 "~ lOOOO 88~7,70 ........ lOlO0 ....... 8930.33 10200 9015,14 72%8o72 3q' 14 S 88. 0 ..... 7551.~2 ...................... 34 ........... 10 ................. S"'89~' 0 '7~1~.%3 35 37 S 87, 0 7~97.39 3~ 16 $ 87. 0 .......... 7580.07 ...... . ........... ~3q":""!2 ................. S 8?~v'O 7612.77 3% 12 S 87, 0 ............. 7827.89 .................. 5~ .......... 27 ............. S 86~ .... 0 79~0~30 ~ 35 S 86. 0 7992 85 5% 10 S 85~ 0 .... 8075.50 ................ 8~58.2.5 3~ 57 S 85, 0 82%1.16 3~ 2 S 8~, 0 ........ 8524.15 .... "-~3~ ........... 50 .............. S 8%, ..... O 8407.56 33 5 S 85, 0 8~9!.54 -~2 ~0 S 82, O .......... &575~47 ................ 8658.79 35 5& S 81. 0 87ql.50 54 28 S 31. 0 ........ 8~2%.15 ........ 5% ...... 5 ..... : '--S~'-80. ..... 0~ 8906.9% $% 7 S 80. 0 .......... HORIZONTAL DISPLACEEENT-= q~20,O0 FEETr--A.T..NORTH,~785_]rBEG.,.._:_&9~._~IN, .... EAST:LA`T`.- MD'='10200 · THE CALCULATION PROCEDURES ARE 'BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF: CURVATURE METHOD E 0.35 865.68 N 3295.48 E 'E ......................... 0'.56 ........... ~6~;'21"'"N ....... ~ ........ 33~9-;63--,.E ........... 3576.50 ..... E 1,2~ ~62.27 N 3~05,55 E 3~3!.68 E 0.65 ~59,55 ~! 3~61.11E 3~87.01 "'E'""-'?~""~7O;O8' .............. ~+S&,~l t~ .......:~":'"'35'1'7,'29"E ................... 35~2.77 E' 0.05 ~53.~G N 5575.q2 E ~598o47 E 0.59 ~50.02 N 5629.65 E E .... ~-~' ...... 0,08 ...... : ..... q~6'.OB"'"N .......... 3~Bg. OE'-E E 0,11 ~42,15 N 3742,5~ E 3768 E ~ 0,68 ~57.71 I~ 57~8.79 E J~2!~82 E 0~1.9 ..... =":--~32,80 ..... N"'-?' ...... ;'~85(+,87- E .............. ~877',5i ........... E . O,~O 827.91 ~ 39~0,79 E ~952,65 E 0,56 .... ~22.55 N 3966.q~ E 3987.&8 E 0.93 ~10o~8 N %07~o73 E ~095 62 E · E .... : ............ 0;55 ....... --F~"395,85..N ............. 818q,58"E .......... '8202,72 ....... E · 0. 2 387, S E %25 ,55 E o.59 sTs.8s 29 .58 E szz.z? ' E o.o 959.83 os,sS E 20.00 .............................................................................................. SPERRY-SUN 'WELL SURVEYING COi~PANY MARATHON OIL COMPANY ................................................................... ANCHORAGE, .... ALASKA .............. PAGE .4 DA~E OF SURVEY NOVEMBER P-S, i975 TRAD~rNG BAY UNiT NO. D-3~A CONPUTATION DATE y~ 'NCARTHUR RZVER ....... SURWEL G ~OSCOF~C MULT~SHOT SURVEY ALASKA ............................................................ NOVE~tBER 28, 1975 ............................... : ............. dOB NUMBER' SU~IG036 ..................................... KELLY BUSHZ~,I6 ELE~. = ~0~,20 ~T~ "ALASKA ................................... ......................................................................... : ........ = ...........K'ELLY-'BUSH~N6'"'EgEv,-"= ..... I06'~20 ~T'; ........ .............................................................. ~NTERPOLATED-'VALUE'S-.FOR EVEN" ~OO~ "FE'ETr-'-OF--~!EASURED...DEPTN ............................................................................................................................ '~. ~,... T R U E S U B - S E A T 0 T A L ;~....' .;> }:.. ':; ..' ':.' . . - .... . '"' SURED .................. VERTICAL ............. VERTICAL ............. RECTANGULAR ...... COORb'ZNATES .................. ~D'~TVD ........................ ~ERT'ZCAE .............. ~%--~ .......................... b~ TH DEPTH DEPTH NORTH/SOUTH EAST/MEST O]FFERENCE CORRECTZON .............. 2000 .............. 193G,~+~ ....... Z850,20 .................. 65,'80 'N'"': .......... :.-.c".".3~,~-~'26.TE-,..;:~-~-~.-.~.--:....,...$3.,;59 .................................................................................................................. ~000 28~0~50 275~.38 ZT&,87 N 762.7~ E ~59~9 95~90. 4000 37~2o24 .............. 5000 6000 5513.33 5~07. 7000 6370.41 626~, ............. 8000 ........ 7190,13 ..... 7083, 90.00 8016.50 79~0. 04 278.23 39 .......................... i3 .~57o47 21 93 ......................... N 11~1~61 E 257.75 'N ................. 1631.56...E..= ................. 369~'~0 ........................ ill'gq: ........ ,~ ~0.,~o27 E ~66.66 117.25 N 2607o5i E 629°58 'N ............. 3180.17'"':E'-'~ ........... 809.'86 .......................... 180,28 ............................. L ............. i .................. 30 ~q2,13 ~ 37q. 2,53 E 983oq9 173o62 .. . 10000 88~7o70 8741.50 578,86 N ~294,58 E 1152,2 168~79 ......... 10200 .............. 9013.14 ..........8906°9~ .................... 359o83-~.~ ............ ~405o33 E ................. 1186~6~ ............................... THE CALCULATION PROCEDURES ARE B gED ON - ' ~ ~ · ........................ · A _ TH~ USE O~ THREE DZMEN~IONAL RABZUS OF CtJRYATuRE METHOD © SPERRY-SUN WELL SURVEYING COMPANY .......................................................................... '- ................................... AI',~CHORAGE ,~ "ALASKA ~ARATHON OIL COMPANY DATE OF S[JRVEY NOVEMBER 26, 1975 FRADING ~AY UNIT NO. D~$~A COMPUTATION DATE SURWEL GYROSCOPIC MULTISHOT SURVEY ~CARTHUR RIVER ............................................................................. NOVE~BER 28~ ..... 1975 ............... 2~ ...... "dOB"NU~BER .... SU3~'603~ ~LASKA KELLY BUSHING 'ELEV. = !0~20 Ii'JTERPOLATED VALUES FOR EVEN 3.00 FEET OF SUR-SEA DEPTH ............................... TRU~ ........ SUB'SEA ......................................... TOTAL .......................................................................................................... ~ ' ....... ..................................................................................................................................... '~EA. SURED VERTICAL VERTICAL RECTANGULAR COORDINATES ~JtD~TVD VERTICAL ~H DEPTH O~PTH NORTH/SOUTH EAST/WEST D~FFERENCE cORREcTION 2000 1936,~1 1830,20 65.80 N ~9.26 E 6~.59 · 1965 1906.20 1800.00 63,72 N 533.~2 E 59,62 2078 ....... 2006,20 ....... 1900.00 ................................ 71,q2";N ............. ~85,08'"'E":7'-- ...... ~ .... 72-o~5 ............................ ' '~ 33 E 83.65 11,17 21~9 210~,20 2000,00 82,57 kt ~o 2299 2206.20 2~00.00 95,1~ N q76o29 E 95,~8 9,95 2~09 ............ 2~06o20 ..... 2200,00 ...................... lO?,S1 ..... N ........... 52~,~8'""E ............... 10~,65 ..... 2519 2~06.20 2300.00 120,0~ N 56~,98 E 113,7~ 10o13 2650 2506.20 2~400.00 152.09 N 609,95 E 12~,09 .. 10.50 27g0 ...... 2606.20-' 2500.00 .....................1%%.~8'[~ ................ 655.%~ E"'·~'-.~':sv ..... 1~g.69 ........... 10.52 £~51 2706°20 2600,00 ].56.~6 N 701.06 E 1~.21 10,59 2962 2806.20 2700.00 167,9~ [4 7~6.98 E 155,85. ~072 2906.20 ...... 2800.00 .................. 179,2~-N .................. 792,9~"5 ................ 166,%8 .................. 1'0',62 5185 5006.20 2900.00 190,1~ N 8~9,07 E 177,15 10.~7 ~295 5106.20 ~000.00 201.58 N 88%.97 E 187,77 5%0% "' ~206.20 .... 5109.00 ................... 215~ t~ ........ · .......... 950e7~ E ................ 198.%~ ......... 5515 $$06.20 5200.00 226.55 N 976.80 E 209,27 I0,8~ 5626 ~06.20 ~500.00 259,00 N 1025,53 E 220,26 "- 10,99 3737 -- 3506.20 ...... 3q-O0.O0 ................. 251.~8 -i'll ' 1069.5% E"-'.'.~ .... 231,12 10.85 38q8 ~606,20 3500.00 26~.11 N 1116,32 E 2%2o1% 11o02 ,., ............. ~ ........ . ......... . ........... -':':~7--'T.~': ......... :i":-". :' -':-~T-.. ,. '.. . · , ,. . . . .. ............. SPERRY-SUN WELL SURVEYING COMPANY PAGE 5 ..................................................................................... ANCHORAGE~ ALASKA ....................................................................................................................................................................................... MARATHON O'fL COMPANY DATE OF SURVEY NOVEPiBER 26, 1975 TRADING SAY UNiT NO. D:3~A COMPUTATZON DATE SURWEL GYROSCOPIC MULTZSHOT SURVEY MCARTHUR"R~VER ........................................................................................................... NOVEMBER "28 ~ .... ~975:'--" ......................... :':"'dOB' NUMBER ..... STJ3;"16036 .............................................................. ALASKA KELLY BUSHING ELEV, = 106,20 FT, · p~ SUP, ED VERT ' TH OEP 2000 1956 1965 1906 .............. 2078 ............. 2006,20 .............. ~900 2189 2106o20 2000 2299 2206,20 2100 ......... 2~09 ............ 2306, 20 2519 2~0~o20 2500 2650 2506.20 2~00 ........... 27~0 ........... 2606.20 ........ 2500 285i 2706,20 2600 29g2 2806,20 2700 ............. 3072 ....... 290~,20 ...... 2800 3183 5006,20 2900 ') 3293 3106.20 3000 ...... 360~ ........ ~206o20 ..... 5iO0 3515 3306,20 3200 3626 3~06,20 3300 ............. 373? ........ 3506.20 ...... 3~00 58q8 3606,20 3500 INTERPOLATED VALUES FOR EVEN 100 FEET OF SUP-SEA DEPTH UE ................. SUB-SEA ..................................... TOTAL ICAL VERTICAL. RECTANGULAR COORDINATES FtD~TVD VERTICAL TH DEPTH NORTH/SOUTH EAST/WEST 'D~FFERENCE .CORRECTION ,~! 1830.20 65,80 N 5q. 9,26 E 63059 · °20 1800.00 63,72 N 333o~2 E 59~62 .'00 ........................... 71.q2".'N ...................... 385 .00 82.57 N q32 DO0 95,1~ N q76 .00 107,81--N .............. 520 .00 120.Oq N 56q .00 132.09 N 609 .00 .................... l~q.28'N ................ 655 .00 156.~6 N 701 .00 167.9~ N 7~6 .00 ................... 179.22'N .............792 .00 190.15 N 839 oO0 201,58 N .00 .............. 213,8~ N ................. ,CO 226,53 N .00 259,00 N 1 .OO ................ 251,38'-N ........... 1 .00 2~.11 N I 88q. 930 976 025 ,08 055 .29 .~8 .98 E 115.78 10.13 .95 E 12~o09 . 10.50 o~5 E ................... 13~.62 .......... i ............... 10,52 o06 E i~5.21 10.59 .98 E 155.85 10,63 o93'E ................ 166.~8 ...................... 10,~2 °07 E 177,15 10og7 ,97 E 187.77 10.62 E ................... 720~5 ..................................... 12.A2 .................................................................. E 85,65 11017 E 9~,56 9.95 E ................ 105.65 ....................... 10;06 ................................................. .7~'E ............. 198o~3 .............................. 10.G6 ..................................................... o80 E 209,27 !0,8~ .35 E 220~26 10,99 069.5q E ............... 231,12 10,85 .................... 116.52 E 2~2.1% 11.02 SPERRY-SUN HELL SURVEYING COMPANY PAGE ............................................................................................................ ANCHORAGE, ALASKA qARATHON OIL COMPANY DATE OF SURVEY NOVEMBER 26~ 1975 FRADING ~AY UNIT NO. D~3qA COMPUTATION DATE SURWEL GYROSCOPIC NULTISHOT SURVEY qCARTHUR-'RZVER ...................................................... :],]]'.-.? ................................ NOVE~BER"28~ ..... 19?5 ......................... i .......... ] ....... ~OB NUMBER "$U3~160~ NLASKA KELLY BUSHING ELEV, = 106,20 INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH tE~ ~'~RED VERTICAL tE. ' DEPTH TRUE ................... SUB2SEA'. ................................. TOTAL: ................................... ' VERTICAL .":REC'TANGULAR COORDINATES ~D-TVD VERTICAL DEPTH '::NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 5959 5706.20 ~071 3806.20 ......... ~183'--r ....... 3906.20 q295 ~006.20 ~07 4106.20 5&O0.O0 27~,17 N 116~.04 E 25~.~9 11.35 3700.00 285oql N 1212.72 E 285.28 11,78 5~00.00 ........:: ......... 296.~9"N'"~:i?~':'~'126!,~2 .... E':i: ..... ~? .... 277.05 ...... ~ ................. II.7~ .. 3900.00 30&.9~ N 1~11.04 E 289.18 12,15 ~OOO.O0 ~17.59 N 1361.20 E 501.5~ 12.~6 ....... ~520 ............ ~20 ~633 ~30 4818.. ................ ~0., ~972 460 5O86 ~70 5199 ............ g,'30 5315 ~90 5~27 500 510 5&53 520 5765 55O ....... 5878 ........... 5~0 5991 550 . .................. ~, lq12 6.20 .......... ~100 O0 327.87''''v .................... 6.20 q-200oO0 337.82 N 6.20 q$OO.O0 ~7,70 N 151~ 6,20 ............ ~OO.O0 ...... ~]7~]'-,'557~65'"N 6.20 6500.00 ..':'... ~66.72 N 1616 6.20 ~600.00 ' '. "~75.27 N 1672 6°20 "' ~700.00 ~55,78"'N .............. ~726 6.20 ~600o00 39~.70 N %779 &.20 ~900.00 ~99.81 N 1852 6,20 ....... 5000.00 ..... ~"'-U ...... ~08'05"N'"-T']'-188~ 6.20 5100.00 " ~16,23 N' 19~6 6,20 5200.00 ... 623,52 f'J 1988 6.20 ...... 5500,'00 650',58-N ....... 20qOo~5-~E 6.20 5~00.00 ' ~57,01 N 2092o51 E .~8 E ~27oll 12,77 .29 E 539.72 12,60 ®91'E-'T=~]-~:]/'352.TO 12,98 37 E.:...!,i' "' ~65 99 ".'~'" 15.29 :3~ ~E ~79:9~ ' 15.95 ~7 E ~07,q2 .55 E ~20,95 13,50 ,29 E g59,79 12,80 ~72'65 ............................. 12'86 .~85,7~ ~,05 E ....................... ~lqoSq ............................ 12.'77 ' SpERRY-SUN NELL SURVEYING COMPANY PAGE 7 ............................................ ' ' - ................................... ANCHORAGE,' ALASKA ............................................ : ...................................................................................................... ' MARATHON'OIL CORPANY DATE OF SURVEY NOVEMBER 26, 1975 TRADING BAY UNIT NO. D-54A COF]PUTATION DATE SURWEL GYROSCOPIC MULTISHOT SURVEY '-'MCARTHUR '"RIVER .......................................................... ' .......................................... NOVEMBER '~'28, .... ~975-F .................................. JOB" NU~I~ER'""SU~-IGO~6'"-"~ ALASKA . .. KELLY BUSHING ELEV. . . INTERPOLATED VALUES .FOR EVEN ~00 FEET oF SU~-SEA DEPTH ....................................................... TRUE ................ SUB,.SEA ........................................... TOTAL': ....................................... : ~ isURED VERTICAL ... VERTICAL .- RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE cORRECTION 6105 5606,20 5500,00 ~45,06 N 21~5,60 E ~99,10 . 99 N 2~97 68 E 511~96 62J..S 5706.20 5600 O0 ~7, . 8 ........... 6350 .......... ~ ....... 5806.20 ..............5700.00 ............................ 452,qT"N ........... 22i~8.~'E ................. 52q..$7 ........................................ 12.4 6~qq 5906.20 5800,00 q57,1! N 2~02,9q. E 558.18 , .6560 ..&006,20 5900,00 461,~2 N 2562,76 E 55ff.79 16.~ ............. 6680 .............. 6106,20 ........ ~000,00 .................. ~65,70"N ............. 2~.28,20 E .............. 5';'~%,~9 ......... -- ................ 19,5 6801 6206.20 6100.00. 869,25 N 2q95,60 E 595,0~ 20,6 9922 6~06.20 ~200.00 ' ~72,10 N 25~.84 E 6~6,15 21,1 . . , ~'51.8~ E .................. 657.05 ...................................... 20,9 ,' ?i&~ 650&,20 6~+00,00 ~72.&~ N 2700.~0 E 658.52 21,2 7285 ' 6606.20 6500,00 472,6~ N 2769.0~ E 679,61 2~,,2 7q07 .......... 6706.~0 ..............6600.00 ~72,07 N ........... 28~7.82 E ............ 700.98 7529 6806,20 6700.00 q. 70,86 N 2907.51 E 722.88 2!,89 )' 7651 6906,20 6800.00 469.&8 N 2978~29 E 7~5.~0 22,52 ........... 777~ ....... 7006°20 .... 6909,00 ................... ~69,6~ H .......... ~050.05-E .................. 7&8,~7 ............................. 25,07 , 7897 7106o20 7000.00 469,64 l,i 5121.q5 E 791.5q 22~87 8019 '720&,20 7100.00 q68.95 N ~191,28 E 815,55 21,99 ....... 8141 ....... 7506.20 ............ 7200-00 466.84"'-N ........ 5260.'2~'-E ...... 854~85 21~q9 8262 '7~0~o20 7500.00 ~6~o58 N 5528o50 E 855.81 20,98 8 0 1 9' 0 9 7 SPERRY-SUN WELL SURVEYING CQ~PANY PAGE 8 · · .................. ANCHORAGE, ALASKA MARATHON OIL COMPANY DATE oF SURVEY NOVEMBER TRADING BAY UNIT NO, D-3~A CO~PUTATION DATE SURWEL GYROSCOPIC P~ULTISHOT SURVEY -M'CARTHUR- RIVER ....................................................... -- ................ = .................... NOVEMBER -28i ...... I~T5''''~?'=',~:~;' ........ :: ........ ;'T'dOB' NUMBER SU3-~IG'O'3G ..................................................... .. ' . . ,. ' ..,.~..., . ALASKA. KELLY GUSHING ELEV, INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH .................................................. TRUE N' ~URED VERTICAL DL/TH DEPTH SUB-ScA . VE,RTICAL REC T,,qNGLtLA R COORDINAT£S MD"~TVD VERTICAL DEPTH NO~TH/SOUTH EAST/WEST DIFFERENCE CORRECT[ON 6582 8505 8624 57~5 9105 9229 ............. 9550 9¢~70 ........... ~7'Io., 99q-9 88 )10070 .......... S~ 7506.20 7~00o 7606.20 7500. 7706,20 ............ 7600. 7806°20 7700,00 ~52.12 N ~596~69 790~20 7800.00 4~7,~2 N 55~,6o95 ~006.20'-' 7900.00 ............................... ~42,6~ N,' ............ ~7~5°~ 6206.20 GlO0.O0 ~1,~ N $871.55 6~06.20 ........ ~200,00 ..................... ~5o4~ 'N''''~- 8506.20 8~00.00 %11.08 N q. 07Io85 $706.~0 8~00.00 5~.59 N ff200°28 0~o20 ~700o00 ~8~.~1 N ~2GG.50 9013.1~ 890~o9~ ~5~.83 ~ 10191 10200 O0 862,78 N 5395,76 E 87G,~ 20,gq- O0 ~59,26 N 5~62°88 E 89&.95 20,~8 O0 ........................... ~55.?0"'~ ................. 3530.81"'E ..................... 917,89 ................................... 20.9~ .................~ ........................................... E 958.~0 20,91 E 959.9'7 21~1~ E ..... : ............ 98]..29 .................................... ~1,31 .................................. ' .................... E 1002,~5 21,1~ E I025,~7 21,03 E ................. 10%~,12 ............................... 20,g5 ........................................................ E '!0~q.,7% 20®g1 E 108U. o7'7 20,05 E .............. I103.5~ ...................... 19.O& E 1125.11 19.26 E 1185~%1 20,75 TIdE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST '20 FOOT MD .(FROM RAOIUS OF CURVATURe) POINTS . . . E]-34A .. I ~ . ]. i - I I. - j FOR 'I'YPE O'F ~URVEY: ,,:.._L~_.~a.~-'.', SURVEY DEPTH: FROM EIELD:~_ ', ','., ......... wELL NO._ COUNTY/PARISH .... DATE OF SURVEY. "- -'-":- ~:: _JOB NO ,,, ~-'iF'O OFFICE:__ _ ..................... MARATHON OIL COMPANY PAGE ........ I ..... TRADING BAY UNIT NO, D"54A NOVEMBER 26, 1975 SURVEY DATE MCARTHUR RIVER VERTICAL SECTION COMPUTED ALONG CLOSURE ........................ ALASKA ....................................................................................................... : .................................................................................................................................................. ~ .............. SP£RRY"SUN WELL 'SURVEYING COMPANY RECORD OF SURVEY ......................................................... TRUE ................... '""-: ................................... INCLINATION ............ DIRECTION ...... DOG'-LEG .................... i ....... 7~-~ ............... "'RECT'ANGUE'AR ................. . .................... _.. '~ ................. D.Ep.T~ ......... . ...... ~EPTH DEPTH OEG MIN BEG ~IN D~G/IO0 SECTION :'~". 2000, 1956,~1 1850,21 ORIGIN AT 2000 FEET 65.80 N ~9',~6 2100, 2025.76 1919,56 2G ~1 N 78, 0 E 0~00 ~97.91 75.1~ N 59~,18 ................................ 2200, '' 2116,75 "'2010,55 ................. 2~ 50 ....................... N '7%,-'0'"':'~'T7 ......:-2~'787'~'~ .......... ~8',56'~i~.i~7-~&;56-'~ 2~00. 2207.66 2101.46 2~ 57 N 7~. 0 E 0.11','i."'..'..' ~79.~9 .,..,~ ~8.04 N 475.08 E ......................... ~ ~ , ........ ~ ............................ 2~00 ......... 2_~8 q8 2192 28 2~ %5 ............ N'""74. 0 E ....... 0';"13 ......... 520';~2---~---I'09';55"-N .......... 51~.35 ~" 2500, 2589.27 228~o07 2q. 47 N 75. 0 E 0.~2 56~.65 i20,~ N 555,82 E ................................ 2600, ...... 2479 2700. 2570 2~00. 2660 2900. 2751 ~000, ........................ ~100, .... 29~1 'I 3~00' ~022 ..................... ~300o -" 5112 3~00, ~20~ .87 .32 2~6~.3.2 25 15 N 75, 0 E 0,21 o7~ - 255~,5q 25 ~7 N 75° 0 E 0.03 687.22 .~2 2g~,92 25 20 N 76. 0 E 0,~ .52 27~5~52 25 ~9 N 76e 0 E 0.01 77~'.6i .90'-' 2825.70 ............... 25 20 .............. N-77o"-O"-E .............. 0,~2 ......, .......815.95 ............ ..... 2575.67 ............... 25 ' '.'2 ............. ?':"7:' N 7 5, ....0 ..... E ........ ;-~'0 '; 24"'".'?~"~'7---605; 26"-~'-?-~"~ 31";'3 8:""r~r-- ........ 594.69 E"' 1~2.~'2 N 655.89 E 155.48 N 677.15 E l~eS~ N 718.67 E' 17~o18 N 760°16 E. 18S,80 .... N .............. 801.85 E" .20 2916.00 25 27 N 76, 0 ET O.qi..t. 856.~5 · : .74 ......... 5006.54 ............. 25 ....7 N"'76,- O-'E ....... 0.~5 ............ 898.20 .......... .9~ 509So75 25 ~6 N 7,%o 0 E 0,98 ~0,55 194.20 N 8~3.54 E 20~.~7'"'N ............. 85qo75 216,38 N 926.27 E .................... ~00. 5295 ~600. 3385 3700. 347~ ,18 ........3186.-98 ............ 25 30 ................N"75~ ..... O'E'-.~--O.~4 ........... 982.89 .......... 227.52-"'N .......... 967.85 E'" .20 3277,00 25 ~9 N 75, 0 E 0.31 1025.72 258.79 N 1009.91E .q6 $~67.26 25 ~0 N 75, 0 E 0.31 1068,06 2a9o95 N 1051,50 E 5800, 5565 3900. 3653 .52 5457052 25 q. 6 N 76. °55 5547,15 26 4 N 77, .78 5656,58 ............. 26- 55 N-"770 0 E 0,50 1110,94 260.45 iq 1095 0 E 0'.55 1154.41 270.55 N 1156 0"£ ....... 0,51 ........ 1198.67- -280~40-'-N "!180 qlO0, 38~2.=5 q200. ' 3921.58 4300. ~010.68 3726.15 26 24 hi 77. 0 5815,58 ....... 26 50 ........... N 78~'0 5904,48 27 0 N 780 0 E 0.18 12q. 2.r--....5 ,-_,.,0'"° · q.O N 122~ .............. "':~ 79 N ........ ~267 E .............. '0o62 ..... ~- ...... 1287,41 ~-.., ~ _ . E 0,16 1532,4~ .309,23 N 1511 ,,49 E ,10 E-' i, ,q2 E .57 E ~S E ........................ MARATHON TRADING FtCARTHUR ................... ALASKA OIL COMPANY ................................................................................................................................................................................................................................. PAGE 2''" BAY UNIT NO, D-54A- NOVEMBER 26, ~975 SURVEY DATE RIVER .VERTICAL SECTION COMPUTED ALONG CLOSURE SPERRY-SUN WELL SURVEYING COMPANY RE6ORD OF SURVEY ...................................................................... TRUE ..................................................... .INCLINATION ............... DiRECTION:?':':'"DOG'LEG ..................................................... REC'TANGULAR ............. ' .......... MEARURED VERTICAL SUB'SEA SEVERITY VERTICAL COORDINATES DEPTH DEPTH DEPTH DEG NIN BEG MIN BEG/lDO SECTION q~O0. q099.56 5995.36 27 17 N 78. 0 E 0.28 1577.88 318.76 N 1356.~2 E 4500. ~188.11 .~081,91 27 ~1 N 79. 0 E 0.61 lq24,05 327,62 N 1~02,~2 E ................................. ~GO0. ..... ~276.82 ...... ~170,62 ::'77: ........ 27"'"29: ........ =~-='"N"Y~;":'O'E'~'~T?':'0.19''':'~ .....::'""1~69.91 ..................... 3~g~'~5"-"N ......... 4700. ~365.66 q259o~ ............................... qSO0. qqS[~.16 ...... ~5~7.96 ~900. ~5~2.56 ~436,36 27 20 N 79. 0 E 0,15- 1515o54 5~5°19 N i~92'.80 E 27 52 N 80. 0 E 0.48 1608,54 3~2.19 N 1584.55 E ........................ 500 510 520 5~0 5~0 ............................ 550 . 56O 5"7O 590 .................. 590 60O 610 630 ....................... 6500 6600 6700 O. "~6~0'.28 .... ~52~.08 ................. 28 'fi2 .................... N'-'81."':"O ..... E .... :"~r-'0,95 ........... 1656'.'21 ............. 369."70-i'~ .......... 163i.97 E O. ~605,97 ~699,77 28 32 N 81, 0 E 0o01 1751,~9 5&~+,65 N 172~.35 E O. .. ~89~.07 ~787.87 28 1~ N. 82. 0 E 0'.56 1798.71 ~91.23 N 177~.19 E O. q982.17 q875°97 28 1~ N 81. 0 E 0.47 18q5,87 398,65 N 1819.92 E " " ~ ~9 ....... ~05,90"'N ............ 1865.81 E O. 5070.73 ' q96~,53 '27 ~I-'"F?~'T~-N 81e .....O'"E-%':: ..... 0;55 . .. O. 5159.20 - 5055,00 ', 27 q7 · N 81~ 0 E 0.10 · ..' 19~8,67 ~-5.19 N 1911,84 E O, .... 52q7.86'- 51q1.66 ........... 27 ~5 N"'82. O--E .............. 0.51-± ......... 198q~Sq ~19;63"N ...... 1957.~5'E O. 5356.*8 52~0.28 27 36 N 82. 0 E 0.05 2031,08 q26.08 N 2003.52 E · O. 5425°02 5518,82 .... ~ ..... 27 ~2 ............. '-N'85~"O'-E ...... O;q7 ............. 2077°52 ............. ~E1.7~-'N ............. 2oqg,gg E O. 551~..31 5~.~07.11 28 0 ~4 8~, 0 E 0.50 212q,q3 ~7.47 N 2096,26 E O. 5601.~0 5q. 95,20 28 15 .. '- N Sq. 0 E 0.5~ 2171.75 q-q2.~l N 21q5,3~ E O. 5690.35 558,.15 27 12 N 85. 0 E 1',1, 2217.~5 ~qC.qO N '2188.87 E O, 5779.~1 567~,I1 27 10 N 85. 0 E O.O3 226~,1I O. ....... 5867.20 ..... 5761.00 ~ ..... 28- 30 ............... N'85. O-E ....... i-,~3 ...... ..... 2310083 .......... ~Sq~SZ-N ...........2281.89 E ., 5952 81 58~6 61 ~i 7 N 86. 0 E 2 66 2382~50 ~ . . , . . . ~-,~.!q N 2535 ~ E .--.60~6.59 ...... 5950.59 ........... 35---5-' ............ N 86, ....O.-E.,L'T-; ....... 1o98 ................ 2~17;08 ........ ~61,'95~i'q .............. 2387.89 E . 6119.71 6013,5~ 35 ~7 N 87, 0 E 0,89 2~72o67 q.S~,86 ~! 2~5,~2 E ....................... MARATHON OIL'~ONP~NY 'PAGE ......... 3 .................. TRADING BAY UNIT NO. D-3~A. NOVEMBER 26, 1975 SURVEY DATE MCARTHUR RIVER VERTICAL SECTION COMPUTED ALONG CLOSURE ........................... ALASKA .. . ..................... SPERRY-SUN WELL' SURVEYING COMPANY RECORD DF SURVEY ................................................................ TRUE ....................... ~ .............................. INCLINATION ............ DIR~.~'CTION";~.-:'OOG'~EEG ............. MEARUREO V~RTICAL SUB"SE~ SEVeRiTY VERTICAL COORDiNATeS DEPTH DEPTH DEPTH BEG ~IN DE.'~ ~IN.'. OEG/IO0 SECTION 6800, ~202,~9 6096, 6900. 628~,86 6178. .............................. 7000. 6367.60 ..... 6261, 7100. 6~50.05 ............................... 7200, ....... 6532.50 ......... 6~26. 7500. GGl~.9,~ 6508. ........................... 7~00. 7500. 7600. 7700. 7600. ........................ ) ooo. ..................... 8200. 6~97.'27 ........ 6591, 6779.~5 6672, 6860.73 675~. 69~1.98 68~5. 7025.22 6917. 710~o85--- 6998. 7187.08 7080, 7269.~1 .... 7165, 7352.08 72~5, .... r ..... ~ ...... 8~00. .......... 7~3~.82 ...... 7328. ' 8~00, 75~8oZ0 ' . 8500. 7~00.7~ 7~9q, 8600. 7683,~5 7577. 8700. 776~.16 7~59, ............... 8800, ...... 78q8.69 .... 77~2, 09 ~% 20 66 ~ 20 ~0 ..................... ~ 10 N 87, 0 E 0.5~ 2529.05 467,81 N 2~99,7q. · N 83, 0 E 0.56 2585.39 ~69,78 N 2556,11 N-53 ;'"" 0 E .............1,13 "-?F'..:?.-:26q, 1 ;'38 ...... 4.69;'78 '"'N ............ 2612.27'-'"E'" 85 36 28 N 93, 0 E 0.30 2697.79 669.78 N 2668,86 30 ...................... 3~-28 ....................... N'9:)'~ ....0 ....... ~ .............. 0';00 .............. 275~;'20 ................. 669.'78"'N ................. 2725,26 7~ 3~ 28 N 9'0, 0 E 0.00 2810.61 469.78 N 2782.05 07 '3~-'.55 ..................... S 89,"TO"'E.: ...... F':"?O;'.B7 ............ 2867,11 .................g'gS~'79""N'"'~ ........... 2838,80 95 ~5 2 S 8~, 0 E 0.~5 292~,2~ ~67,79 N 2896.20 295~+,02 5~ . 55 20 S 29. 0 E 0129 ~ 2981,80 q.&6.T8 N ........................................................................... : .......................................~:...._~ .............................................................................. 78 ~5 %0 S 99. 0 E 0,66 3039o9~ ~66,78 N 02 35 ~0 S 9'3. 0 E 0.00 3098,05 ~66.78 N 63 ......... 55' 18. .................. . S '90'.'--0 E"-7"~ ...... 0o~6 '~155'&5. ..... T ....... ~66~'78"N "- 88 5~ ~'0 S 89. 0 E 21 ............. 3~ 35 .................. S-88, 0 .... E ....... 88 34 1~ S 88. 0 E 0.35 352~o5~ ~61,Sq Iq ., 62 ........... 5q 10 .... :'-,":'"'8"89~'"0'-E'--,~-0';56' ....3380.~3 ..... ~ ...... ~60¥86.-1-~ 90 ~3 37" S 87, 0 E -1.2~ " 5~35,31 ~57.96 N ................... : ..... . ......... '' 25 3% 12 S 87. 0 E O.OG 35~6o85 452.07 N 96 ~ 12 S 87. 0 E 0,00 5602,57 4~9.15 N 3012.33 3070.&4 3&28.42 0°85 5212,2S ~65.7S N 0.57 ........... 5268.65 ......... ~63.80'--N ......... 8900. 7931.15 7824.95 3% 27 9000. 8013.51-- 7907,31 ............ 5% 53 9100. 8096.25 7990,05 3% 10 E "E- S'86. 0 E. 0.06 '371~°35 q~1.25 N ': ........... S 86,'-0-E ............ 0,09 3770.~5 ........... 437.29'-'N .......... S 85, O°E 0.68 3825,81 ~32.~0 N 3185,29 E $282.02-E ~2'98.2~ E 3~09.68 3~65.91 ., ~522.0~ 3578,17 363~.50 3690.9~ E 3767.51E 3803.66 E MARATHON OIL'COMPANY TRACING BAY UNIT NO, MCARTHUR RIVER D-3qA NOVEMBER VERTICAL SECTION PAGE .......~ ...... :---] 26, 1975 SURVEY DATE COMPUTED ALONG CLOSURE SPERRY"SUN WELL SURVEYING CO~!PANY SU3~.~60~G RECORD OF SURVEY ............................................................. TRUE ............................................ INCLINATION','"~ ..... DIF:ECTION-T'-~!'DOG~L'EG-.',.'~T:ZT,T-,~.T77¥T~TFTT2T? .... RECTANGULAR ........................ MEARUREO VERTICAL .SUB'SEA SEVERiTY:.':...VERTic~'Lr'.''':':.'' cOORDiNATES DEPTH DEPTH DEPTH ~ OEG MiN BEG MIN DEG/iO0 SECTION . 9200. 8178.81 807.2.61 $~ 21 S:'~'!'5, 0 E 0.18 3881.q. 5 ~27,q8 N 5859.67 E 9300. 8261.77 8155,57' 33 57 S ~"5. 0 E 0.~0 3956.52 ~22.61N 3~15,~0 E 9500. 8~27 9500. ........ 8511 9700, 8595 ........................ 9800 9~00 10000. 10100. 10200. 8679 8762 8927 9010 .70 8321.50 ~3 50 S 8~ .49 ........8q05.29 ....................... 53-'5 .................... .67 8~89;q7 ~2 ~O S 62 "70"E= ........ ::'77'O';'56"':---~7*"3991'5~'"7:;~'~=qlC','TG--N ....... : ........ 3970.96 E . 0 E 0.19 ~0q6o27 ~lO,gq N 4026.55 E , ........ 0 .... E ............ 0~'9~ ............... q099.75 ............ ~0~;'29""N .............. ~080.51 E . 0 E 0.68 q152oq3 396,78 N .~133.96 E .35 .... 8573.15-"~ .......... 35 .52 8656.12 55 .76 87~8,56 .59 8821,39 .38 890q,18 ._ I2 .... %-'=='.'S ..... 8:2~ 0'"E":~:'~-0','53-?- .... 7~205;87 .... ~-"$8¢;'l'6-~FF--,-:~188.19--'E- 56 S 81. 0 ~ 0.91 4260.14 380.~2 N 42q$.~2 E 28 S El, 0 E .0,53 ~315.I5 371,57 N. q299.22 E 5 S 60. 0 E 0.68 ~369.39 361,8~ N ~35~.~1 E 7 S EO, 0 E 0.03 ~2~.68 552.10 N ~09.6~ E .... ..................................................................................................................................................... THE CALCULATION PROCEDURES ARE 'BASED ON THE USE OF THE T/XNGENTIAL OR CHORD METHOD . HORIZONTAL' DISPLACEMENT 4~2..9,68 FEET- AT-NORTH ...... 85'""DES,' ...... 2G-'MIN,"""EAST(TRUE') ............................... .. · · , ALAGI(A STATE "FROM,~' TO ' O.H.. "TO, ! ~T,,,,.,z,, TY,.~ ~ U/-~.bhZ ~,Z~YP_.. ",O. O, ST,,.. ~_ TOT,,- O,~T.,*~-W.~N ~T,,.. t~q PROGRAMMER ANGLE UNIT . STAKE DIRECTION TRUE CENTER DATA ,.,.s-,- ~..,~. ,4 o - o o -.ST ,= -.,s,-, ¢q'O 4 - ~o ,. __ SURFACE TIME DEPTH SURFACE TIME VOLT,,,,,o,,~,~,c~.? ,,c ~o 0~~ ,,c A~-IMUTH TI E A~IMUTH k...., -- I TIME ~ ORIENTATION -~ TO FROM -'-~/&;2-- /",?~ TO ,_~-~- I I7--00 ~,-,..-,-c,,~ .:'-qS" ~--Io"" ~"~' S,~o-~o '3 13 ...co ORIENTATION TO ; FROM TO ,., .EF. PT .. l'>",~ TO, '..~ J ,L KEL,~ ELEVATION t DATA? [] YES [] NO REMARKS IN RUN MEASURED OUT RUN IN RUN MEASURED OUT RUN IN RUN MEA~I~IRED OUT RUN' SURFACE TIME DEPTH SURFACE TIME SURFACE TIME DEPTH SURFACE TIME SURFACE TIME DEPTH SURFACE TIME --,--~_;,,~ ,, .-. > ¢';'/-c~. :.'. '-c>.: ~7'4- 7~ ;"°-'-:t":'~'~ ¢ L/'~-'~ ~" ..... "::' .'. ~' /: :?-: .:;' _ X ?- 2/r_) :~ .;, / - u.~- ~ '"';': ---' ' ' ' ,_, ..,.-, ~_., ?':"' :::'- ~ 0 / 0 ~":;,,';-oo <? o ~ ,~::,-,,:, , ,' · ..---~ ~-~ ~ .... '* 2'0 "~:- co (~ ~ -oc~7' " '~ ?q ,-, 'Y~_,¥ rV ¢~ 0 ~,~% ~': ....,. ~,c:~ ;~ d;'? - .%0 _ -'-7.~-.:'~ :: .:~ o,'o -" ;., ~:- :< 6 ~ .,, .o:. . . ., ..-: ,:.,::-.: d~/ ..'.'. --.-~_ ~ - ~...~__- -~ , i _~ ., L _ : ,"/~" ~.-_._ C2- c'~. 4--'r, - / 0 t' _::, ';' ,-- --~ ~--"" _~ ~"'"'"" "~ ~-"; .... '-. w-:-.'--::~ V /:- ..,,:,,.'~ ~' '" --Z:-"_. . _: :-- : ....... -" "':- ':':" '"'" ~ ~'~ ~ , ~-, ..... r.:T<:..~':' :', Vc-' o ',"----.'-"~ "-ti ~,_ .' '7'-l-cd '- . .'-~ .._ . ' ~ ,:- '-, , ~'... ,.3 . ~ :-~. ._:' ,"., .- ~ '7 ,. _ l--.:,: :' ~' ~ v ,-',.,':-, L/~x ..... . ._,'"~- .. .,.7, o.-..,../:,'-:_ ..... · L.__~ 2. '>-.': __ II :'.,?_: ,~ · ,, .360° CLOCK WISE FROM NORTH F~, OR "O" AZIMUTH POINTER ,., ~ AtY,'AYS DE IN GEOGRAPHIC biAKE DI~4ECTION (AZ) ,.~-~i)t X SETTING = STARTGYRO A~-. ASSUMED HOLE DIRECTION CO P, t3E C']' ION FACTOR (.';fART OF DRIFT CURVE) ~, STAKE N t~;.CLINATION BELOW 10° SETTING = STAKE AZ.= S,D. C.F. = S.D. -- I.S. = 0o INCL. BETWEEN 10o- 50° i~£)EY, SETTING = STAKE AZ. -- ASSUMED HOLE AZ. ''~; 'S'D'--A'H'D' (+ 180°)]~ ~0 ~ ~ 9 INCL. ABOVE 50° ~ S - S.D. - A.H.D. ~60° (~ 180°) -~--~+ 60o(~ 180°) -.. BEARING AZIMUTH CONVERSION TABLE NOOE 000 S90E 90 S00W 180 N90W 270 N01E 001 S89E 91 S01W 181 NB9W 271 N02E 002 S88E 92 S02W 182 N88W 272 N03E 003 587E 93 S03W 183 N87W 273 N04E 004 SB6E 94 SO4W 184 N86W 274 N05E 005 SB5E 95 S05W 185 N85W 275 N06E 006 S84E 96 S06W 186 N84W 276 N07E 007 S83E 97 S07W 187 NB3W 277 NOBE 00/3 ' S82E 98 S0BW 188 NB2W 27~ N09E 009 S81E 99 S09W 189 N81W 279 N10E 010 S80E 100 Sl0W 190 NSOW 280 NllE 011 S79E 101 S11W 191 N79W 281 N12E 012 S78E 102 S12W 192 N78W 282 N13E 013 S77E 103 S13W 193 N77W 283 N14E 014 S76E 104 S14W 194 N76W 284 N15E 015 S75E 105 S15W 195 N75W 285 N16E 016 S74E 106 S16W 196 N74W 286 N17E 017 S73E 107 S17W 197 N73W 287 N18E 018 S72E 108 S18W 1,98 N72W 288 N19E 019 S71E 109 S19W 199 N71W 289 N20E 020 STOE 110 S20W 200 N70W 290 N21E 021 S69E 111 S21W 201 N69W 291 N22E 022 S68E 112 S22W 202 N68W 292 N23E 023 S67E 113 S23W 203 N67W 293 N24E 024 S66E 114 S24W 204 N66W 294 N25E 025 S65E 11 5 S25W 205 N65W 295 N26E 026 S64E 116 S26W 206 N64W 296 N27 E 027 S63E 117 S27W 207 N63W 297 N28E 028 S62E 118 S28W 208 N62W 298 N29E 029 S61E 119 S29W 209 N61W 299 N30E 030 SGOE 120 S30W 210 NGOW 300 N31E 031 S59E 121 S31W 211 N59W 301 N32E 032 S58E 122 S32W 212 N58W 302 N33E 033 S57E 123 S33W 213 N57W 303 N34E 034 S56E 124 S34W 214 N56W 304 N35E 035 S55E 125 S35W 21 5 N55W 305 · N36E 036 S54E 126 S36W 216 N54W 306 N37E 037 S53E 127 S37W 217 N53W 307 N38E 038 S52E 128 S38W 218 N52W 308 N39E 039 S51E 129 S39W 219 N51W 909 N40E 040 S50E 130 S40W 220 NS0W 310 N41E 041 S49E 131 S41W 221 N49W 31 N~2E 042 S48E 132 S42W 222 N48W 312 N43E .043 : S47E 133 S43W 223 N47W 313 N44E 044 S46E 134 SZl4W 224 N46W 314 N45E 045 S45E 135 S45W 225 N45W 315 N46E 046 S44E 136 S46W 226 N44W 316 N47E 047 S43E 137 S47W 227 N49W 317 N48E 048 S42E 138 S48W 228 N42W 318 N49E 049' S41E .139 S49W 229 N41W 319 N50E 050 S40E 140 SSOW 230 N40W 320 N51E 051 S39E 141 S51W 231 N39W 321 N52E 052 S38E ' 142 S52W :232 N38W 322 N53E 053 S37E 143 S53W 233 N37W 323 N54E 054 S36E 144 S54W 234 N36W 324 N55E 055 S35E 145 S55W 235 N35W 325 N56E 056 . S34E 146 S56W 236 N3aW 326 N57E 057 S33E 147 S57W 237 .133W 327 N58E 058 S32E 148 S58W 238 N32W 328 N59E 059 S31E 149 S59W 239 N31W 329 NGOE 060 S30 E 150 SG0W 240 N30W 330 NGIE 061 S29E 151 S61W 241 N29W 331 N62E 062 S28E 152 S62W 242 N28W 332 NG3E 063 S27E 153 S63W 243 N27W 333 N64E 064 S26E 154 S64W 244 N26W 334 N65E 065 S25E 155 SG5W 245 N25W 335 N66E 066 S24E 156 S66W 246 N24W 33G N67E 067 S23E 157 S67W 247 N23W 337 NGSE 068 S22E · 158 S68W 248 N22W -338 N69 E 069 S21 E 159 S69 W 249 N21W 339 NTOE 070 S20E 160 S70W 250 N20W -340 N74E 074 SlGE 164 S74W 254 N16W 344 N75E 075 S15E 165 S75W 255 N15W 345 N76E 076 S14E 166 S76W 256 N14W N77E 077 S13E 167 S77W 257 N13W ]4~ N78E 078 S12E 168 S78W 258 N12W N79E 079 SllE 169 S79W 259 NllW :~4'~ NSOE 080 Sl0E 170 SS0W 260 N10W N81E 081 S09E 171 S81W 261 N0fIW N82E 082 S08E 172 S82W 262 N01~W N83E 083 S07E 173 S83W 263 NO/W ;" N84E 084 S06E 174 S~4W 264 NB5E 085 S05E 175 SEtSW 265 i','()'.~'~ "" N86E 086 S04E 176 S86W 266 N()4 ~'~ .;' N87E 087 S03E 177 S137W 267 ~'~ ~'" NSBE 088 SO'''''~, 178 S88W 26H N89E 089 S 179 sHgw · ~ .:,,~ -' Ng0E 090 S0,.~ 180 sg0w 210 SPERRY-SUN WELL SURVEYING COMPANY sURVEY FIELD DATA SHEET NO. '=~ ,.,.,... · . , ..,o,~ SURFACE TIME DEPTH SURFACE TIME suRFACE TIME DEPTH SURFACE TIME SURFACE TIME DEPTH SURFACE TIME , ---- r~ / · ~ tTo-~t~- Igq- ZO ~ - iUu~ ~I,~ oo 134ci° ~ ~o ~'~ 0 _~ :-, ·/'Sf _ /~- Lbd --;'_ ' , ---p _ ~- ~ ~ ~ . ............. ~-~.-~-.~-- ~ ....................... ~ _2:-:z:,.::~ ' '- "-, ...... ~-~ 76 O~~ /'T' ,I /' ."~ ~,. ~ .... FORM SP-41 {~EY. 3') O"-~PLET'ION REPORT 26 APR · ARATHON OIL CO TBU ~YROSCOPiC SURVEY DECLINATION 24 DEG EAST AD-ius CF--CURVATURE'METHO'D-oF--CofqPUTA-TIoN'S ........... K B ELEV 106.2 FT ..OMPUTED FOR SDC BY F N LINDSEY AND ASSOCIATES ......... -: .................. ALE-""CAE(uL'ATib'N-~-PERFORi,,~ED BY I B M ELECTRONIC COMPUTER 'E/NS, DRIFT VERTICAL SUB DRIE_.T ....... -. T_O_T_..A_L___CO_O~.DI.N_.A___TE$_- C L 0 S U R-E S- SEVERITY SECT.~ ~ I ....................................... : '.: E _,D_T;H___.A__~.G_LE__ ........ D E_P_T_.H .............. SE.A. ........ D_I_R E__C. ..................................................... bi ST~I~,CE ANGLE DEG/'I 0'01~? ....... D M DEG, D M S ........................................................................................................ - ........................................................................................ ................................................................ : ...................... - ............. '~ '~' .~-_'i-i' ~_7~.;L-C.. b_'5'~ ~i sZ_A L .."L. ~.~_ ~..o o.i % A ~ ~_'~L.-~_.~_ Oiil.-_..._L;_' ?:.*--i E~i ~-ie_ ~'._SL'L. gi~_.~_~' ~'W..i-S ~' ri, CS. u .~ v s.¥ ....................................................................................... . ........................................................................ _75_..0_0 .... 33_._~..9 ....... 8~30,33 ......... 832z+,13 _SSZh,.o_o.E ........._z,_.!..6,.'7.], .... .IN_, ..... 4021,96 E.. z+OZ+3,z+8 1'4 8z+ 5 5 ~ .......... O_,O.O_._.O. ....... : ........ .A,..._0_~_._7_,_5_._8__ 9.6oo ..... 3.3 ........ 0 ........ 85:[3.,7..9. ....... 8~+07~59 ....... S83.0. C~E ............. ~.ZO._..~7___.?N.,._ ~076.6.7_ E ~+097.28 N 8~ :[5 I E ....... 0,88:[ ................... ~_0_..?_!_.....9_2_. .9 7.? 0.......~__3 __ __0_ ....... :8_..~.?......._6_..5 ....... 8z~91...,_.45 ..... $.82_._00..E ............. 9_ g_ 3_ .t ..3.. _6._. _ N: ........ z+), 30_ .,_6.7. E ........ 4150.32 N 8z+ 25 2 :[_._g ................ 0.,_5~5_ .............. ~_Z_A~_.__5__O_._ .~?__0_.~-,~_3.__~...5. ........ 87.6.5.0z, .... 8658.8~+ ..... sso..,_ooE ............. 3..86_,2.3...N ...... .~.2.38..79.E .... z+256.35 N 8z+ z+7..36_..E ............. 0_,81.1. ................. ~. 2._5_. .2 __,__5_.. 5_ _ ~0.0.oo ........ ~.._...Z.~. ...... a~+7..9/+ .... 87(+!....?~ ..... SS:[.ooE ............. 377_..._oo.N .... ~+~93.~._.E 4~10.~+6 N 8~+ ~8 56..E ..... O..~_~Z ................ ~.;~.0__7._._._.~__8_ 10100 3Z+ 0 8930,72 8824,52 SSO,OOE 357,7/+ N z~3z, 9,27 E /-+36~+.79 N 85 10 .. O. .E ............ O-A'.O..O. .............. ~.3.._6_..2_...,__*~_9_ :i~i~ ~'iO_Li~.-~i"':i?Z."i-~' o ~.~,,.~.~'. ii ~ ¢ o z-..ii~ ~_'i' '.s ~'7 i'o 0 ~..'"ZZ ~.'~..~ ;'~°--711..~. '.i"~'~.o'~.' o ~ ~ ..... ~. ~ z ~. ~ z ,~ ~ ~ z ~ z ~ 6 ..... z..~z:f ..................... ~ ~.$_.~.,_.~.z. .'L_O.._3.0...Q_._i.3.3_...__3._O ........... 9096.,77 .8990..,.57 ........ 57.6__._00E .......... 3.~3.,_.5_3.. ..... ~. ...... 6z+.58.,08 E z+z+71,3.1' N 85 35 32_5 .......... 0,5_8.5. ................... 10400 32 0 9180.87 907z~,67 $77,00E 331,00 N z, 5~0,68 E z+522.81 N 85 z+8 10 E 1.525 ............................................. ,~ ......................... ~ ............................. . ........................ :.o?oo ~8 z5 9z,~+,.~+o 9~¢~.20 S?Z.OOE 288','87'-"~ ....... .ggS'-~."ZO'"E ....... 4662"]:6 N_86.2~ .... ~.Z z'og~'Ci ...... 2-t~ ........ 5 ........ -96i9','~ ..... 95:[3.2~ ........ S?g,'";'O'5~ ....... 2'~'~"";'b'Z"-iN .... ~'7'~+-o-,"~'3 E ~747.?Z N 8(, ~+9. Z7 1-'~-0'0-0"-"'2'5-"-]~'5- ......... ~7"09;~'5' ...... 96'03 ."4.'5 ....... S7'8,-'C~OE ......... '-2-~"'~-;"56"-'~ ......... ~'782.38 E z+789.05 N '86 58 ~7 E !.Cz+5 z.+Tag,.OZ Z"~'"l"8'"5'"-2g"'"g5 ........ 9~'7'2';'77 ........ 9766",-57 ...... $7'8';'C~bE ........... 2'3-6';'(J"8 N ....... 4.'85g.'69 E 4.862./4.2 N 87-':[~ 1 E 0.382 z+852.z+2 ........................................................ .: .............. . ........................................................................................................................................................................................................................... ......................................................... HARATHON TBU 34A GYROSCOPIC SURVEY 7 NAY 79 INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE CODE HEASURED VERTICAL NAME DEPTH DEPTH TOTAL COORDINATES .C_._L 0__ $__ U___B__ E .........._SUB D_IS TANCE ....... ANGLE SEA DM .... S G 9588 8503,74 411,26 N G % 9972 8824.78 379.50 N G 2 10020 8864~8 375.22 N G 3 10100 8930.72 367,74 N G 4 10137 8961.40 363.95 N G 5 10320 9113,48 340.99 N G 6 10426 9202.99 327,80 N H 0 10487 9255.34 319.56 N H 1 10548. 9308,26 310.71N 9. ASE 10587 9342.26 305.12 N H 2 10600 9353.62 303.28 N BASE 10680 H 3 10697 94'23.79 291,79. N 94. 3-'8-"'-7-~- ----2"8'-~-'-~-i--N-- BASE 10760 9494.44 280.48 N H 4 107'86 9517.53 277.08 N BASE 10933 H 5 10938 BASE 11088 4070.16 E 4090.89 N 84 13 48 E 8397.54 4278,~! E 429~_.2_! .... ~ 84_ 55___~_1._~._ S11. S.58 4305.05 E 4321.37 N 85 i 7 E 8758.28 4349.27 E 4364.7~_ .~_8.5_._~.~__0_._E ~8_24.52 4~68.75 E 448~.75 N 85 38 11 E' 9007.28 .......................................... 4523.98 E 4535.84 N 85 51 20 E 9096.79 4601.47 E 4611.57 N 86 12 22 E 9236.06. ...................................................... 4607.51 E 4617.48 N 86 14 2 E 9247.42 .................................... 4651.85 E 4660.83 N 86 26 28 E 9332.56 4679.97 E 4688.36 N 86 34 12 E 9388.24 ............................................................... 4691.41 E 4699.59 N 86 37 11 E 9411.33 9649.18 259.21 N 4754.32 E __,__4_~6.1.?_3_8 .... ._N_.._8.6 ._52_..4_5___g ..... 9.5__fl_.2.98 96.5_3.,_6_.8_ ......... 2__5_~.:_66._N _ _4_.Z_5..__6_.,__47._.._E.. .......... _.4!6.3......4__4 ........... N. __86___5.3._. 1.~ .... E_9~547.48 9789,32 244.50 N 4818,89 E 4825,09 N 87 5 43 E 9683.12 H 6 11105 9804.72 242.89 N WF 11152 9847.35 238.56 N TD 1118.0 9872.77 236.08 N 4825,89 E 4832,00 N 87 7 7 E 9698.52 4845.21 E 4851.08 N 8_7_ ...... !Q_._5.Z__E 9741.15 4856.69 E 4862.42 N 87 13 1 E 9766.57 MARATHON TBU 34 ~F~EASURED D'EP!H.AND OT.HER DATA TRUE ...... DEPTH DEPTH SEA GYROSCGPIC SURVEY 2.6 APR 79 FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, ND-TVD VERT I CAL D I F F E R EN_C E ........ C.O. R__R_._E._ _c_ _T_ I_O_N_ ............ T 0 ! A L ....cO.OR D INA T E S ~-: ........... -~-~-~-i ...............-8~06, 8400 ...... '].0'8-4 ...... ................ ' ........................................................................................................... ],_0.~.4 ........................ ~11,07 N 40'71,75 E 9L --~7_lQ ................ 8606,___ 8500__. 11 ~: 9829 8706, 8600 11 ~'L ................... ~..4.9 ............... 8806. 8700 11 '21 10.070 ..............8906, _ 8800 11 % .............. !.0191 ................ 9006. ...... 8900 .... ],l ~l .................... 1.0.311 ............ 9106. 9000 12 ~s~ ...................... .._..1~430 .......... 9206, __9100 12 ~L. ............1.0.5_4 6 ............. 9 306 .................. 10660 ...................... 9406 10773 9506 '~' 'L ..................... !..0.88 5 .................... 9606 ")~ ................... 1..g99 6 ...................... 9706 ................... 1_1107.. ....................... 9806 · 9200 12 · _~._.9.30.0'.'._._12 · 9400 12 · 9500 12 · ...... ~.700 .... 13 03 - ],_.9. .................................... ~02... 60 .jN ..... 4136.06 E 23 ................... 2.0_ ........................... ~92 ,_79._..N ..... 4200,17 _iE 43 20 381.61 N 4265.70 E ............... E ................................ 05 ......................... 2.1 ........................... 3~2,1.'7_N ...... 4683,96_ E .................................................... 2;3 ......................... 1..8 ................................... 3_27,32 tN.' ..... 452.5,~8 E ......................................................... ~9 .......................... 16 ..................................... 3],I, 05 ._N ...... 4582,09. E ................................................................ 53 ............................... 17 ............................................ 294,69 .N ....... 4.635,07 E ......................................... 6'/ ........................................ lfL~ ......................................... 278,77.._N ......... ~685,70 .E ~8 ........................... ]._1 ................................. 264,83 N 473~,09__E ............................. --z ......... 89 ..................................... :Il ....................................... 252,91 N ........ ~780,71 E .................................................... O0 ............................................. 1.1 ............................................... 242,74_N ............ ~826,56_ .E .......................... . r .................................... ! ................... ~ ............................................................................................................................................................................................................................................. ~ ......................................................................... £ ....................... : , ..................................................................... ~- , ........................................................................................ -r .......................................... L. 30i' 33, . . . ~ ........................................................................................................................................................................................................................................................................... : 3S ...................................... ...................................... · .................. ; ............................................................................... ,.~ ................................................................................................. , ......... , ...................... ~ ..... . ~ ................................................................................................................................................................................................. ' .................................................................................................................................................................... ~ ....... 2,7' MARATHON TBU 34 GYROSCOPIC SURVEY 26 APR 79 · ,~ ........ I~-E-~-P'O'E-ATED"vALUEs"FOR` EVEN 1000' FEE'f-'oF'"-kEA$"U'NED-~EPTH, .-_ = .... TRuE .~ ........... ~_E~SUR ED VERT I CAL SUB ~:, DEPTH ........... DEp TH ........... SEA ........... 7~ ........................................................ 0 ~: llOCO 9709, 9603, 252,56 N 4782,38 _E ................... . ~ .. F ..................................................................................................... z .............. ............................................ · I~ . i~; .. . L ............................................................................................................................................................................................................ t r ........ ~ w : ............................................... .. ~ : . ~ , . , .. ............................................................................................................................................................................. .~....: .. .-. · 3APLET-ION. REPORT '26 APR 79 ARATHON OIL CO TEU 34A Y~O_~.C_OD!.C SURVEY ........................................................ DE_C,~I_NAT_i_ON 24 DEG EAST ANGENTIAL V'.ETHOD OF COMPUTATIONS ................... - .............. K B ELtV 106,2 FI · .O__~!P__..U__~E.D.~F.OR _.SDC..._B.¥__F .~, LINDSEY AND ASSOCIATES ............................. R-Z C.OR D__o F_ ._s URV E Y ...... _A_LL..__CAL..CUUAT[_~..N.S__.?E__.~.E_O_.~I',4ED BY-I B M E..LECT_RQNIC_COMPUTER .................................... TRU.E ......................................................................................................... DOG LEG__ 'E. AS_, .... P~._I~__~E~_~.ICA.~ ............. SUg ......... DRI.~T TOTAL.....COORDINATE$.. C L O S U R E S .... SEVERIT.Y ....... SECZ~_~ · E.~!~...._&~_~_~E_ ....... QE_~.~H ............. ~.E_A ............. D_IREC ..... .......... DISTANCE _ANGLE ..... ' DEG/iOQF~ ........... D 'I ST_gut~ ......................................................... -- .... D ....................................... -- ...... ...... 9600 .....3...3_ ...... O_ ....... 8_51z~...19 .... F..407.c)9 ..... $$?.:0C)E ............. 41._0,07_._N_. ~o76.o.1_._E 4o96.59 N 84 ]..5 ].lB ........ E 0o9C)~ ............... ..9_..~D...0._].._.3_.3__ O. ............ ~59_870.6 ...... 8491,86_ ...... 582..,OOE.............. /+.02,/--+9_.__~ ........ _.4!27..9.5_. El--] 4149,51 N 84 26 1 E 0.'545 4144.74 ........ ?.8._Q...O.__~_~ ............ O. ....... 8681....93 ...... 8575.73 ...... SsI.O.OE ............... 3.9..3,C)7__~ ......~183.74 E 4202.25 N 84 37 13 E Q..5.~.~ ................. _4_]._9_~_._0__5_ .~7Q...o._.._~.3_._~5 ........... 8.765,.07 .......... s5.58....87. ....... Sa.O]...O.O.E ............ 3_84.,$2 .... N .... 4238,45 E 425:5.84 N 84 49 7 E ..... 0.,9.30 .................... iO..O..O.g ..... 3_~,_.....15 ....... 8847?73 .... 87~1,,53 SSI.,_...O_OE ............ 37.5...,.5_~..__.N .... __4294',0~ E 43].0.43 N 85 0 ~.7_..E .......... Q,7..5._0_ ............... ~.3_Q_7_.,_~_.~_ lOlO0 34 0 8930,54 8824,44 SS. 0,OOE 365,81 N 43419,11 E 4364 47 N 8-5 11 31 E O,61z+ ~+361,_8_4 .......................................................................................................... -~ .................. · .. ........................................... · ,~ . . ..... .............................. .0200 ~4 0 q013,54__ uoO~._,36 .......... $7 .... .,. .......................... ' ........... ~ .' ............ '. ...................................................... ? OOE 35'3,23 N 440.~,60 E 4417,74 N 8.5 24 49 E ...i,.677 ................. 1..0.3..~_0..__3_.~ ....... 3.0. ........ 9..(~96...,93 ....... 8990,~3 ........... S~6,.QO~ .......... 3.3_.9_.~'87__.N. 44.57_,.15.E 4470,09 N 85 .38 21 E ........ O_,I,f_~+7._ ...... "C'~,O0 32 0 o18!,73 Q075,53 S77,00E 327,~5. ...... ! .................... ' L 0. ._5 0_.0__.._3.._0_ ........ ..0._ ....... 9.268,34 ........... ~162,14_ ....... $%3._,_..Q.Q.E .... '__3_.;~3,33.__N ......... 4556,60-E 4567,36 N 86 .3 58 E 2,870 ............... 6..5_~_6_:__6_9_ L. Q6.0.O__..2_9._ ......... Q.._ ...... 9_3_5 5. ,_8.0 ............ ~2..4_9_,6.0__:..__S.?__3_,..Op.E .......... 29.9,16__.N ......... ~602.,9.6 .... = 4612,67 N 86 16 52.E ........ i...,.OO.O ......... "~7.0.0 ...... 2.8 ...... 1.5 ....... 94_...4..3..~..8.~ ...... ?.3~7._._~.9 ....... 's.72,;.O_OE ........... 28~+._53 .... N ....... ;6~.?._9_8 ..E 4656.68 N SS 29... 48 E .. 0.8_9.Q ............... '08~0._.~ ....... 2. I7_ ........ O ........... .9_53.2.,79 .......... 9426..?.79 .......... $_'f4..?P'_Q.E ............. 2_72.,..0.2 ...... ,~_~ ...... '.46~.1._,62 E 4699,50 N 86 40 .5:3 E 1,556 .............. ~+..6_9_.~.._,.._3_.2~... ]/_0.?.0.~ ..... 2_._6 ......... f.)_ ..... _.9..~.2.2..,_8.~ ........ 9516,67._.'....$7_4.;.QOE.:= ....... 2.5.9.,..9:_4.....N .......... _.4_.?.~3,-~6. E 4740,89 N 86 51 2.4 E 1.,_O00 .................... _4_7._~_0_,__~_1_ ~..!0._.0_.Q._..~2..5__.!_._5_ ......... c)113,_.3.'! ...... ?.607._,_1! ......... $.7.87Q_P.% ............ 2~!,....0...._7_ ..... ~I ...... ~.??.5.,..98._E 4782.08 N 86 59 2.5 ........... E 1.885 ..................... ~7_.~2_..,__0_5__ ii100 2.5 0 C~803,94 969'7,?4 $'/?,OOE 241,56 N 4816,66 E 4822 71 N 8:~ 7 44 E 0 49~ ................. 4.~2.2_.~_7__i_ ................................................ ~ _~ ................................................ · · !.!~-8.'.,.~.-.-~.*t_---z±~ .......... 9. 8_ ..-F_~_.?~_5_9._ .......... ~.7..7P,..,_.3,.9,' ........ ST__8..,.Op...,E ............ 2..3_~_,6.~ ..... N .......... .4849_..,42~ E 4855,09 N 87 1.3 49. .... E 0..,612 ................... . ....................................... - ........................................................................ ] .............. ~ ......................... OTTOM HOLE CLOSURE 4855,09 FEET AT N 8'7 .113 49 E ' ........................ ......................................................... : ........ ., ............................................................................................... ........................................................ : ...................................................... ~ ....................................................................... , ............................................ ........ '. ..... _: ....................................................... , ................................................................................................................... ~ _~ .................... .] ................................................................... _.. .................................................................. : .............................................................................................. INTERPOLATED TRUE VERTICAL DEPTHS~ COORDINATES AND CLOSURES FOR GIVEN DEPTHS CODE NANE TRUE M-E-AS0-~ ED ........ VERT-iCAL DEPTH DEPTH TO T AL- ..... ~'-o'C:~D INA TE S ._ CLOSURE ISTANCE ANGIiE ..... D M S SUB SEA G I G 2 G 3 G 4 G 5 G 6 H 0 .. H 1 ~bb20 8s~;'31 ~7-~$-7 N ~305.05 E ....... ~32i.23 N 85 2 25 E 87~8. i--1~ .... 10100 8930,64 365,81 N 4349,11 E 4364.47 N 85 il 31 ~ .... 8~-24-,44 --lO-f~$-- 8961.31 361.15 N 43g9-;~"--~--' 4384.17 N 85 i6 29 E- 885'5.i-1 ........................... 10320 9113.89 337.49 N 4467.48 E 4480.21 N 85 40 47 E 9007.69 10426-- 9204.25 324.15 N ..... ~21~-2 ......E' ...... 4532.82 N 85 53'5'6-~-- '9~9'8.o5 ............ ...................................................................................................................... 105~8 9310.32 306.53 N ~578,85 E ~589.~0 N 86 ~0 11 E 920~.12 ................. BASE · :,' H 4 BASE H 5 BASE Ft $ 4595.94 E 4.506.78 N 86 15 13 E 9238-'23 l"O'6~d ................... 9'42'6-,-27 ........... ~'8-7",'4-6-'--~-- ........ ~-63'8";-~-7-"~ ........ 4647.87 N 86'-27-14'-E ....... 9-~"20';'-0~ --1076-0 .............. 9'49-7;"~"~- .......Z~7'-;'b~ N 4674.16 E 4582.~6 N 86 36 ..... ~"~ E .... 10786 9525';'~'i ........~'7-J-,~"7'--~ ........ '~-~-5";-~ .... ~- ......... 4693.50 - N" 86 .... 39 2'-l--'E .... 94i'4.31 10933 9652.7~ 257.01 N 474-7~-~-'~- ............. 4754.48 N-'86 ..... 54 ..... 4 .... ~ .... 9546'51 11105 9808.48 241.13 N 481g;-?'~-""-~ .................. 4~'.7~ ...... ~ 87 ....... B ........... g .... E .... 9702.28 : 1:52 9g5'-'~-~'~ ......... ~-5-?-"-b-4---~- ....... 4-~-~-?~"~"~'-~ ....... ~'B'4'~-"'7~ .......... ~ ....... ~"--: 1 "g--i' 'E ..... 9-~"44.97 --:1180 9876,59 23~,60 N · ~8~9,~2 E .... -4'8'-5-~-"'~-~ .... ~ 8-7---'~'3 ~9 E 9770,39 .......... 34 __ 'v~EASURED, ~PTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUE SEA · .. .. . ~';EASURED VERTICAL SUB lqD-TVD VERTICAL ............. D E P'TE]]~]_-__ ] _ _D ~ ~.ZH ..... S E.A-~ .[EE [~[N ~]"]]]]_~.O.D R.~C_T [ ON _._ TOTAL DEPTH, CODRDINATE$ ............ ' ._. 9710 8606- 8500, '!104 20 9829 8706, 8600, 1123 19 9950 8806, 8700, 1144 21 10071 8906, 8800, 1164 20 ............ !~01.?._l ............... 9.006, .......8900~ .......!185 21 .................... 10311 9106. 9000. 1205 20 ............ 1 ~.~..2 ~ ................. 9206.? .......9_1 O0 · ....... 1...2_22 ......... _Z_i_ ......· ............ ........ _]._ .0_5~ 3 9306, ..... 9200. ..... 12_3. Z ............. 1_.~ ....................... ................... !_.Q65_7._ ....................... 9406. 9300..1251 ........................... !.4 ...................... 10770 9506, 9400, 1264 13 ................. ! _0.88 !_ ....................... 9.6.06, ....9500_, ....... 127.5._L~:__; ...................... !.! ........ ] ..................... ............ l o_?_?._.g .......................... ? 7.0 410,70 N 4070.86 E ......................' 401~66 N 4135.17 E .. . 391,15 N 4199.71E .......... 379,94 N 4266,11E 368.67 N 4332.88 E ~54,34 N 4398,77 ~ ....... 338.57 N 4462,79.5 328.82 N 4522,29 E 307,20 N 4576,67 E 290,79 N 4628,72 E 275.78 N 4678,50 E 262,18 N .... 4725,94_.E ............................... 251,77 N a772,20 E INTERPOLATED VALUES FOR EVEN ~.000 FEET OF' F.F-ASURED DEPTH. , o ..... : ...................... '..T R_UE ........................................................................... ....... ~,'~E A_. SUR.E D_ ......... V ER T_ I CAL ........... SUB .............................................................. D [_P .T_H.. .............. D_E? T_H .............. SE.~A ............ T.O T_AL .....CC.O R ~ I ~_~ A_~ E_S_'_ ....... .............. ~: ~'~-6~0_---__~_ __.--__'..-:_i i'."i ~- ~'.~ ~?-..i]-_~.__~--~ ~ ~S ;i ............ -~"~ ~-;.-~ ~Z]'S' i~'%' ~_-~-~-':~.~- 1]~.Q.O_0 .................. ~7~3, 9607.., ............. 25~.,O.7_ N ...... z+77~ ,t+8 E ....... -. ,, .................................................................................................................................................................................. _, .................................... "~ SUBMIT IN D~C~TE* STATE OF ALASKA (See other In- st ructions on rever~e side OI/ AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* WELL WELL ~_~ DRY Other W [ b, TYPE OF COMPLETION: WEI.I. ~ OVER EN ~ BACK RESVR. Other_ 2. NAME OF OPERATOR Union Oi 1 Company of (;~ql ifornia * ,5. ADDRES..R OF OPERATOR P. O. Box 6247, Anchorage. AK -qg_~lO 4. i,o(:,,rlox or WELL (Report location clearly-and in accordance with any State requirements)* At surface 756.8' FSL & 1209.5' FWL, Sec. 6, T8N, R13W, SM At top prod. Interval reported below 1159' FSL & 355I FWL, Sec. 5, T8N, R13W, SM At total depth 1091' FSL & 718' FWL, Sec. 5, T8N, RI~W, SM 13. D.&TE SPUDDED Il4. DATE T.D. REACHED il5. DA.T~ COM-P SUSP OR ABAN-D. 10-13-75 J 11-20-75 ! O1-10-76 9,.0_89' TVD q:o10' TVO Single 5. API NU~I. EP~CAL CODE 50-133-20225-01 6. LEASE DESIGNATION /~q'D SERIAL NO. ADL-18729 7. IF INDIA-N, ALLOTTEE OR TRIBE NA/%iE 8. UNIT,FA.!q~%I OR LF_,ASE NAME Tradinq Bay Unit 9. %VELL NO. D--34~ (14-5) 10. FIELD A.ND POOL, OR ~,VILDCAT McArthur River-Hemlock 11. SEC., T., R., M., (BOTTOM HOI.¢. OBJECTIVE) Sec. 5, T8N, R13W, SM 12. PEI~,'IIT NO. 75-54 16. ELEVATIONS ~DF, RKB, ~T, GR, ~rC)* {17. F-LEV. CASINGHEAD I 41.2' KB Inject ion rr~c.r~uc;.G !NTERVAL(S;, OF THIS COMPLETION--TOP, BOTTOM, NA3VIE (MD AND Tyonek G Zone: Top @ 9,634'MD, 8,540'TVD Btm @10,295'MD, 9,O89'TVD (TD) KB, 106' MSL · ~ 21. INTER',,'ALS DRILLEDBY ROTARY TOOLS ' CABLE TOOLS A 1 I None ,23. %VAS DIRECTIONAL t SURVEY A'LAD E I I ~ Yes i 24. TYPE EL,ECTiIlC AND OTtIER LOGS RUN DIL/SP, BHC Sonic/G_R, Fm Density, Cmt Bond i 25. CASING RECORD (Report all strings set in well) "-13-3/8",, OD 61// / J-55 ! 2,080' 17~" , 2000 sx ] -- 9-5/8" OD [40// & 47// I N-80 [ 10,295' i ~21" I (See Attachment) .-- * Set on 10-0 -70 -- Milled sec}ion from 2 080"- 2 1~8' to sidetrack oriq h lc, ~0-24-7[. I 27. TUBI_NG RECOC,.D l SCi[E~'N (SffD~ SIZE DEPTH SET (}.'iD) ! i PACtCER SET (~.TD) 3~" . 10,0~4' //1 @ 10,073' [ //2 @ 9~981' 26. LINER R.EC O.HD SIZE [ TOP (RID~ IBOTTOM iMD) SACKS Nan a[ ' 28. ~EB. FORAT/O~$ OPeN ~O ~O~UC-~ON' (intcrvnL size m~d ~uraber) (See Attachment) 30. PRODUCTION 29. ACID, Si!OT, F2AC'i UP, E, Cv~';LE.~T SQUE-~Z~, ETC. D-------------------~T~i II,;TERV.~L (MD) /A!'~iC, UN£ .A_ND I~2!ND OF 1YL~'IER_iAL USED l {See Attachment D~,'I'£" I:'I,'~"F P~(il~d)(i.~.~ ! PRODUCTION MElt{OD tFlov.'ii~g, adz lifL, pump~g--size and type of pump) [%VELL STATUS (ProducLng or ..... [ ~ [ .... t-in) 01-12-76 ,1 Water Injection , _ [ Injection ' DATZ ,3F TgST, I~[OURS _ES'I'D '[CI!OXE SIZE [PROD'N FOR OI~BB~. t / -- I I i ,689. t -- oooI 7oo I I I -- _ I O. R. McClellan 32./,1STOF ATTACHMENT~I Directional..Survey, Cs~ & Cmt Record, Perf Record, Treatinq Record, Tubino Record 7;2. I hereby c~t~fy that the foregoing and attached information is complete and correct as determined from all-availabl6'records SIC;NEL' ~m~{/ ~. ~--~IlJl_lf[~_~../TITLE Dlst', Drlg . Supt. ' -' DATE 3/8/76 *(See Instructions and Spaces for Additional Data on Reverse Side) * Marathon Oil Company - Sub-Operator INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases ~r'~ Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise showF~) for depth measure- ments given in clher spaces on this forn~ ar-icj ~r'~ any Items 20, and 22:: If this well is completed for separate prc. duction fr©m more thar~ one tntervaJ zone (multiple completion), so state ~n item 20, and in ite.'~ 22 show the p,c.Juc~.g int£rval, or ~nte,vals, top(s), bottom(s) and name (s) (if any) for only the interval reported in iter'n 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce, J, show- ing the ack:litional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34..ciUMM~,H.y ()b' POI~.MA'I'I(.)N TESTS INi'I.LII)IN(; IN'I'EIiVAL. TF~qTET) I)})E~SURE DATA ~ ~COVEI{IF~s ()F ()IL GAS 35 G~GIC WAT~I AND MUD NAM~ ~ ~ , , , ~one lvonek .... ,, 38, CORE DATA, Aq'rACIt nnlE~ D'~:¢~O~:'O~ LITI,I'OLOGY. POn'OSI, TY. FRAC~R~. AN~, D'~I~'TEI,) ~II'~WS O'~ OIL, GAS' OR' iiii I i i I None , , , February 28, 1979 Re .' Trading Bay Unit, D-34A Union Oil Company of California Permit No. 79-11 Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Dear Sir: Enclosed is the approved application for permit to drill the above referenced well at a location in Section 5, Township 8N, Range 13W, SM. well samples, core chips and a mud log are not required. A directional survey is required. If available, a taPe` containing the digitized log information on all logs shall be submitted for copying except experimental logs, veloc- ity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulatations promulgated thereunder (Title 5, Alaska Administrative Code).' Prior to commenc- ing operations you may be contacted by the Habitat Coor- dinator's office Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution.Control Act, as amended. Prior to commencing operations you may be con- tacted by a representative of the Department of Environ- mental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issu- ance of this permit to drill. ~r. Robert T. Anderson Trading Bay Unit, D-34A February 28, 1979 To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to L~ notified so that a representative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that %~e may have a witness present. Very truly yours, ~{oyle ~. Hamilton Chairman E¥ C.~.~D~.~ O? 72{2 C~? ...... ~ .... Alaska Oil & Gas Conservation Commission Enclosure cc: Department of Fish & G~e, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor; Supervisor, Laker Law Compliance Division w/o encl. Objective We do not plan on squeezing the existing perforations in the G-Zone. Abandonment of these G-Zone sands will be accomplished with the 7" liner lap approximately 395~ up into the 9-5/8'~ casing across the G-Zone perforations and cement with approxi- mately 250 sx cement. Pressure test 9-5/8 casing and 7" liner. Squeeze cement if necessary. The present well will be deepened with 955' of 8-7/2" through the Hemlock formation. The Hemlock top approximately 840'FWL, I070'FSL, Sec. 5, T8N, R13W, liner will be run and cemented to above the present forations as noted above. A tubing string will lift equipment. Perforate-the-Hemlock-pay-zone. zone will be perforated and tested and completed producer. hole will be penetrated SM. The 7" G-Zone per- be run with gas The Hemlock pay as a Hemlock /-27- i] 7"JC- ~o buT' - Ioo, 0oo~ 7" Lin' ® I \~ZSO i [. . 4o ~..t, ST~G~ dCR ~ ~F79' 7' N l PP/,.& PI~,oFIL~ -MARATHON O!C 00. -- DOLLY VARDEN PLATFORM - Drill Occk Floor-----~ _I Rfser LLsc4 l~el:ore ~.ih~ 13~/8'' Sur-fqcc . ,. x, /x--~FI oWline Driilin9 x, U 26" 20"Riser Hippie.. C.~lamp- o~ Hu.b Preventer (20", 2,oo0~ ~yd¢-~I ) II I I 24 0 0 UN.- MRO KUST. SHEL'L F..C. ~ D-gr.d D-G 1 ~1D-14rd ,'-C -I D FC -,A~ D-23 O+ i~D-16 ,/ MARATHON 01L COMPANY . ANCHORAGE DIVISION TRADING BAY UNIT McARTHUR RIVER FIELD HEMLOCK TOP I~ENCH-I CONTOUR .?>C0)¢' I'" -. 2000' , Alaska Oil h Cas Con~crvation co;.ni:'..siou 3~.0i Porcupine [}rive ADchorage, Ale. siva 99501 A J.'} t', i N I ,-:'-' ";? P. A ~ I ~r. T.: Re: Application of Hnion Oil Company of California, el:orator . ~ '' . to dri]I and con. p!ete e.f the ~.ra,:linq ~ay Unit, _ .......... _ Fa)' Unit D-34A. wo!] as part of the ~re~'sure r~air~tenance . project appro%~ed }.v Conservation Or,er t;r. ~..'ayne Rodges, Land?an ,.nion Oil Company of California P. O. Do× 6247 Anchorage, A].asl:a 9950~. ~ Tb.o referenced application which was rec.-e-ived on Fc:kr~:;':rv 26, ., 1~.7 , stated that the Trading Day :]nit ~'-oll ~-~,:~, w~].l ~-~ complctcd ~n tae ~em!ock for~ation a~ ~ crest~l fin~! drawal Foint. The Alaska Oil and cas Conservation Commi'ssion l~erel-.:y .:~utl',c,r].zes the drilling and coT~letion of the ~ef_~enc ..... well pur:~uant to Pule 5 of Conservation Order No. 80. Very truly your~,.: / / · , l,onnie C. S~,ith Commis s ioncr Union Oil and Gas /ison: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager F~bruary 21, 1979 Alaska Oil and Gas Conservation C ommi s s ion 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska McArthur River Field Application to Complete Trading Bay Unit, D-34A (14-5) Gentlemen: Union Oil Company of California, as operator of the Trading Bay Unit, hereby requests approval to complete and produce the subject well to be completed in the Hemlock formation at a crestal final withdrawal point, pursuant to Rule 5 of Conservation Order No. 80. The subject well will be drilled from the Dolly Varden Platform by Marathon Oil Company, suboperator. Very truly_yours, Laffdman Union Oil and Ga~ ,1/ison: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager Fmbruary 21, 1979 State of Alaska Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska Permit to Drill or Deepen TBUS D-34A, Dolly Varden Platform, McArthur River Field State Lease No. ADL-18729 Gentlemen: Enclosed for your approval are three (3) copies of the above captioned Permit to Drill TBUS D-34A. Also enclosed is our check number 18905 in the amount of $100.00 to cover the filing fees of this permit. Very truly yours, sk Enclosures · Poma I0'-- 40 I . ~%'. I-I--71 ': STATE OF ALASKA SUBMIT IN (Other instructions on reverse side) OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYP[ OF WOBK DRrLL b. TYP~ OF W~LL WILL W~LL O~H~ ZON~ ZON~ 2 NAME OF OP~ATOR Union 0i] Company of Ce] ~fornia * 3.ADDR~ ~ OPhiR P.0. Box ~2~7, Anchor~e, AK ~9~02 ~.~ ~w~, 7~7'~SL, sec ~-8~-l~w-s~, CoRd ~0, Le~ A-] , 0o] ]y V~rdea At pro.seal prod. zone 8~0' [~L, ]070' FSL, Sec DEEPEN 13. DISTANCE IN MILES AND DIRECT[ON F~OM NEAREST ToWN OR POST OFFICE* 12 Miles West of Nikiski API #50-133-20225-01 6.LF, A~E DI~IGNATION A~N'D S~m~.AL NO. ADL-I8729 A-926 ?. IF INDIAN, A. LLO't-r~:lfi OR TR,LBE NAME 8. UNIT, FARM OR LEASE NA~ME Trading Bay Unit 9. ~WELL NO~-.._. D-34A 10. FIELD AND POOL, OR WILDCAT McArthur River Field Il. SEC., T.. R.. M.. [BO'I~0,M HOLE OBJECTIVE} Sec 5, T8N, R13W, 12. SM 14. BOND INFORMATION: TYPE Statewi dc Surety and/or No. Un i ted Pac i f i c ,~. DISTANCE F,OM PROPOSED' 4186 I f rom 1 ease LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. ] i ne {Al-~o to nearest drJg, unit, i£ any) 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, l~r. 700'from well D-2A 21. ELEVATIONS IShow whether DF, RT, CH. etc.~ KB 106.2' Above MSL 23. Insurance Co. B-55502 8. NO. OF ACRES IN LEASE I3085 [19. PROPOSET) DI~H'Ifi -! 11,250' MD / 9,940' TVD PROPOSED CASING AND CEMENTING PROGFLA.1VI A~o,,-~, $ ] 00 ~ 000 17.NO. ACRES ASSIGNED TO THiS WELL. 80 ~. ROT~RY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK %VILL START* 02-26-79 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADrE SETTING DEPTH quantity of cement _ _ ,8½,, 7,, ~ 29// N-80 ll,250'MD 250 SX ,_ , , , , , , ,, See Attached * Marathon 0il Company - Sub Operator IN ABOVE SPACIg D~SCRIBE PI~OPOSED PROGR-~;I: If proposal is to deepen 'give data on present productive zone a-B_d proposed new pro-duct~ve zone..l~_~.._rqpg_sai is to ar,l! or deepen (lwectjonally. give pe_rt_,m_~nt data' on stibsurface tbc~tions and _measured and true 'vertical depths. Give blowou[ p~ev-e_nter' prat.ram. S!GNIJ~''--~' F~]~¢I'¢ '~A,~,-I~,JJ,~,~ -/i- - DATg February 21, 1979 wrnm District Land Mgr. (This space for State office use) SAMPLES AND CORE CHIPS HE~ULR.[~ [] Y~ ~ NO DIRECTIONAL SURVEY RE~ [yES [] NO / ~ONDITIONS M/UD LOC [] ~ ~NO OF APPROVAL, IF AN'Y: A.P.I, NUMEP, ICAL CODE 6~ c' - i~ '3 ":2 c..z .z 6' ~' :~/ 2128179 DAT~ 2/28/79 Objective We do not plan on squeezing the existing perforations in the G-Zone. Abandonment of these G-Zone sands will be accomplished with the 7" liner lap approximately 395' up into the 9-5/8'i casing across the G-Zone perforations and cement with approxi- mately 250 sx cement. Pressure test 9-5/8 casing and 7" liner. Squeeze cement if necessary. The present well will be deepened with 955' through the Hemlock formation. The Hemlock approximately liner will be forations as noted above. A tubing string will lift equipment. Perforate-the-Hemlock-pay-zone. zone will be perforated and tested and completed producer. of 8- 1/2" top will 840'FWL, I070'FSL, Sec. 5, T8N, R13W, run and cemented to above the present be The as a hole be penetrated SM. The 7" G-Zone per- run with gas Hem'lock pay Hemlock :.-5 k~" $£ 7-85. /...¢//sw_,,.fE .,,-/~£/..S "r- c .x t:t Q-I~C. % L..,t¢..... Top ! -MARATHON OIL GO. Fiowline -- DOLLY VARDEN PLATFORM - Driilin@ ilippl¢ Dr/il 0eck Floor -- U 'x 20"Riser Preventer (20", 2,oo0~ Hydt-il ,) 2_0" Ri~cr C..lamp- or~ Hub (.a CT) union March 8, 1976 Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska Union Oil and Gas r ;sion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 ,,C--~' t:'-'"-'~"-; ,, 99504 RE: T~os D-? (14-33) TBOS D-34A (14-5) DOLLY VARDEN PLATFORM Dear Mr. Hamilton: Enclosed for your approval and review are three (3) copies of the Sundry Notice & Reports on Wells for TBUS D-7 workover and two (2) copies of the Well Completion or Recompletion Report & Log for TBUS D-34A Rd. Very truly yours-, Callender District Drilling Supt, sk Encl. cc: Marathon Oil Company Atlantic Richfield Company Amoco Production Company, (D-7 only) Phillips Petroleum Company (D-7 only) Skelly Oil Company (D-7 only) Standard Oil Co. of Calif. (D-7 only) USGS-Rodney Smith Division of Lands-Pedro Denton (TBUS D-34A) Union Oil and Gas Division' Western Region Union Oil Company 0_.,~lifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 union February 17, 1976 Dear Mr. Hamilton: Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99502 RE: FIGURE 8 UNIT #1 BIG RIVER UNIT #1' t/ ~/,.~ ": :£: T::S :-: ~4-~ Enclosed for your files are the Monthly Report of Drilling & Workover Operations (Form P-4) for each of the above captioned wells. Also enclosed is the Sundry Notice & Reports on Wells (Form 10-403) for the TBUS D-5 workover. Very truly yours, · Callender District Drlg. Supt. sk Encl. ~ No. ~=.~ STATE OF ALASKA REV. ~' 1-70 OIL AND GAS CONSERVATION COMMII-i'EE SUBMIT ~ DUPLICATE ' MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS APl NU~/EHICAL CODE 5o-133-2~25-ol ADL--18729 1. ~. IF INDIA}4r. ALOTi-EE O]:{ TRIBE NAME O,L ~] ~,,, [-] O~-E,, Water Injection ~rELL wELL 2. NAME OF OPEB~TOR *Union Oil Company of California 3. ADDRESS OF OPEI~A. TOR 909 Wes~ Ninth Avenue, Anchorage, Alaska 99501 LOCATION OF WELL Surface: 756.8' FSL & 1209.5' FWL, Sec. 6, TSN, R1BW, SM 8. L.~IT FA. HA{ OR LEASE NA3dE Trading Bay Unit 9 WELL NO D-34A (14-5) 10. FIEI.D A2qD POOL. OR WILDCAT McArthur River Field-"G" Zone 11_ SEC., T., R., M.. (BOTTOM HOLE o~ Sec. 5, T8N, RI~, SM 12. PERMIT NO. 75-54 13. REPORT TOTAL DEPTH AT F2qD OF MONTH, CI-L~XGES IN HOLE SIZE. CASING AND C2~'ViENTING JOBS INCLUDING DEPTH SET ANq> VOLLqVIES US~.P~ORATIONS, ~TS ~ ~SUL~. FISHING JO~. J~K 5N HO~ ~D SIDE-~CKED HO~ AND ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~N~ITIONS. Tradin$ Bay Unit Well D-34A' Jan. 1-5 The production packer was being run in hole on wireline when the line came out of the rope socket dropping the packer and setting tools to 10,145'. After retrieving the Baker setting tool with an overshot, the packer was milled over and the fish recovered. ~'~packer was then run in on drill pipe and set at 10,073' DPM (10,065' WI//). Jan. 6-10 A packer was run in hole on wireline and set at 9,973' The ~-" · o~ buttress N-80 9.2# tubing was run in to 10,065' WLM, wellhead equipment and injection lines were install-ed, and the rig released at 2~30 hours, 1/10/76. * ~ff~r~on Oil Company, Sub-Operator SIGht'C_' r__ ~ ' ~-- 1~-- , . ~ ~ Dist. Drlg. Supt. nA~ 2/10/Tg ~TE ~Re~er~ o, tni, ~erm i= ~e~i~ed to~ e,c~ ¢o~endor ~th~ regard~e=, et ~e et,tas ~f eperot~, end m~st ~ tiled I, d~pli¢~te with the oil end gal con.ervatian commlffee byfhe 15th of Ihe succeeding month,unle~a otherwiee directed. Document Transmittal Union Oil Company of California I. Inl n TO H. W. Kugler Oil & Gas Division 3001 Porcupine Drive A~tchorage, AK 99504 DATE SUBMITTED TACCOUNTING MONTH 2/2/76 FROM R. G. Warthen AiP.O, Box 6247 Anchorage.,, AK 99502 TELEPHONE NO, TRANSMITTING THE FOLLOWINO: FIiqAL IL 5 Synergetic Log (Prelim. Analy:¢is) . [5" ~ Computed Log - ~ Marathon TBU D-27' ,, Marathon TBU D-34A' 2" 5" So~c 5" 5" GN-FD Direction 5" Gamma Ray VDL FORFJ 69 ff~EV 2/70l PRINTED IN U.S.A, l~rm No. P.-.4 I'~,~'V. $- I-?0 STATE OF ~-A.SKA" OIL WrLL OIL AND GAS CONSERVATION C I'FI'EE .- , MONTHLY REPORT OF DRILLING AND WORKOVER , ;%..r,: % ~.c,.~F;..;' !.. ~'~,~ [~ o~,~, Water Injection '~. NAME OF OP~TOR *Union Oil Company of California 3. ADDRESS OF OPE-14.ATOR 909 West Ninth Avenue~ Anchorage, Alaska 99501 4. lOCATION OF WF_.I.J.. Surface: 756.8' FSL & 1209.5' FWL, Sec. 6, TSN, R13W, SM APl N~.MERICAL CODE 50-13B-20225-01 LEASE DES:GNA%FiON AND SLUqlAL NO .. ADL-18729 ? IF INDiAi'~ ALgDT~._E OR TRIBE ',~AI~E SI_ L.~IT F..KR~! OR '.-EASE N.-XME Trading Bay Unit g WELL NO D-3~A (114-5) 10 FIEL.D AND POOL OR V,'ILDCA? · McArthur River Feild-"G" Zon~ I1. SEC.. T., R. :,I (BO'I~OM HOI~E Sec. 5, TSN, R1BW, SM 12 PEi~iIT ~*o. 75-54 13. REPORT TOTAL DEPTH AT END OF MONTH. CIr!A.\'GE$ IN HOLE SIZE. CASING A~ C~I~N'~NG JOBS INCLUDING DEPTH S~ ~%~ VOLL~ US~. P~ORATIONS. ~TS ~%~ ~SUL~. FISHING JO~. JUnK L~ HO~ ~ND SIDE-~CKED HOLE ~P ~Y O~R SIGNIFICanT ~G~ ~ HO~ ~ITIONS. T_rading Bay Unit Well D-34A' Dec. 1-8 Cement and retainer were drilled out and the hole circulated clean to a depth of 10,250'. The casing was tested to 3,000 psi. The G-Zone Bench 4 interval was perforated from 10,138' to 10,178' with 3 holes per foot. The interval was then acid!zed and a tracer survey was run. The survey indicated that injection was going into a shale interval below Bench 4. Dec. 9-15 A cem~.nt retainer was run on drill pipe and se~ @ 9950'. Squeezed cement, 150-sack, 15.7# slurry, to isolate Bench ~ from the shale interval. Reperf- orated Bench ~ from 10,138' to 10,178'o A drill stem test to clean up perf- orations recovered 16 barrels of mud and water. Bench 4 was acidized with h,850 gallons of acid and displaced with filtered inlet water, at a rate of 1,150 BWPD at 3,50eps!. A tracer'survey while injecting filtered Inlet water indicated water entering the formation at 10,138' to 10,178' and some water going out and down to 10,220'. 275-gallons of 5% HCL acid with bO0~ of diver- ter was spotted on perforations and displaced with 390 barrels of filtered Inlet water at a rate of 2,5OOBWPD. Bench 3 was then perforated with three holes per foot from 10,122' to lO,leO' (22 feet) and acid!zed with 3,100 gallons of acid. Dec. 16- ~3 A tracer'log showed the water to be going out the perforations in Bench 3 and leaving the well bore below Bench H. The casing was perforated below Bench h and a squeeze was attempted but the perforationSwoui~ not break down. A tracer survey indicated the water to be going"into Bench 4. Dec.24-31 A sand fracture treatment with 74,5OOpounds of sand and 40,000 gallons gelled water was made with Benches 3 and k open. A Gamma Ray log Showed the frac sand with tracer went into Bench 4. An injectivity test showed 2,OOOBWPD entering Bench 4, 1,3OOBWPD entering. Bench 3, and 1,oeo BWPD entering Bench 2, at an injection pressure of 4,OOOpsig. Prior to this f-~ injectivity test Bench 2 was perforated from 10~027' to 10~0~2'. szah*E~ /lW-~vv~ ,\. x_~k~^~ r~_, ~r~z Dist. Drip. Su~t. · ~xr~ 1/1-4/7fi NOT'--Report off th,e form Il requi~ed for each calender rr.~th% regardless of the sis,us of operetions, end must ~ tiled In duPli~!· with'tnS -: ; ' : ' 011 end gal conlefvotbfl commlflse bythe 15~ of IhS suoc~ding ~n~,~lsu otherwise directed. :_:- · Marathon Oil Company, Sub-Operator o,, 1. 5 ' 976 Dear Mr. Hamilton: Union Oil and Gas D" 'qon' Western Region Union Oil Company bT~California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 279-7681 unlen .January 15, 1976 Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99502 RE: STATE REPORTS Enclosed for your files and listed below are the Monthly and Completion reports for Union Operated projects for the month of December. TBS A-14 (WO) TBS A-8 (WO) TBS A-27 (WO) TBUS D-34A (Drlg.) Monthly Report (P-4)~-7 Sundry Notice Monthly Report (P-~) Sundry Notice (10-403) Monthly Report (P-4) Sundry Notice (10-403) Monthly Report (P-4) Big River Unit #1 (Expl.) Monthly Report (P-4) Well Completion Report. (p_7) sk Encl. (18) Very truly yours, jt~mR Cailen~er District Drlg. Supt. Union Oil and Gas "'~vision: Western Region Union Oil Compan~b"~ California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 Dear Mr. Marshall: union December 10 1975 t ! '-:____,. __._ _ Mr. Tom MarshM1 : .:., ,. Division of Oil & Gas ' , --. .... . - State of Alaska ':':' 3001 Porcupine Drive ; ;_ Anchorage, Alaska 995C~4-!- "'" ~' 'i CC TBUS D-34A (14-5)' .... Enclosed for your files are two (2) copies each of the Monthly Reports of Drilling & Workover Operations (Form P-4) for each of the above captioned workovers. Also enclosed is the Sundry Notice & Reports on Wells (Form 10-403) for TBS A-19 workover. sk Encl. . Very truly yours, , Callender District Drlg. Supt. CC: Marathon Oil Co. Atlantic Richfield Co. Rodney Smith-USGS Marathon Oil Company Anchor~.~..Division Production Operations US & Canada PO Box 2380 Anchorage Alaska 99510 Telephone 907/274 1511 December 9, 1975 Mr. Hoyle Hamilton Ak. Dept. of Oil & Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Hamilton' Marathon Oil Company transmits for your records and file copies of the Directional Survey on well D-34A, Dolly Varden Platform, Trading Bay Unit, McArthur River Field, Cook Inlet, Alaska. Should you find need for additional information, please advise this office. Respectfully yours, DALE T. CADDY Operations Superintendent DTC/HL/sg Attachment ~om ~ro. p--~ STATE OF ALASKA ~. &~ 1-70 SUBMIT IN DUPLICATE" OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT o,~ [-j GA, [] o~.z~ Water Injection 2. NAME OF OPE:R. ATOR ~ "~' ': _ _ . *Union Oil Company of California 3. ADDRESS OF OPhiR 909 Wes% Ningh Avenue, ~chor~e ~ Alaska LOCATION OF WELL Surface: 756.8' FSL & 1~09.5' FWL, Sec. 6, T8N, Ri~W, SM ~ API'NUAIERICAL CODE 50-133-20225-01 ~6LEASE DESiGNA?ION AND SERIAL NO / ADA-18729 7. IF INDIA]~. ALO'I ti-th O]~ TRIBE NAIv~E ~8.~' L.~IT. F.~i OR LEASE N.~ME Trading Bay Unit D-3~A (14-5) 10. F~-Zr~ A-ND POOL, OR %VILDCAT McArthur River Field-"G" Zone I1. SEC., T., R., M.. (BOT'TOM HOL~ o~ . Sec. 5, T8N, Ri~W, SM 1~. P]~:{MIT NO. 75-5g 13. REPORT TOTAL DEPTH AT END OF MONq~{, CI-LA~\'GES I~ HOLE SIZE. CASING AIN-D C~ENTING JOBS INCLUDING DEPTH SET A.Nq~ VOLLq~9~-.S USED. PE!R. FORATIONS. TESTS A/xFD PdgSULTS. FISHING JOB~, JI/NK L~ HOLE A_ND SIDE-TP.~CKED HOLE AND A.,N'Y OTHiER, SIGNIFICANT CPIANGI~ IN HOI~ CONT)ITIONS. Trading Bay Unit Well D-34A' tl/1 = 11/19 Drilled ~ol,, sidetracked ho~ from 6,310' to total depth at 10,295' MD 11/20, 21 Ran 9-5/8" casing to 10,295' and cemented with 630 sax of Class 'G' cement 1st stage. Bumped plug with 1,500 psi., held OK. DV stage collar #1 @ 9296'. DV stage collar ~2 @ 5879'. Cemented 2nd stage through DV collar @ 9296' with 1150 sax but DV collar would not hold so had to hold pressure until cement set. - 11/22 - 11/2~ Moved rig to Well D-26 and repaired subsurface safety valve. 11/2 - 1 /3o Moved. rig back on well and .drilled out stage, collars and cement to 10,249'. Ran CBL, GR, and Collar log. Poor bonding was. indicated. Perforated and squeezed with 150 sax through perforations at the top of Bench #~ (10,138' - 10,139' ). Perforations at the top of Bench ~2 (10,018' - lO,O19') would not take fluid at 5,000 psi. The 9-~/8" casing was then cemented from perforations at 4,030'-4,O31' to surface with a total of 1,050 sax. * Marathon Oil Company, Sub-Operator m. I~OTE--Report on this form it required for each calendar ~th% regardless of the tlatu, of operations, ond must ~ filed in dupli~te with the oil and got con.ervot~n comml~ee bythe 15~ of Ihe eucc~ding ~n~,~leM otherwise directad. O' ¢'-~"' O. B~x 6207, Anchorage, Alaska 99502 ~'~/ d. A. Fouch& President December" ,, Mr. K. ~.. Thoma M~,PC, TI-iON OIL '" .... ~-" P. O. Box .2380 Anchorage, AK 99510 Dear M~. Thoma: We are pleased to suom~w ~.r;e ori~nai and ten' (!O)'copies of our Gyroscopic Survey No. SU3-i.¢_O36~ run in your well No. _ D-BhA, .in the McArthur River ~-~eza~ K~na! Peninsula '~-~ '~ Alaska. on ,November .26¢ 1975. The orig. 4m~al survey folder con- tains fie].d data shee%s, t4zmesneers,' ' tabulation sheets¢ horizontal projection and' film. . We appreciate this oooortunity to be of service to you hope our efforts warramt your continued confidence. . . 'Yours very tru!y~ ':'~ · ~ Benji Lipsey -.: District Manager CH Enclosures (!0) union Union Oil Comb.._.,~'of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 .November 17, 1975 Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 _. .. 5 -- r'-,- (-,, 1/ --D ?.,.. :__T - CONFER: '-- ~ ~" RE: TBUS D-2ARd. (13-5) TBUS D-34 (14-5) DOLLY VARDEN PLATFORM Dear Mr. Marshall: Enclosed please find two (2) copies each of the Monthly Report of Drilling , & Workover Operations (Form P-4) for both the above captioned wells. Marathon Oil Co. wishes to hold the final completion report on well D-2A Rd. until surveys can be run to determine gas lift performance, reservoir pressure and the need for perforating additional benches. sk Encl, (4) cc: Marathon Oil Co. Atlantic Richfield Co. Standard Oil Co. Skelly Oil Co, Phillips Petroleum Co. Amoco Production Co. Rodney Smith-USGS Very truly yours, t. JJim R. Callender District Drlg, Supt, 1-9 1975: ' ~ No. P--4 STATE OF AJ.A~KA SUBMIT IN DL.'PLICAT~ ,~'v. a-,-?o % APi N~.i~.mc,u. CODE 50-133-20225-01 OIL AND GAS CONSERVATION COMMll-rEE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS ggSll'l o,L,,~ [] OA,,..,.L F-] O,S'-, Water Injection Well NAME OF OPEi~.ATOR * Union Oil Company of Californi~ '.~. ADDRESS OF OPI~:I.ATOR 909 West Ninth Avenue, Anchorage. Alaska 4. LOCATION OF WELL 756.8' FSL, 1209.5 FWL, Sec. 6, T8N, R13W, SM KB-lO6.2' above MSL 6 LF-,ASE DESIGATA?ION AN-D SERIA. L NO_ ADL-18729 IF INDIA]~, ALOTI-EE OR TRIBE NAME 8. %~IT F.~RA{ O1t LEASE NAME Trading Bay Unit 9 WELL KO D-34A- (14-5) 10. FLFJ33 AND POOL. OR WILDCAT McArthur River Field G-Zone 11 SEC., T., R., M.. (BOTTOM HOK.E OB.mCrn~ Sec. 5, T8N, R13W, SM 12. PgP,.MIT NO. 7~-B4 13. REPORT TOTAL DKPTH AT END OF MONTH, CHA~\'GF, S IN HOLE SIZE, CASING AD CKMENTING JO]ES INCLUDING DEPTH SET AN~D VOL~ USED. PER.FORATIONS, TESTS ~ R~ESULTS FISI~LING JOBS JTJ'I2;K L~T HOLE AND SIDE-Tlq~C~ HOLE A/~D AJqY oTI4ER SIGNIFICANT CI4_A_NGES IN HOLE CONT)ITIONS Well D-34A was being drilled at a depth of 6,310 feet on November l, 1975. A 12-1/4" hole was being drilled. Last casing is 13-3/8" set at 2,080' where the window was cut for the kickoff. The 9-5/8" casing was cut off at 2,214' and pulled from the well. A window was cut from 2,080' to 2,158'. A 210 sack cement plug was set across the top of the 9-5/8" casing stub and up across the window in the 13-3/8" for plugging and kickoff. The plug was drilled out to 2,090' and direction tools run and the well kicked off. On 11-1-75 at a depth of 6,216' the direction hole was on course with the following coordinates' True Distance Vertical Coordinates from Depth Angle Direction Depth North East Surface 6216 28o N81 E 5693 568 2188 2231 NOV 1 g 1975 * Marath(~J',,~qq-ieom[~a~- '-'~JS-OlYerator ~E--Report on this fo~ iJ required for ~ calendar ~ths regardless of the status of operations, Q.d must ~ flied in dupli~te with the oil and got conservation commiflee by the 15~ of the suoc~ding ~n~, ~le~ otherwise directed. Form 10-403 ~.~ :(~ . . : ; ~ -i--~ubtn ~l J jOijLAN~~~J~~~ ITTEE SUNDRY NOTICES AND REPORTS )NWELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT~" for such proposals.) 2. O:L F1] WELLL-J WELL OTHER Water Injection 2. NAME OF OPERATOR * Union 0il Company iof California ADDRESS OF OPERATOR 909 West Ninth Avenue~ Anchorage~ AK 4. LOCATION OF WELL At su trace 756.8' "intentions" In Triplicate ;equent Reports" In Duplicate 99501 FSL & 1209.5' FWL, Sec. 6, T8N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) R,T, 106,2' above MSL Page I ct z 5, APl NUMERICAL CODE 50-133-20225-01 6. LEASE DESIGNATION AND SERIAL NO. ADL-18729 7. IF INDIAN, ALLOTTEE OR TRIBE NAME ]4. 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. D-34A (14-5) 10. FIELD AND POOL, OR WILDCAT -McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 5, T8N, R13W, SM 12. PERMIT NO. 75-54 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING L.J FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other). SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) . .. (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. In the original request for a permit to drill well D-34A, submitted on_:09-20-75, it was stated that we planned to cut a window in the 9-5/8" casing at about 5600' and drill an 8-1/2" directionally controlled hole to total depth at 10,709'MD. We have altered our plans to include the following. 1. Run a "free-point indicator" tool to establish the amount of free 9-5/8" casing. 2. Cut 9-5/8'i casing at free-point (approx. 2200') and pull casing. 3. Cut a 100' window in the 13-3/8" casing from approximately 2100' to 2200'.- 4. Set a cement kick-off plug across the window and down into the 9-5/8" stub. 5. Drill a directionally controlled 12-1/4" hole from the kick-off point to total depth at 10,709' TMD and 9200' TVD. 6. Log the well using Dual Induction, Gamma Ray, Sonic, and Density logs. * Marathon 0il C0mp.a.n.y - Sub-contractor {~,/O:zm 1-~¢ Uallen~¢~ ~ TITLE APPROVED BY / TITLE CONDITIONS OF APPROVAL, IF ANY: Dist, Drlg, Supt, DATE-10/22/75 DATE Instructions On Reveme Side 7. Run 10,700' of 9-5/8" casing as follows: 3500' of 9-5/8" OD, 40#, N-80, Butt' to 3500' 5200' of 9-5/8" OC, 47#, N-80, Butt. to 8700' 2000' of 9-5/8" OD, 47#, P-110, Butt. to 10,700' 8. Cement 9-5/8" casing first stage with approximately 1000 sacks of ~lass G cement. Run a stage collar at approximately 6700' and cement with sufficient volume to bring cement up across the shoe of the 13-3/8" at 2100'. Exact cement volumes te be calculated from the open-hole caliper log. 9. Run cement bond logs and collar logs for perforation control. 10. Perforate and treat the G-zone for water injection. 11. Run a permanent packet and 3-1/2" tubing for completion with the packer set above the G-zone. NOTE' Thi.~ change of plans ~'~'ill allow drilling a 'larger h~ole (!2-1/4" vs. 8-1/2") ~*"l'~shed i~ole angle at 2100' (31u) will make a less and the al ready e o~ ' risky drilling program as the average anticipated angle to reach tile target location is 32o. September 19, 1975 Re: Trading Bay Unit D-34 A (14-§) Union Ot 1 Company 75-54 Mr. R. T. Anderson District Land Manager Union Oi 1 Company 909 West Ninth Avenue Anchorage, Alaska 99501 Dear Sir: Enclosed is the approved application for permit to drill the above.referenced well at a location in Section 5, Township 8H, Range 13~, SM. . ~{ell samples, core chips, and a mud tog are not required.. A directional survey ts requi red. Many rivers in Alaska and their_ dra~a_~ systems ~have .been c)asstfi~ as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promul~te~_~there- under (Title 5, Alaska Administrative Code). Prior to coaaencing operations you may be contacted by the Habitat Coordinator's office, [~partment of .Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter'--03, Article 7 and the regulations promulgated t~re~er (Title !8, Alaska Administrative Code, Chapter 70) and by the Federal ~Water Pollution Control Act, as amended. Prior to cm~enclng operations ~. you may. be contacted by a representative of the Department of Env!ronnmntal Conservation... Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska ~partment of Labor is being notified-of the issuance of this permit to drill. In the event of suspension or abandonment please give this office adequa~ advance notification so that we may have a wt't~ss present. O. K. Gtlbreth, Jr. Chat man Alaska Oil and Gas Conservation Committee OKG:be Enclosure cc: Department of Fish and ('~me, Habitat Section w/o encl. . Department of Environmental Conservation w/o enct. Department of Labor, Supervisor, Labor Law Compliance 10 -- 401 . ~ I-I--71 STATE OF: ALASKA OIL AND GAS CONSERVATION ,COMMITTEE. SUBMIT IN /Other lnstruction~ on reverse side) API#50-133-20225-( PERMIT TO DRILL OR DEEPEN DRILL I'~ DEEPEN ~). TYPE OF WELL o,,.WEL~ [] WEL,.O~' ~] oT,,,Water In~ection ZONE [] N^ME OF OP~TOR *Union Oil Company of California 3. ADDRESS O'F OP~R 909 West Ninth Avenue, Anchorage, Alaska 99501 ~. LOCAT,O.W OF WELL Ats.r~a~e 756.8' FSL, 1209.5' FWL, Sec. 6, T8N, R13W, SM Conductor 10, Leg A-1 (NE) At proposed prod. zone 1150' FSL, 660' FWL, Sec. 5, TSN, R13W, SM 13. DISTANCE IN MILES ANO DIRECTION FI~OM NEAREST TOWN OR POST OFFICE* 12 miles west of Nikiski 14. BOND INFOI~MATION: ~ewide United P.acific Insurance Co - B-55502 :surely and/or mo. ' 15. DISTANCE FRON! PROPOSED' - J181 NO. OF ACRES IN LEASE LOCATION TO NEAREST 4620' from leas - ] PROPERTY OR LEASE LINK. ~. - _ . . (AI~ to nearest drip, u.it, i~ any) lmne _ 3085. ' ~. mSVA~ PaO~ P.OPOS~U ~CA~O~' .9. P~OPOS~ / OR APPLIED FOR. K. 10,709' MD 2800' from G-Zone} Well D-32 9,200' T~ 21. ELeVaTIOnS {Show whether DF, ~T. G~, etc.} KB 106 ~ ~L~ ZONE 6. ~LF_,ASE DESIGNATION A.NT ~ADL 18729 Ic. OEOLI t C~NO ! ! J 1 EKKg 't' , , I~ ~1 I I ~ ~l t -- Trading Bay ~iq l e. WE~LNO. DRAFT J i' ~34~(~4-5) ! s~ I McArthur ~ver-/~&~one SEC., T., R., HOLE OBJECTIVE) Sec. 5, T8N, R13W, SM 12. ~%~, 000.00 17. NO. ACRES ASSIGNED TO THiS WELL (Water Injection) ROTARY OR CABLE TOOLS Re t ary APPHOX. DATE %VOHK %~"ILL START' Sept. 15, 1975 . , SIZE OF HOLE SIZE OF CASINO ,WEIGHT PER FOOT GRADE SETTING DE~'I'H quantity of cement ,. _ '8-i/ ' 2" 7" 29.# N-80 5400' -i0,709 ' 900 sacks ,, ,, ,,, ,,, We plan to cut a window in the 9-5/8" caszng at about 5,600'-& drill an 8-1/2" directionally controlled hole to TD at 10,709' MD, log the well using a dual induction, Gamma Ray Sonic & Density Logs, run a 7" liner from TD back to lap the 9-5/8" shoe with about 200' of lap, cement the liner with 900 sacks of cement, and squeeze as necessary for a good cement job. Run Cement Bond Logs & collar logs for perforation control. Perforate & acidize the G-Zone for water injection. Run a permanent packer & 3-1/2" tubing for completion with the packer set above the G-Zone. *Marathon Oil Company Sub-Operator, Dolly Varden Platform TN ABOVE SPACE DESCTLIBE I~ROIm~)SD P~OGR.~V[: If propo~l is to deepen 'give data on present productive zone and proposed .new productive zone. Jt.p.r_o_pg.~s~l t~ ~o drill Or aeepen cllrectjonall¥, glve pe_ .rp~_/m$ .data' on sd, bsurface l~.~tion.~ and .meas. ux~d. mhd true vertical depths. Give blowou P~'ev~.nter- Prog.ram. ' .:-~ (This space for 5tare office use) COIN-PInIONS OF A~PRO'v'A~, If tSAMPLES AND CORE CHIPS REQULR~ MUD DIRECTIONAL SURVEY RE'Q~ ~yzs ~ NO APFROVED BY. - T~ ~*~ ,d ~ In--ohs ~ Reve~ S' · tOTH~R REQUIREMENTS: . A.P.I.NI/MEP~CAL CODI~ ~_.~o./.~5- zo zz~--o/ Smptmmhar 19. 1975, · September 19, 1975 The slot t/10 in well Leg A-1 is presently plugged off at 7140' with a cement retainer and cememt. The well was a Hemlock injector which was lost to injection. The drilled well is planned for a G-Zone injector. The G-Zone target is located 1150' FSL & 660' FWL in Section 5, T8N, R13W, SM at a measured depth of 10,380' & a true vertical depth of 8,880'. Proposed TD will be at 1,175' FSL & 700' FWL of Section 5, T8N, R13W at 10,709' MD & 9,200' TVD. The blowout preventer system consists of a 13-5/8" Cameron, Type "U", hydraulic double gate, 5000 psig, W.O.G., preventer and a Hydril, Type "GK", 13-5/8" preventer. The system is controlled with a Koomey pressure regulating system. Drilling mud will be a water base gelled mud system of about 10]~ per gallon mud weight as required. · Direction control of the well will be directed and surveyed by Marathon .and a contract directional company. (42-? )-8 RD . TO u,281 '~9N TSN (22-4) R 13~V R. 13 W UNION WELL LOCATION MAP MARATHON SUB-OPERATOR - · TRADING BAY STATE UNIT D-$4' SCA', £ I"= 2000' .SEPT. 9 C}~.'uCK L]'~ST t'Y)R t~f.i~.f W]",]L,T~ ]i)EP, Jq. ITS Ck'm!W.u-,f , o ]. Is the[m:: n~t ,- ", '"-- ..................... ~ .... ............... y ~:,:'~ 2. Is we].~ [o loe ]oea[ed in a de~ln:::d )'yz)] .............. ,/, - 3. Is a re.r:.~t.er~xl s:rvev ~u~:e" _...u.l.m__,'.'%..,,,,,:::i',.,,et..7:... '----+------- - / ,.,."~'%~,.~,.,, ~/',...: ' ~. z~ w~l.i ]_o~d p~q~: ..... di~:~,~c~ ~om D~op~ ]:.~ . .........U?~,~ (2) ~c. ..................... / .................... ~',:~ 5. :l:':r.~ well located proper di.s:t:ance fra~ other wc,lls .......... . ....... ~.-....4/~ ~ z -. ~ 4 g, g- ~ e..~.~f~ ~.0, '~. '~ ' ~ , _ , ~ Is well t:o b.e deviated ~ 8. is ol~rater ~e only affecl:ed ~nrty ................ d~>[ ....... - 9. Can p~.i.t be approved before 'hen-day wa.i[ ............. , .1.0. Does ottawa[or have a ~)nd in florae ................... ;;;,:. (3) Admin. ].1 Is a conservation order needed ' ('~'~'~ -"~'~ 12. Ils ad.!ministrative approval needed ................. "" ].3. !s c©nduct, or ~tring provided .................... i,! i..q c't':ough cc.n..nt used t.o c:[.rcu]ate on conductor and surface '15. \'Jill c~ttent -hi{'; ~n surface ~md i:tte~sted:i_ate or protuction strJ.~tgs . _ ) , b.'" Will ccm:'~.~, c:c~vc';~ all. kno,,,.nn prod~}.ctive N¢',rizons .......... __ .?._~_ . J.'7, 1'7.; '!! r'.,urface casin.q protect fresh wai'.er zones ........... ~,'~) cas:. CHECK LIST FOR NEW WELL PERMITS Company (-/*~;m*~ Yes No Remarks 1. Is the permit fee attached ..................... ~K Lease & Well No. ~U ~-~4Z~ 2. Is well to be located in a defined pool ............... /~ 3. Is a registered survey plat attached ................ ' 4. Is well located proper distance from property line ......... ~ 5. Is well located proper distance from other wells .......... ~ 6. Is sufficient undedicated acreage available in this pool ...... ~(, 7. Is well to be deviated ...................... ,~ ,B. Is operator the only affected party ................ ~h,a( 9. Can permit be approved before ten-day wait ............. L~ 10. Does operator have a bond in force ................. ll. Is a conservation order needed ................... 12. Is administrative approval needed ................. 13. Is conductor string provided ...................... 14. Is enough cement used to circulate on conductor and surface . 15 Will cement tie in surface and intermediate or production strings 16. Will cement cover all known productive horizons ........... 17. Will surface casing protect fresh water' zones ............. 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating ............. Additional Requirements' Approval Recommended' Geol o~y Engi nee ri ng' TRM 1-r~A4 HWK ~/~¢~'.OKG HHH JAL LCS .....,,,:",.-'~?..~ JCM ~I Revised 1/15/75 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 APPENDIXi No'special'eflorl has been made to chronologically :. .. organize this category of information. C 0 U N : KENAI STAT DENS : ALASKA 8gg. DATUM FORMAT SPECIFICATION LENGTH: 65g BYTES ENTRY BLOCKS: TYPE DESCRIPTION g TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS: API COUNT MNEM UNITS LOG 1 DEPT FT 2 SP MV 3 CILD MMHO 4 CILM MMHO 5 CLL8 MMHO 6 GR GAPI 7 CALI IN 8 DRHO G/C3 9 NPHI PU 1~ RHOB G/C3 11 NRAT C/C 12 NCNL CPS 13 FCNL CPS 14 GR GAPI 15 CALI IN 16 DT US/F API API API FILE TYPE CLASS MOD NO. SIZE 1 DATA LISTING OF EVERY SIZE g g g g g 4 7 1 g g g 4 7 11 46 g g 4 7 11 44 g g 4 7 21 8 g g 4 42 31 32 g g 4 42 28 1 g g 4 42 44 g ~ g 4 42 68 3 g ~ 4 42 35 1 g ~ 4 42 42 1 ~ g 4 42 34 92 ~ g 4 42 34 93 ~ g 4 6g 31 32 g g 4 6~ 28 3 ~ g 4 6g 52 32 ~ g 4 lggTH FRAME ll2gg.8~g -24.5gg 74.473 127.g57 61.376 199.9M~ -M.M2M 2.498 -999.Mgg -999.MMM -999.MMg 164.9MM lll5g.ggg -46.75~ 49.2~4 47.863 26.393 121.6gg 18.24~ 2.Sgg 2.g66 616.9~2 298.584 185.3g~ 111gg.gg~ -31.25~ 7~.469 GG.g69 59.156 93.2g~ 19.16g 2.58~ 2.21g 416.988 189.189 83.6g~ llg5g.gg~ -86.~gg 27.g4~ 23.335 2g.137 44.7gg 7.548 2.528 1.336 684.255 444.444 38.~ llggg.~g~ -93.gg~ 24.66g 29.648 21.g86 4g.8gg 12.18~ 2.47~ 1.644 697.464 391.677 35.9~ l~95~.gg~ -95.5g~ 24.66g 31.g46 18.535 47.~gg 12.g8g 2.529 1.684 619.g47 31~.596 47.8f~ lgggg.g~ -81.5g~ 19.231 19.953 15.417 41.2g~ 19.26~ 2.592 1.478 643.929 417.846 41.1gg lg85g.gg~ -75.75~ 22.699 21.281 12.g23 49.ggg 11.42N 2.557 1.526 569.712 442.299 41.4~ REPR CODE ENTRY 66 0 REPR SAMPLE CODE 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 5.25g 8.3g~ 8.75~ 8.55g 9.25g 8.9gl 8.8g~ 8.45~ 8.65g 8.30g 8.70~ 8.250 8.7gg 8.25g 8.75~ 8.35g PROCESS LEVEL 67.8g~ 7g.75.~ g.f41 69.40~ 55.9g~ f.~3f 6G.7~g ~.~27 G4.858 g.~8~ 64.8gg g.g21 64.~gg VAX/VMS HOY VAX/VMS HOY VAX/VMS HOY FFFFFFFFFF FFFFFFFFFF FF FF FF FF FFFFFFFF FFFFFFFF FF FF FF FF FF FF FOR~15 22-SEP-1963 lg:16 LVAg~ 22-SEP-1983 lg:16 DISKl:[LOGGER]FOR~15.DAT;8 FOR~15 22-SEP-1983 1~:16 LVAg: 22-SEP-1983 lg:16 DISKl:[LOGGERJFOR~lS.DAT;8 FOR~15 22-SEP-1983 1~:16 LVAg: 22-SEP-1983 10:16 DISK1:[LOGGER]FOR~15.DAT;8 H H 000 Y Y H H 0 0 Y Y H H 0 0 YY HHHHH 0 0 Y H H 0 0 Y H H 0 0 Y H H 000 Y VAX/VMS VAX/VMS VAX/VMS 000000 RRRRRRRR 000000 RRRRRRRR O0 O0 RR O0 O0 RR O0 O0 RR O0 O0 RR O0 O0 RRRRRRRR O0 O0 RRRRRRRR O0 O0 RR RR O0 O0 RR RR O0 O0 RR RR O0 O0 RR RR 000000 RR RR 000000 RR RR RR gg gO RR 0~ gg RR 0~ gOgg RR gg ~ggg g~g. gg 11 5555555555 1I 5555555555 1111 55 1111 55 11 555555 11 555555 11 55 11 55 11 55 11 55 11~ 55 55 11 55 55 111111 555555 111111 555555 DDDDDDDD AAAAAA TTTTTTTTTT DDDDDDDD AAAAAA TTTTTTTTTT DD DD AA AA TT DD DD AA AA TT DD DD AA AA TT DD DD AA AA TT DD DD AA AA TT DD DD AA AA TT DD DD AAAAAAAAAA TT DD DD AAAAAAAAAA TT DD DD AA AA TT DD DD AA AA TT DDDDDDDD AA AA TT DDDDDDDD AA AA TT :;;; 888888 ;;;; 888888 ;;;; 88 88 ;;;; 88 88 88 88 88 88 ;;;; 888888 ;;;; 888888 ;;;; 88 88 ;;;; 88 88 ;; 88 88 ;; 88 88 ;; 888888 ;; 888888 H H 000 Y Y H H 0 0 Y Y H H 0 0 YY HHHHH 0 0 Y , H H 0 0 Y H H 0 0 Y H H 000 Y VAX/VMS HOY VAX/VMS HOY VAX/VMS HOY FOR~15 22-SEP-1983 1~:16 LVAO: 22-SEP-1983 10:16 DISK1:£LOGGER]FOR~lS.DAT;8 FOR~15 22-SEP-1983 1~:16 LVA~: 22-SEP-1983 10:16 DISKl:[LOGGER3FOR~lS.DAT;8 FOR~15 22-SEP-1983 lg:16 LVA~: 22-SEP-1983 10:16 DISKl:[LOGGER3FOR~15.DAT;8 VAX/VMS VAX / VMS VAX/VMS REEL HEADER (REEL COUNT 1) LENGTH: 132 BYTES REEL NAME: P.C.D.C. ORIGIN: SERVICE NAME: EDIT REEL CONTINUATION NUMBER: ~1 PREVIOUS REEL NAME: COMMENTS: LIS FORMAT CUSTOMER TAPE DATE: 79/ 4/13 TAPE HEADER (TAPE COUNT 1) LENGTH: 132 BYTES TAPE NAME: 55125 DATE: 79/ 4/13 ORIGIN: SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: ~1 PREVIOUS TAPE NAME: COMMENTS: ********************************************************************** E 0 F * * * * * * * * * * * * * . FILE HEADER (FILE COUNT 1) LENGTH: 62 BYTES FILE NAME: EDIT .MM1 SERVICE SUB LEVEL NAME: MAXIMUM PHYSICAL RECORD LENGTH: 1~24 OPTIONAL PREVIOUS FILE NAME: WELL SITE INFORMATION LENGTH: 187 BYTES C N : W N : F N : RANG TOWN : MARATHON OIL COMPANY TBU D-34A DEEPEN (14-A) MC ARTHUR 13W BN SECT : 5 18888.888 -81.258 28.324 11.36~ 2.586 1.548 18758.888 -78.08~ 48.551 18.68~ 2.367 2.168 1878~.88~ -58.25~ 55.463 15.18~ 2.464 1.978 1865~.888 -75.75~ 24.889 11.36~ 2.515 1.6~4 186~8.88~ -56.25~ 58.~76 21.260 2.523 2.316 1855~.888 -55.580 184.713 23.84~ 2.516 2.426 18588.88~ -22.88~ 178.649 26.588 2.451 2.752 18458.888 -26.58~ 112.728 16.94~ 2.454 2.~26 184~8.88~ -25.250 68.256 15.26~ 2.479 2.88~ 18358.~8~ -36.75~ 114.815 26.948 2.534 2.864 18388.888 -18.588 59.784 26.888 2.562 2.822 18258.888 -99.588 91.281 44.48~ 2.578 3.596 182~.8~g -84.~8~ 89.536 43.44~ 2.578 3.76~ 10158.88~ -84.8~g 89.536 39.52~ 2.733 3.546 181~.8~ -84.~88 89.536 33.94~ 2.679 3.18~ 19.855 598.826 43.652' 529.386 51.523 588.588 23.55f 615.186 65.464 481.544 159.956 418.124 188.382 328.892 111.686 484.77~ 63.896 561.132 186.668 374.888 92.897 368.511 8.886 188.689 8.886 199.856 8.886 286.778 8.886 257.488 13.552 397.254 31.333 236.888 46.132 238.895 17.539 388.894 51.523 157.814 97.275 166.881 152.757 136.422 125.893 267.696 36.644 227.799 118.832 189.824 66.681 114.972 8.886 75.584 8.886 51.488 8.886 68.918 8.886 88.652 48.588 48.8g8 44.688 42.988 44.780 48.g88 45.988 72.88~ 88.988 68.5~8 67.288 78.2~8 66.888 62.488 73.8~8 53.888 52.888 82.788 114.388 lf4.498 36.688 33.7~g 42.3f8 34.4fg 35.9~8 34.4~g 36.1~ 34.4~ 8.7~g 8.388 8.788 8.250 8.988 8.488 8.758 8.15g 9.188 8.888 9.1Z8 8.388 18.558 9.78~ 9.388 9.15~ 18.558 9.158 9.458 8.68~ 11.758 8.758 8.888 9.858 8.88Z 8.98g 8.8g8 9.108 8.888 8.818 68.688 g.822 76.3Z8 8.847 67.288 8.819 66.952 8.831 72.85~ 8.187 81.888 8.288 75.258 8.878 78.288 94.688 8.847 74.388 8.824 69.658 -8.259 65.988 -8.259 65.888 -8.259 65.88~ -f.259 65.8gg BEGINNING DEPTH: ENDING DEPTH: DEPTH INCREMENT: 11288.88 lZg88.ZZ -g.58 THE NUMBER OF FRAMES ENCOUNTERED WAS 2241 FILE TRAILER (FILE COUNT 1) LENGTH: 62 BYTES FILE NAME: EDIT .881 SERVICE SUB LEVEL NAME: MAXIMUM PHYSICAL RECORD LENGTH: OPTIONAL NEXT FILE NAME: E 0 F * * * * 1824 * * * * * * * * * * TAPE TRAILER, (TAPE COUNT 1) LENGTH: 132 BYTES TAPE NAME: 55125 ORIGIN: SERVICE NAME: EDIT DATE: 79/ 4/13 TAPE cONTINUATION NUMBER: NEXT TAPE NAME: COMMENTS: ********************************************************************** REEL TRAILER (REEL COUNT 1> LENGTH: 132 BYTES REEL NAME: P.C.D.C. ORIGIN: SERVICE NAME: EDIT REEL CONTINUATION NUMBER: 61 NEXT REEL NAME: COMMENTS: LIS, FORMAT CUSTOMER TAPE DATE: 79/ 4/13 E 0 f * * * * * * * * * * * * * ***END OF JOB
