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Home My WebLink About198-120Wallace, Chris D (CED) From: Julie Wellman - (C) <Julie.Wellman@hilcorp.com> Sent: Thursday, November 26, 2020 5:09 PM To: Wallace, Chris D (CED) Cc: Dan Marlowe; Katherine O'connor Subject: OA Pressure communication on Grayling G-05RD (PTD #198120) Hello Chris, This morning, the water injector G-05RD's OA pressure had jumped from 85 psi to 2000 psi after being put on injection yesterday. The OA was bled down to monitor buildup and the pressure climbed right back up. The well was shut in at 6:30 AM. Please let me know if you have any questions. Thank you, Julie Wellman Regulatory Tech — Hilcorp Alaska, LLC o: 777-8505 1 c: 360-265-4397 Julie. We11man(&hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. P) D i9912-60 Hilcorp Well: G-5RD Field: Grayling 06/18/2020 1000 2000 3000 4000 4) JT 5000 6000 !Z 0 0 7000 8000 9000 10000 11000 50 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 60 70 80 90 100 110 Temperature (Deg. F) —Press 20 – Perfs 16" 1. 13-3/8" 9-5/8" — 7" TBG 4 1/2 - Pkr Temp 20 Temp Report date: 10/6/2020 • • FAD 1`1 % 12_0o Hilcorp Alaska LLC Well:IG-05RD Field:IGrayling 104/27/2018 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5001 0 I 1000 ‘NIV _ Pressure-Temperature Profile - 1. RIH 6-6-16 .„ - 2. Static 2000 3000 — 111 4000 a) 5000 D 2 6000 Q Ti 7000 _ 8000 1 lit- 9000 _ W X 0.0........... - -- 10000 11000 I I 1 t 1 I I 50 60 70 80 90 100 110 120 130 140 Temperature (Deg. F) -4-27-18 Pressure – Perfs 16" 13-3/8" 9-5/8" -7" —•- TBG 4 1/2 Pkr 4-27-18 Temp 6-6-16 Temp Report date: 5/9/2018 SCANNED M/-U' 1 .1 N8 • • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Friday, June 10, 2016 11:56 PM To: Larry Greenstein Subject: RE: Request for RTI for G-05RD PTD # 1981200 Larry, Keep the well on injection. We will process the AA application and I will get back to you if I have any questions. Regards, Chris Original message From: Larry Greenstein <lgreenstein@hilcorp.com> SCANNED JUN 1 7 2016 Date: 06/10/2016 2:09 PM (GMT-09:00) To: "Wallace, Chris D (DOA)" <chris.wallace@alaska.gov> Subject: RE: Request for RTI for G-05RD PTD # 1981200 Hi Chris Just thinking out loud here... Knowing that there'll be no Commission approvals from 6/12 —6/22. If everything looks in order to you, would it be possible to keep this well online after the two week temporary injection window is up until the Commissioners return and can process the AA?? It does appear to me that the containment of the injected fluids is intact so I don't believe this would pose much of a risk to the overall integrity of the injection project or the secondary barrier in this well in particular. Let me know if this would cause you any grief. Larry From: Larry Greenstein Sent: Tuesday, June 07, 2016 9:32 AM To: 'Wallace, Chris D (DOA)' Subject: Request for RTI for G-05RD PTD # 1981200 Hi Chris We've completed the temp survey after a week of temporary injection in this high rate waterflood well and overlaid this with a previously taken temp survey run during the time this well was on AA prior to its WO in 2012. The attached plot shows this new temp survey has a high correlation with the latest of the compliance temp surveys run during the AA period indicating there isn't any fluid flow out of the casing except at the perfs. As stated below, this is an important well for the consistent operation of the injection pump for that leg room and, in addition, it's important for the pressure support of the nearby oil wells M-28, G-32 & G-33. Based on this data, Hilcorp is requesting to return this well to continuous injection with monthly reporting of daily injection volumes/pressures and biennial temperature surveys to confirm that injection is being contained in the authorized EOR strata. With oil prices where they are, Hilcorp does not envision being able to economically repair the mechanical integrity in this well in the immediate future. 1 • • Please let me know if you need anything else to proceed with this request. Thank you Larry From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Tuesday, May 31, 2016 12:19 PM To: Larry Greenstein Subject: RE: Notification of probable tbg x IA communication and request for temporary injection for G-05RD PTD # 1981200 Larry, As discussed on the phone, injection for the 2 weeks is approved and we look forward to reviewing the temp survey at that time. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907) 276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Larry Greenstein [mailto:lgreenstein@hilcorp.com] Sent: Tuesday, May 31, 2016 11:07 AM To: Wallace, Chris D (DOA) Subject: Notification of probable tbg x IA communication and request for temporary injection for G-05RD PTD # 1981200 Hi Chris To summarize the integrity issue for the Grayling G-05RD well: Early this morning, the G-05RD well was shut-in due to probable tbg x IA communication (see e-mail below). Although it took a number of hours to build up pressure in the IA, there would be no reason to believe this increase was thermal in nature or anything other than a small, steady leak through the tubing or packer. As a result, we aren't requesting any diagnostic time to confirm the communication. The G-05RD well was WO in July 2012 to regain mechanical integrity. It had been on an AA for a few years prior to the WO which means we have a number of older temp surveys showing that the injected fluids were always contained to the approved injection intervals. Although re-perfed in July 2012, no additional pools or sands were added with those sets of perfs. The last 4 1/2 yrs the well has maintained mechanical integrity and the most recent 90 day TIO plot (attached) shows no indication of a pressure increase leading up to last night's pressure changes. 2 The Bingham pump supplyinivater to the leg room with the G-05RD well runs smoothly with the well online. The loss of the water going into this well puts the pump at the bottom of its pump curve and makes stable injection more difficult. This is another reason why we aren't requesting any diagnostic downtime,just a temporary return to injection followed up by the 12 hr shut-in temp survey to confirm injection containment. As the plan forward, Hilcorp would like to request a temporary injection period of 1 - 2 weeks to establish a stable downhole thermal profile. A new 12 hr shut-in temp survey will be overlaid with an older baseline to confirm the containment of the fluid exiting the casing at the peas. The results of this overlay will determine whether a request for continued injection under an Admin Approval will be proposed or not. Please let me know if anything else is needed to proceed with this request. Thank you Larry From: Travis McCaughey Sent: Tuesday, May 31, 2016 4:38 AM To: Larry Greenstein Cc: Kenneth Wingard Subject: Grayling - G-05RD IA Pressure UPDATE Pressure increased through the night to 2100. Well SI @0430. Thank you Travis From: Travis McCaughey Sent: Tuesday, May 31, 2016 12:42 AM To: Larry Greenstein Cc: Kenneth Wingard Subject: Grayling - G-5 IA Larry, Noticed A-5 IA has jumped up from 280-1700. How would you like us to proceed?Thank you. Travis Grayling 3 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning proiect. They are available in the original file and viewable by direct inspection. /~- / .~:7 File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA [] [] OVERSIZED Diskettes, No. Other, No/Type Logs of various kinds Other Complete COMMENTS: Scanned by: Bevedy Mildred Dareth;~n Lowell Da,e: ~/~( Is, ~ TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha~owell RECEIVED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 2 4 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate 1=1 Other Complete Performed: Alter Casing ❑ Pull Tubing G Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeIII❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ 198-120 .. 3. Address: 3800 Centerpoint Drive, STE 100 Stratigraphic ❑ Service G 6. API Number: Anchorage, AK 99503 50- 733 - 20060 -01 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 Trading Bay Unit G -05RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): 4. McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured 10,650 feet Plugs measured N/A feet true vertical 9,968 feet Junk measured N/A feet Effective Depth measured 10,559 feet Packer measured 9,263 feet true vertical 9,330 feet true vertical 8,056 feet Casing Length Size MD TVD Burst Collapse Structural 367' 26" 367' 367' Conductor 591' 16" 591' 591' 2,630 psi 1,020 psi Surface 3,078' 13 -3/8" 3,078' 3,016' 2,730 psi 1,130 psi Intermediate Production 7,257' 9 -5/8" 7,257' 6,297' 5,750 psi 3,090 psi Liner 3,711' 7" 6,936'- 10,647' 6,811'- 9,964' 8,160 psi 7,020 psi Liner �^'; 1.: ! Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematic feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# / L -80 9,313' (MD) 8,105 (TVD) Packers and SSSV (type, measured and true vertical depth) �v 1 q /wiz. Baker S -3 Packer 9,263' (MD) / (TVD) SSV N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 7000 500 2900 14. Attachments: 15. Well Class after work: .. Copies of Logs and Surveys Run Exploratory ❑ Developmentt❑ Service O Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: i Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ S WAG ❑ GINJ ❑ SUSP❑ S PLUG ❑ 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 -205 Contact Michael Dunn Printed Name Michael Dunn Title Sr. Reservior Engineer Signature 1f- Phone 907177 -8382 Date 8/24/2012 R$DMS AUG 2 8 23124 V'' 2 61 ' 1 0//2/ Form 10 -404 Revised 11/2011 Submit Original Only H • McArthur River Field, TBU Well: G -05RD As Completed: 7/7/98 Hilcorp Alaska, LLC SCHEMATIC Casing Detail RKB to TBG Hngr = 42.70 SIZE WT GRADE CONN ID TOP BTM. CMT Tree connection: 4 - 1/2" 5,000# 26" Surf. 367' 2 ,] Butt Surf. 591' 1398 sx LLLd --- 13 -3/8" 54.5 K -55 Butt 12.615 Surf. 3,078' 2600 5'x 16° Redrill 7,257' € Window 13 - 3/2 9 - 5/8" 47 N - 80 Seal Lock 8.681 6,925' 7,257' " 9 - 5/8" 43.5 N - Seal Lock 8.755 5,187 6,925' " DV Collar 9 -5/8" 40 N -80 Seal Lock 8.835 79' 5,187 @ 4,376' 9 -5/8" DV Collar 4,376' 4,378' 9 -5/8" 47 N -80 Seal Lock 8.681 Surf. 79' " 7" liner 29 L -80 Buttress 6.184 6,936' 10,647' Tubing Detail l■ 4 - 1/2" 12.6 L - 80 I IBT 3.958 Surf 9,313' Jewelry Detail Sidetrack Whipstock No Depth Item KOP 7,257' 1 9,263' Baker 5 -3 Packer 2 9,302' "BXN" Nipple 3 9,313' WLEG Perforation Detail . ' Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Present Condition G -2 9,475' 9,500' 9,013' 9,032' 25' 5 7/22/2012 TCP perf G -2A 9,508' 9,548' 9,038' 9,068' 40' 5 7/22/2012 TCP perf G -3 9,562' 9,602' 9,078' 9,108' 40' 5 7/22/2012 TCP perf G -4 9,638' 9,708' 9,135' 9,187' 70' 5 7/22/2012 TCP perf G -5 9,752' 9,848' 9,220' 9,294' 96' 5 7/22/2012 TCP perf HB -1 9,995' 10,020' 9,410' 9,430' 25' 5 7/22/2012 TCP perf it cjimilk Jog IMF _v_iM. HB- 3 &4 10,160' 10,192' 9,546' 9,572' 32' 5 7/22/2012 TCP perf d HB- E 3 &4 10,205' 10,315' 9,583' 9,675' 110' 5 7/22/2012 TCP perf PERFORATION DATA (last perforated 9/16/98) .= G -2 =G -2A G -2 9,470' 9,495' 25' 6 7/6/1998 TCP perf a G -3 9,478' 9,493' 15' 4 9/16/1998 2 -1/8" Power strip G -4 G -2A 9,530' 9,545' 15' 6 7/6/1998 TCP perf G -5 9,508' 9,540' 32' 4 9/16/1998 2 -1/8" Power strip B G -3 9,565' 9,595' 30' 6 7/6/1998 TCP perf FE' = 9,563' 9,588' 25' 4 9/16/1998 2 -1/8" Power strip G -4 9,635' 9,700' 65' 6 7/6/1998 TCP perf 9,638' 9,688' 50' 4 9/16/1998 2 -1/8" Power strip TO @ 10,445' G -5 9,750' 9,850' 100' 6 7/6/1998 TCP perf possibly wireline 9,753' 9,815' 62' 4 9/16/1998 2-1/8" Power strip B 1 9,995' 10,020' 25' 6 7/6/1998 TCP perf 9,995' 10,020' 25' 4 9/16/1998 2 -1/8" Power strip Plug Back Depth = 10,559' B -3 &4 10,205' 10,315' 110' 6 7/6/1998 TCP perf Bottom of Liner = 10,647' 10,160' 10,192' 32' 4' 9/16/1998 2 -1/8" Power strip TD = 10,650' MD/9968' TVD 10,210' 10,242' 32' 4' 9/16/1998 2 -1/8" Power strip MAX HOLE ANGLE = 42° 10,270' 10,302' 32' 4' 9/16/1998 2 -1/8" Power strip Last Updated: 8/24/12 by TDF • 11 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -05RD 50- 733 - 20060 -01 198 -120 6/15/12 7/26/12 Daily Operations: 06/21/2012 - Thursday R/U E -Line M/U 2" Gauge. TIH Tag @ 9,198'. POOH. TIH w/ hole punch 9,192' to 9,195'. POOH. M/U 2" RTC cutter. TIH & fire cutter @ 9,190'. POOH. Lost 2.7" Gauge & 2" bar from under gun. R/D E -Line and start nippling down tree. 06/22/2012 - Friday R/U E -Line set CIBP @ 83" from hanger in 4 -1/2" tubing. Stack BOPS, Hy -Dril, Kill lines, Choke lines. Run accumulator lines, fill tubing close blinds & test to 1,000 psi. Casing holding @ 10 psi. R/U HYD Choke & Lines. Run & function test accum lines. 06/23/2012 - Saturday Finished R/U HCR Valves, HYD Choke & Pre test BOPS. Testing BOPS with State Rep. Attempt to close annular & annular failed. Nipple down annular & remove for replacement. Waiting on annular. 06/24/2012 - Sunday Install replacment annular and tested. Tested 4.5" variable rams 200 psi low / 3,000 psi high. Run spear with grapple and latch tubing, pulled 125k unable to release hanger. Call for e-line crew with jet cutter. Continue to work on hanger with no movement. Release spear and POOH to inspect spear for damage. RIH two foot deeper and latch, attempt to pull hanger with no success. Pull up to 135K lock brake, using hammer attempt to shock hanger with multiple strikes to workstring. Release spear and wait on e-line crew. 06/25/2012 - Monday Rig up e-line, make up jet cutter, work tools in hole. Unable to get below 68 feet. Decision made to cut tubing. Rig down e- line. Rig up 2 accelators, oil jars, crossover and tubing spear, engage tubing below hanger, work tools in attempt to warm jars. After 5 jar strokes hanger released. POOH and lay out hanger assembly. Recovered hanger, + 2.5' pup joint and 15.58' cut joint. Pick up BHA and move to rig. Rig up power swivel on BHA RIH to top of fish at 68' engage swivel and mill top of flaired tubing using Piranaha mill. Mill and circulate on fish. 06/26/2012 - Tuesday Milled and circulated on top of flaired tubing, made 1 foot. Remove power swivel tied into the derrick. Attempt to remove mill. Preparing BHA to make outside cut. Pickup washpipe (8 -1/8" OD) begin threading up, torqued, lower down and tag top of fish @ 110' RKB. Pick up Jar BHA and make up to crossover. RIH, fish tagged into top sub, pick up power swivel and prepare to make mechanical cut. Pick up w /18k weight including rig block, pull up slowly. At 15 ft engage 4- 1/2' tubing collar, pull 2k over weight to shear retainer pins. Slack off 14 feet engage power swivel and rotated over fish in attempt to cut tubing. Shut down power swivel and PUH to tag collar. No indication of collar at same depth. Indicates tubing is cut and inside wash pipe. Remove swivel and crossover from top of washpipe. 4 -1/2" tubing wash pipe with visble fluid level in tubing indicates CIBP in cut tubing. Rack jar assembly. Pick up spear to pull tubing from washpipe. Rack washpipe, pick up 3 joints of 5" drill pipe. Recovered 64.90' of 4 -1/2" tubing string (cut) with CIBP. Laydown bottom section of washpipe, pickup 3 joints of 5" drill pipe and 1 joint of 4 -1/2" pipe. Pick up overshot and begin making up BHA. Dress overshot with tubing grabble for 4 -1/2" tubing. Latch tubing and insure proper catch depth. Pull up on fish to 165K, set slips. Install tubing clamps, relax block and begin rigging up E -line. E -line rigging up with jet cutter for 3 -1/2" tubing. Prepare to RIH to obstruction. • • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -05RD 50- 733 - 20060 -01 198 -120 6/15/12 7/26/12 6/27/2012- Wednesday RIH with a -line, 2.70" jet cutter assembly , sat down at 8145' pull up tools stuck in collar. Work cable and tubing for 30 minutes, slipping up hole, tools free, POOH to inspect tools. Rehead pick up 2.70" guage ring, added a -line jars, RIH with gauge ring, tag obstruction 8145, same depth. Attempt to work thru obstruction, unable. RIH with orbital cutter to top of obstruction at 8145, prepare to cut 3 1/2" tubing , Cut is confirmed, POOH with a -line, rig off a -line, and latch on tubing with block, pull up hole, hanging weight is 102,000Ibs and tubing is free. Laying down 4 1/2" landing joint plus 3 joints of drill pipe, remove overshot, pull up to first collar, remove partial joint, install TIW. As per State of Alaska inspector, circulate well at 3 bbls /min full circulating volume. Rig down pump lines, make up air slips for 4 1/2" tubing. Latch on to tubing and begin pulling and laying down single, at report time we have 70 joints of 4 1/2" tubing ( 2,198 ft ) on the deck. 6/28/2012 - Thursday v Continue o eration pulling 4-1/2" 10-20, tubing looks s u and laying down 4 1 2 production tubin check NORM, range from 10 0, tub oo s good with some internal scale. Out of hole with all 4 -1/2" production tubing, change air slips to handle 3 -1/2" change out elevaors for 3 -1/2" 8rd tubing upset. Function test BOPS against 3 -1/2" tubing. Pulling out of hole with 3 -1/2" production tubing, racking, checking NORM. Out of hole with 3 -1/2" production tubing. Total joints 41 full joints plus 22' of cut joint. Rig down elevators and pick up elevators for 2 -7/8" PH -6 workstring, replace tongs to handle BHA, change slips for BHA, make up overshot. BHA ( grapple to catch 3 -1/2" tubing, Oil Jar /bumper jar combo, 6 Drill collars, Acc Jar, Top sub back to 2 -7/8" PH -6) ; Change out tongs to handle PH6 , replace air slips. RIH with BHA, picking up workstring, tally new layer of PH6, continue running in hole ; Pick up tally, drift and rih with workstring to latch fish (3 1/2" production tubing). RIH with BHA and workstring, at time of report, 53 joints in hole (1653.60) and BHA length of (226) total depth 1879.60. 6/29/2012 - Friday Replaced tongs, and elevators, continue in hole with BHA and workstring. Continue ops,running joint # 160 = depth of 4,992' + 226' BHA; RIH with work string and BHA to latch 3 -1/2" tubing at appx 8,182' currently have 190 joints in hole (5928' plus 226 BHA = 6,154'). Continue Running in hole with BHA; RIH with BHA and work string, picking up Joint # 252 (7,862.40) plus BHA (226) current depth 8,088 feet. Tag top of obstruction at 8090, PUH lay down joint, pick up swivel make up joint. RIH and tag obstruction @ 8,090'. Pull up engage fish, begin jarring at 140K add torque on downstroke. Continue to jar and put right hand torque when slacking off, jarred at 140K, for 1 hour, weight dropping prior to jar stroke, fish came free. POOH rack drill collars, pull up to overshot, NO FISH, inspecting equipment now. Deep gashes on the bottom of overshot. 6/30/2012 - Saturday Pick up carbide shoe, washpipe, and jars, drill collars to go in hole. RIH with BHA to top of obstruction, (6" carbide shoe, 6 jts of wash pipe, jars, drill collars and acc jar) ; Ran stands in hole to top of fish, pick up power swivel, hook on to single joint, tag @ 8109' rotating on obstruction. Wash to 8,310' with top of fish internal at 8,113'. Currently pulling out of hole with workstring and BHA. • • 11 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -05RD 50- 733 - 20060 -01 198 -120 6/15/12 7/26/12 7/1/2012 - Sunday OOH with BHA, (carbide shoe, wash pipe assembly). Prepare overshot and BHA for next run. Waiting on State of Alaska for BOPE test, waived will perform Sunday. RIH with BHA, tag fish at 8,113'. Using power swivel rotate over fish, engage slips, pull 120K, set down weight with bumper jars to fully engage, pull 140K begin jarring on fish. Jar at 140K while adding right hand torgue and slacking off, continue to jar, came free. POOH w/ overshot. Expose overshot, have 3 1/2" tubing in the overshot. make up tongs to begin laying out 3.5" tubing swing to pipe rack and tally length. Recovered 33 full joints of 3 1/2" production tubing with 9 ft cut joint in the overshot and 4.5' cut joint on bottom. 7/2/2012 - Monday Perform BOPE Test. Test Annular to 250psi low/ 1,500psi high. Complete test. RIH with BHA, and 125 stands of 2 -7/8" PH- 6 plus 34 single joints of 2 -7/8" PH -6 to reach top of cut pipe @ 9,191'. RIH with single joints to reach top of fish. 7/3/2012 - Tuesday Pick up power swivel, and begin operations. Begin washing over fill and making hole. Continue to mill over obstruction, recovering metal shavings, scale and other materials. POOH with workstring & BHA. Remove wash pipe and shoe. Pick up 3.5" overshot, jars, drill collars, and acc jars make up workstring and begin tripping in hole. Running in hole with BHA and workstring. 07/04/2012- Wednesday Running in hole with BHA to overshot tubing and packer assembly. On btm with BHA and pick up two single joints. Tag top of fish and sit down weight. Moving downhole, pick up 10k over and sit down weight. Pick up on fish pulling 10K over pull. Pick up full joint laying down both singles and POOH racking doubles in the derrick. Pulled 8 stands and weight dropped off. Pick up stand and RIH tag obstruction at casing collar. Attempt to latch, continue to move down. POOH. OOH with BHA. Pick up 3.25" spear to latch internal of double ID in packer BHA. RIH with BHA and workstring. RIH with BHA to top of packer. Tag top of fish, chase down hole with three stands, sat down and added 30K down on fish. Pull 8K over and started tripping pipe. POOH racking double stands in the derrick with BHA (3.25" packer spear). Continue to POOH. 07/05/2012 - Thursday Y Continue to POOH. POOH racking doubles in derrick with BHA. At surface with racking drill collars. No fish in the spear. Checking tools to confirm markings on the grapple. Rebuilt the bottom of the tool into a mule shoe design with small upsets to move junk inside of packer in order to latch. Make up packer spear, oil jars, drill collars, accelerator jar and pick up workstring to RIH. RIH with BHA to top of packer @ 8,957' attempting to latch fish moving downhole. RIH with 3 additional stands and then pick up 9 singles, pushing packer downhole, currently at 9,483'. Pick up and run additional 10 joints of 2 7/8" PH -6 workstring @ 9,816' attempt to break circulation. Packer is moving downhole, pick up 10 joints of workstring current depth is 10,131'. Unable to latch into packer with spear. Call for piranha mill to go inside 3.250" packer body to remove junk. Pick up additional joint, move down hole 15 feet take solid. Work spear down in attempt to latch, rotate to right to move obstruction, no luck, rotate left to engage spear cannot latch. POOH. Current depth is 10,146' at the top of packer. Total overall length of fish from pkr top to WLEG is 77 ft. Called for eline. Rig up swivel and attempt to pump down workstring to break trash from the bottom port, pressure up to 3,000 psi and holding pressure. Waiting on eline and monitoring pressure on workstring for pressure drop. • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -05RD 50- 733 - 20060 -01 198 -120 6/15/12 7/26/12 07/06/2012 - Friday Pressure up on work string to 3,000 psi in attempt to circulate or break trash from spear. Rig up E -line to run in hole and punch circulating ports. RIH with eline tools, locate accelerator jars, and top sub. Pull thru 2 joints of workstring and correlate several times on depth. Pressure up on workstring. Continue to check collars and BHA depths, pulled up to center of 2 -7/8" workstring joint above BHA and fire guns. Out of hole with a -line, gun did not fire due to short in wiring. Repair and re -ran in hole, log on depth directly above BHA. Picked up into full joint of 2 -7/8" workstring. Verify several times to insure correct and above BHA, pump up to 400 psi, fire gun. POOH with E -line to rig down and begin pulling workstring and BHA. Punch holes @ 9,450'. Rig down E -line. Release a -line crew. Continue to pull workstring and BHA. OOH with workstring. Lay down and tag joint w /holes and rack two stands of drill collars. Third drill collars plugged, jars plug with scale. P/U carbide mill to clean 3.25" bore in packer. New set of oil jars and bumper. P/U 4 drill collars and workstring. RIH with 3 stands; P/U swivel, pump thru BHA at 3 bbls per minute to insure tools are clean. Begin RIH with BHA and workstring. RIH with Junk Mill to clean out inside ID of Baker packer. 07/07/2012 - Saturday On bottom with junk mill, circulating down tubing and up casing to prevent trash in the workstring. P/U 4 joints to continue to top of fish. Wash thru fill down to top of packer. Pickup power swivel and tag top of packer. Break circulation and pump 10 bbl HEC pill down tubing washing down and into top of packer. Begin milling ID of the Baker packer. Mill is taking torque, increase speed on the swivel and mill junk inside larger ID. Moving slowly into packer. Increase speed of the rotation on the power swivel while fanning the junk with carbide mill, making headway. Milling on metal junk inside ID of packer at 10,154' mill down 2 feet inside packer, continue to mill and circulate down workstring an up casing. Rotating at higher RPM on top of metal junk. Continue to mill on ID of fish making hole close to 3 feet inside the packer. Made full 3 feet inside ID, shut down pumps, laydown 1 joint, remove swivel and POOH racking doubles in the derrick. OOH with work string, racking back drill collars and jars to remove junk mill. Tally pipe while POOH to confirm depth. Remove mill for inspection. Pick up spear, make up equipment and BHA to RIH. 07/08/2012 - Sunday RIH with BHA and 2 -7/8" workstring. On bottom with spear, spacing out to sting into packer. Pick up power swivel and begin rotating to enter top of packer. Work spear by rotating right to enter top of packer, spudding down and turn to left to latch. Continue to use bumper jars to engage slips, carrying only 3k additional weight. Unable to re- engage fish POOH to inspect tools. Out of hole with spear. Metal marks all the way up the sides and grapple was sprung open. Pick up new BHA. RIH with Piranha mill to mill up packer down to 3 -1/2" tubing. RIH with BHA to mill out packer. 07/09/2012 - Monday RIH with piranha mill to top of packer. Continue in hole with BHA, 10 stands from top of fish. Pick up power swivel, install rubber in hog head for circulation and lower to top of fish at 10,146'. Fanning over top of fish milling on packer, continue to reverse circulate while milling packer. Milling over packer, made 4 feet 11 inches thru the packer and top of the mill out extension. Continue milling recovering large metal pieces. Continue milling with 7K down on fish and made additional 3 ft over fish. Milling collar on mill out extension. • • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -05RD 50- 733 - 20060 -01 198 -120 6/15/12 7/26/12 07/10/2012 - Tuesday Continue operations. Depth is 11 ft from start of milling. Seal receptacle is .92', SAB packer is 4.92', mill out extension is 5.35'. Circulating sweep to recover metal from milling operations. Laydown single joint, remove power swivel and rubber from Hog's head. POOH with workstring and BHA. Continue to POOH. Preparing for BOP test. 07/11/2012 - Wednesday Install control panel and pressure test. Start engines, test all rig equipment, remove TIW, open BOP's and begin tripping work string. POOH with work string and BHA. Rig up slickline to run in hole with 5" impression block, tag obstruction at 10,159'. POOH check impression. Re -run and hit harder, POOH. Impression of metal on one side of the block, check measurements agains current completion schematic. Make up plug on test joint and prepare to test BOP stack. Make up chart recorder and prepare for pressure test. Test BOP 200 psi low / 3,000 psi high. Move to Koomey for test. Remove test plug, install wear bushing, prepare for BHA assembly. Discuss BHA plan with Fishing Tool Supv. Begin rig up to RIH with BHA. 07/12/2012 - Thursday Function test BOPE. Short trip in hole with 1 stand plugged drill collars 20 stands tubing LD Collars Hole fill 6 bbl after 24 Hrs. P/U 2nd choice, Junk Mill, Boot basket, BS, Jars Collars 317 jts tbg. RIH to 10,160' est circ several attempts. Milling w 1 -2 k WOB torque 1,500 -3,000 after 1.5 torque evened smooth milling pumped 2 sweeps new cuttings evident. 07/13/2012 - Friday Milling pumping sweep 80 bbl lag on sweep circ tubing clean set back swivel. POOH. Stand back BHA LD Mill wear pattern shows 3.9 ID fish, good wear pattern indications fish possibly spinning. MU BHA w/ Dress of shoe 5 -3/4" OS 4 -3/4" Grapple Rupture disc sub, bumper sub, jars and collars. TIH w/ fishing assembly. PU Power swivel wash down 1 single and tag joint to 10,162' + - work over fish top 30k -10k max overpull no pump pressure increase LD 2 singles 10k. POOH w 10K drag lost drag indications 12 -15 stands off bottom. 07/14/2012 - Saturday POOH w BHA overshot empty, cutlip scarred internally 2" OD junk scarred 4" above cutlip. MU 6" OD x 4 -7/8" Burning shoe on 1 stand WP jarring assembly and 1 stand hang in slips. RIH with washover assembly. Rig up power swivel, single tag on fish top @ 10,160' + -. Attempting to continue washing over fish. Significant metal cuttings in returns that are not being created from this run. 07/15/2012- Sunday POOH with washover aassembly. Shoe worn smooth very little ID wear bottom joint wash pipe scarred. MU BHA 5.75" OD wavy shoe 1 jt washpipe Washpipe ext w/ wire grabs 1 jt washpipe and jarring BHA total length 230.21'. TIH with pipe from derrick. 07/16/2012 - Monday TIH with washover assembly. PU power swivel, Wash /Burn over fish 1.5 feet then gained 5 feet mill over <1. Fish moving down hole depth 10,171'. Losing hole stalls and high torque. RD power swivel clean trap found 0 -ring possibly from hydraulic section of packer, back up ring, and shale. POOH for overshot run, LD 2 joints wash pipe, bottom approx 18" hydraulic section of packer in shoe matching circ recovered o -ring. MU washpipe BHA with wireline grab 1 joint up and jarring assy. TIH w/ wash over assy. • • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -05RD 50- 733 - 20060 -01 198 -120 6/15/12 7/26/12 07/17/2012 - Tuesday TIH w/ washpipe assy pick up swivel. Tag up on top of fish burning over x -over approx 1 foot. Scale and possibly some formation in returns, stalling and packing off making no hole. POOH string was pulling wet, noticeable still 60 stands from surface. Pull BHA no Fish scarring on burning shoe internally only light spiral. TIH w 5 -3/4" OS w 4 -3/4" grapple and cutlip guide during trip did rig check. POOH pipe was not coming, wet suction was open, tank volume down. Pick up power swivel wash to TOF @ 10,171 + -'. Work fish with bumper sub move 3' overshot slipping off or fish free. POOH. 07/18/2012- Wednesday POOH to BHA. Stand back and lay down BHA, Overshot shows fish engagement approximatelly 1' shy of grapple no major OD scarring cutlip sligtly flared . Make up new Milling BHA Wavy bottom shoe, wire grab extension bumper sub, jars, collars, accelerators x -over and 2 -7/8" Tbg Shoe OD 6" ID 4 -.75 ". RIH with pipe out of Derrick. Tag TOF wash and ream. Wash over fish 25' circulating heavy metal cuttings/ scale. 07/19/2012 - Thursday Continue wash over of fish total length of WP 43' circulate heavy dense metal cuttings mixed with scale. Circ Bottoms up x 2 stand back swivel and POOH. Washpipe empty but BHA has been over fish to top of Drive sub. MU Short catch OS and Fishing assy. RIH 158 stands. PU power swivel, wash over and latch fish, work same to 130K set back power swivel. Install TIW valve jar on fish to 130K. Fish free. POOH. 07/20/2012 - Friday POOH with BHA lay down fish and break all fishing tools. RIH with collars and lay down. Make up 6" OD Piranah Mill and 7" casing scraper x -over and RIH with pipe in derrick single in and Tag @ 10,231'. PU Power Swivel and continue milling crushed shale packing st mill face torque difficult milling to 10,245'. Milling ahead at 10,455', getting metal in returns which is new junk. Size indicates possible small wireline string plugging off on tag. 07/21/2012 - Saturday POOH lay down 38 jts and pull 2 stands. MU storm packer RTTS. RIH w storm packer cannot get past wear bushing, recieve x -over pull wear bushing ID 9 ". RIH w 2 stands and set RTTS at 9,621'. Lay down 4 singles. Rig down rig floor and set back. ND BOPE Riser and wellhead spacer, NU wellhead. 07/22/2012 - Sunday Continue wellhead installation and testing. Welding pad -eyes on base beam off operator side base beam. Install /test wellhead NU riser & BOPE. Test pipe rams 200 psi low / 3,000 psi high. Witness of test waived by Jim Regg of AOGCC. LD test plug and PU RTTS retrieving head. RIH engage and release packer, fill hole. POOH and lay down packer. POOH with Mill /Scraper assy lay down same. RIH w Gauge carrier and 41 Guns 4 -1/2" OD space out jts. 07/23/2012 - Monday MU Packer and RIH space out RA sub 1 jt above packer plus 9,336' tubing. Rig Up E -line for GR correlation. Correlate per supplied Log adjusted depth up 16'. Set packer @ 9,336' pressure annulus to 600 psi. Attempt to fire guns 3 full cycles per SLB procedure. Monitor well and Fill 5 bbls. POOH Laying down workstring. Continue POOH laying down work string. Y , • • • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -05RD 50- 733 - 20060 -01 198 -120 6/15/12 7/26/12 07/24/2012 - Tuesday POOH with workstring. LD gun assembly RD Schlumberger. Change rams to VBR. Pick up handling tools and tongs, strap BHA and pipe prepare to run casing .PU WLRG and Nipple profile joint and Packer. Rabbit and RIH w 4.5" 12.6# L -80 IBT connections. 07/25/2012 - Wednesday Rig Up slickline make gauge ring to pump out ball disc sub. Tag where disc sub fell through. RIH to 9,360 didn't see wireline re -entry guide on weight indicator. POOH. M/U 3.81 plug. M/U and pressure test lubricator per productions instructions and monitor. RIH and hit fluid level unexpectedly at 1,050'. RIH to profile @ 9,303' cannot get plug to latch. POOH to see if pin sheared hitting fluid level too fast. No Shear but seals damaged and some missing rubber. Redress and sand down seal OD and dress of no go stop for scars. RIH with redressed plug and attempt to set. Ordered N test plug for AM. Run scars on x -plug indicate problems in no go. Seal not damanged, N test plug should not be affected. Well secured. 07/26/2012 - Thursday Rig up wireline. RIH with N test plug and set in Nipple. Pressure up to 3,500 psi, expansion pressure on annulus 250 psi. POOH with wireline and rig down. Pressure test annulus to 2,500 psi and chart. Hold for 30 minutes. Bleed off pressure, remove pressure hose from wellhead, replace plugs, release well to Production operations. P IR�1 wo Regg, James B (DOA) From: Brooks, Phoebe L (DOA) Sent: Friday, August 03, 2012 10:02 AM A ? J To: Larry Greenstein ( , l z ' Cc: Paul Langley - (C); Regg, James B (DOA) Subject: RE: MIT report for Well G -05RD workover (PTD# 198120) Attachments: MIT G -05RD 07- 26- 12.xls Larry, Attached is a revised report for MIT G -05RD 07- 26 -12. I've included 3500 in the tubing data per Jim Regg. I also changed the type of injection from "P" to "W" and the type of test from "W" to "P" (I believe these two fields were swapped). Thank you, Phoebe Phoebe Brooks �� Statistical Technician II NEB N'jiA'1 c `? Zri3 Alaska Oil and Gas Conservation Commission Phone: 907 - 793 -1242 Fax: 907- 276 -7542 From: Larry Greenstein [ mailto:lgreenstein @hilcorp.com] Sent: Thursday, August 02, 2012 6:18 PM To: Regg, James B (DOA) Cc: Mike Dunn; Wayne Johnson; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Wallace, Chris D (DOA); Paul Langley - (C) Subject: RE: MIT report for Well G -05RD workover (PTD# 198120) That is correct, Jim, this was the pre- injection or WO MIT prior to bringing G -05RD online. The e -mail has already gone out to the field guys to remind them to let you know the timing for the initial MIT after the well stabilizes thermally. I've pulled the TVD of the new packer depth to partially complete the MIT form (attached) and I did receive the scan (attached) of the pressure test. Sorry for the incomplete report. Larry From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Wednesday, August 01, 2012 9:18 AM To: Paul Langley - (C) Cc: Mike Dunn; Wayne Johnson; Larry Greenstein; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: RE: MIT report for Well G -05RD workover I am assuming this is supposed to be your pre - injection MIT as required by Area Injection Order 5, Rule 5 ( see attached). MIT report is incomplete. Did you chart test? If so, scan and send. Jim Regg AOGCC 1 . • • • 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 From: Paul Langley - (C) fmailto:plangley@(Philcorp.coml Sent: Monday, July 30, 2012 5:18 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Mike Dunn; Wayne Johnson Subject: RE: MIT report for Well G -05RD workover Sorry, attached the wrong copy From: Regg, James B (DOA) [mailto:jim.regg(aalaska.gov] Sent: Monday, July 30, 2012 5:09 PM To: Paul Langley - (C); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Mike Dunn; Wayne Johnson Subject: RE: MIT report for Well G -05RD workover Send excel version Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 From: Paul Langley - (C) [mailto:plangleyhilcorp.com] Sent: Monday, July 30, 2012 4:54 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Mike Dunn; Wayne Johnson Subject: MIT report for Well G -05RD workover Ms. Brooks Please find the attached MIT report for G -05RD PTD 198120 for your records. Please advise if you require the charts as well. Regards Paul Langley WSM Grayling Platform Hilcorp Alaska LLC 1 2 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaq(rDalaska.gov, doa.aoocc.prudhoe.bay alaska.aov; phoebe.brooks(d)alaska.aov OPERATOR: Hilcor p Alaska, LLC FIELD I UNIT I PAD: McArthur River/Trading Bay Unit/Grayling Platform • l j 4 { Y DATE: 07/26/12 OPERATOR REP: Paul Langley AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well G -05RD Type Inj. W TVD 8,856' ' Tubing 0 ' 3,500 - 3,500 3,500 Interval 0 P.T.D. 1981200 Type test P Test psi 2214' Casing 0 2,550 - 2,550 '2,550 PIF P ' Notes: MD of pkr = 9266' OA Tbg pressure test done during WO Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing PIF 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 Inj. 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 G 07 - 26 - 12 • P iggiawo Regg, James B (DOA) From: Wayne Johnson [wjohnson @hilcorp.com] it v Sent: Wednesday, August 01, 2012 2:13 PM �� To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: Paul Langley - (C) Subject: RE: G -5 Jim They did pressure the tubing to 3500# to the packer, it was held actually longer than 30 minutes but they did not have a Barton meter on it. The casing was pressured tested to 2550# for 30 minutes and was attached to a Barton Meter which is the chart you received. Wayne Johnson Foreman Hilcorp Alaska, LLC Grayling Platform` 0 201 Office: 907 - 776 -6632 SEWED Fax: 907- 776 -6635 Email: wjohnsonPhilcorp.com From: Regg, James B (DOA) [mailto jim.regg @alaska.gov] Sent: Wednesday, August 01, 2012 1:57 PM To: Wayne Johnson; Brooks, Phoebe L (DOA) Cc: Paul Langley - (C) Subject: RE: G -5 So, Tubing = 3500psi and IA =2550 psi for the entire 30 min test? Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 From: Wayne Johnson fmailto:wjohnson@hilcorp.coml Sent: Wednesday, August 01, 2012 9:26 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: Paul Langley - (C) Subject: FW: G -5 Jim, Here is the chart for G -5RD Wayne Johnson Foreman 1 • • Hilcorp Alaska, LLC Grayling Platform Office: 907 - 776 -6632 Fax: 907 - 776 -6635 Email: wjohnsonPhilcorp.com From: Wayne Johnson Sent: Monday, July 30, 2012 4:50 PM To: Larry Greenstein Cc: Mike Dunn Subject: G -5 Paperwork for G -5RD. Wayne Johnson Foreman Hilcorp Alaska, LLC Grayling Platform Office: 907 - 776 -6632 Fax: 907 - 776 -6635 Email: wiohnson@hilcorp.com 2 �� U Mr 5s 7 A fr -135 B f__.._.. -120 \ . �\ p ° 10 5 - :_ --_— QO O 5 O p 7 ( ‘ . ' a° 90 J.13 .0 _ 3000 11 , .-- , . Er . ~ - 50 0 • 5 ' o 60 O 2000 % / Zg6 .� 45 /50 \ , : s _- - . s -tia 2 1 000 ' ? #!sI i . CORPORATION~ o O Ca lta ' 1 .-- P.) ' CHART N0. MC MP 5000 150E cr Z.1-1 o 0... o, u 0 0 0 0 . .0 0 0 o A,` 't 0 0 0 0 '' METER O Z 8 i CHART PUT ON TAKEN OFF C72 11111 Z � O dT O O O.. O O O. M N N O n.\ LOCATION c., ,- \ \ \ REMARKS 3 D ,L1 Ij - O A \ \ Co 0 - / / g , . 717.C4 . / / C%i / / -,- * 0 . i ii. :* .6 / P.' �c \ 00 0! 0� 2 w O•.- _ p00 c o �! 00 " 4 09 000c" • S L" . 00 7,- / • • 'emu C -0 s Regg, James B (DOA) Eq6 I'O From: Regg, James B (DOA) Sent: Wednesday, August 01, 2012 9:18 AM To: Paul Langley - (C) Cc: Mike Dunn; Wayne Johnson; Larry Greenstein; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: RE: MIT report for Well G -05RD workover Attachments: aio5.pdf I am assuming this is supposed to be your pre- injection MIT as required by Area Injection Order 5, Rule 5 ( see attached). MIT report is incomplete. Did you chart test? If so, scan and send. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 7934236 From: Paul Langley - (C) [mailto:plangley@ hilcorp.com] Sent: Monday, July 30, 2012 5:18 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Mike Dunn; Wayne Johnson Subject: RE: MIT report for Well G -05RD workover Sorry, attached the wrong copy From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, July 30, 2012 5:09 PM To: Paul Langley - (C); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Mike Dunn; Wayne Johnson Subject: RE: MIT report for Well G -05RD workover Send excel version Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Paul Langley - (C) [mailto:plangley(ahilcorp.com] Sent: Monday, July 30, 2012 4:54 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Mike Dunn; Wayne Johnson Subject: MIT report for Well G -05RD workover Ms. Brooks Please find the attached MIT report for G -05RD PTD 198120 for your records. Please advise if you require the charts as well. Regards 1 • • • Paul Langley WSM Grayling Platform Hilcorp Alaska LLC 2 4 1` • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test n _ ' Submit to: jim.recion:alaska.gov; doa. aogcc.prudhoe.bay(a)alaska.aov; phoebe.brooksealaska.gov 17 & ?9 �" \` OPERATOR: Hilcorp Energy LLC FIELD / UNIT / PAD: McArthur River Field/Trading Bay Unit/Grayling DATE: 07/26/12 OPERATOR REP: Paul Langley AOGCC REP: No Witness Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well G -05RD Type Inj. W TVD 9,266' Tubing 3,500 Interval 1 P.T.D. 198120 Type test M Test psi 2550 Casing 2,550 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 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 TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Dnlling Waste M = Annulus Monitonng 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 G - 05RD 73 3 t C -c S,eD t Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, June 20, 2012 4:56 PM ‘6e 61 Z6/ ( To: 'Wayne Johnson' Cc: Schwartz, Guy L (DOA) Subject: RE: Floor safety valves on Grayling (Williams #404) Approval granted for TBU G -5RD (PTD 19810) only at this time. TIW must be made up with crossover while pulling 6800+ ft of 4.5" tubing and readily accessible near the well. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Wayne Johnson [mailto:wjohnson(ahilcorp.com] Sent: Wednesday, June 20, 2012 3:51 PM To: Regg, James B (DOA) Subject: RE: Floor safety valves on Grayling (Williams #404) G -05rd ''J'.��1L € C:E PTD: 198 -120 Thanks From: Regg, James B (DOA) [mailto:jim.regg@aalaska.gov] Sent: Wednesday, June 20, 2012 3:49 PM To: Wayne Johnson Cc: Mike Dunn; Claude Owen; Grimaldi, Louis R (DOA) Subject: RE: Floor safety valves on Grayling (Williams #404) Which well? Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 From: Wayne Johnson [mailto:wjohnsonCa�hilcorp.com] Sent: Wednesday, June 20, 2012 3:39 PM To: Regg, James B (DOA) Cc: Mike Dunn; Claude Owen; Grimaldi, Louis R (DOA) Subject: Floor safety valves on Grayling (Williams #404) Mr. Regg We have only a 3 %2 EUE 8rd floor safety valve (TIW). Is it okay if we pull our 4 %2 X 31/2 completion with this valve. We have verified that our radial torch for the 4 1/2 tubing if needed will clear the drift of the floor valve. Drift of the 3 %2 TIW 1 • is 3 1/8 id. We have exhausted our reerces for a 4 tubing valve. We will be ordering 2 from down south hopefully in two week delivery if possible. Please CC Mike Dunn or Dave Owen in case I have my computer off for waiver. Thanks Wayne Johnson Foreman Hilcorp Alaska, LLC Grayling Platform Office: 907 - 776 -6632 Fax: 907 - 776 -6635 Email: wiohnsonPhilcorp.com 2 • • rir 97-2 Fr U 1J GT AILAMA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Michael Dunn 1 Senior Reservoir Engineer �� { �` Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock 86 Middle Kenai G Pool, TBU G -05RD Sundry Number: 312 -205 Dear Mr. Dunn: rtiLitANED ��'i 3 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. Commissioner 71‘ DATED this day of June, 2012. Encl. • • RECEIVED , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 0 5 2012 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing 0 Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Reperforate & Recomplete , is 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Development ❑ Exploratory ❑ 198 -120 3. Address: Stratigraphic ❑ Service Ei • 6. API Number. 3800 Centerpoint Dr., Suite 100 Anchorage, Alaska 99503 50 -733- 20060 -01 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El Trading Bay Unit G -05RD ` 9. Property Designation (Lease Number): 10. Field/Pool(s): Trading Bay Unit (ADL- 00017594) McArthur River Field/ Hemlock & 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): 10,650 • 9,968 . 10,337' 9,694 N/A N/A Casing Length Size MD TVD Burst Collapse Structural 367' 26" 367' 367' Conductor 591' 16" 591' 591' 2,630psi 1,020psi Surface 3,078' 13 -3/8" 3,078' 3,016' 2,730psi 1,130psi Intemiediate Production 7,257' 9 -5/8" 7,257' 8,160' 5,750psi 3,090psi Liner 3,711' 7" 6,936'- 10,647' 6,811'- 9,964' 8,160psi 7,020psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,470 - 9,495; 9,508-9,545; 9,563- 9,595; 9,009 - 9,028; 9,038 - 9,065; 9,079- 9,103; 4 -1/2" 12.6#/ L -80 6,879' 9,635 - 9,700; 9,750 - 9,850; 9,995- 10,020; 9,132 - 9,181; 9,219 - 9,296; 9,410- 9,430; 10,160 - 10,315 9,545 -9,675 3 -1/2" 9.3#/ L -80 9,368' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): SAB -1 Packer and N/A 9,291(MD)/ 8,875'(TVD and N/A 12. Attachments: Description Summary of Proposal Ill 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Development ❑ Service El - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/14/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ El - 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 Tom Fouts Phone 907- 777 -8398 Printed Name Michael Dun Title Senior Reservoir Engineer Signature 1,f� Phone 907-777 -8382 Date 6/4/2012 / � V e%' /' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 311 2 O Plug Integrity ❑ BOP Test 'e Mechanical Integrity Test V Location Clearance ❑ Other: re5/ BOP 1 3000 pss l • �, , ; f 5 e e to r S .►-1 cl , ca i / f y r� Subsequent Form Required: A ® dl- 0 APPROVED BY Approv d by: COMMISSIONER THE COMMISSION Date: ; /,/ 2 � 1 / B r ' JUN z ff ob. gr • rm 10-403 Revised 1/20 V( I y G� �`�� S ubmit in Duplicate �✓ • • Well Work Prognosis Well: G -05RD Hilearp Alaska, LLC Date: 06/01/2012 Well Name: G -05RD API Number: 50- 733 - 20060 -01 Current Status: SI Injector Leg: Leg #4 (SW corner) Estimated Start Date: June 15, 2012 Rig: William Rig 5 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 198 -120 First Call Engineer: Mike Dunn (907) 777 -8382 (0) (907) 351 -4191 (M) Second Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 AFE Number: Budgeted Cost: Current Bottom Hole Pressure: — 3500 psi @ 9295' TVD (mid pert of 9850' MD) Maximum Expected BHP: — 3500 psi @ 9295' TVD (No new perfs being added) Max. Allowable Surface Pressure: 0 psi (Using 0.435psi /ft to surface) Brief Well Summary G -05RD is a shut -in G -Zone and Hemlock injector. It is located on the west flank of the main structure, just north of the Grayling platform, and when injecting, supporting offtake near the northern end of the crest. The well was sidetracked slightly updip in July 1998 and completed with 3 -1/2" and 4 -1/2" tubing and a permanent packer. The G -zone and Hemlock 1, 3, and 4 zones were perforated with TCP guns, but initial injection rates , were less than expected. The same zones were re- perforated with 2 -1/8" Power Jet guns with a nominal but noticeable increase in rate. In December 2005 tubing integrity failed when pressure on the 4 -1/2" X 9 -5/8" annulus began. The well received Administrative Approval to inject, and continued to inject until February 2010 when it was shut -in for "an apparent cooling anomaly" on a temperature survey. In March 2012 a plug was set in the X nipple and the well passed a combined MIT (CMIT) to 2000 psi on the tubing and 2000 psi on the annulus. However, after many attempts to retrieve the plug were unsuccessful, wireline attempts were halted and the well was put on the workover list. The objective of this rig workover is to pull the completion, clean out to PBD, re- perforate, and run a new completion. The well is expected to inject approximately 4500 bwpd with an approximate split of 80:20 of Hemlock : G -Zone. Notes Regarding Wellbore Condition • Plug in the X nipple at 9334'. A CMIT to 2,000psi passed in March 2012. • DV collar at 4376' has been noted to have leaked in the past. Recent CMIT to 2000 psi passed. • Fill is likely at the bottom of the hole, perhaps up to and covering some perfs V • Maximum hole angle is 42° at 9637' MD. Inclination drops to 26° near bottom �� NOrrLT: A CCCC_ R., Ln5 ��J��c �'t x .+..r � " C Procedure: f 1. RU E -line with jet cutter and cut the tubing just above the packer. 2. Plumb FIW lines to circulate down the annulus and up the tubing, through the tree, to circulate the wellbore and insure no gas is present in the string. 3. Notify AOGCC of pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 3000 psi HIGH. 4. PU landing joint and make -up to tubing hanger. Pull hanger up to floor height. Install stripper rubber. Circulate at least 2 bottoms up to adequately clean hole. • • Well Work Prognosis Well: G -05RD Hilax�rp Alaska, LLC Date: 06 /01/2012 5. POOH with completion tubing. LD same, check for NORM. 6. PU packer milling assembly. Mill packer and retrieve same. Note: when packer is unset and perforations see a full head of fluid, the hole may go on a vacuum. If losses are low, continue with plan. If losses are too high to circulate fill and /or metal shavings, pump pills as necessary to reduce fluid losses. Circulate hole clean of metal shavings. Use magnets at surface to catch metallic debris. 7. After milling up packer and circulating hole clean, PU a rock bit with open jets and a casing scraper positioned to scrape the casing down to 9400', but not to the perforations. RIH to top of fill. Clean out well to PBD. Circulate BU to remove fill, cuttings, and metal shavings. POOH. 8. MU Schlumberger TCP guns on workstring and RIH. RIH with memory GR tool on slickline. Position guns to perforate as follows, using the Thermal Decay Time Log Run X15 July - 1998. Note: A log printout from Petra will be sent to the rig as part of the well package. Zone Interval Feet G - 2 9,475' — 9,500' 25 G - 2 9,508' — 9,548' 40 G - 3 9,562' — 9,602' 40 G - 4 9,638' — 9,708' 70 G - 5 9,752' — 9,848' 96 HB - 1 9,995' — 10,020' 25 HB -3 &4 10,160' - 10,192' 32 HB -3 &4 10,205' - 10,315' 110 Total: 438 9. If losses occurred earlier because of low bottom -hole pressure, losses may accelerate following the re- perforation event until the well finds its stable point again. There is no need to circulate the hole, following re- perforation. After detonation, monitor well by shooting a fluid level and /or noting any blow. Make sure gas detectors are working and tested. Once the well is determined to be static, POOH. 10. POOH with guns. LD same. Confirm that all charges fired. Lat f e " 4 A J 11. Provide a minimum 25 hour notice to AOGCC prior to the workover MIT test / F ;la r 12. PU 4 -1/2" packer and 4 -1/2" tubing. RIH. Space out and set packer at 9300'. Land the tubing hanger, and pressure up backside to confirm packer is set. Hold 2500 psi for 30 minutes for the casing MIT test. If the pressure does not decline more than psi in 30 minutes, the well has passed the Workover MIT. Provide Larry Greenstein with the ess ure test results as well as the completed 10 -426 form for the MIT. ,2 frt ' f75 L aSe.c. 13. Set BPV. ND BOPE and NU tree. Test tree. 14. RIH with slickline and pull plug from the X nipple. 15. Turn well over to Production Supervision (TOPS) for restart of injection. 16. Within 2 weeks of stable injection, schedule an Initial MIT with AOGCC. Provide the AOGCC 24 hour notice prior to the MIT test. All pressure test results and completed 10 -426 are to be provided to Larry Greenstein immediately following the test. • • II McArthur River Field, TBU Well: G -05RD As Completed: 7/7/98 HiIcorp Alaska, LLC ASBUILT PTD: 198 -120 CASING AND TUBING DETAIL RKB to TBG Hngr = 32.97 SIZE WT GRADE CONN ID TOP BTM. CMT Tree connection: 4 -1/2" 5,000# 16" 75 J -55 Butt Surf. 591' 1398 sx 13 -3/8" 54.5 K -55 Butt 12.615 Surf. 3,078' 2600 sx 9 -5/8" 47 N -80 Seal Lock 8.681 Surf. 79' " 3,078'( 9 -5/8 DV Collar 4,376' 4,378' Possible 9 -5/8" 40 N -80 Seal Lock 8.835 79' 5,187 DV Collar Leak @ 9 -5/8" 43.5 N -80 Seal Lock 8.755 5,187 6,925' " 4,736 ti to 9 -5/8" 47 N -80 Seal Lock 8.681 6,925' 7,257 " 6,939 - \ / 1 -- R Window 7,257' 7" liner 29 L -80 Buttress 6.184 6,936' 10,647' Sidetrack w KOP ipstock Tubing 7,257' 4 -1/2" 12.6 L -80 BTC Mod 3.958 Surf 6,879' 3 -1/2" 9.3 L -80 8rd Mod 2.992 6,879' 9,368' JEWELRY DETAIL NO. Depth ID Item 1 6,879' 4 -1/2" Butt Mod x 3- 1/2" 8rd Mod crossover 9,291' I 2 2 9,291' 3.25 Baker "SAB 1" pkr, 3.25 With K -22 tubing anchor 3 9,297' 3.75 Mill out Extension 3 S �u 4 9,334' 2.813 "X" nipple 5 5 9,368' 2.992 3 -1/2" tubing tail PERFORATION DATA (last perforated 9/16/98) G -2 9,470' 9,495' 25' 6 7/6/1998 TCP perf 9,478' 9,493' 15' 4 9/16/1998 2 -1/8" Power strip G -2A 9,530' 9,545' 15' 6 7/6/1998 TCP perf 9,508' 9,540' 32' 4 9/16/1998 2 -1/8" Power strip - G -2 G -3 9,565' 9,595' 30' 6 7/6/1998 TCP perf G -2A 9,563' 9,588' 25' 4 9/16/1998 2 -1/8" Power strip - G -3 G -4 9,635' 9,700' 65' 6 7/6/1998 TCP perf G -4 9,638' 9,688' 50' 4 9/16/1998 2 -1/8" Power strip EE G -5 G -5 9,750' 9,850' 100' 6 7/6/1998 TCP perf B 9,753' 9,815' 62' 4 9/16/1998 2 -1 /8" Power strip B -1 9,995' 10,020' 25' 6 7/6/1998 TCP perf TOF @10,337' -B -3&4 9,995' 10,020' 25' 4 9/16/1998 2 -1/8" Power strip B-3 &4 10,205' 10,315' 110' 6 7/6/1998 TCP perf 10,160' 10,192' 32' 4' 9/16/1998 2 -1/8" Power strip 10,210' 10,242' 32' 4' 9/16/1998 2 -1/8" Power strip 10,270' 10,302' 32' 4' 9/16/1998 2 -1/8" Power strip Plug Back Depth= 10,559' Note: Plug stuck in the nipple at 9,334' on 3/11/12. Passed CMIT, but Bottom of Liner = 10,647' TD = 10,650' MD/9968' TVD could not pull plug after many attempts. MAX HOLE ANGLE = 42° Last Updated: 5/31/12 by TDF • w • II McArthur River Field, TBU Well: G -05RD As Completed: 7/7/98 Hilcorp Alaska, LLC PROPOSED RKB to TBG Hngr = 32.97 Tree connection: 4 -1/2" 5,000# CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. CMT Possible 16" 75 J -55 Butt Surf. 591' 1398 sx DV Collar 13 -3/8" 54.5 K -55 Butt 12.615 Surf. 3,078' 2600 sx Leak 4,736' Redrill 7,257' 3,078L Window 9 -5/8" 47 N -80 Seal Lock 8.681 6,925' 7,257' " 9 -5/8" 43.5 N -80 Seal Lock 8.755 5,187 6,925' ,, 9 -5/8" 40 N -80 Seal Lock 8.835 79' 5,187 9 -5/8" DV 4,376' 4,378' Collar 6.936' 9-5/8" 47 N -80 Seal Lock 8.681 Surf. 79' ,, 7" liner 29 L -80 Buttress 6.184 6,936' 10,647' / _. Tubing Sidetrack 4 -1/2" 12.6 L -80 BTC Mod 3.958 Surf ±9,368' Whipstock KOP 7,z5r 7 JEWELRY DETAIL NO. Depth ID Item 1 +/- 9,291' 3.25 Baker "SAB -1" pkr, 3.25 With K -22 tubing anchor 2 +/- 9,300' 3.75 Mill out Extension 3 +1- 9,334' 2.813 "X" nipple 4 +/- 9,368' 2.992 4 -1/2" tubing tail 9,291' 1 PROPOSED PERFORATION DATA 2 Zone Top Btm Amt Accum. Date Present Condition 3 SPF Last Opr. 4 G -2 ±9,475' ±9,495' 25' 6 Future TCP perf G -2A ±9,508' ±9,548' 40' 6 Future TCP perf G -3 ±9,562' ±9,602' 40' 6 Future TCP perf G -4 ±9,638' ±9,708' 70' 6 Future TCP perf G -5 ±9,752' ±9,848' 96' 6 Future TCP perf HB -1 ±9,995' ±10,020' 25' 6 Future TCP perf =G - HB -3 &4 ±10,160' ±10,192' 32' 6 Future TCP perf EEG - 2A HB -3 &4 ±10,205' ±10,315' 110' 6 Future TCP perf = G -3 G-4 G -5 B -1 =B -3 &4 Note: Plug stuck in the nipple at 9,334' on 3/11/12. Passed CMIT, but could not pull plug after many attempts. Plug Back Depth = 10,559' Bottom of Liner = 10,647' TD = 10,650' MD /9968' TVD MAX HOLE ANGLE = 42° G - 05RD WBS 05.17.12.doc Last Updated: 5/31/12 by TDF • • II McArthur River Field, TBU Well: G -05RD As Completed: 7/7/98 Hilcorp Alaska, LLC PROPOSED PERFORATION DATA (last perforated 9/16/98) G -2 9,470' 9,495' 25' 6 7/6/1998 TCP perf 9,478' 9,493' 15' 4 9/16/1998 2 -1/8" Power strip G -2A 9,530' 9,545' 15' 6 7/6/1998 TCP perf 9,508' 9,540' 32' 4 9/16/1998 2 -1/8" Power strip G -3 9,565' 9,595' 30' 6 7/6/1998 TCP perf 9,563' 9,588' 25' 4 9/16/1998 2 -1/8" Power strip G -4 9,635' 9,700' 65' 6 7/6/1998 TCP perf 9,638' 9,688' 50' 4 9/16/1998 2 -1/8" Power strip G -5 9,750' 9,850' 100' 6 7/6/1998 TCP perf 9,753' 9,815' 62' 4 9/16/1998 2 -1/8" Power strip B -1 9,995' 10,020' 25' 6 7/6/1998 TCP perf 9,995' 10,020' 25' 4 9/16/1998 2 -1/8" Power strip B -3 &4 10,205' 10,315' 110' 6 7/6/1998 TCP perf 10,160' 10,192' 32' 4' 9/16/1998 2 -1/8" Power strip 10,210' 10,242' 32' 4' 9/16/1998 2 -1/8" Power strip 10,270' 10,302' 32' 4' 9/16/1998 2 -1/8" Power strip G -05RD WBS 05.17.12.doc Last Updated: 5/31/12 by TDF ,, , . S • n , Well Work Prognosis Well: G -05RD Ilikorp Alaska, I LC Date: 06/01/2012 1. Williams Workover Rig 0 BOP Grayling P1311001, BOP 2012 Ill iii IiI III ill ill III IiI r Width 4.16' 3.74' Weight 13,1008 1 (a) Ill Iii Ill III a shawl. "" c Total BOP height shove 136/86MLWS (' 136/86M : _ 948 k dimensions —`: 0 11.48' mu Length 7.73' _ 1- 3.00' Width across body 2.72' • Width across flanged gf outlets 1- E1= �w— waaaaa� Weight 960016041 65 Mt 900' a �� III III III III III / ' Mud Cross 1 r � "� . i 2860165 w/ valves ,�k• ,y� _ 4h� 1.74' L 1j ` iii III iii iii iii 1.� Riser above dnl deck I i I I I I This number will vary tom well to wel 1.00' to 3.00• Dnil Deck 13 6/8 6M Riser 86001bs 15.00' III III V III III Spool 1 d 13 8/8 6M X 1 p 6o8 6 M is 1.95' 1800165 III _ ill MOW lli` ..... ' III III Crossover Spool 13 SS5MX 11 BM 1800166 2.83' III III 1 Top of Welhead • • Regg, James B (DOA) Prb t e tz4y From: Regg, James B (DOA) Sent: Tuesday, March 13, 2012 12:09 PM r \lq 77111A I To: 'Larry Greenstein' Cc: Schwartz, Guy L (DOA) Subject: RE: G -5RD (PTD# 198 -120) - RTI results Change to test pressure should have been discussed with us first. MIT requirements in regulation 20 AAC 25.412 and AIO 5, Rule 5 require minimum test pressure of 0.25 *Packer TVD (2218psi). As a general practice, we require 1.2 times injection pressure for barrier verification in wells with mechanical integrity problems unless approved otherwise by AOGCC. Also, it would have been appropriate for AOGCC witness. We are not requiring this to be redone; guidance for future considerations. Jim Regg AOGCC 333 W. 7th Ave, Suite Anchorage, AK 99501 100 511,41001ED MAR V 907 - 793 -1236 From: Larry Greenstein ( mailto:Igreenstein@hilcorp.com] Sent: Tuesday, March 13, 2012 11:50 AM To: Regg, James B (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: G - 5RD (PTD# 198 -120) - RTI results !asked that same question, Jim. Turns out they are planning on limiting the injection pressure in this well to 2000# (historically 1900 #), so although the approved procedure targeted 2500#, they felt they wanted to go gentler in this well. Hope that isn't a problem. The temp survey will be the real test of fluid containment as the casing looks good for the injection pressure expected. Larry From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, March 13, 2012 11:42 AM To: Larry Greenstein Cc: Schwartz, Guy L (DOA) Subject: RE: G -SRD (PTD# 198 -120) - RTI results Reason why pressure limited to 2000 psi? Procedure approved was for 2500psi test. What is injection pressure? Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 From: Larry Greenstein mailto :l. r- -n -in • hilcor..c.m) Sent: Tuesday, March 13, 2012 9:36 AM To: Regg, James B (DOA) 1 y r Tl G - Regg, James B (DOA) Prb I`fglwo From: Larry Greenstein [Igreenstein@hilcorp.com] Zij t z Sent: Thursday, March 22, 2012 4:23 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: G -5RD (PTD# 198 -120) - RTI results - Update Attachments: G -5RD CMIT summary.docx e. Jim, After successful completion of the CMIT, the bad news began. I've attached a short summary of the efforts on this well to date. Bottom line, we have not begun step 2 yet. We'll let you know when we get the well ready for the short injection cycle. Larry From: Regg, James B (DOA) [mailto:jim.regg @ataska.gov] Sent: Monday, March 12, 2012 12:05 PM To: Larry Greenstein Cc: Brooks, Phoebe L (DOA) Subject: RE: G -5RD (PTD# 198 -120) - RTI results . _. MAR ,l 54 z( ;, Larry - we need this also on our MIT report form. Th. ks. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: Larry Greenstein [mailto• • reenstein @hilcorp.com] Sent: Monday, March 12, 20 11:13 AM To: Schwartz, Guy L (DOA)• •egg, James B (DOA) Subject: RE: G -5RD (P ► # 198 -120) - RTI results Hi Guy & Jim, On 3- 11 -12, w- uccessfully completed a CMIT to 2000# (we plan to limit injection to that pressure pressure) on the G- 5RD well. B• the tubing and casing started at 0 pressure. After reaching 2000# on both, the pump was shut down and the pressu -s were monitored for % hour. They held steady (see the attached chart). Tough to see both the red (slightly above) d blue (almost on top) lines on the chart because both are so close to the 2000# max on the chart (I had to zoom it closer). With your permission, we'd like to go on to step 2 of the plan and bring this well on to establish a solid temp profile (- 1 month) before running a temp survey. Please let me know if you have any questions. Larry 1 • • T6c.t 6 -OSe_4\ Pr6 i Z `,IZ9c) Regg, James B (DOA) From: Ted Kramer [tkramer @hilcorp.com] Sent: Wednesday, April 25, 2012 11:13 AM �l To: Regg, James B (DOA) l Cc: Schwartz, Guy L (DOA); Larry Greenstein Subject: K -24RD2 and G -5RD updates Jim, I wanted to write a note and give you an update on the above two wells. O JJN 0 6 2U1Z K -24RD2 We attempted to run a camera in this well to confirm or deny the parted tubing (4,438 feet) issue to help get this well ready for repair. We ran the camera and made it to 4,468 feet (no part in the tubing observed) became stuck (Heavy buildup on the tubing walls observed). Attempts to free the camera resulted in pulling out of the rope socket leaving the camera in the well. We then rigged up slickline to retrieve the tool. We latched onto the camera with slickline but could not pull it free. We then had to cut the slick line leaving those tools in the well also. Plan forward is to mobilize Coil tubing to the King platform to rig up on this well to fish out the camera and to clean the tubing in advance of the CUDD unit. We need to tubing clear and relatively clean in order to get a cutter down the well to cut the tubing for removal. The coil tubing unit just came off of the Dolly platform. The vendor has some repairs to perform on the unit this week and then we will take it to the King Salmon for this well. The CUDD unit is scheduled to be here May 6 If the K -24RD2 is not ready in time, we will go to the Dolly Platform with it for a conversion and then back to King as soon as this well is ready. G5RD ✓ Attempts to remove the plug from the tubing after the jug test were unsuccessful. We ran into the well with e-line to see where the plug was. The thought was that if the plug was located below the packer we might be able to shoot off the tubing tail to restore the well to injection. Unfortunately, the plug was confirmed by a -line to be stuck above the packer so this is not possible. Therefore, we have placed this well on the workover list for when a workover rig is placed on the grayling platform. We anticipate that a rig will be there around June 15 • Please let me know if Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC Office Phone 907 - 777 -8420 CeII Phone 985 - 867 -0665 1 Regg, James B (DOA) R i tfIZoo From: Larry Greenstein [Igreenstein©hilcorp.com] Sent: Thursday, March 22, 2012 4:23 PM � 1 3177771(Z' To: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: G -5RD (PTD# 198 -120) - RTI results - Update Attachments: G -5RD CMIT summary.docx - Jim, After successful completion of the CMIT, the bad news began. I've attached a short summary of the efforts on this well to date. Bottom line, we have not begun step 2 yet. We'll let you know when we get the well ready for the short injection cycle. Larry From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, March 12, 2012 12:05 PM To: Larry Greenstein Cc: Brooks, Phoebe L (DOA) Subject: RE: G -5RD (PTD# 198 -120) - RTI results,, iiAk, Larry - we need this also on our MIT report form. Th. ks. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Larry Greenstein [mailto• • reenstein @hilcorp.com] Sent: Monday, March 12, 20 11:13 AM To: Schwartz, Guy L (DOA)• •egg, James B (DOA) Subject: RE: G -5RD (PT► # 198 -120) - RTI results Hi Guy & Jim, On 3- 11 -12, w- uccessfully completed a CMIT to 2000# (we plan to limit injection to that pressure pressure) on the G- 5RD well. B. the tubing and casing started at 0 pressure. After reaching 2000# on both, the pump was shut down and the pressu -s were monitored for 1 /2 hour. They held steady (see the attached chart). Tough to see both the red (slightly above) d blue (almost on top) lines on the chart because both are so close to the 2000# max on the chart (I had to zoom in closer). With your permission, we'd like to go on to step 2 of the plan and bring this well on to establish a solid temp profile (- 1 month) before running a temp survey. Please let me know if you have any questions. Larry 1 • • IRg /zoo Grayling G-5RD eAmx. Summary of Events 3 -8 -12 RIH with 2.88" GR to 6876' sat down. POOH. Rerun 2.88" GR sat down 6934'. Worked to 7000'. 3 -9 -12 RIH 2.88" GR trying to clean TBG. 3 -10 -12 Cleaning out TBG with 2.867" broach and Star Bit. 3 -11 -12 RIH with PX plug. Hard to set. Set plug. RIH with prong. Jug test tbg- casing. 3 -12 -12 Thaw out Lubricator. Try to pull prong. Bail top of prong. Latch prong couldn't pull. 3 -13 -12 Latch prong. Beat up couldn't pull shear off. Move to G -7 3 -14 -12 Rig up 0.150 wire. Latch prong. POOH with prong. RIH with GS couldn't pass 9247'. RIH with bailer. Bailer full. Bail to plug. RIH latch plug. Plug came free. Pull up to 9282' plug hung up. . Wire parted. 3 -15 -12 Drop cutter bar. No cut. Drop second cutter. Wire cut. Rig down Dolly unit -Rig up Grayling unit. Fish cutter bar. 3 -16 -12 Fish second cutter OOH. RIH with bailer. Full of slush. Tools came loose. Fish out second tool string. 3 -17 -12 Crew working on other wells. Waiting on delivery of braided line to try again to clear well of tool. Regg, James B (DOA) 1'5 o From: Regg, James B (DOA) Sent: Tuesday, March 13, 2012 12:09 PM To: 'Larry Greenstein' ( ief q (l) t 77 Cc: Schwartz, Guy L (DOA) Subject: RE: G -5RD (PTD# 198 -120) - RTI results Change to test pressure should have been discussed with us first. MIT requirements in regulation 20 AAC 25.412 and AIO 5, Rule 5 require minimum test pressure of 0.25 *Packer TVD (2218psi). As a general practice, we require 1.2 times injection pressure for barrier verification in wells with mechanical integrity problems unless approved otherwise by AOGCC. Also, it would have been appropriate for AOGCC witness. We are not requiring this to be redone; guidance for future considerations. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 d� AR i�I Anchorage, AK 99501 r 907 - 793 -1236 From: Larry Greenstein [mailto:Igreenstein @hilcorp.com] Sent: Tuesday, March 13, 2012 11:50 AM To: Regg, James B (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: G -5RD (PTD# 198 -120) - RTI results I asked that same question, Jim. Turns out they are planning on limiting the injection pressure in this well to 2000# (historically 1900 #), so although the approved procedure targeted 2500 #, they felt they wanted to go gentler in this well. Hope that isn't a problem. The temp survey will be the real test of fluid containment as the casing looks good for the injection pressure expected. Larry From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, March 13, 2012 11:42 AM To: Larry Greenstein Cc: Schwartz, Guy L (DOA) Subject: RE: G -5RD (PTD# 198 -120) - RTI results Reason why pressure limited to 2000 psi? Procedure approved was for 2500psi test. What is injection pressure? Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 From: Larry Greenstein [mailto:l•reenstein . hilcorp.com] Sent: Tuesday, March 13, 2012 9:36 AM To: Regg, James B (DOA) 1 • • Regg, James B (DOA) From: Larry Greenstein [Igreenstein @hilcorp.com] Sent: Tuesday, March 13, 2012 9:36 AM To: Regg, James B (DOA) Cc: Brooks, Phoebe L (DOA) Subject: RE: G -5RD (PTD# 198 -120) - RTI results Attachments: G -5RD CMIT Chart 3- 11- 12.jpg; G -5RD CMIT 3- 11- 12.xls Here you go, Jim & Phoebe. Sorry, I didn't think to include this originally. Just happy to see it held tight. Larry From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, March 12, 2012 12:05 PM To: Larry Greenstein Cc: Brooks, Phoebe L (DOA) Subject: RE: G -5RD (PTD# 198 -120) - RTI results Larry — we need this also on our MIT report form. Thanks. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Larry Greenstein [mailto:Igreenstein @hilcorp.com] Sent: Monday, March 12, 2012 11:13 AM To: Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: RE: G -5RD (PTD# 198 -120) - RTI results Hi Guy & Jim, On 3- 11 -12, we successfully completed a CMIT to 2000# (we pla • limit injection to that pressure pressure) on the G- 5RD well. Both the tubing and casing started at 0 pressure. A -r reaching 2000# on both, the pump was shut down and the pressures were monitored for 1 /2 hour. They held stead see the attached chart). Tough to see both the red (slightly above) and blue (almost on top) lines on the chart beca =e both are so close to the 2000# max on the chart (I had to zoom in closer). With your permission, we'd like to go on to ste• of the plan and bring this well on to establish a solid temp profile (— 1 month) before running a temp survey. Please let me know if you have any • - stions. Larry Original Message From: Michael Dunn Sent: Monday, March 12, 2012 8:52 AM 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reacealaska.aov: doa .aoacc.prudhoe.bavaalaska.gov; phoebe.brooks(otalaska.00v; quy.SChwartznalaska.gov OPERATOR: Hilcorp Alaska, LLC FIELD / UNIT / PAD: McArthur River Field/Trading Bay Unit/Grayling Platform DATE: 03/11/12 OPERATOR REP: Wayne Johnson AOGCC REP: none Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well G -5RD , Type Inj. N TVD 8,878 ' Tubing 0 2030 2030 2030 Interval 0 i P.T.D. 1981200 Type test P Test psi 2000 Casing 0 2005 2000 ' 2000 - P/F P Notes: CMIT to return well to injection - Inj pressure OA 185 185 185 185 to be limited to 2000# 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 Inj. 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 1 = 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 T = Test dunng Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) 2012 - 0311 MIT TBU_G - 5RD CMIT ?ePrn- 145 \ il Al 7 --;_21 ? yczj • , A • 11 # 1 , *%44•Like.: • • Regg, James B (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, March 12, 2012 12:01 PM To: Larry Greenstein; Regg, James B (DOA) Subject: RE: G -5RD (PTD# 198 -120) - RTI results Larry, As per our agreement you are cleared to inject into G -5RD. A temperature survey will be needed at about 1 month of injection to see if the anomaly is still present near the packer. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Larry Greenstein [ mailto:Ireenstein @hilcorp.com]� Sent: Monday, March 12, 2012 11:13 AM To: Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: RE: G -5RD (PTD# 198-120) - RTI results Hi Guy & Jim, On 3- 11 -12, we successfully completed a OMIT to 2000# (we plan to limit injection to that pressure pressure) on the G- 5RD well. Both the tubing and casing started at 0 pressure. After reaching 2000# on both, the pump was shut down and the pressures were monitored for 1 /2 hour. They held steady (see the attached chart). Tough to see both the red (slightly above) and blue (almost on top) lines on the chart because both are so close to the 2000# max on the chart (I had to zoom in closer). With your permission, we'd like to go on to step 2 of the plan and bring this well on to establish a solid temp profile (- 1 month) before running a temp survey. Please let me know if you have any questions. Larry Original Message From: Michael Dunn Sent: Monday, March 12, 2012 8:52 AM To: Larry Greenstein Subject: FW: Scanned Image Larry, we tested G -5RD. It held "like a jug" at 2000 psi. We can limit injection pressure to same. Mike Dunn 1 Reservoir Engineer Hilcorp Alaska, LLC mdunn @hilcorp.com Office: (907) 777 -8382 Mobile: (907) 351 -4191 1 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Tuesday, February 28, 2012 8:25 AM To: Larry Greenstein; Regg, James B (DOA) Subject: RE: G -5RD temp anomaly (PTD# 198 -120) temp anomaly Larry, The proposal is accepted. Give Jim or I a call as soon as you get results on the CMIT. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Larry Greenstein [mailto:lgreenstein @hilcorp.com] Sent: Tuesday, February 28, 2012 6:59 AM To: Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: RE: G -5RD temp anomaly (PTD# 198 -120) temp anomaly Per our conversation, Guy, here's what Hilcorp proposes for the G5RD well's RTI approach. 1) Perform a CMIT to 2500# to prove up the casing's integrity to the packer. 2) If successful, bring on injection for a month to establish a solid downhole temperature profile and run a temp log. 3) Overlay the temp log with previous logs for analysis and review with AOGCC. 4) If all looks appropriate, return this well to injection and recommence the bi- annual temp survey's for compliance. Thank you and let me know if you would like anything else. Larry From: Larry Greenstein Sent: Friday, February 24, 2012 4:26 PM To: 'Schwartz, Guy L (DOA)'; Regg, James B (DOA) Subject: RE: G -5RD temp anomaly (PTD# 198 -120) temp anomaly Thanks for the quick response, Guy. I don't believe a CMIT was ever performed. At the time, we had plenty of other wells online and didn't 'need' this well... but times have changed. Assuming we could get a good set of the plug in the TT, we sure could attempt a CMIT or jug test to prove up on the casing. As 1 too agree that the anomaly doesn't specifically point to a leak on the backside of the casing, a successful jug test would indicate intact casing and packer and, with the daily monitoring we perform, would allow us to operate this well with the same safety as other wells on the platform. Hopefully we can discuss this yet today so I can get the platform working towards this goal over the weekend. Really appreciate your efforts and thoughts, Guy. Larry From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Friday, February 24, 2012 3:32 PM 2 • . To: Larry Greenstein; Regg, James B (DOA) Subject: RE: G -5RD temp anomaly (PTD# 198 -120) temp anomaly Larry, I looked email and attached PP slides. I have a quick question ... did it ever pass a CMIT? The email states a tubing x IA leak.... I haven't pulled all the records but that would prove good casing down to the packer. My take is that the temp anomaly is not a clear indication of a leak on the backside. My thoughts are to set a plug in tubing tail and do CMIT and then put in on injection again short term and follow up with another temp survey. will discuss this with Jim later today. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Larry Greenstein [mailto:Igreenstein @hilcorp.com] Sent: Friday, February 24, 2012 2:44 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: FW: G -5RD temp anomaly (PTD# 198 -120) temp anomaly Question for you guys, Having recently lost G -19 to a potential inner /outer casing communication issue, the waterflood system on the Grayling is having trouble staying online. We were looking through the other injection wells and noticed the shut -in G -5RD well as a possible RTI candidate. At the time, the waterflood volumes were more than adequate to have the G -5RD well shut -in as a precaution for this slight cooling above the packer as noted in the attached ppt, but now we are on the edge of losing waterflood and would like to revisit this decision. The temp anomaly doesn't seem to indicate actual cool water going behind pipe and out anywhere uphole (no cooling spike indicated), it seems more like some logging aberration that appeared with the 2010 survey. As a possibility, if we were able to bring this well back on, we could re- establish a temperature profile over the next 2 -4 weeks, run a temp survey again to see if this anomaly was still there or better or worse. I've also attached the last correspondence with Tom regarding this well and 1 apologize as it looks like neither of you were copied on those e- mails. The G -5RD well is currently on our LTSI list and you've been receiving the pressure plots quarterly on this well (and the other LTSI wells) since it has been shut -in. Please call me as soon as you get to read this to discuss our options. Thank you Larry 777 -8322 From: Michael Dunn Sent: Thursday, February 23, 2012 10:41 AM 3 To:'Larry Greenstein Subject: G -5RD temp anomaly Larry, This does not look like compelling evidence that water is going into the formation above the packer. Since G -19 went down, the Bingham is running at harmonic vibration. We need to open up another injector. This seems like a candidate to re -visit with the State on. Mike Dunn Sr. Reservoir Engineer Hilcorp Alaska, LLC Office: (907) 777 -8382 Cell: (907) 351 -4191 4 • Chevron John Zager Union Oil Company of California General Manager, Alaska 3800 Centerpoint Drive, Suite 100 MidContinent/Alaska SBU Anchorage, AK 99503 Tel 907 263 7815 V6\.'(1150 Mobile 907 223 0128 �JJ Fax 907 263 7897 Email jzager @chevron.com h—` -ZA %a tek -t kkocs November 16, 2011 _ \y UIC Manager ` 00o Thor Cutler, OCE -082 M' 0 U.S. Environmental Protection Agency, Region 10 1200 Sixth Ave., Suite 900 Seattle, WA 98101 Re: Amended Request for Permit Transfer: Underground Injection Control (UIC) Permit No. AK- 1I006 -A by Union Oil Company of California ( "Union ") to Hilcorp Alaska, LLC Dear UIC Manager: Please replace my letter dated November 15, 2011 requesting permit transfer of Underground Injection Control (UIC) Permit No. AK- 1I006 -A by Union Oil Company of California ( "Union ") to Hilcorp Alaska, LLC. Union Oil Company of California ("Union") has entered into an Asset Sale and Purchase Agreement dated July 1, 2011 to sell its interests in the Cook Inlet Area to Hilcorp Alaska, LLC, ( "Hilcorp ") with an anticipated closing scheduled on or about December 15, 2011, assuming certain regulatory approvals are received by December 1, and all other Closing conditions are met. The actual closing date may vary depending on how quickly certain regulatory approvals are processed. The transfer of Union's interest to Hilcorp is conditioned on the completion of the transaction ( "Closing ") pursuant to the Asset Sale and Purchase Agreement by and between Union and Hilcorp. Union and Hilcorp will advise you upon Closing that the transfer has become effective, and Hilcorp has taken over Union's interest and operations, including the above referenced UIC Permit No. AK- 1I006 -A. Should the Closing for any reason not occur, Union will advise you that it has retained its interest. Environmental Protection Agency (EPA) Form 7520 -7, Application to Transfer Permit, is enclosed. Eight wells are permitted as candidate wells for Class I operation under this permit. These eight wells are: Dolly Varden Platform wells D -9RD and D- 15RD2, Grayling Platform wells G -5RD and G -16, King Salmon wells K -11 and K- 24RD2, and Steelhead Platform wells M -27 and M -30. Currently, only D -9RD has received written authori7atinn from EPA Region 10 to commence Class I infection. An agreement memorializing the transfer of UIC Permit No. AK- 11006 -A from Union to Hilcorp is also enclosed. 1 of 2 UIC Manager • • US Environmental Protection Agency November 16, 2011 Page 2 We appreciate your attention to this request and apologize for the inconvenience. Should you have any questions, please do not hesitate to contact Faye Sullivan at FayeSullivanOchevron.com or 263 -7685. Regards i (IP, ft John ager f Enclosures: / US EPA Form 7520 -7 Agreement to Transfer UIC Permit No. AK- 1I006 -A cc: John A. Barnes, Hilcorp Alaska, LLC Marc Bentley, ADEC Cathy Foerster, AOGCC 2 of2 • • OMB No. 2040 -0042 Approval Expires 12/31/2011 United States Environmental Protection Agency ` Washington, DC 20460 C Application To Transfer Permit Name and Address of Existing Permittee Name and Address of Surface Owner Union Oil Company of California; P.O. Box 196247 State of Alaska, Department of Natural Resources Anchorage, AK 99519 -6247 550 West 7th Avenue, Ste. 800; Anchorage, AK 99501 State County Permit Number Locate Well and Outline Unit on Alaska NA -State waters offshore AK- 11006 -A Section Plat • 640 Acres N Surface Location Description I I� I I t I � .SC 1/4 of ne 1/4 of sw 1/4 of SW 1/4 of Section Township Sn Range 13w -414- -- -- - 4 - t-- -I- - Locate well in two directions from nearest lines of quarter section and drilling unit I I Surface :-4-1-4- _ 4 -1-4 _ 1 Location 754 ft. frm (NIS) S Line of quarter section I I I I I ( L and ,1138t• from (E/W) w Line of quarter section. W I I I I I 1 I Well Activity Well Status Type of Permit j — 4-1-4- 4' x Class I fr Operating _, Individual I I I I I I Class II _ C L Area _ - '- I ` T _ - 717 _ - Modification/Conversion a I 1 „ Brine Disposal x Proposed Number of Wells ' -4 —��— -4-1-4- 1 Enhanced Recovery I I I I I I Hydrocarbon Storage S _ Class III Other Lease Number See Attached well Number See Attached Name(s) and Address(as) of New Owner(s) Name and Address of New Operator Hilcorp Alaska, LLC; 3800 Centcrpoint Drive Suite 100; Hilcorp Alaska, LLC; 3800 Centerpoint Drive, Suite 100; Anchorage, AK 99503 -5826 Anchorage, AK 99503 Attach to this application a written agreement between the existing and new permittee containing a specific date for transfer of permit responsibility, coverage, and liability between them. The new permittee must show evidence of financial responsibility by the submission of a surety bond, or other adequate assurance, such as financial statements or other materials acceptable to the Director. Certification I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. (Ref. 40 CFR 144.32) Name and Official Title (Please type or print) Signature Date Signed John Zager, General Manager 4 r 11/15/2011 EPA Form 1520 -7 (Rev. 12 -08) • i • • Attachment to Form 7520 -7, Application to Transfer Permit One well is fully authorized for operation as a Class I well. An additional 7 wells are proposed candidate wells, but are not fully authorized for operation as Class I wells. The location map and surface well location shown on the front page of EPA Form 7520 -7 illustrates the location of the 1 authorized and operating Class I well. Well information for each of the 8 permitted wells is included on this page. Well API No. Lease Feet from Section Seward Meridian Line (Surface location) Sec Twp Range Authorized Well D -9RD 150- 733 - 20131 -01 -00 ADL 018729 756 FSL/ 1138 FWL 6 8N 13W Permitted wells M -27 50- 733 - 20423 -00 -00 ADL 018730 974 FNL/ 531 FWL 33 9N 13W M -30 50- 733 - 20430 -00 -00 ADL 017594 967 FNL/ 520 FWL 33 9N 13W G -5RD 50- 733 - 20162 -01 -00 ADL 018730 1838 FNL/ 1487 FEL 29 9N 13W 0-16 50- 733 - 20060 -00 -00 ADL 017594 1879 FSL/ 1381 FEL 29 9N 13W K -11 50- 733 - 20148 -00 -00 ADL 017594 617 FSL/ 131 FEL 17 9N 13W K -24 RD2 50- 733 - 20330 -01 -00 ADL 018730 733 FSL/ 131 FEL 17 9N 13W 0-15 RD2 50- 733 - 20159 -02 -00 ADL 018729 754 FSL/ 1130 FWL 6 8N 13W FSL = Feet from south line of quarter section (feet south section line) FNL= Feet from north line of quarter section FWL= Feet from west line of quarter section FEL= Feet from east line of quarter section • Agreement to Transfer UIC Permit No. AK- 1I006 -A This Agreement to Transfer UIC Permit No. AK- 1I006 -A ( "Agreement ") is made the 15 day of November, 2011 between Union Oil Company of California, a California corporation ( "Union "), and Hilcorp Alaska, LLC., a Delaware limited liability company ("Hilcorp"), collectively referred to as the "Parties," or individually as a "Party." RECITALS WHEREAS, Union and Hilcorp have executed an Asset Sale and Purchase Agreement dated effective as of July 1, 2011, ( "ASPA ") whereby Union agreed to sell its therein described interests in the Cook Inlet Area to Hilcorp; and WHEREAS, Union's interests in the Cook Inlet Area include UIC Permit No. AK- 11006 -A; and WHEREAS, Union wishes to effect the transfer of that permit to Hilcorp as authorized by regulation promulgated by the Environmental Protection Agency ( "EPA ") at 40 CFR § 144.38(b); and WHEREAS, the EPA requires a written agreement between Union and Hilcorp containing the specific date for transfer of permit responsibility, coverage and liability between them. Agreement to Transfer UIC Permit No. AK- 1I006 -A • . AGREEMENT NOW, THEREFORE, in consideration of each Party's intent to consummate the closing of the ASPA, and for such other consideration the receipt and sufficiency of which is hereby acknowledged, the Parties agree as follows: 1. In the absence of notification to the Parties by the Director of EPA of the Director's intent to modify or revoke and reissue the permit, then effective as of the date of closing of the transaction contemplated by the aforementioned ASPA (the "Closing "), which Closing is projected to occur on or about December 15, 2011, subject to certain regulatory approvals being received by December 1, 2011 and all other Closing conditions being met, Union transfers and assigns to Hilcorp, and Hilcorp agrees to accept and assume, all of Union's rights, responsibilities, and liabilities under UIC Permit No. AK- 1I006 -A. The specific date for transfer of permit responsibility from Union to Hilcorp for this permit will be on the actual Closing date, which is anticipated on December 15, 2011, but may be later depending on when Closing actually occurs. 2. Should the Closing not occur for whatever reason, the Parties agree that Union shall retain all of its rights, responsibilities, and liabilities under UIC Permit No. AK- 1I006 -A, and Hilcorp shall have no rights, responsibilities, or liabilities under the permit. 3. In the event that the Director of EPA notifies the Parties of the Director's intent to modify or revoke and reissue the permit, then, assuming the Closing will nevertheless occur, Union shall undertake commercially reasonable efforts to cooperate with Hilcorp should it 2 Agreement to Transfer WC Permit No. AK- 11006 -A • • choose to engage with EPA while the Director works to modify or revoke and reissue the permit. 4. Notices shall be made as follows: Union: Steve Wright Asset Development Manager 3800 Centerpoint, Dr., Suite 100 Anchorage, AK 99503 (907) 263 -7865 sswr @chevron.com Hilcorp: John Barnes Senior Vice President Exploration and Production - Alaska 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 (907) 263 -7739 5. This Agreement may only be amended by written agreement signed by a duly authorized representative of each Party. 6. Except as set forth herein, this Agreement shall be binding only upon, and inure only to the benefit of, the Parties and their respective successors and assigns. No Party shall assign its rights or benefits under this Agreement without the prior written consent of the other Party. 7. This Agreement shall be governed by the laws of the state of Texas. 3 Agreement to Transfer UIC Permit No. AK- 11006 -A • • 8. The Parties have jointly drafted this Agreement, and this Agreement shall not be interpreted against or in favor of either of the Parties on the ground that any Party participated in drafting this Agreement. 9. This Agreement constitutes the entire agreement and understanding of the Parties with respect to the matters addressed herein. 10. In the event that there is any conflict between terms and conditions of this Agreement and the ASPA, the terms and conditions of the ASPA shall prevail. 11. No Party or representative, agent, or attorney for a Party has made any representation or warranty to influence the execution of this Agreement that is not expressly contained in this Agreement. 12. This Agreement may be executed in counterparts, all of which • together shall constitute one and the same instrument. 13. By execution of this Agreement, each of the Parties hereto represents and warrants that they have the corporate power and authority to execute and deliver this Agreement and that each of the Parties has the power and authority to make and carry out its obligations hereunder. WHEREFORE, this Agreement shall become fully enforceable and effective in all respects on the latter of the two dates appearing below. 4 Agreement to Transfer WC Permit No. AK- 1I006 -A • • Union Oil Company of California, Hilcorp Alaska, LLC, a a California corporation Delaware limited liability company By: ,_ .. . .! B y: - ---- -- Name: 'akd ^ Name: Lv V 4 t A'S Its: __ f'C'y' — tr - c c Its: ' 1 Date: _Nov, 1,7 fii.A Date: M J T Z - o t 4 5 Agreement to Transfer UIC Permit No. AK- 1I006 -A • • Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Friday, October 14, 2011 7:31 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Cole, David A; Martin, J. Hal; Lambert, Steve A; Ayer, Phil M; Ross, Gary D; Quick, Mike [ASRC]; Hallett, Trudi R. Subject: 2011 Third Quarter's LTSI Well Monitoring Report Attachments: Master Well List TIO Report 2011 10 01.xis Hi Tom & Jim, Here is the third quarter's report for the LTSI wells utilizing pressure monitoring in lieu of an MIT to determine any mechanical integrity problems. l c o v The wells G -29RD, G -27, G -22 & G -5RD have been moved to this LTSI report as their downhole problems (like parted tubing) do not allow a temp survey to be run to the proper depth to confirm water entry into the perfs. As a result, they are all shut -in and will remain so for now. The An -17, An -29, Ba -16 & GPP 33 -14RD wells showed increases in the 13 3/8" annulus, but they all have leveled off lately. Ba -17, after an MIT, was used in August to disposed of some fluids collected during the well kill operations on Baker. It may be used again in October for fluids collected during a well abandonment operation. I have left this well on the LTSI well list because after this usage, the well will revert to being shut -in for the foreseeable future. All the pressures seen during the usage in August looked appropriate and the well appears to have maintained its mechanical integrity throughout the disposal operations. The general pattern of stable or slowly rising pressure trends continued this month for the Baker & Dillon wells on this list with the only other pressure anomaly related to the seasonal trend in pressures apparent in Ba -15RD. The well kill operations performed on the Dillon platform in August show up very clearly on the plots. Other than the noted issues, there doesn't appear to be any wells that show indications of any well integrity problems. Larry • 10/14/2011 Plot Pressure /tate vs Time - Well G -05RD • 400 - .. - ..., .., - - ._, . _.. - - 200 4. 180 350 9 5/8' 13 3/8" 160 300 Tubing ""Vol G -5RD 140 250 120 F2 v, 200 __... _.__.._._____ ___ _._ -. - ._.. -- -- _ -_ -_- _- ..__.__ -__.- -_._ ...._..._.__ __ - -._ _._ -. 10 v m CI. 80 150 60 100 — .._._. 40 50 20 0- -0 7- 7 7 7 7 7 O o N N V La ici ii," co O) O o O O O o O Date 5/9 13 3/8" 20" TubinrIMME TIO Report 10/01/11 190 0 0 0 09/30/11 190 0 0 0 Data Sheet 09/29/11 190 0 0 0 09/28/11 190 0 0 0 09/27/11 190 0 0 0 G -05RD 09/26/11 190 0 0 0 09/25/11 190 0 0 0 09/24/11 190 0 0 0 INJECTION 09/23/11 190 0 0 0 09/22/11 190 0 0 0 09/21/11 190 0 0 0 Permit # 1981200 09/20/11 190 0 0 0 09/19/11 190 0 0 0 09/18/11 190 0 0 0 Admin Approval # AIO 5.012 09/17/11 190 0 0 0 09/16/11 190 0 0 0 09/15/11 190 0 0 0 API # 50- 733 - 20060 -01 09/14/11 190 0 0 0 09/13/11 190 0 0 0 09/12/11 190 0 0 0 04/01/2011 to 10/01/2011 09/11/11 190 0 0 0 09/10/11 190 0 0 0 09/09/11 190 0 0 0 09/08/11 190 0 0 0 09/07/11 190 0 0 0 09/06/11 190 0 0 0 09/05/11 190 0 0 0 09/04/11 190 0 0 0 09/03/11 190 0 0 0 09/02/11 190 0 0 0 09/01/11 190 0 0 0 08/31/11 190 0 0 0 08/30/11 190 ' 0 0 0 08/29/11 190 0 0 0 08/28/11 190 0 0 0 08/27/11 190 0 0 0 10/14/2011 8:47 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 10 01.xIs G -05RD • • Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Thursday, October 13, 2011 9:14 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Martin, J. Hal; Lambert, Steve A; Hallett, Trudi R. Subject: 2011 September's Waivered Injection Well Report Attachments: Master Well List TIO Report 2011 10 01.xis Hi Tom & Jim, Here is September's monthly report for all the active monitored injection wells. ..-- -- tctis -- `O I did move G -29RD, G -22 & G -5RD out of this report and over to the LTSI report due to the inability to get a temp survey deep enough for a successful MIT. These wells have been shut -in and will remain so for now. These monitored wells, including the newly added wells, are responding as expected to ups and downs in injection volumes without any apparent pressure or rate anomalies observed. Bottom line, I don't see any indication that any of these wells are losing control of the injected fluids downhole. Larry 11/8/2011 • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, June 16, 2010 3:21 PM To: 'Lambert, Steve A' Cc: 'Myers, Chris S'; 'Johnson, Wayne E ; 'Cote, David A'; 'Greenstein, Larry P' Subject: RE: G-05RD (198-120} MIT temp survey Steve, I know you are not in right now, but I was doing some filing and ran across this message. Has there been any resolution/determination of what the temperature anomaly might be? Thanks in advance, Tom Maunder, PE AOGCC G~S'Cl ~ ~ ~~~ From: Maunder, Thomas E (DOA) Sent: Tuesday, March 09, 2010 3:12 PM To: 'Lambert, Steve A' :. ~ i7~„~, :: ~ ?fJ~~~x Cc: Myers, Chris S; Johnson, Wayne E; Cole, David A; Greenstein, Larry P ~ ~ ~~" ~'" Subject: RE: G-OSRD (198-120) MIT temp survey Steve, 1 have also received the temperature survey for G-16. Comparing the surveys, the anomaly you have identified clearly shows up. I look forward to further communication regarding Unocal/Chevron's assessment. Tom Maunder, PE AOGCC From: Lambert, Steve A [mailto:salambert@chevron.com] Sent: Tuesday, March 02, 2010 4:50 PM To: Maunder, Thomas E (DOA) Cc: Myers, Chris S; Johnson, Wayne E; Cole, David A; Greenstein, Larry P Subject: G-05RD MIT temp survey Tom a temperature survey was run on well G-05RD on February 28, 2010 for the purpose of confirming mechanical integrity. The results were reviewed in the office this afternoon and we have some concerns about a temperature anomaly that appears from 8,200'-9,290' MD. This interval lies above the packer at 9,292'. There appears to be a subtle temperature change in this area that is difficult to explain. For this reason we shut the well in at 3:30 this afternoon. I have attached a copy of the temperature survey, the pressure history and the well schematic. The temperature plot contains a comparison with the previous survey run in February 2008. Comparing the 2 surveys highlights the area of concern. We will continue to evaluate the log and review it with our in-house experts before proposing a long term plan for this well. Please let us know if you have concerns or recommendations concerning our plans for this well. Steve Lambert Senior Advising Petroleum Engineer Chevron North America Exploration and Production 3800 Center Point Suite 100 Tel 907 263 7658 salambert@chevron.com 6/16/2010 • • Chevron Well: G-5RD Field: Grayling 02-28-10 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 0 1000 - -- -- Pressure-Temperature Profile I 1 Going in hole TVD 2000 - - - 3000 - -~ .-~ 4000 - I ~ I `. I ~ 5000 - H ~ I t C. D 6000 -- 7000 - 8000 -- I -- I 9000 - ~ -- 10000 45 50 55 60 65 70 75 80 85 90 95 100 105 110 115 120 125 130 Temperature (Deg. F) 2-28-10 Pressure - Perfs 16" 13-3/8" 9-5/8" 7" - -TBG 4 1/2 2-28-10 Temp 2-20-08 Tem Report date: 3/9/2010 G-SRD Compliance Temperature Survey. i Maunder, Thomas E (DOA) __ From: Lambert, Steve A [salambert@chevron.com] Sent: Monday, March 03, 2008 2:32 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Greenstein, Larry P Subject: G-5RD Compliance Temperature Survey. Attachments: Survey 2-20-08.zip Page 1 of 1 Well G-05RD (PTD 198-120) was granted Administrative Approval (AIO 5.012) on March 1, 2006. As required under the approval, afollow-up survey was run on 2-20-08. The survey (attached) confirms that all injected fluid is being contained within the perforated intervals. Please contact me if you have any questions regarding the survey, «Survey 2-20-08.zip» ~~~ ~~~ s~ 6/16/2010 ~~ 1000 2000 3000 4000 .-. d d ~ 5000 .t~.r 6000 d 0 7000 8000 9000 10000 Pressure (psia) 500 1000 1500 2000 2500 3000 3500 4000 4500 0 0 11000 45 55 65 75 85 95 105 115 125 135 145 155 Temperature (Qeg. F) -~ -- 2-20-08 Pressure - Perfs 16" 13-3/8" 9-5/8" 7" -° --TBG 4 1/2 -~--2-20-08 Temp ~1-21-06 Temp • -- _=.r i ~. -~ ~ -- -__J FRANK H. h1URKOWSKI, GOVERNOR i 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADtiIINISTRATIVE APPROVAL AIO 5.012 !V1r. Steve Lambert Advising Reservoir Engineer Unocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 ~u~~~~ JAN ~ 2Q0~ RE: TBU G-SRD (PTD 198-120) Request for Administrative Approval Dear tilr. Lambert: Per Rule 9 of Area Injection Order 5, the Alaska Oil and Gas Conservation Commission ("AOGCC") hereby- grants Unocal Alaska ("Unocal")'s February 22, 2006 request for administrative approval to inject water in Trading Bay unit ("TBU") G-SRD. Unocal notified the Commission on December 13, 2005 that TBU G-SRD exhibits tubing-casing pressure communication and that the well had been shut-in. Approval to continue injection for the purpose of performing well integrity diagnostics was granted by sundry number 305-393 on December 27, 2005. Unocal has elected to perform no corrective action at this time on TBU G-SRD. Temperature surveys performed as part of the diagnostic testing confirm the injected fluids are exiting the well at the perforations and monitoring has show°n that pressures are contained within the wellbore. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. The Commission's administrative approval to inject in TBU G-SRD is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2, Unocal shall monitor and record tubing, inner annulus, and outer annulus pressures and injection rate daily; • • Mr. Steve Lambert March 1, ?006 Page 2 of 2 Unocal shall submit to the Commission a monthly report of well pressures and injection rates; 4. Unocal shall perform a temperature survey every 2 years in lieu of the mechanical integrity test as outlined in Rule 5 of AIO ~ to demonstrate continued production casing integrity. For purposes of this requirement, the next temperature survey is due no later than February 28, 2008; ~. Unocal shall immediately shut in the well and notify the Commission if there is any change in the well's mechanical condition; and 6. after well shut in due to a change in the well's mechanical condition, Commission approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been ,laska and dated March 1, 2006. Daniel T. eamount, Jr. Cathy P. F erster Commissioner Commissioner -~`, ~ C ; ~ ~~a, , y ,~:1,~ ~ `~~ T t ? !'1; ~ . r ~ r'~ \ ~ ~ ~\ ` -, /-: TS ,i ~ ~.F~f~ ~ 5__ :\ ~=Y~G\F.: ', . ~, requested. Chevron === Steve Lambert Advising Reservoir Engineer Unocal Alaska Union Oil Company of California Box 196247 Anchorage, Alaska 99519-6247 Tel 907-263-7658 Fax 907-263-7847 salambert@chevron.com February 22, 2006 RECEIVED . .. ..1" \!\I\í{ \1 ~ l.\)\.ì~ FEB 2 4 2006 fjIG¡~~~f> . Alaska Oil & Gas Cons. Commission Anchorage Commissioner Chair John Norman Alaska Oil and Gas Commission 333 W. 7th Ave., Suite #100 Anchorage. Alaska 99501-3509 Dear Chair Norman: ~(ê<ê~\~ã ~\as.()'·:). Unocal requests administrative approval under Area Injection Order 5, Rule 9 for the continuation of injection of non-hazardous Class" fluids for the Grayling Platform Well No. G-5 RD, Injector (Permit # 98-120) in McArthur River Field. To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. Sundry notice of operations (Form 404). 3. Temperature survey (attached). 4. Maximum allowable injection pressure calculation in graphical form (attached). 5. Brief/relevant well history (below and attached). Well G-5 was originally completed as a Hemlock producer in 1968. The well produced almost 4 MM barrels before it watered out in December 1974. The well was converted to a dual Tyonek "G" and Hemlock water injector in late 1975. G-5 was the major source of pressure support for the west side of the crest of the structure. The well injected almost 66 MM barrels of water before it was shut-in for a redrill in 1998. G-5 was shut-in due to tubing and casing communication and due to a poor injection profile. Hemlock bench 2 was taking a majority of the fluid. Following the red rill , the well was completed as a single string "G" zone and Hemlock injector in July 1998. Only benches 3 and 4 were completed in the Hemlock. An injection profile in March 1999 showed that 480/0 of the injection was entering the "G" zone and 52% was entering the Hemlock. No injection was entering bench 2. On December 9,2005 G-5RD developed communication between the tubing and casing and was shut-in. The AOGCC approved returning the well to injection for a test and on January 22, 2006 the well was returned to injection. A temperature survey run on February 21 following 30 days of injection, confirmed that all the injection was exiting the perforations. If approval is received to resume injection, Unocal will continue to monitor and record daily injection rates and tubing and casing pressures. This data will be provided to the AOGCC as part of the monthly reporting process. A temperature survey will be run every 2 years to insure that the injected water is contained within the completion interval. Chair John Norman AOGCC February 22,2006 Page 2 ~~Xo~ - Steve Lambert cc: MIT book Well File DV Collar 4~6' -f 6936' - - -- Sidetrack Whipstock KOP 7257' t UNOCALe RKB to TBG Hngr = 32.97 Tree connection: 4-1/2" 5.000# " / 1 - - - _. SIZE 16" 13-3/8" Redlill Window 9-5/8" 9-5/8" 9-5/8" 9-5/8" DV Collar 9-5/8" 7" liner Tubing 4-1/2" 3-1/2" Trading Bay Unit Well # G-SRD Actual Completion 7/7/98, Reperf 9/16/98 WT 75 54.5 GRADE 1-55 K-55 CASING AND TUBING DETAIL CONN ID Butt Butt 12.615 CMT 1398 sx 2600 sx /:-:-:-:-: :-:-:-:-:'\. TOP Surf Sun. 7257' BTM. 591 ' 3078' 47 N-80 Seal Lock 8.681 6925' 7257' 43.5 N-80 Seal Lock 8.755 5187 6925' 40 N-80 Seal Lock 8.835 79' 5187 4376' 4378' 47 N-80 Seal Lock 8.68\ Surf. 79' 29 L-80 Buttress 6.184 6936' 10,647' 12.6 L-80 Buttress Mod 3.958 Surf 6879' 9.3 L-80 8rd Mod 2.992 6879' 9368' JEWELRY DETAIL NO. J)epth ID Item 6879 4- 112" Butt Mod x 3- 112" 8rd Mod crossover 2 9292 3.25 Baker "SAB- I" pkr, 3.25 With K-22 tubing anchor 9297 3.75 Mill out Extension 9334 2.813 "X" nipple 4 9368 2.992 3-1/2" tubing tail PERFORA TION DATA G-2 9,470' 9,495' 25' 6 7/6/98 TCP perf 9,478' 9,493' 15' 4 9/16/98 2-1/8" Power strip G-2A 9,530' 9,545' 15' 6 7/6/98 TCP perf 9,508' 9,540' 32' 4 9/16/98 2-1/8" Power strip G-3 9,565' 9,595' 30' 6 7/6/98 TCP perf 9,563' 9,588' 25' 4 9/16/98 2-1/8" Power strip G-4 9,635' 9,700' 65' 6 7/6/98 TCP perf 9,638' 9,688' 50' 4 9/16/98 2-1/8" Power strip G-5 9,750' 9,850' 100' 6 7/6/98 TCP perf 9,753' 9,815' 62' 4 9/16/98 2-1/8" Power strip B-1 9,995' 10,020' 25' 6 7/6/98 TCP perf 9,995' 10,020' 25' 4 9/16/98 2-1/8" Power strip B-3&4 10,205' 10,315' 110' 6 7/6/98 TCP perf 10,160' 10,192' 32' 4' 9/16/98 2-1/8" Power strip 10,210' 10,242' 32' 4' 9/16/98 2-1/8" Power strip 10,270' 10,302' 32' 4' 9/16/98 2-1/8" Power strip Landing Collar = 10,559' O:\OOE\O~ón\cb~a9J~Wel1s\G-05Inj\G-05RDInj\Schematics\G-5rd Schm 9-16-98Perf.doc TD:: 10,650' MD/9968' TVD MAX HOLE ANGLE = 42° 9292' ~"";"""'.'. '\.... r.···.···'·.····.·.·.·.:..·..·:·:..... 2 " ",,,., '," '. .. '.:"""'.,1.. '. ..,.\' 3 . . 4 5 - - - = G zone & = Hemlock Perfs 9470'· 10315' - - - - - - / " ORA WN BY: TAB REVISED: 02/22/06 500 (I 1000 2000 3000 4000 5000 6000 1000 8000 9000 10000 11 000 55 Report date: 2122/2006 Well: 1250 2000 2750 3500 4250 5000 5750 65 75 85 95 105 115 25 135 145 Temperature (Deg. Pressure Perfs 16" 13-3/8" ~7'f -2-20-06 -1-21-06 ex-5RD Well History Last Update: Date 1/13/1998 7/1/1998 7/2-3/1998 7/4-5/1998 7/6/1998 9/6-11/1998 9/6-11/1998 9/14-16/1998 3/6-7/1998 12/9/05 1/22/05 1/21-22/06 1/22/2006 Description G-5 (RAN TEMP SURVEY) RIH with 2.72" GR to 9155'RKB. Would not go past. POOH. Start electronic gauges. Wait till gauges awake. RIH with electronic gauges at 60 ' per minute, making 2 minute stops, at 1,000'; 2,000'; 3,000'; 4,000'; 5,000'; 6,000'; 7,000'; 8,000';9,000'; and 9,145'RKB. POOH at 60' per minute. Out of hole Schlumberger and RIH with AIT/LDT/CNUSonic/GR tool string. Set down and could go no deeper than 9400'. Log from 9400' to 7262'. POOH with logging tools. RD Schlumberger. Prepare to run 7" liner. Ran 3711' of 7" 29# L-80 TKC buttress liner to 10,650'. Rotate and reciprocate liner while circulating. Drop ball and set liner with top of liner at 6936' and bottom of liner at 10,647', Could not shear release running tool before ball blew out at 2900 psi. Left hand safety release running tool. Attempt to reengage running tool to rotate liner. Unable to establish rotation, appeared that rotation dogs were slipping. Prepare to mix and pump cement. Pump 1050 sx (220.7 bbl) Class G cmt with additives, drop wiper plug and displace with 10 bbl fresh water and 240 bbl mud. Did not bump plug. Unstung from liner with running tool. POOH with drill pipe, last 1460' had heavy cmt coat on OD of drill pipe. RIH with 8-1/2" clean out assembly. Took weight at 5788', washed down to hard cement at 6200'. Drilled hard cement from 6200' to top of liner at 6939', Circ and POOH with 8-1/2" cleanout assembly, Pressure test casing and liner lap to 2300 psi for 30 min. (Dropped to 2274 psi in 15 min and 2254 psi in 30 min.) RIH with 6" clean out assembly. Tag cement at 6943' and clean out cement to 6960'. RIH to 9915' and wash down to 10,035'. Tagged wiper plug at 10,035'. Drill wiper plug and hard cement from 10,035' to 10,558'Ianding collar. Circ hole to filtered inlet water. Closed pipe rams and pressure test 9-5/8" casing and 7" liner lap to 2300 psi- bled to 2150 psi in 30 min. Questionable ram leak, rainy conditions made it difficult to see ram leak. POOH with 6" clean out assembly. RU Schlumberger and log TDT from 10,545' to 6900'. Log CET/CBT from 10,546' to 6900'. RD Schlumberger. Closed blind rams and retest casing and liner lap to 2330 psi- bled to 2276 psi in 30 min. Perform weekly BOP test. Load out Halliburton TCP guns. RIH with 4-5/8" guns on drill pipe. RU Schlumberger and run GR-CCI tie-in pass. Placed guns on depth and drop bar to fire guns: 9470'- 9495',9530'-9545',9565'-9595', 9635'-9700', 9750'-9850', 9995'-10020',10205'-10315' at 6 spf. Fluid level dropped, filled annulus with 8 bbl FIW. Circ well with 30 bbllhr loss. POOH with spent guns. PS - (Completed 5 day SBHP Survey). Pulled electronic gauges out of Ihole. Bleed down lubricator. Turned top gauges off. Turned bottom gauges off. Checked information looked good. The Fall Off Survey, conducted on 9/6-11/98 (prior to reperforating the well to increase injection rate) indicates a relatively low permeability completion (517 md-ft) over the 370' of perforated interval (+/-270' of pay). The skin factor is about +5.0. The current injection rate is about 2,200 BWPD PF - Perforate & "G" Zone & Hemlock W/2-1/8" Power Jet Guns, 4HPF, 00 Phase. Schlumberger Water Injection Profile Surface Conditions: Zone G-2 G-2A G-3 G-4 G-5 8-1 8-3&4 8-3&4 8-3&4 Pressure observed on tbg-csg annulus. Shut well in. Receive approval for injection test. Start injection for 30 day test period. Ran temperature survey following 30 day injection period. No indications of tubing or casing leaks, O:IOOElOOEFieldsl TBUlGraylingIWellsIG·05In\G'()5RDln\Well HistorylC35RDWellHlstoryJHM Perforated Interval 9,470'-9,495' 9,509'-9,544' 9,563'-9,595' 9,635'-9,700' 9,750'-9,850' 9,995'-10,020' 10,160'-10,932' 10,210'-10,242' 10,270'-10,302' Water Inj. BPD -452.7 -379.1 -84.5 -344.8 -515,5 o o -1273.6 -695 -3745.2 Percent 12.1 10.1 2.3 9.2 13.8 ° ° 34 18.5 100 Page 1 01 1 1,000 . ~ 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000· 10,000 . 11,000· 7,000 8,000 9,000 10.000 SF HP -Intema! Fluid Hydraulic Pressure Formation facture pressure @ 0.7 #/ft -Production CYP@ 70% -MASP (production Ci.'!sing) -MA$P {Jntermed¡~teca5¡ng) -Surface CYP @45% - Outside Containment for Surface casing ~-- MA$P (Surface casing) Current Pressure Røadìngs RE: G-5RD Injection ) ) Thanks Tom) I am sending over the AA today. We have also had a chance to evaluate the logs on G-16 and I will be sending that analysis over as soon as I can get it summarized. \&--0 From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us) Sent: Thursday, February 23, 2006 7:57 AM To: Lambert, Steve A Subject: Re: G-5RD Injection Thanks Steve, I would agree with your assessment the temperature log for G-5RD shows that the water is being accepted into the intended injection zone. On this basis it is acceptable to keep the well in operation. This well should be added to Larry's list as others have. I will look forward to receiving the AA. When you submit the AA, be sure it is a separate document from the 404 transmitting the temperature information. That helps eliminate possible mishandling over here. Call or message with any questions, Tom Maunder, PE AOGCC If" till" ~"1 ('" I!:)I 2006 ~tA~tNlE{~) 1\\1Pt"lwt \\~ ({.¡. ~ Lambert, Steve A wrote, On 2/22/2006 3 :06 PM: I don't think we waíted long enough following injection to run the temperature log. We always request a 12 hour delay following injection before we run the log, but in this case we probably should have waited 18 hours. With more time I think we would have picked up the character of the static log. I think the log still shows us what we want to know. There are no shallow zones which are receíving injection water. Only G-5RD is shut-in, the rest of the waterflood is up and running. From: Thomas Maunder [mailto:tom, maunder@admin.state.qk.us] Sent: Wednesday, February 22, 2006 1:19 PM To: Lambert, Steve A Subject: Re: G-5RD Injection Hi Steve, I have had an opportunity to look at the temperature log. It shows the expected cool down with the resumption of injection. It is interesting that your "after" log doesn't show the before character. Hal had a couple of wells on King that showed the character in both logs. Any idea why the difference? Did shutting in the well force the water flood down? Tom Lambert, Steve A wrote, On 2/22/2006 10:34 AM: 10f2 3/1/2006 10:29 AM RE: G-5RD Injection ) ) Tom we have the well shut in. We will contnue to prepare the admin approval. If we can get your early approval to return to injecion, we would appreciate it. From: Thomas Maunder (mailto:tom. maunder@admin.state.ak.us] Sent: Wednesday, February 22, 2006 9:46 AM To: Lambert, Steve A Subject: Re: G-SRD Injection Steve, I won't be able to look at this until maybe this afternoon. I am in and out due to allergy shots. Tom Lambert, Steve A wrote, On 2/21/20062:22 PM: Tom, Unocal received approval of the sundry for temporary injection into well G-5RD. (Sundry 305-393) The injection test was started on January 22, and a follow-up temperature survey was run yesterday (Feb. 20). The temperature survey does not indicate any anomalies and we are in the process of preparing the request for Administrative Approval to continue injection. With your approval we would like to continue injection into the well until we have received a response from the AOGCC on the request for Administrative Approval. «G-5 Temperature Survey.zip» 2 of2 3/1/2006 10:29 AM ) Chevron III Steve Lambert Advising Reservoir Engineer February 23, 2006 Thomas Maunder Alaska Oil and Gas Commission 333 W. 7th Ave., Suite #100 Anchorage. Alaska 99501-3509 (f- \rvÐ V'!\lJ Dear Tom: ) Unocal Alaska Union Oil Company of California Box 196247 Anchorage, Alaska 99519-6247 Tel 907-263-7658 Fax 907-263-7847 sala m bert@chevron.com RECEIVED FEB 2 4 2006 Alaska Oil & Gas Cons. Co·rnroission Anchorage Please find attached state form 404 and the temperature log for well G-5RD. The log was run following a 30 day injection period. The temperature profile confirms that all of the injected fluid is leaving the wellbore at the perforations. If you have any questions or would like to discuss this further please contact me. ~~~~ Steve Lambert cc: MIT book Well File ~ÇANNE~,) ~~'£B 2 S 2DÛ& ) STATE OF ALASKA ) ALASI\.A OIL AND GAS CONSERVATION COMMISSION J:)ECE1V REPORT OF SUNDRY WELL OPERATIONS' . I ED StimulateU rCBth2- r!J 2006 Waiver 041 :Tirw'F~e,Q~i,orÐ Re-eñle'sJ<J1spJh~~~t~t!!!rSo Comrnission 5. Permitto~U~~lr: Exploratory 0 98-120 Service 0 6. API Number: 50-733-20060-01 9. Well Name and Number: Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 Stratigraphic 0 1. Operations Abandon U Repair Well U Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Ope rat. Shutdown 0 2. Operator Union Oil Company of California Name: 3. Address: Box 196247, Anchorage, Alaska 99519 7. KB Elevation (ft): 99' aove MSL 8. Property Designation: Trading Bay Unit ADL 17594 11. Present Well Condition Summary: G-5RD 10. Field/Pool(s): MacArthur River Field, Tyonek G and Hemlock Plugs (measured) Junk (measured) Total Depth feet feet measured 10,650' true vertical 9,9681 feet feet Effective Depth measured 10,558' true vertical 9,887' TVD Burst Collapse 367' 591' 2,630 1,020 3,016' 3,090 1,130 7,130' 5,750 3,090 6,811-9,964' 8,160 7,020 Casing Structural Conductor Surface Intermediate Production Liner Length Size 367' 26" 591' 16" 3,078' 13 3/8" 7,257' 95/8" 3,711' 7" MD 367' 591' 3,078' 7,257' 6,936'-10,647' Perforation depth: Measured depth: 9470-9495, 9530-9545, 9565-9595, 9635-9700, 9750-9850, 9995-10020, 10205-10315 True Vertical depth: 9009-9027,9052-9065,9080-9102,9132-9181, 9218-9296, 9411-9430, 9582-9675 4 1/2" 12.6#, L-80 Surf-6,879' Tubing: (size, grade, and measured depth) 3 1/2" 9.3#, L-80 6,879-9,.368' Packers and SSSV (type and measured depth) Baker Model"D" Perm Packer Depth 9,292' 12. Stimulation or cement squeeze summary: Intervals treated (measured): {:b-ß e:J 7 RBDMS 8Ft. J.' ~;1 (I ~. 2006 Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 3182 2400 13. Oil-Bbl Tubing Pressure 2500 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Temp Survey Daily Report of Well Operations 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: OilO Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 0 GINJ 0 WINJ 0 WDSPL 0 Sundry Number or N/A if C.O. Exempt: ~Oj~q~ ~ p"t.. 7"h\ Advising Reserv~ ,~?~~ 'ð J6PO Contact Printed Name . s~mbert Signature~ Form 10-404 Revised 04/2004 Title Date ""[/23/-Z00[, Submit Original Only o Rht'C\N^1 500 o 1250 2000 Pressure (psia) 2750 3500 4250 5000 5750 8000 - 1000 Pressure-Temperature Profile 2000 3000 4000 - ... Q) ~ 5000 - c :E I ..c 6000 ... Q. Q) C 7000 9000 fIf!!f J 11000 55 65 75 85 95 105 115 125 135 145 Temperature (Deg. F) -2-20-06 Pressure 13-3/8" -T8G Perfs 9-5/8" -2-20-06 Temp 16" _7tl -1-21-06 Temp Report date: 2/23/2006 @~l! ¡rrF :®ûuuulb e (ill'. U~~ I. .~. · , 'u' , - .,- , ,: e ¡~.'.j'¡ , ! , :1 ~ Œ\ Lrù FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Lambert Reservoir Engineer Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 \ qq,r I dJ) Re: Trading Bay Unit G-5 RD Sundry Number: 305-393 Dear Mr. Lambert: (, 'If' l.", S" ~ .... ð')~ßi.¡JlJs~EL,. 0< (U 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing- has been requested. DATED this1i1:day of December, 2005 Encl. r;].1 RE.CEI\/t=:D "'1"-r I,¿Jt7-1 k STATE OF ALASKA " . r æ, '~~7 O!:,¡ ALAe Oil AND GAS CONSERVATION COMMI ION . \"d(.. DEl.? 2. k! _0 ~ APPLICATION FOR SUNDRY APPROVAL Alask:;)ólÎ.:lBS Gon5. 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: b.f\rhnrsoe Perforate U Waiver U Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 1. Type of Request: Abandon U Alter casing 0 Change approved program [] 2. Operator Name: Union Oil Company of California 3. Address: P.O. Box 196247 Anchorage, Alaska 99519 7. KB Elevation (ft): 99' above MSL 8. Property Designation: Trading Bay Unit ADL 17594 11. Suspend 0 Repair well 0 Pull Tubing 0 Other U 5. Permit to Drill Number: 98-120 ./ 6. API Number: o o Exploratory 0 [] Development Stratigraphic Service v 50-733-20060-01 9. Well Name and Number: G-5 RD 10. Field/Pools(s): McArthur River Field, Tyonek G/Hemlock PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): 10,650' Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 9,968' Effective Depth MD (ft): 10,558' Effective Depth TVD (ft): 9,887' Plugs (measured): Junk (measured): Length 367' 591' 3,078' 7,257' 3,711' Size MD 367' 591' 3,078' 7,257' 6,936'-10,647' TVD 367' 591' 3,016' 7,130' 6,811 '-9,964' Burst Collapse 26" 16" 2,630 3,090 5,750 8,160 1,020 1,130' 3,090 7,020 133/8" 9 5/8" 7" Perforation Depth MD (ft): 9470-9495,9530-9545,9565- 9595, 9635-9700, 9750-9850, 9995-10020,10205-10315. Perforation Depth TVD (ft): 9009-9027,9054-9065,9080- 9102,9132-9181,9218-9296, 9411-9430,9582-9675 Tubing Size: 41/2" 3 1/2" Tubing Grade: 12.6#, L-80 9.3#, L-80 Tubing MD (ft): Surf-6.879' 6,879-9,368 Packers and SSSV Type: Baker model "0" perm packer 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Packers and SSSV MD (ft): Packer @ 9,292' 13. Well Class after proposed work: Exploratory 0 Development 0 Service [] 15. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Nam,,- ~teve Lanf\e1 Title Reservoir Engineer Signature \ ~ \r'k..... r ^ ~ ~ Phone Date 1/1/2006 Date: Steve Lambert 263-7658 12/20/2005 COMMISSION USE ONLY '30'8; ¿J13 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 Other: 4~ ~It \ \..~ BOP Test 0 o o Mechanical Integrity Test Location Clearance ~\'l ~pc~~~ ~~-\- SUbsequen~_r~ . -\ ~~\ -..u-f ~~~~,c.c '\ ~Ça,~ "- ( I~{ ; ~ APPROVED BY Approved byT / f /1' t(l1" n OJ c. I i\ I 9\>~ISSIONER THE COMMISSION Form 1lr-'403 R~005 ~ I V I I \J ! "\ L. RBDMS 8Ft ,IAN 0 3 2006 Date: 1~-~1-~ Submit in Duplicate e e Chevron === Steve Lambert Reservoir Engineer Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7658 Fax 907 263 7847 Email salambert@chevron.com R I\/E December 20, 2005 L2 j~ 2005 A¡¡¡8k~ ~ CommissÎ(m Anchorage Tom Maunder Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 RETURN TO INJECTION GRAYLING PLATFORM WELL NO. 5RD MCARTHUR RIVER FIELD , Dear Tom: Unocal is proposing to return well G-5RD to injection. Enclosed is form 10-403. Well G-5RD experienced pressure on the tubing casing annulus and was shut-in on December 9. The well is a critical component of the efforts to maintain productivity and improve recovery from the Hemlock reservoir. Following is the proposed procedure for bringing this well back on injection. 1) Obtain permission to inject. 2) Baseline temperature survey 3) Inject until the well has stabilized (approximately 1 month). 4) Follow-up temperature survey. 5) Obtain variance to inject. 6) Monitor well daily and repeat temperature surveys every two years. Sincerely, ~t Please let me know if you require additional information. T~CÐt-J\.'M...(¿S;j G-~~~Œ.\ á-\J~~~~ æ~~~r I \-.c.~Q:.~0-~"C~~~\<L ~\C::?" T+n \~'c..o.-~~'~-\- ~~~~\~ \.'>~ \O-~r-- ~\"";> ~ <:o~'\~.\.\'-.:)",~s;. \~ "Z..C)~.\l-.é.. ''"? t<:)~~'~~\-~C3.-~~ s:\~ tPA ~~~-\t~~\.~&~ ~\-l.\G <:.~~ \ 4.~ , \0 d-~'\<"~')(. \ \) JfJ-1JV1:I::?~e.~:'m ' Steve Lambert Enclosure Union Oil Company of California / A Chevron Company FW: G-5 Shut-in e e Subject: FW: G-5 Shut-in . .. . From: "Lambert,ßteve A" <salambert@unocal.com> Date:Tue,13 Def?005 03:45:09 +0800 To:' Thomas Mauh~~r:><tom _ ma\1ndet@admin.state.ak.us> ...,.,. .. Sorry Tom, the correct well name is G-5RD not G-5. 4 \<;.~- \"dO From: Lambert, Steve A Sent: Monday, December 12, 2005 10:22 AM To: Thomas Maunder Cc: Cole, David A; Greenstein, Larry P Subject: G-5 Shut-in Well G-5 experienced high casing pressure and was shut-in on December 9. Attached is a plot of the recent well performance. We are planning to have the wellhead inspected to insure that it is not a wellhead problem. The well will remain shut-in. «Injection Performance 12-05.xls» Content-Description: Injection Performance 12-05.xls Performance 12-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 12/27/2005 10:40 AM 1 o Press 9 5/8 1 3 3/8 .....- Press Rate 1 o e e ,s<t --'dO MECHANICAL INTEGRITY REPORT' .... :..IG RE~~;'_S'::: OPER Ex FIELD ")ir'O~\,~0 I-I"LLL NUMBER G - () S R \) ::?UD D.....;:~: '~t;.LL DAIJ.. TD: TVD j :?BTD; ill) TVD . till.. e2.si~g: Shoe: MD TVD¡ DV: ill) -TVD _::"':ìe'2:": ì\\ Shoe: \O"L\.~ MD I'lD i :CF: (,<;3 Co HD :TD :-'Joi:;g: Packer HI) TVD; Set ê. t ~V) ana Perfs <;'-\\.'0 "-' to \ D ~ \ ~ '.' :.ole Si.ze :-:ECP.Þ-1EC'·..L INTEGRITY - PART il Annulus Press Test: ~p 15 min j 30 min Coüaents: IN«\\ ""-'>~::r>\t ~c..';',,>';;J ~\.. \,::" l~-.)~ \-< IÀ ~~~ÌI,'tCA..~C)(J- ~ '. ld d -0 S- ~CHÞ3'lJ:CÞ.J.. INTEGRITY - PART /2 \050"::>)< ~.. ., dCds' 2'_\. blo \ 50 ., DV e em en c Volumes:' .A..mt. Liner \ ~ Cwt -"01 to cover Der=s ~ 7>a¿~ 'f:...':> 4<; ~~\s~· (ß)\.2ß.\~...J.? -fSt:i:/ "l'heorecical Toe SI':i'''' «>" \ I~Q c F~" \-~ \, ~~ C'Lt,()'-.\Çð \\~, \.-o? 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' ............... ..~~.~.....~N'...~_ ...·"_"....IIIIIiIllVlll~""""II"'"_II'"~~~"..III'_=....._~__.--...-~1!II ....d hI!' == ô ~~ ~ .,:.~.....I ~ Ay,toShapes. " "'0 0 ~ -4 ïl1 ¡ ~ '¡':J:':A:'::"'~ ~ ." ......···:···:::::::::::::::..T:::;:::::::;::::::::::::::~7,:::::::;:::::::;:::;::L8~F~~¡fD~~~::.::~:;:::.:~~2~~¡¡;~!'r~%··_.... ¡ ,R ·...TTT<.;rf~,~-=.ij¡·:dn n /1 :. ';!@. L ;::..~.. ;¡. , ~fi~ ~, :~~;;~...:...":"'-.~~~,"_...._""..............:.......;....~..~:....,,.._~._ .~~_.......,".........",..........."",..",....~ ~.~_~~"""".".""""""~".,,,.,,,,,~.,_,,_,,,,,,_,,_,,.,,."""""""i""". """""" ..,,'''...''... .................."""'.",,",,",, ...."."......................................,.. 1.1/' ., , .. Slide 1 [Fwd: G-5 Shut-in] e e fIt):xL t q ß:- lZú il3«.q.- ()<5~ Subject: [Fwd: G-5Shut~in] From: Thomas Maunder <tom_maunder@admin.state.ak..us> Date:. Mon, l~].~ec 2005 10:27?~4i-~900\iJx~~\~ To: JIm Regg'~Jlm_l1egg@admm.sta:te.ak.us> d?-.~~ '¿{ftL". ':0::," FYI. Another one for Unocal. -------- Original Message -------- Subject: G-5 Shut-in Date: Tue, 13 Dee 2005 03:22:28 +0800 From: Lambert, Steve A<:::;<:t~91T'Þ~E1:;(~~1~(?C:;(;l;:C:;c:Jll!:?: To: Thomas Maunder <tom maunder@admin.state.ak.us> cc: Cole, David A<:gc:;c:>~"'(~~~c:>c:;9~:c:;(?1!l?:, Greenstein, Larry P <greensteinJ..p@unocal . com> Well G-5 experienced high casing pressure and was shut-in on December 9. Attached is a plot of the recent well performance. We are planning to have the wellhead inspected to insure that it is not a wellhead problem. The well will remain shut-in. «Injection Performance 12-05.xls» Performance Contcnt- T)'pe: applicalion;'vnd.ms-cxcel Content-Encoding: base64 .., 'Ii" t!\\M\i::~t,:r \~~'tr\'J -..J J~"~", c 1 of} 12/12/2005 1 :00 PM G-51 ---- __ Press 95/8 Press 13 3/8 Press -.- Rate 1 ,000 1 o 0 MEMORANDUM ') State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor !7) Kei1 Z'¡ ZA 10'-; DA TE: Tuesday, February 22, 2005 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA G-05RD TRADING BAY UNIT G-05RD LC' CO - (~O ( FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: '"ÍÌ:'''' P.I. Suprv JC!'-- Comm Well Name: TRADING BAY UNIT G-05RD Insp Num: mitLG050220181 113 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-733-20060-01-00 Permit Number: 198-120-0 Inspector Name: Lou Grimaldi Inspection Date: 2/19/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well G-05RD Type Inj. p TVD 8875 IA 410 2280 2260 2260 P.T. 1981200 TypeTest SPT Test psi 2218.75 OA 156 165 165 165 Interval 4 YRTST PIF P Tubing 3100 3100 3100 3100 Notes: Good test. IA checked for fluid to surface. SC¡ANNE[) MÞ¡R 11 2.005 Tuesday, February 22, 2005 Page I of I .) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test .rf ~/\ {) \f\ ¡ ~ G Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us greensteinlp@unocal.com; trodriguez@unocal.com OPERATOR: Unocal Alaska FIELD I UNIT I PAD: McArthur River Field I TBU I Grayling Platform DATE: 02/19/05 OPERATOR REP: David Myers / Charles Chezik AOGCC REP: Lou Grimaldi Packer Depth Pretest Initial 15 Min. 30 Min. Well G-5RD Type Inj. S TVD 8,875' Tubing 3,100 3,100 3,100 3,100 Interval P.T.D. 198-120 Type test P Test psi 2219 Casing 410 2,280 2,260 2,260 P/F Notes: OA 156 165 165 165 Well G-16 Type Inj. S TVD 8,833' Tubing 3,250 3,250 3,250 3,250 Interval P.T.D. 168-109 Type test P Test psi 2208 Casing 1,750 2,300 2,290 2,290 P/F Notes: OA 210 210 210 210 4 P 4 P Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) SCANNED FEB 2 8 2.005 MIT Report Form Revised: 06/19/02 MIT_Grayling- 02-19-05.xls MICROFILMED 7~3O~02 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Saved as M:/weepie/microfilm_marker.doc MEMORANDUM · TO: Camille O. Taylor ~'~/~v~ Chair Maunder THRU: Tom P.i. Supervisor~'~'~ ' FROM: JOhn Cdsp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: OCtober 1, 2002 SUBJECT: Mechanical Integrity Tests Unocal Trading Bay Unit McArthur River Field Grayling Platform NON-, CONFID, ENTIAL - Packer Depth Pretest Initial 15 Min. 30 Min. We,I .G-5R.D. I,Typein. j.I 'S IT'V'D- I ~s ITu~i.~l 3~001 3~001 ~00 i' ~00 I~n, ter~&~I 4 P.T.D:I 1981200 I~Pe~s~l . I,Tes~ps~l, 2400 I ,Casingl 760 I 24o0 I 24o0 I 2400 I P/F I _P Notes: OA pressure 70 psi. 'we,! g-16 I Typelnj. I 'SI T.V:D. i 8833 I'Tubi,ng !, 3250 I ;~250. I 3250 I 3250 I'hte. rvall ,4 P.T.D.I 1681090 ITypet,estl P ITestpsiI 24,50 I Casingl 1900 I 2450 I 2425 I 2425 I P/F ,I E Notes: OA pressure 310 w~,I ~-~ I Type,nj.I s I T.V.D. I ~ I Tub'ngl ~00 I'~00 I ~00 I ~00l i~tervail 4 P,.'T.D.I 1690170 ITyPetes{I, P ITestpsiI' 2500 I Casi'ngI 640 I 2500 I 25oo I. 250o I P/F I P Notes: OA pressure 125 - 210 during pressure test. . We,I g-22 ITYpelnj. i s'I ~:V.D. ! ~ I Tu~"n~I ~00'1 ~001 ~001 ~0~ llnte~v=~l 4 P'..T.b.I ~750,60 ITypetes.t.I P.. ITestpsil'2350 I Casingl 6~-0 .I. 2350 I 2350 i ~.350 '1' PIE I;'P No ,res: OA pressure 180 psi. - 300 during pressure test,. , , wel,I G-23RD I T~,e,nj.! S IT'v'D' ! 6459 I Tubing ! ~00 I ~00 I ~00 I ~00 i l.tervail 4 PiiT. D.I 1790140 ITypetestI P I Testpsil 2300 I Casing I' 560 I 2'30O I 2300 I 2300 I P/F I P Notes: OA pressure 86 psi. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS IN J, S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required byVariance W= Test dudng Workover O= Other (describe in notes) Test's Details I traveled to Kenai Alaska 09-30-02 to be available to travel to the Grayling Platform ~ 0630 hrs. 10-01-02. Testing went Well w/Water Flood Operator David L. Meyers conducting tests in a safe & efficient manner. No failures were witnessed. All OA pressures were observed & recorded during tests. With no permafrost concerns, all tests utilized filtered Inlet water for test fluids. M.I.T.'s performed: _5 Attachments: Number of Failures: _q Total Time during tests: 4 hm. ,,cc; MIT report form 5/12/00 L.G. MIT Grayling Pit. 10-01-02jc.xls 10/9/2002 Beverly Harrison Business Ventures Assistant Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonbOunocal.cmn UNOCAL May 30, 2002 To: Lisa Weepie AOGCC 333 W. 7th Ave. Anchorage, AK 99501 DATA TRANSMITTAL - Alaska / Offshore / Grayling Platform Dry Samples G-5RD 7290'-9000' Box 1 of 3 } e/~-j~ 0 9000'-9960' Box 2 of 3 ~lc~ q '~) 9960'-10650' Box 3 of 3 G-21.RD 7870'-9300' Box 1 of 3 o94 0¢Y 9300'-9890' Box 2 of 3~ (/8 cbc{ / 9890'-10950' Box 3 of 3 Please acknowl~f/~¢/ receipt by jcgning .~nd/e}umir/g one copy of this transmittal or FAX to (907) 263-7828. Received by: ~ f/~44/~¢~[ Date: 5 ~ ,'~ ¢0~1-- STATE OF ALASKA ALASKA OiE-AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED: ABANDONED: SERVICE: X 2. Name of Operator 7. Permit Number Unocal Oil Company of California (UNOCAL) 98-120 3. Address 8. APl Number P. O. Box 196247, Anchorage, Ak 99519 50- 733-20060-01 4. Location of well at surface "'~;~"i"!~i~i~71'~ii!~;"~;~i i~[ 9. Unit or Lease Name 1838' FSL, 1487' FEL, Sec. 29, T9N, R13W, SM .' ..... -. : . .~ Trading Bay Unit At Top Producing Inte~al "G" Zone ~ 9,421 1683' FNL, 1194' FEL, Sec. 29, T9N, R13W, SM ; ~ ',',~'. ~ ; Grayling G-5RD At Total Depth .... ~-~' ..... ~ ~ , 11. Field and Pool 1308' FNL, 582' FEL, Sec. 29, T9N, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. McArthur River Field 99' RKB above MSL ADL 17594 Hemlock and Middle Kenai "G" Zone 12. Date Spudded6/19/1998 13~DateT~D~R~a~~~d~14~Dat~C~m~~~~us~.~rAband.~15~~at~rD~~~h~if~~sh~~~~16~N~~~f~~m~~~~i~ns7/1/1998 7/8/1998 '- 61' feet MSL 1 ~. Type Electric or Other Logs Run AIT/LDT/CNUSonic/GR/S P/PEF, TDT/CET 23. CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 26" 1" wall 0 367' Drivern Driven 0 16" 75¢ J-55 0 591' ~" 1398 sx 0 13-3/8" 54.5~ K-55 0 3078' 18" 2600 sx 0 9-5/8" 40-47¢ N-80 0 7257' 12-1/4" 3000 sx 0 7" 29¢ L-80 6,936' 10,647' 8-1/2" 1050 sx 0 24. Perforations open to Production (MD+TVD of Top and Boffom ~d 25. TUBING RECORD inte~al, size and number) 6 SPF W/4-5/8" TCP Guns. SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 12.6¢, L-80 Sud To 6,897' 9470-9495', 9530-9545', 9565-9595', 9635-9700', 9750-9850', 3-1/2", 9.3¢, L-80 6,879' To 9,368' Baker SAB-1 ~ 9,292' 9995-10020', 10205-10315' MD. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9009-9027', 9054-9065', 9080-9102', 9132-9181 ', 9218-9296', 9411-9430', 9582-9675' TVD. 27. PRODUCTION TEST Date First Production ~ Method of Operation (Flowing, gas lift, etc.) NA~ Water Injector Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO NA NA TEST PERIOD => NA~ NA Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (corr) Press. NA NA 24-HOUR RATE => NA 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. 0RI61NAL Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 'r 30. ---- ' GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Tyonek "G" 9,421' 8,972' Hemlock 9,993' 9,409' 31. LIST OF A-I-rACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~-.)'~' c /'~t ~ Dale Haines Title Drilling Manager Date 7/8/98 Form 10-407 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each addilJonal interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-~i~ ~ jection, Gas Injection, Shut-in, Other-explain. ~- ;~ Item 28: If no cores taken, indicate "none". i: ;daska Oil ~: RKB to TBG Hngr = 32.97 Tree connection: 4-1/2" 5,000# 6936' Sidetrack Whipstock KOP 7257' 9292' 2 _=G zone & Hemlock ___-- Perfs 9470'- -- =- Landing Collar = 10,559' Bottom of Liner = 10,647' TD = 10,650' MD/9968' TVD MAX HOLE ANGLE = 42° SIZE GRADE Trading Bay Unit Well # G-SRD Actual Completion 7/7/98 CASING AND TUBING DETAIL CONN II) TOP BTM. CMT 16" 75 J-55 Butt 13-3/8" 54.5 K-55 Butt 12.615 Redrill Window 9-5/8" 47 N-80 Seal Lock 8.681 9-5/8" 43.5 N-80 Seal Lock 8.755 9-5/8" 40 N-80 Seal Lock 8.835 9-5/8' DV Collar 9-5/8" 47 N-80 Seal Lock 8.681 Surf. 79' 7" liner 29 L-80 Buttress 6.184 6936' 10,647' Tubing 4-1/2" 12.6 L-80 Buttress Mod 3.958 Surf 6879' 3-1/? 9.3 L-80 8rd Mod 2.992 6879' 9368' Surf. 591' 1398 sx Surf. 3078' 26009x 7257' 692_5' 7257' 5187 692.5' " 79' 5187 4376' 4378' JEWELRY DETAIL NO. Depth ID Item 1 6879 -4-1/2" Butt Mod x 3-1/2" 8rd Mod crossover 2 9292 3.25 Baker "SAB-I" pku-, 3.25 With K-22 robing anchor 3 9297 3.75 Mill out E~ension 3 9334 2.813 "X" nipple 4 9368 2.992 3-1 f2" tubing tail PROPOSED PERFORATION DATA I I AcCUm. Date Zone Top Btm Amt SPF ! Last Opr. Present Condition G-2 19,470' 9,495' 25' ! 6 [ 7/6/98 TCP per G-3 !9,565' 9,595'I 30'I 6 . 7/6/98 ITOPperl G-4 9,635' 9,700'165'I 6 I 7/6/98 IT_Cpp,~rf 0-5 9,75°'i 9,85°'I 1~'i 6 i 7/6/98 lTCPperf .. B-1 9,995' I 10,020' 25' I 6 7/6/98 [__TOP pen' B-3&4 10,205' 10,315' 11.0,;! 6 i 7/6/9_ 8 lT.._CPperf G-5RDactua17798.doc DIL&WN BY: TAB REVISED: 07/09/98 RKB to TBG Hngr = 32.97 Tree connection: 4-1/2" 5,000# 690,36. Sidetrack Whipstock KOP 7257' 9292' _--G zone & Hemlock Perf$ 9470 u Landing Collar = 10,559' Bottom of Liner = 10,647' TD = 10,650' MD/9968' TVD MAX HOLE ANGLE = 42° 1 .._ , Trading Bay Unit Well # G-5RD Actual Completion 7/7/98 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. CMT 16" 75 ,1-55 Butt 13-3/8" 54.5 K-55 Butt 12.615 Re&ill Window 9-5/8" 47 N-80 Seal Lock 8.681 9-5/8" 43.5 N-80 Seal Lock 8.755 9-5/8" 40 N-80 Seal Lock 8.835 9-5/8" DV Collar 9-5/8" 47 N-80 Seal Lock 8.681 Surf. 79' 7" liner 29 L-80 Buttress 6.184 6936' 10,647' Tubing 4-I/2" 12.6 L-80 Buttress Mod 3,958 Surf 6879' 3-1/2" 9.3 L-80 8rd Mod 2.992. 6879' 9368' Sm-f. 591' 1398 sx Surf 3078' 26C~)sx 7257' 6925' 7257' 5187 692,5" 79' 5187 4376' 4378' JEWELRY DETAIL NO. Depth ID Item 1 6879 -4-1/2" Butt Mod x 3-1/2" 8rd Mod mossover 2 9292 3.25 Baker "SAB-i" pkr, 3.25 With K-22 tubing an~or 3 9297 3.75 Mill out Ex-tension 3 9334 2.813 "X" aipple 4 9368 2.992 3-1/2" tubing tail PROPOSED PERFORATION DATA ] ACcum' ' Date1 Zone Top Btm Amt SPF I Last Opr. Present Condition G-2 I 9,470'. 9,495' 25' 6 ! 7/6/98 TOP G-2A I 9,530' 9,545' 15'I 6 I 7/6/98 ITCP perf G-3 9,565' 9,595,130;i 6_ j7/6/987/6/98 l~OPperf G-4 9,635' 9,700' I 65'I 6___ ¥CP perf G-5 9'750' i 9'850'i 100'. _6 i 7/6/9~8 ITOPporf 9,995' 10,020' B'II 25' I 6__. i 7/6/9~8 ,TCPperf B-3&4 10,205' 10,315'J 110' 6 i 7/6/98 TOP perf I ~Ui P 4- ~aska Oii '~ Gas Cons. ' '"-' ~ O0Bm~S810~ Anchorage G-5RDactua17798.doc DRA~,~ BY: TAB REVISED: 07/09/98 G-5RD Redrill Rig Work Summary 6/20/98 Pressure test BOPE to 5000 psi, annular to 3500 psi. Witness of test waived by Blair WondzelI-AOGCC. RU Schlumberger and set 9-5/8" bridge plug at 7283' ELM (3' above a casing collar). RIH with whipstock/window mills/MWD. Tag bridge plug at 7287' dpm. Orient whipstock at 45 deg right of high side. PU 3' and set whipstock with index tool and 3500 psi pump pressure. Shear off whipstock with 40K overpull. Change well over from brine to 9.0 ppg mud. Mill window from 7261' to 7273'. 6/21/98 Continued with mill and drilled formation to 7285'. Ream and circ window. Perform FIT to 2300 psi = 15.3 ppg EMW at 7273' MD/7142' TVD. No breakdown. POOH with window mills. All 3 mills undergauge. RIH with second tri-mill assy and ream window. POOH and top mill in gauge. RIH with 8-1/2" insert tri- cone bit #1 and drill from 7285' to 7357'. 6/22-27/98 Drill 8-1/2" hole from 7357' to 9676' 6/28-30/98 Drill 8-1/2"hole from 9676' to 9694'. Circ for bit trip. POOH, lay down MWD. Test BOPE (witness waived by Blair Wondzell- AOGCC). N RIH with Bit #3 (Insert Tri-cone). Drill 8-1/2" hole from 9694' to 10,290' drop single shot, POOH with bit #3. RIH with bit #4, ream from 10,075' to 10,290'. Drill 8-1/2" hole from 10,290' to 10,513'. 7/1/98 Drill 8-1/2" hole from 10,513' to 10,650' TD. Drop single shot and POOH. RU Schlumberger and RIH with AIT/LDT/CNLISoniclGR tool string. Set down and could go no deeper than 9400'. Log from 9400' to 7262'. POOH with logging tools. RD Schlumberger. Prepare to run 7" liner. 7/2-3/98 Ran 3711' of 7" 29# L-80 TKC buttress liner to 10,650'. Rotate and reciprocate liner while circulating. Drop ball and set liner with top of liner at 6936' and bottom of liner at 10,647'. Could not shear release running tool before ball blew out at 2900 psi. Left hand safety release running tool. Attempt to reengage running tool to rotate liner. Unable to establish rotation, appeared that rotation dogs were slipping. Prepare to mix and pump cement. Pump 1050 sx (220.7 bbl) Class G cmt with additives, drop wiper plug and displace with 10 bbl fresh water and 240 bbl mud. Did not bump plug. Unstung from liner with running tool. POOH with dailysum. DOC 7/4-5/98 7/6/98 7/7-8/98 drill pipe, last 1460' had heavy cmt coat on OD of drill pipe. RIH with 8-1/2" clean out assembly. Took weight at 5788', washed down to hard cement at 6200'. Drilled hard cement from 6200' to top of liner at 6939'. Circ and POOH with 8-1/2" cleanout assembly. Pressure test casing and liner lap to 2300 psi for 30 min. (Dropped to 2274 psi in 15 min and 2254 psi in 30 min.) RIH with 6" clean out assembly. Tag cement at 6943' and clean out cement to 6960'. RIH to 9915' and wash down to 10,035'. Tagged wiper plug at 10,035'. Drill wiper plug and hard cement from 10,035' to 10,558' landing collar. Circ hole to filtered inlet water. Closed pipe rams and pressure test 9-5/8" casing and 7" liner lap to 2300 psi- bled to 2150 psi in 30 min. Questionable ram leak, rainy conditions made it difficult to see ram leak. POOH with 6" clean out assembly. RU Schlumberger and log TDT from 10,545' to 6900'. Log CET/CBT from 10,546' to 6900'. RD Schlumberger. Closed blind rams and retest casing and liner lap to 2330 psi- bled to 2276 psi in 30 min. Perform weekly BOP test. Load out Halliburton TCP guns. RIH with 4-5/8" guns on drill pipe. RU Schlumberger and run GR-CCI tie-in pass. Placed guns on depth and drop bar to fire guns: 9470'-9495', 9530'-9545', 9565'-9595', 9635'-9700', 9750'-9850', 9995'-10020', 10205'-10315' at 6 spf. Fluid level dropped, filled annulus with 8 bbl FIW. Circ well with 30 bbl/hr loss. POOH with spent guns. Run 3-1/2" x 7" SAB packer with K-22 tubing anchor on tapered tubing, 3-1/2" 8rd mod x 4-1/2" buttress mod. Reverse circulate packer fluid with corrosion inhibitor in annulus. Drop ball to set packer at 9292' with 2500 psi tubing pressure. Pressure test annulus to 2320 psi, bled to 2303 psi in 30 min. Land hanger. Sheared out ball with 2800 psi. Set BPV, ND BOPE, NU tree and test to 5000 psi. MIT on annulus to 2300 psi, no pressure drop in 30 min. Witness of MIT was waived by Blair WondzelI-AOGCC. Move rig to G-15. dailysum. DOC STATE O F ALAS KA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: Unfon Oil Company (UNO.GAL) FIELD / UNIT / PAD: ~',~. LJ._, _(?/~-~_,./:.c.~ DATE: ! d6MMENT$: " '~oMMENTS: 'coMMENTS: - COMMENTSi c,~Mi'vlENTS: ; __ TBG. INJ. FLUID {;ODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUO OTHER P.P.G, Grad. 0.00 WELL TEST: Initial 0.00 4 - Year 0.00 Workover 0. 00 Other 0.00 Dlstdbution: odg- Well File c - Operator c- Database //' ! c - Trip Rpt Fil~ c - inspector OPERATOR REP SIGNATURE: '~~rM-,,- L/'v~Q-.~...._ , AOGCC REP SIGNATURE: Mi~' 't (F~ '17/96) UNOCAL GRAYLING Platform G-5Rd slot 94-17 McArthur River Field TBU, Cook Inlet, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : PMSS <7261-10650> Our ref : svy5801 License : Date printed : 10-Jul-98 Date created : 22-Jun-98 Last revised : 10-Jul-98 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 36 18.018 Slot location is n60 50 22.920,w151 36 47.999 Slot Grid coordinates are N 2502389.758, E 212200.264 Slot local coordinates are 1839.90 N 1485.90 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North UNOCAL GRAYLING Platform, G-5Rd McArthur River Field,TBU, Cook Inlet, Alaska SURVEY LISTING Page 1 Your ref : PMSS <7261-10650> Last revised : 10-Jul-98 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth R E C COO 0.00 0.00 0.00 0.00 0 100.00 0.32 181.29 100.00 0 200.00 0.20 265.10 200.00 0 300.00 1.20 298.90 299.99 0 400.00 1.10 303.30 399.97 0 500.00 1.03 296.80 499.95 1 600.00 1.02 295.21 599.94 2 700.00 2.55 319.40 699.89 4 800.00 5.15 328.80 799.65 10 900.00 7.87 339.00 899.00 20 TANG U L A R R D I NAT E S Dogleg Deg/100ft Vert Sect · 00 N 0.00 E 0.00 0.00 .28 S 0.01 W 0.32 -0.16 .57 S 0.19 W 0.36 -0.47 · 08 S 1.28 W 1.04 -1.10 .96 N 3.00 W 0.13 -1.93 .89 N 4.60 W 0.14 .67 N 6.21 W 0.03 .74 N 8.46 W 1.67 .27 N 12.23 W 2.67 · 50 N 17.01 W 2.94 -2.73 -3.62 -4.31 -4.30 -2.46 1000.00 8.47 338.50 997.99 1100.00 8.42 339.11 1096.90 1200.00 8.35 338.80 1195.84 1300.00 8.07 338.40 1294.81 1400.00 7.92 337.30 1393.84 33.74 N 22.16 W 47.43 N 27.47 W 61.03 N 32.71 W 74.33 N 37.92 W 87.21 N 43.16 W 0.60 0.10 0.08 0.29 0.21 0.76 4.11 7.47 10.68 13.63 1500.00 7.67 337.11 1492.92 1600.00 7.47 336.90 1592.05 1700.00 7.47 336.61 1691.20 1750.00 7.47 336.50 1740.77 .1800.00 7.57 337.30 1790.34 , 1850.00 8.12 336.00 1839.88 1900.00 8.50 336.30 1889.35 2000.00 10.00 336.50 1988.05 2100.00 12.17 335.71 2086.18 2200.00 13.73 336.11 2183.63 99.70 N 48.41 W 111.83 N 53.55 W 123.77 N 58.68 W 129.73 N 61.27 W 135.74 N 63.83 W 142.01 N 66.54 W 148.62 N 69.46 W 163.35 N 75.89 W 180.91 N 83.69 W 201.37 N 92.83 W 0.25 0.20 0.04 0.03 0.29 1.16 0.77 1.50 2.17 1.57 16.35 18.95 21.46 22.69 23.97 25.27 26.59 29.60 33.09 37.10 2300.00 15.68 336.71 2280.35 2400.00 17.65 337.21 2376.14 2500.00 19.60 337.11 2470.90 2600.00 20.22 337.80 2564.93 2700.00 19.78 337.80 2658.89 224.64 N 102.99 W 1.96 251.04 N 114.20 W 1.97 280.47 N 126.60 W 1.95 311.92 N 139.65 W 0.66 343.59 N 152.58 W 0.43 41.86 47.50 53.89 60.88 68.09 UNOCAL GRAYLING Platform, G-5Rd McArthur River Field,TBU, Cook Inlet, Alaska SURVEY LISTING Page 2 Your ref : PMSS <7261-10650> Last revised : 10-Jul-98 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES Dogleg Vert Deg/100ft Sect 2800.00 19.22 338.11 2753.16 2900.00 18.53 338.11 2847.78 3000.00 18.13 338.30 2942.70 3100.00 17.38 338.30 3037.94 ~,3200.00 17.13 338.90 3133.44 3300.00 16.12 338.50 3229.26 3400.00 13.20 337.71 3325.99 3500.00 10.55 335.40 3423.84 3600.00 10.23 336.11 3522.20 3700.00 10.18 335.80 3620.62 3800.00 9.63 336.61 3719.13 3900.00 9.72 337.21 3817.71 4000.00 9.22 337.90 3916.34 4100.00 9.38 338.00 4015.03 4200.00 9.08 338.71 4113.73 4300.00 8.48 338.71 4212.56 4400.00 8.18 340.11 4311.50 4500.00 7.72 341.71 4410.54 ~...4600.00 7.90 341.80 4509.62 4700 00 7.83 341.61 4608.67 374.52 N 165.11 W 0.58 75.22 404.54 N 177.17 W 0.68 82.22 433.75 N 188.85 W 0.40 89.07 462.09 N 200.12 W 0.75 95.77 489.71 N 210.95 W 0.31 102.43 516.36 N 221.34 W 1.02 108.91 539.85 N 230.76 W 2.92 114.39 558.74 N 238.90 W 2.69 118.34 575.18 N 246.31 W 0.34 121.51 591.37 N 253.53 W 0.07 124.69 607.11 N 260.48 W 0.57 127.85 622.57 N 267.07 W 0.13 131.14 637.77 N 273.35 W 0.51 134.54 652.75 N 279.42 W 0.17 137.99 667.66 N 285.33 W 0.32 141.53 681.89 N 290.88 W 0.60 144.98 695.45 N 295.98 W 0.36 148.43 708.52 N 300.51 W 0.52 152.08 721.42 N 304.76 W 0.18 155.85 734.42 N 309.06 W 0.07 159.64 Ail data is in feet unless otherwise stated. Coordinates from slot #4-17 and TVD from wellhead (99.00 Ft above mean sea level). Bottom hole distance is 2310.41 on azimuth 22.54 degrees from wellhead. Vertical section is from S 0.00 W 0.00 on azimuth 55.62 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRAYLING Platform,G-5Rd McArthur River Field,TBU, Cook Inlet, A1 aska Measured Inclin. Azimuth True Vert R E C Depth Degrees Degrees Depth C 0 0 4800.00 7.47 341.80 4707.78 747 4900.00 7.97 343.11 4806.88 759 '~5000.00 9.72 344.80 4905.69 774 5100.00 12.05 345.50 5003.88 792 5200.00 13.07 346.11 5101.49 813 TANGU RD INA 5300.00 12.68 347.61 5198.97 835 5400.00 12.77 347.90 5296.52 857 5500.00 12.17 350.40 5394.16 878 5600.00 12.13 351.90 5491.92 899 5700.00 11.37 351.00 5589.82 919 .06 N .86 N .64 N .89 N .97 N 5750.00 10.13 346.71 5638.95 928 5775.00 9.92 341.61 5663.56 932 5800.00 9.95 333.00 5688.19 936 5825.00 9.88 325.30 5712.82 940 5850.00 9.83 320.50 5737.45 943 .67 N .19 N .39 N .18 N .32 N 5875.00 9.78 315.71 5762.08 946 ',5900.00 9.82 313.40 5786.72 949 1'5925.00 9.47 313.30 5811.37 952 5950.00 9.60 314.50 5836.02 955 6000.00 9.25 315.61 5885.35 961 .47 N .65 N .62 N .31 N .72 N 6100.00 8.92 317.21 5984.09 972 6200.00 8.05 318.61 6083.00 983 6300.00 8.05 320.30 6182.01 994 6400.00 7.65 320.90 6281.08 1004 6500.00 7.20 323.71 6380.24 1015 .89 N .87 N .75 N .62 N .41 N 6600.00 7.78 324.21 6479.38 6700.00 8.77 325.11 6578.34 .84 N .78 N .42 N .98 N .19 N 1025.74 N 1037.48 N LAR T E S 313.24 W 317.28 W 321.50 W 326.33 W 331.66 W 336.73 W 341.40 W 345.47 W 348.71 W 351.73 W 353.52 W 354.70 W 356.36 W 358.56 W 361.14 W 363.98 W 367.01 W 370.06 W 373.04 W 378.83 W 389.71 W 399.61 W 408.71 W 417.38 W 425.29 W 432.96 W 441.28 W SURVEY LISTING Page 3 Your ref : PMSS <7261-10650> Last revised : 10-Jul-98 Dogleg Deg/100ft Vert Sect 0.37 0.53 1.77 2.34 1.03 163.33 167.23 172.08 178.40 185.91 0.51 0.11 0.81 0.32 0.79 193.98 202.28 210.88 219.95 228.83 2.94 3.65 5.94 5.31 3.29 232.53 233.91 234.78 235.05 234.84 3.27 1.58 1.40 0.96 0.79 234.29 233.47 232.58 231.74 230.24 0.42 0.89 0.24 0.41 0.58 227.71 225.72 224.22 223.02 222.26 0.59 0.99 221.89 221.65 UNOCAL GRAYLING Platform, G-5Rd McArthur River Field,TBU, Cook Inlet, A1 aska SURVEY LISTING Page 4 Your ref : PMSS <7261-10650> Last revised : 10-Jul-98 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth R E C T A N G U L A R Dogleg Vert C 0 0 R D I N A T E S Deg/100ft Sect 6800.00 9.28 324.61 6677.10 6900.00 9.28 326.00 6775.79 7000.00 9.20 327.21 6874.49 1050.31 N 450.31 W 0.52 221.44 1063.57 N 459.49 W 0.22 221.35 1076.97 N 468.33 W 0.21 221.63 7100.00 8.97 328.50 6973.24 ~7200 00 8 77 332 21 7072 05 7261.00 8.49 333.52 7132.36 7435.00 13.30 343.30 7303.18 7499.00 14.40 350.10 7365.33 1090.34 N 476.73 W 0.31 222.24 1103.73 N 484.35 W 0.61 223.51 1111.87 N 488.53 W 0.56 224.66 1142.56 N 500.02 W 2.95 232.51 1157.45 N 503.50 W 3.07 238.04 7625.00 18.00 16.40 7486.46 7719.00 21.10 27.00 7575.06 7811.00 22.30 27.50 7660.54 7905.00 23.70 32.70 7747.08 8000.00 25.30 42.30 7833.55 1191.62 N 500.69 W 6.41 259.65 1220.64 N 488.90 W 5.00 285.77 1250.88 N 473.33 W 1.32 315.71 1282.60 N 454.88 W 2.62 348.84 1313.70 N 430.89 W 4.51 386.20 8160.00 27.80 53.90 7976.77 8282.00 29.80 57.00 8083.68 8386.00 32.80 59.60 8172.53 8473.00 36.20 61.20 8244.22 8513.00 36.70 59.20 8276.40 1361.01 N 377.69 W 3.59 456.82 1394.29 N 329.27 W 2.05 515.57 1422.62 N 283.29 W 3.16 569.52 1446.93 N 240.44 W 4.04 618.61 1458.74 N 219.82 W 3.22 642.30 ~.18536.00 37.90 59.30 8294.70 "~8626.00 39.60 58.30 8364.88 8717.00 39.40 59.80 8435.10 8812.00 39.50 58.90 8508.46 8906.00 39.70 59.20 8580.89 1465.87 N 207.84 W 5.22 656.21 1495.06 N 159.67 W 2.01 712.45 1524.83 N 110.03 W 1.07 770.23 1555.60 N 58.10 W 0.61 830.46 1586.41 N 6.71 W 0.29 890.27 Ail data is in feet unless otherwise stated. Coordinates from slot ~4-17 and TVD from wellhead (99.00 Ft above mean sea level). Bottom hole distance is 2310.41 on azimuth 22.54 degrees from wellhead. Vertical section is from S 0.00 W 0.00 on azimuth 55.62 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRAYLING Platform, G-5Rd McArthur River Field,TBU, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES 8999.00 39.80 58.60 8652.39 9094.00 40.20 58.20 8725.17 9186.00 40.30 59.70 8795.38 9280.00 41.00 58.50 8866.70 9375 . 00 41 . 60 59 . 60 8938 . 07 9468.00 41.30 58.70 9007.78 9639.00 42.20 58.40 9135.36 10255.00 32.50 58.00 9624.46 10614.00 27.00 58.00 9936.02 10650.00 26.50 58.00 9968.17 SURVEY LISTING Page 5 Your ref : PMSS <7261-10650> Last revised : 10-Jul-98 Dogleg Deg/100ft 1617.13 N 44.21 E 0.43 1649.13 N 96.22 E 0.50 1679.79 N 147.14 E 1.06 1711.24 N 199.68 E 1.12 1743.48 N 253.45 E 0.99 1775.04 N 306.30 E 0.72 1834.46 N 403.44 E 0.54 2031.03 N 720.75 E 1.58 2125.39 N 871.77 E 1.53 2133.98 N 885.51 E 1.39 Vert Sect 949.64 1010.64 1069.98 1131.10 1193.68 1255.12 1368.84 1741.72 Single Shot Survey 1919.64 Single Shot Survey 1935.83 PROJECTION TO T.D. - NO SURVEY Ail data is in feet unless otherwise stated. Coordinates from slot #4-17 and TVD from wellhead (99.00 Ft above mean sea level). Bottom hole distance is 2310.41 on azimuth 22.54 degrees from wellhead. Vertical section is from S 0.00 W 0.00 on azimuth 55.62 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Comments in wellpath MD TVD Rectangular Coords. Comment 10255.00 9624.46 2031.03 N 720.75 E Single Shot Survey 10614.00 9936.02 2125.39 N 871.77 E Single Shot Survey 10650.00 9968.17 2133.98 N 885.51 E PROJECTION TO T.D. - NO SURVEY Targets associated with this wellpath Target name Geographic Location T.V.D. G-5Rd GZT - 20-Apr-9 212608.000,2504233.000,0.0000 9000.00 Rectangular Coordinates Revised 1852.68N 362.53E 20-Apr-98 Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99501 ?ele: (907) 263-7889 Fax: (907) 263-78_28 E-rna/L' ch/Idersd@unoca/, corn UNOr..AL Debra Childers Geotech Ass/stant DATA TRANSMITTAL June 7, 1999 TO' Laurie Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items: L(~GTYPE " SCALE LOG DATE INTERVAL LOGGED # Platform Well Medium SENT TO CCL 5 5/14/99 10300-10560 1 :SCU 13-9 B-Line '/ AOGCC CCL 5 5/14/99 10300-10560 1 SCU 13-9 Film -/ AOGCC GR/CCL Correlation Log 5 4/23/99 7000-10564 1 SCU 13-9 B-Line ¢' AOGCC GR/CCL Correlation Log 5 4/23/99 7000-10564 1 SCU 13-9 Film ¢ AOGCC Injection Profile with PSP 2 3/4/99 2000-12896 l JGrayling G-36 DPN B-Line ,' AOGCC Injection Profile with PSP 2 3/4/99 2000-12896 1 Grayling G-36 BPN Film -/ AOGCC Injection Profile with PSP ~ 6 3/6/99 9400-10340 1 Grayling G-5RB B-Line / AOGCC Injection Profile with PSP ~ 4' 3/6/99 9400-10340 1 Grayling G-5RD Film v- AOGCC Packer Setting Record 5 4/21/99 9000-9180 1 Bruce 18742-14 B-Line./, AOGCC Packer Setting Record 5 4/21/99 9000-9180 1 Bruce 18742-14 Film v' AOGCC Perforating Record 5 3/14/99 10500-10650 1 SCU 24A-05 B-Line / AOGCC Perforating Record 5 3/14/99 10500-10650 1 SCU 24A-05 Film ¢' AOGCC Perforating Record 5 3/15/99 10400-10560 1 SCU 42B-05 B-Line,/ AOGCC Perforating Record 5 3/15/99110400-10560 1 SCU42B-05 Film ¢ AOGCC Perforating Record 5 4/20/99 9000-9350 1 Bruce 18742-14 B-Line / AOGCC Perforating Record 5 4/20/99!9000-9350 11Bruce 18742-14 Film ,.,' AOGCC Perforating Record/CCL 5 4/8/99 10435-10562 1 ! SCU 13,¢J'~ B-Line / AOGCC Perforating Record/CCL 5 4/8/99 10435-10562 1 SCU 13-/9' ~ Film ¢' AOGCC Production Prodile with PSP 4¢5-'- _.,-:*- 3/4/99 2000-10050 1 Grayling G-7 B-Line ,..- AOGCC Production Prodile with PSP tlS- .2,, 3/4/99 2000-10050 1 Grayling G-7 Film v AOGCC Gas Lift Survey with PSP 1 2/14/99 9180-10462 1 Steelhead M-29 B-Line ,/ AOGCC Gas Lift Survey with PSP 1 2/14/99 9180-10462 1 Steelhead M-29 Film v AOGCC Gas Lift Survey with PSP 1 2/22/99 1000-10422 1 Steelhead M-31 ~B-Line ..,' AOGCC Gas Lift Survey with PSP 1 2/22/99 1000-10422 1 Steelhead M-31 Film -,," AOGCC Gas Lift Survey with PSP 1 2/23/99 1500-10472 1 Steelhead M-32 B-Line ,/ AOGCC Gas Lift Survey with PSP 1 2/23/99 1500-10472 1 Steelhead M-32 Film v'IAOGCC Injection Profile with PSP 5 3/4/99 2000-12896 1 Grayling G-36 DPN B-Line,/ AOGCC Injection Profile with PSP 5 3/4/99 2000-12896 1 Grayling G-36 DPN Film ¢ AOGCC Injection Profile with PSP 2 3/6/99 9400-10340 1 Grayling G-5 RD B-Line '-/AOGCC Please ack eipt by slgnlnc~ und returning one copy of this transmillal or FAX to (07) 263-~828. Received byE.. Date: 3]a~.3 gi[ ,~ i::~-,s,~. L;Oi'F:;. ~ :,-~,m~i.',.n,..,,.,::...~:,...,,, Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: childersd@unocal, com UNOCAL ) Debra Childers Geotech Assistant DATA TRANSMITTAL October 15, 1998 To: Laurie Taylor From: Debra Childers 3001 Porcupine 909 W. 9th Avenue Anchorage, AK 99501 Anchorage, AK 99519-6247 Alaska Oil & Gas Unocal Transmitting the following items: ~-~) .o¢¢SCU 341-4 1¢ 1 5" i CorrelationiDepth Determination Log Completion 1 1 !2"/5" Dual Induction Tool/Gamma Ray 1~ 112"/5" !Sonic Digital Tool/Gamma Ray iTBU G-15RD 1 1 i5" i Reservoir Saturation Tool 1 1 2"/5" Litho-Density/Compensated iNeutron/Gamma Ray 1 5" iCompletion Record w/Gamma i Ray/CCL i '5" iCompletion Record 5" iCompletion Record i 5" i Dual Burst Thermal Neutron Decay iTBU G-12RD 1 1 ¢ 7f['OqZ, #2 ~_ ~ Time Log ,[/ 5" iCompletion Record iTBU G-12RD I 1 1~ ~',/2OiTBU G-5RD i' ....... ~ .......... -i'15" iCompletion Record 1 11-Aug-98iAlaska Oil & Gas i 1 20-Aug-981Alaska Oil & Gas I 1 20-Aug-98!Alaska Oil & Gas t 1 20-Aug-981Alaska Oil & Gas t 1 20-Aug-98iAiaSka Oil & Gas -' 1 29-Aug-98{Alaska Oil & Gas I 05-Sep-98!Alaska Oil & Gas ~ 1 10-Sep-98!Alaska Oil & Gas ! I 12-Sep-98iAlaska Oil & Gas ~ 1 12-Sep-98iAlaska Oil & Gas ~ 1 14-Sep-98!Alaska Oil & Gas Please ackno,~edge receipt by signing and returning one copy of this transmittal or / Received by: ~~.~/~'~;--~ Date: - or~ ! 6, ~998 0 * Ata~a Oit & ~ Cons. Comm~oa Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99501 Tele: (go7) 263-788g Fax: (907) 263-7828 E-maih childersd@unocal, com UNOCAL Debra Childers Geotech Assistant DATA TRANSMITTAL August 6, 1998 To: Laurie Taylor From: Debra Childers 3001 Porcupine 909 W. 9th Avenue Anchorage, AK 99501 Anchorage, AK 99519-6247 Alaska Oil & Gas Unocal qg.o~,q qg. zo Transmitting the following items:. TBU G-15RD 1 15",2" Array Sonic Tool TVD ~ ~.:! - ~:1 :~7/21/98 TBU G-15RD I 15" Array Sonic Tool/Gamma Ray VDL log ~ I 7/21/98 TBU G-15RD I 15",2" Array Sonic Tool 1 7/21/98 TBU G-15RD 1= 1 5",2" Density-Neutron/Gamma Ray 'I'VD I 7/21/98 TBU G-15RD 1 15",2" Array Induction Tool/Gamma Ray 1 7/21/98 TBU G-15RD I 15",2" Array Induction Tool/Gamma Ray TVD 1 7/21/98 TBU G-15RD 1 15",2" Density-Neutron/Gamma Ray 1 7/21/98 TBU G-21RD 1 15" Cement Evaluation/Gamma Ray Log I 5/30/98 iTBU G-21RD 1 15" Compensated Cement Bond/Gamma Ray Log 1 5/30/98 TBU G~5RD 1 15",2" Platform Express/Array Induction Imager/Gamma Ray 1 7/1/98 TBU G-5RD 1 15" Gamma Ray Tie in Log 1 7/6/98 TBU G-5RD 1 15" Cement Bond Log 1 7/5~98 TBU G-5RD 1 15" Cement Evaluation Log 1 7/5/98 TBU G-5RD 1 15",2" Platform Express/Three Detector LithoDensity 1 7/1/98 Compensated Neutron/GR TBU G-5RD 1 15",2" ~Thermal Decay Time Log 1 7/5/98 TBU G-5RD 1 15" Digital Sonic Array/Gamma Ray 1 7/1/98 Please acknowledge receipt by signing ~nd returning one ~py of this transmi~l or F~ ~o (907) 263-7828 I R eivedby: - ~ Date: AU~ 06 i998 ~r~e TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS C~NSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 19. 1998 Dale Haines Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519-6247 Re~ Trading Bav Unit G-5RD UNOCAL Permit No. 98-120 Sur. Loc. 1838'FSL. 1487'FEL. SEC. 29, T09N. R13W, SM Btnmholc Loc. 1021'FNL. 204'FEL. SEC. 29. T09N. R13W. SM Dcar Mr. Haines: Encloscd is thc approved application for permit to rcdrill thc above referenced well. Thc permit to rcdrill docs not exempt you from obtaining additional permits required by law from other govcrnmcntal agcncics, and does not authorize conducting drilling operations until all other rcquircd permitting determinations arc made. Bloxvout prevention cquipmcnt (BOPE) must bc tested in accordance with 20 AAC 25 035. Sufficicnt notice (approximately 24 hours) must bc given to allow a representative of the Commission to witness a test of BOPE installcd prior to drilling ncw hole. Notice may be given by contacting thc Commission at 279-1433. David W. Johnston Chairlnan '.~ BY ORDER OF THE COMMISSION dlf/Enclosurcs ¢C~ Dcpartmcnt of Fish &Gamc. Habitat Section v,'/o cncl. Dcpartmcnt of Environmental Conservation w/o encl. TONY KNOWLES, GOVERNOR ALASK& OIL AND GAS CONSERVATION CO~MISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June l" 1998 ADSIINISTI~ATIVE APPROVAL NO. 80.73 Re' The application of Union Oil Company of California. operator of the Trading Bay Unit (TBU). to drill, complete and produce the TBU G-5RD. Mr. Rick D. Cross Senior Landman Unocal Alaska Resources L~-OCAL Corporation P O Box 196247 Anchorage. AK 99519-6247 Dear _'xlr. Cross' ",'our application of June i2. 1998 for a permit to drill the TBU G-5RD development service well indicates that the drilling and completion of the well will provide additional oil recovery from the Hemlock and Middle Kenai "G" oil Pools. -7he .-Xiaska Oil and Gas Cc',nservation Commission hereby authorizes the driiiino_ and con-mietion of the TBU G-SRD well pursuant to Rule 5 of Conservation Order No. $0. DONE at Anchora_oe..-~laska and dated June i 7. 1998. Chairman Camilla Oechsli Commissioner Robert N. Christenson Commissioner Unocal Alaska Resources Unocal Corporation · 909 West 9th Avenue, P.O. Box 196~7 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL Rick D. Cross Senior Landman June 12,1998 Mr. Robert Crandall Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Permit to Drill G-5RD Trading Bay Unit Cook Inlet Area State of Alaska Dear Mr. Crandall, Union Oil Company of California (Unocal), as Operator of the Trading Bay Unit, requests your approval to re-drill the Trading Bay Unit G-5 as an injection well in the Middle Kenai G Zone and Hemlock formation pursuant to Rule 5 Conservation Order No. 80. · The G-5RD will be drilled and completed from the Grayling Platform improving the bottom hole location, and fluid injection distribution, resulting in recovery of additional reserves from the targeted formations. Enclosed is a check, #2002668, in the amount of $100.00 as required by 20 AAC 25.005(c)(1) to process an application for permit to drill. UnoCal appreciates your review and approval of this application. Sincerely yours, / / / -' / ,?, /<; // Rick D. Cross Senior Landman STATE OF ALASKA OIL AND GAS CONSERVATION COMM. 51ON PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill RedrillX 'l lb. Type oYweil Explorator~ stratigraphicTe'si DeveloPment Oil ...... Re-entry DeepenI ServiceX Development Gas Single Zone Multiple Zone '2. Name o~ Operator 5. DatLJm Elevation (DF or KB) ~?. Field and Pool Unocal 99' RKB above MSL '~ River Field 3. Address P. O. Box 196247 ' ' ' 6. ~rope~ Designation Middle Kenai G/Hemlock Anchorage, Ak 9~19-6247 .., . ADL 17594 4.' Loc~tio~ of ~ell at's~Ra~e 7. Unit or Prope~ Name ' "11. Type B~d (see 20MC25.025) 1838' FSL and 1487' FEL Sec. 29, TDN, R13W, SM ~rading. Bay Unit AK Statewide Oil & Gas Bond At top of productive inte~al G-zone (9000' ~D) 8. Well Number Number 1587' FNL and 1124' FEL Sec. 29, TDN, R13W, SM G-5RD U 62-9269 At total depth 9. Approximate spud date ' ' Amount 1021' FNL and 204' FEL, Sec. 29, TDN, R13W, SM 6/2~98 $200,000 ~2. Distance to n~arest ' 13. Distance to nearest well 14~ Number of a~res i~ prope~ '15' ProPosed depth (MD and ~D) prope~ line 1084' ~ 7450' MD.~ 1 1,038' MD 10,984'~TD (G-19) Lease 5116acres ~_o 10,000'~D 16. ~o be c0mpie~ed for deviated wells .... 17. AntiCipated pres~u~see 20 ~C 25.035 (e~(2) Kickoff depth 7450 feet Maximum hole angle 55~ Maximum SuRace 1~6 psig. At total depth (~D) 4400 psig ' ~8~ Casing ....... Se~ing Depth ........ program size .... Specifications Top BoSom Quan~i~ of cement Hole Casing weight Grade Coupling J Length MD ~ '~D ' "~D exist 26" ' 7.~l;'watl ' D~iven .~ 367' '0' "0' ' 367' ' ''367' 'Driven . . . ,, exist 16" 75 J-55 BU~ 591' 0 0 591' 591' 1398 sx exist 13-3/8" 54.5' K-5'5 Bu~ 307~' 0~ 0' 3078' 3015' 2600 sx exist 9-5/8" 40-47 N-80 ~ealLok ~450' '0 ' ' 0 7450' 7319' '150~ sx & 1500 sx KOP . Stage collar at 4376' . . 8.5" '7" 29 L:80 - 'BU~' 378~' 7200' , 7071' 11,038' 10~000' 5~0 sx 19. To be completed for Redrill, Re-ent~ and Deepen Operations , .... ~*%? ?~? Present well condition summa~ " .... '~' Total depth: measured 10,312 feet Plugs (measured) ?~-.~-'~-'~ ~'~ ' true ve~ical 10,163 feet .~ ~... -'~.~::'~ Effective Depth measured 9965 feet Junk (measured) "- , true ve~ical 9818 feet .... · .... . .~ ~ ;'f~ ~',~C'3.'~ Casing Length S~ze Cemented MeaSured Depth True Vedical Depth Structural 367' 26" Driven 367' 367' Conductor 591' 16" 1398 sx 591' 591' Sufiace 3078' 13-3/8" 2600 sx 3078' 3015' Inte~ediate Production 9657' 9-5/8' 3000 sx 9657' 9512' Liner 758' 7' 200 sx 9544'- 10,302' 9399'-10153' Pefioration Depth: measured 9208'- 9980' gross inte~al (see a~ached schematic) true vedical 9065'- 9833' gross inte~al 20. A~achments: Filing Fee X Pr~¢e~ Pla~ BOP Sketch X Dive,er Sketch Drilling Program X Drilling Fluid Program X Time vs Depth Plot Refraction aqalysis Sea~ed.Repo~ 20~C25.050 Requirements X 21. I hereby cedi~ that the foregoing i~ t~e and correct to the beSt of my knowledge Signed ~. ~ ~ ~ Title: Drilling. Manager. Date ~ )~, tS~ ¢ ' ' ' Commission Use Only '¢ Pe~it Nb~er ' I ~P'I ~umber' " I Approval ~ate /I ,~ ~ ' [ ~ee cov~ le~er ~ ~,/~ 0 ~ ~0-? ~. ~ ~ ~ O- ~, I .. ~ ~~/ for other requirements Conditions of approval Sample,'reqUired Yes ~No) Mud log required Yes ~ Hydrogen Sulfide measures Yes ~ Directiona~Su~ey~ required ~ No Required working pressure for DOPE~,,~ ~- ,~u~R~MS~M)' 1~ 15M Other, Dsv'd W. J0h,stoi',':" by order of ~/~ Approved by . ~mmissioner the comm~.ssion Date ¢~... Form 10-401 Rev. 12-1-85 I . tin triplicate UNOCAL GRAYLING Platform G-5 slot #4-17 McArthur River Field TBU, Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : G-SRd Version Our ref : prop2915 License : Date printed : 10-Jun-98 Date created : 20-Apr-98 Last revised : 10-Jun-98 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 36 18.018 Slot location is n60 50 22.920,w151 36 47.999 Slot Grid coordinates are N 2502389.758, E 212200.264 Slot local coordinates are 1839.90 N 1485.90 W Projection type: alaska ~ Zone 4, Spheroid: Clarke - 18~ Reference North is True North UNOCAL GRAYLING Platfoz-m, G- 5 McArthur River Field, TBU, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S PROPOSAL LISTING Page 1 Your =el : G-SRd Version Last revised : 10-Jun-98 Dogleg Vert Deg/100ft Sect 7450.00 7.92 336.94 7319.45 1136.14 N 499.83 W 0.00 170.31 7475.00 10.26 348.93 7344.14 1139.91 N 500.94 W 12.00 171.34 7500.00 10.46 352.96 7368.73 1144.35 N 501.64 W 3.00 173.07 7600.00 11.70 7.24 7466.88 1163.41 N 501.48 W 3.00 183.21 7700.00 13.49 18.31 7564.49 1184.55 N 496.54 W 3.00 198.50 7800.00 15.65 26.61 7661.27 1207.69 N 486.83 W 3.00 218.91 7900.00 18.05 32.84 7756.98 1232.77 N 472.38 W 3.00 244.36 8000.00 20.60 37.62 7851.34 1259.73 N 453.24 W 3.00 274.80 8100.00 23.26 41.37 7944.10 1288.49 N 429.44 W 3.00 310.1~ 8200.00 25.98 44.37 8035.01 1318,97 N 401.07 W 3.00 350.29 8300.00 28.76 46.84 8123.81 1351.10 N 368.19 W 3.00 395.13 8400.00 31.58 48.91 8210.25 1384.77 N 330.90 W 3.00 444.54 8500.00 34.42 50.67 8294.12 1419.90 N 289.30 W 3.00 498.39 8600.00 37.29 52.19 8375.16 1456.39 N 243.50 W 3.00 556.52 8700.00 40.17 53.52 8453.17 1494.15 N 193.63 W 3.00 618.78 8800.00 43.06 54.70 8527.92 1533.06 N 139.82 W 3.00 685.01 8900.00 45.97 55.76 8599.22 1573.03 N 82.23 W 3.00 755.00 9000.00 48.89 56.72 8666.87 1613.94 N 21.01 W 3.00 828.59 9100.00 51.81 57.60 8730.68 1655.68 N 43.68 E 3.00 905.55 9194.83 54.59 58.37 8787.48 1695.92 N 108.05 E 3.00 981.47 9500.00 54.59 58.37 8964.32 1826.36 N 319.81 E 0.00 1230.18 95'61.57 54.59 58.37 9000.00 1852.68 N 362.53 E 0.00 1280.35 9620.10 54.00 58.37 9034.16 1877.60 N 403.00 E 1.00 1327.88 9720.10 53.00 58.37 9093.64 1919.76 N 471.44 E 1.00 1408.27 9820.10 52.00 58.37 9154.52 1961.37 N 538.99 E 1.00 1487.60 9920.10 51.00 58.37 9216.77 2002.42 N 605.62 E 1.00 1565.86 10020.10 50.00 58.37 9280.38 2042.89 N 671.32 E 1.00 1643.02 10120.10 49.00 58.37 9345.32 2082.77 N 736.06 E 1.00 1719.06 10220.10 48.00 58.37 9411.58 2122.05 N 799.83 E 1.00 1793.96 10320.10 47.00 58.37 9479.14 2160.71 N 862.60 E 1.00 1867.68 10420.10 46.00 58.37 9547.97 2198.76 N 924.36 E 1.00 1940.22 10520.10 45.00 58.37 9618.06 2236.16 N 985.09 E 1.00 2011.54 10620.10 44.00 58.37 9689.39 2272.92 N 1044.76 E 1.00 2081.63 10720.10 43.00 58.37 9761.93 2309.03 N 1103.37 E 1.00 2150.47 10820.10 42.00 58.37 9835.65 2344.46 N 1160.89 E 1.00 2218.03 10920.10 41.00 58.37 9910.55 2379.21 N 1217.31 E 1.00 2284.29 11020.10 40.00 58.37 9986.59 2413.27 N 1272.60 E 1.00 2349.23 11037.59 39.83 58.37 10000.00 2419.16 N 1282.16 E 1.00 2360.45 G-5Rd GZT - 20-Apr-98 All data is in feet unless otherwise stated. Coordinates from slot #4-17 and TVD from wellhead (38.60 Ft above mean sea level).~ Bottom hole distance is 2737.93 on azimuth 27.92 degrees from wellhead. Total Dogleg for wellpath is 69.36 degrees. Vertical section is from S 0.00 E 0.00 on azimuth 58.37 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GP, AYLING Platfoz-m,G-5 McArthur River Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : G-SRd Version Last revised : 10-Ju~-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing 7450.00 7.92 336.94 7319.45 2976.04N 1985.73W 0.00 170.31 211728.37 2503537.77 7475.00 10.26 348.93 7344.14 2979.81N 1986.84W 12.00 171.34 211727.36 2503541.57 7500.00 10.46 352.96 7368.73 2984.25N 1987.54W 3.00 173.07 211726.76 2503546.02 7600.00 11.70 7.24 7466.88 3003.31N 1987.38W 3.00 183.21 211727.40 2503565.08 7700.00 13.49 18.31 7564.49 3024.45N 1982.44W 3.00 198.50 211732.85 2503586.09 7800.00 15.65 26.61 7661.27 3047.59N 1972.73W 3.00 218.91 211743.12 2503608.98 7900.00 18.05 32.84 7756.98 3072.67N 1958.28W 3.00 244.36 211758.18 2503633.71 8000.00 20.60 37.62 7851.34 3099.63N 1939.14W 3.00 274.80 211777.98 2503660.19 8100.00 23.26 41.37 7944.10 3128.39N 1915.34W 3.00 310.14 211802.47 2503688.36 8200.00 25.98 44.37 8035.01 3158.87N 1886.97W 3.00 350.29 211831.58 2503718.14 8300.00 28.76 46.84 8123.81 3191.00N 1854.09W 3.00 395.13 211865.23 2503749.45 840~.00 31.58 48.91 8210.25 3224.67N 1816.80W 3.00 444.54 211903.33 2503782.20 8500.00 34.42 50.67 8294.12 3259.80N 1775.20W 3.00 498.39 211945.78 2503816.30 8600.00 37.29 52.19 8375.16 3296.29N 1729.40W 3.00 556.52 211992.46 2503851.66 8700.00 40.17 53.52 8453.17 3334.05N 1679.53W 3.00 618.78 212043.24 2503888.19 8800.00 43.06 54.70 8527.92 3372.96N 1625.72W 3.00 685.01 212097.98 2503925.77 8900.00 45.97 55.76 8599.22 3412.93N 1568.13W 3,00 755.00 212156.53 2503964.32 9000.00 48.89 56.72 8666.87 3453.84N 1506.91W 3.00 828.59 212218.74 2504003.72 9100.00 51.81 57.60 8730.68 3495.58N 1442.22W 3.00 905.55 212284.42 2504043.86 9194.83 54.59 58.37 8787.48 3535.82N 1377.85W 3,00 981.47 212349.77 2504082.52 9500.00 54.59 58.37 8964.32 3666.26N 1166.09W 0.00 1230.18 212564.65 2504207.74 9561.57 54.59 58.37 9000.00 3692.$8N 1123.37W 0.00 1280.35 212608.00 2504233.00 9620.10 54.00 58.37 9034.16 3717.50N 1082.90W 1.00 1327.88 212649.06 2504256.93 9720.10 53.00 58.37 9093.64 3759.66N 1014.46W 1.00 1408.27 212718.52 2504297.40 9820.10 52.00 58.37 9154.52 3801.27N 946.91W 1.00 1487.60 212787.06 2504337.35 9920.10 51.00 58.37 9216.77 3842.32N 880.28W 1.00 1565.86 212854.68 2504376.75 10020.10 50.00 58.37 9280.38 3882.79N 814.58W 1.00 1643.02 212921.34 2504415.60 10120.10 49.00 58.37 9345.32 3922.67N 749.84W 1.00 1719.06 212987.04 2504453.88 10220.10 48.00 58.37 9411.58 3961.95N 686.07W 1.00 1793.96 213051.75 2504491.59 10320.10 47.00 58.37 9479.14 4000.61N 623.30W 1.00 1867.68 213115.45 2504528.71 10420.10 46.00 58.37 9547.97 4038.66N 561.54W 1.00 1940.22 213178.12 2504565.23 10520.10 45.00 58.37 9618.06 4076.06N 500.81W 1.00 2011.54 213239.75 2504601.14 10620.10 44.00 58.37 9689.39 4112.82N 441.14W 1.00 2081.63 213300.30 2504636.43 10720.10 43.00 58.37 9761.93 4148.93N 382.53W 1.00 2150.47 213359.78 2504671.09 10820.10 42.00 58.37 9835.65 4184.36N 325.01W 1.00 2218.03 213418.15 2504705.10 10920.10 41.00 58.37 9910.55 4219.11N 268.59W 1.00 2284.29 213475.40 2504738.47 11020.10 40.00 58.37 9986.59 4253.17N 213.30W 1.00 2349.23 213531.51 2504771.16 11037.59 39.83 58.37 10000.00 4259.06N 203.74W 1.00 2360.45 213541.20 2504776.81 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from SE Corner of Sec. 29, TgN, R13W SM a~d TVD from wellhead (38.60 Ft above mean sea level).~--- Bottom hole distance is 2737.93 on azimuth 27.92 degrees from wellhead. Total Dogleg for wellpath is 69.36 degrees. Vertical section is from N 1839.90 W 1485.90 on azimuth 58.37 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ UNOCAr. GRAYLING Platform, G- 5 McArthur River Field, TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : G-SRd Verslo~ ~2 Last revised : 10-Jun-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O 0 R D S Depth Degrees Degrees Depth C 00 R D I N A T E S Deg/100ft Sect Easting Northing 7450.00 7.92 336.94 7319.45 1136.14N 499.83W 0.00 170.31 211728.37 2503537.77 7475.00 10.26 348.93 7344.14 1139.91N 500.94W 12.00 171.34 211727.36 2503541.57 7500.00 10.46 352.96 7368.73 1144.35N 501.64W 3.00 173.07 211726.76 2503546.02 7600.00 11.70 7.24 7466.88 1163.41N 501.48W 3.00 183.21 211727.40 2503565.08 7700.00 13.49 18.31 7564.49 1184.55N 496.54W 3.00 198.50 211732.85 2503586.09 7800.00 15.65 26.61 7661.27 1207.69N 486.83W 3.00 218.91 211743.12 2503608.98 7900.00 18.05 32.84 7756.98 1232.77N 472.38W 3.00 244.36 211758.18 2503633.71 8000.00 20.60 37.62 7851.34 1259.73N 453.24W 3.00 274.80 211777.98 2503660.19 8100.00 23.26 41.37 7944.10 1288.49N 429.44W 3.00 310.14 211802.47 2503688.36 8200.00 25.98 44.37 8035.01 1318.97N 401.07W 3.00 350.29 211831.58 2503718.14 8300.00 28.76 46.84 8123.81 1351.10N 368.19W 3.00 395.13 211865.23 2503749.45 840~.00 31.58 48.91 8210.25 1384.77N 330.90W 3.00 444.54 211903.33 2503782.20 8500.00 34.42 50.67 8294.12 1419.90N 289.30W 3.00 498.39 211945.78 2503816.30 8600.00 37.29 52.19 8375.16 1456.39N 243.50W 3.00 556.52 211992.46 2503851.66 8700.00 40.17 53.52 8453.17 1494.15N 193.63W 3.00 618.78 212043.24 2503888.19 8800.00 43.06 54.70 8527.92 1533.06N 139.82W 3.00 685.01 212097.98 2503925.77 8900.00 45.97 55.76 8599.22 1573.03N 82.23W 3.00 755.00 212156.53 2503964.32 9000.00 48.89 56.72 8666.87 1613.94N 21.01W 3.00 828.59 212218.74 2504003.72 9100.00 51.81 57.60 8730.68 1655.68N 43.68E 3.00 905.55 212284.42 2504043.86 9194.83 54.59 58.37 8787.48 1695.92N 108.05E 3.00 981.47 212349.77 2504082.52 9500.00 54.59 58.37 8964.32 1826.36N 319.81E 0.00 1230.18 212564.65 2504207.74 9561.57 54.59 58.37 9000.00 1852.68N 362.53E 0.00 1280.35 212608.00 2504233.00 9620.10 54.00 58.37 9034.16 1877.60N 403.00E 1.00 1327.88 212649.06 2504256.93 9720.10 53.00 58.37 9093.64 1919.76N 471.44E 1.00 li08.27 212718.52 2504297.40 9820.10 52.00 58.37 9154.52 1961.37N 538.99E 1.00 1487.60 212787.06 2504337.35 9920.10 51.00 58.37 9216.77 2002.42N 605.62E 1.00 1565.86 212854.68 2504376.75 10020.10 50.00 58.37 9280.38 2042.89N 671.32E 1.00 1643,02 212921.34 2504415.60 10120.10 49.00 58.37 9345.32 2082.77N 736.06E 1.00 1719.06 212987.04 2504453.88 10220.10 48.00 58.37 9411.58 2122.05N 799.83E 1.00 1793.96 213051.75 2504491.59 10320.10 47.00 58.37 9479.14 2160.71N 862.60E 1.00 1867.68 213115.45 2504528.71 10420.10 46.00 58.37 9547.97 2198.76N 924.36E 1.00 1940.22 213178.12 2504565.23 10520.10 45.00 58.37 9618.06 2236.16N 985.09E 1.00 2011.54 213239.75 2504601.14 10620.10 44.00 58.37 9689.39 2272.92N 1044.76E 1.00 2081.63 213300.30 2504636.43 10720.10 43.00 58.37 9761.93 2309.03N 1103.37E 1.00 2150.47 213359.78 2504671.09 10820.10 42.00 58.37 9835.65 2344.46N 1160.89E 1.00 2218.03 213418.15 2504705.10 10920.10 41.00 58.37 9910.55 2379.21N 1217.31E 1.00 2284.29 213475.40 2504738.47 11020.10 40.00 58.37 9986.59 2413.27N 1272.60E 1.00 2349.23 213531.51 2504771.16 11037.59 39.83 58.37 10000.00 2419.16N 1282.16E 1.00 2360.45 213541.20 2504776.81 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #4-17 and TVD from wellhead (38.60 Ft above mean sea level). Bottom hole distance is 2737.93 on azimuth 27.92 degrees from wellhead. Total Dogleg for wellpath is 69.36 degrees. Vertical section is from S 0.00 E 0.00 on azimuth 58.37 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ [cCr-'ated by Sutncrlortd For.' T. Billin~sle.y I Ome p~ot~ed : lO-Jun-98 Plot Reference ;s C-SRd Vets;on ~2. o~rCmates are in feet reference slot ~-17.~ 4600 ¢20O 3800 3600 5400 3200 3000 I 280o --,'--. ,+_ 2600 t_ 2400 o Z UNOCAL :Structure: GRAYLING Platform Well : 0-5 Field : McArihur River Field Lacatlon : TaU, Cook Inlet, Alaska ONOCALe 2200 2COG 1800 1600 East (feet) -> 1200 1000 800 600 400 200 0 200 400 600 800 1000 1200 1400 1600 1800 , i t I L. I i [ t I I .I I I I I ~ I I r 1 I I I t [ I I[i~ ¢600' t4400 E420C ~ ~-8300 1400 (~ 92009700~':~/8200-' 5100 8800 //~000 %6000 %5900 8400 ! /7800 1200 ",,5800 8000i X5600 7800~ KOP ~~o ~9oo 1000 N5300 x~,¢~oo 53oc ~ 5~oo 800 % ¢700 ¢900 % 4600 4600 ~ 4500 30( ~ ~¢00 tOO ~00 ~~o 3700 ¢000 L 3800 T.D...,_.~,~ ! 0000 ../ 9SO0 ..~/9800 //970O ~-"9500 .-"8J¢00 ~-"~300 ,-/~200 ...'/~ 1 O0 ./ //o'" 9000 /-" 8900 i800 /'~"8800 3700 .-'/8700 .,,,'"860o 8500 ./84-00 / 740OL .,,.~700072°° oo /.-~aoo [,200 /" 6600 : oo °° 8200 8300 ,,oa /,~2oo ~-~no:°~ ~..--'~saa .... ~ i i i i I i i '" ¢1oo ¸oo 200 1000 800 600 400 200 0 200 400 600 800 1000 1200 1400 1800 180C Easf (feel) -> [C~'-o;cd ~y ~u~lond~"Or: T. Billing~ley I Dote plotted : 1Q-Jun-g8 P!ct Reference ~ O-SRd Vets;on ~2 Jcccramctes cre ;n feet reference slot ~4-17. true Vertical 3ep~ere~ce wellheed. ~ .UNOCAL Structure : GRAYLING Platform Well : G-5 J Field : McArthur River Field Location : TBU, Cook Inlet, Alaska IiNOCAL~ 3OO 310 320 33O 34-0 TRUE NORTH 350 0 10 180 2O 3O ¢0 6O 290 7O 8O 2Rn 0 i802 270 2 O 180 150 120 9. , -,kT~°°~© / I t I 90 ,i/// ~_3~, kX¢~°°/ ~ Ii i 00 110 2~C) 120 200 160 190 180 1 70 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well UNOCAL GRAYLING Platform slot #4-17 McArthur River Pield TBU, Cook Inlet, Alaska 3-D MINIMUM DISTANCE CLEARANCE Baker Hughes INTEQ REPORT Your ref : G-SRd Version #2 Our ref : prop2915 License : Date printed : 10-Jun-98 Date created : 20-Apr-98 Last revised : 10-Jun-98 Field is centred on n60 50 4.803,w!51 36 18.018 Structure is centred on n60 50 4.803,w151 36 18.018 Slot location is n60 50 22.920,w151 36 47.999 Slot Grid coordinates are N 2502389.758, E 212200.264 Slot local coordinates are 1839.90 N 1485.90 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEAP-a. NCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath GMS <0-11905'>,,D-26,DOLLY VARDEN Platform PGMS <0-10873'>,,D-48,DOLLY VARDEN Platform GMS <800-2700'>,,D-lO,DOLLY VARDEN Platform MSS <2742-13908'>,,D-10,DOLLY VkRDEN Platform MSS <10913-11930'>,,D-47,DOLLY VAPd3EN Platform PGMS <O-12970'>,,D-44,DOLLY VARDEN Platform MSS <3550-17010'>,,D-21,DOLLY VARDEN Platform MSS <3550-16606'>,,D-23,DOLLY VARDEN Platform PGMS <O-10450'>,,D-42,DOLLY VAR/DEN Platform GMS <O-11180'>,,D-34,DOLLY VARDEN Platform MSS <2730-13462'>,,D-24,DOLLY VkRDEN Platform PMSS <12052 - 12438'>,,D-7Rd#2,DOLLY VARDEN P1 GMS <O-12900'>,,D-7Rd,DOLLY VARDEN Platform GMS <9600-13300'>,,D-7,DOLLY VARDEN Platform PGMS <8000-12100'>,,D-4Rd, DOLLY VARDEN Platfor GMS <O-11100'>,,D-4,DOLLY VARDEN Platform GMS <O-12050'>,,D-12Rd,DOLLY VARDEN Platform MSS <9453-12381'>,,D-12,DOLLY VkRDEN Platform MSS <2220-8175'>,,D-18,DOLLY VA.RDEN Platform GMS <0-12237'>,,D-30Rd,DOLLY VA_RDEN Platform MSS <lO156-13600'>,,D-30,DOLLY VARDEN Platform MSS <O-12071'>,,D-1,DOLLY VA/%DEN Platform GMS <0-10800'>,,D-17Rd,DOLLY VA3~DEN Platform MSS <10665-11808'>,,D-17,DOLLY VARDEN Platform MSS <2701-11682'>,,D-ii,DOLLY V~RDEN Platform Closest approach with 3-D Minimum Distance method Last revised Distance 29-Jul-96 9188.4 29-Jul-96 9692.3 29-Jul-96 13773.6 29-Jul-96 12393.3 29-Jul-96 7923.6 29-Jul-96 6632.4 29-Jul-96 14577.7 29-Jul-96 14603.1 29-Jul-96 7093.2 29-Jul-96 12316.5 29-Jul-96 11887.1 29-Jul-96 7520.9 29-Jul-96 7555.3 29-Jul-96 7769.6 29-Jul-96 12393.6 29-Jul-96 12393.6 29-Jul-96 14290.8 29-Jul-96 14290.8 29-Jul-96 8377.9 29-Jul-96 7487.0 29-Jul-96 7346.6 29-Jul-96 7779.8 29-Jul-96 12598.8 29-Jul-96 12598.8 29-Jul-96 8130.0 7525.0 7700.0 7450.0 7450.0 7850.0 7900.0 7450.0 7450.0 7450.0 7450.0 7450.0 7750.0 8150 0 7575 0 7450 0 7450 0 7450 0 7450 0 7450 0 7750 0 829-5.0 7900.0 7450.0 7450.0 7850.0 Diverging from M.D. 7525.0 : 7700.0 7450.0 7450.0 7850.0 7900.0 7450.0 7450.0 7450.0 7450.0 9246.0 7750.0 8150.0 7575.0 7450.0 7450.0 9402.0 9402.0 7450.0 7750.0 8225.0 7900.0 7450.0 9390.0 7850.0 PGMS <0-10900'>,,D-9Rd, DOLLY VARDE~ ~tform GMS <5600~10700'>,,D-9,DOLLY VARDEN._ ...atform PGMS <0-1234§'>,,D-46,DOLLY VARDEN Platform MSS <2944~7950'>,,D-19,DOLLY VAR]DEN Platform MSS <6059-16650'>,,D-19St,DOLLY VANDEN Platfor GMS <0-10650'>,,D-5Rd,DOLLY VARDEN Platform MSS <2642~10250'>,,D-5,DOLLY VARDEN Platform GMS <0-10935'>,,D-15Rd,DOLLY VARDEN Platform PGMS <2100~10225'>,,D-15Rd2,DOLLY VA-RDEN Platf PGMS <6600-10920'>,,D-3Rd2,DOLLY VARDEN Platfo GMS <0-10881'>,,D-3,DOLLY VARDEN Platform PGMS <8700-11100'>,,D-3Rd, DOLLY VAi~DEN Platfor MSS <2727-11000'>,,D-13,DOLLY VARDEN Platform PGMS <0-10300'>,,D-45,DOLLY VARDEN Platform GMS <0-11000'>,,D-27,DOLLY VARDEN Platfor~ GMS <0-12445'>,,D-28,DOLLY VARDEN Platform MSS <2506-11160'>,,D-32,DOLLY VARDEN Platform PGMS <0-12520'>,,D-40Rd, DOLLY VARDEN Platform GMS <6100-12573'>,,D-40,DOLLY VARDEN Platform GMS <0-11600'>,,D-41,DOLLY VARDEN Platform MSS <8330-11350'>,,D-25,DOLLY VARDEN Platform GMS <0-11510'>,,D-25Rd, DOLLY VkRDEN Platform PGMS <0-11150'>,,D-43,DOLLY VARDEN Platform GMS <100-13050'>,,D-29,DOLLY VARDEN Platform gGMS <0-13111'>,,D-29Rd,DOLLY VARDEN Platform 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jui-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 PGMS <700-12250'>,,D-SRd,DOLL¥ VARDEN Platform 29-Jul-96 MSS <8722-13932'>,,D-8,DOLLY VARDEN Platform 29-Jul-96 MSS <l1790-15510'>,,D-6St,DOLL¥ VARDEN Platfor 29-Jul-96 MSS <6662-12195'>,,D-6,DOLLY VARDEN Platform 29-Jul-96 PGMS <0-13700'>,,D-6Rd,DOLLY VARDEN Platform 29-Jul-96 GMS <0-13600'>,,D-14Rd,DOLLY VARDEN Platform 29-Jul-96 MSS <7866-12700'>,,D-14,DOLLY VARDEN Platform 29-Jul-96 MSS <1205-10506'>,,D-20,DOLLY VkRDE~ Platform 29-Jul-96 PGMS <10000-14645'>,,D-16Rd,DOLLY VARDEN Platf 29-Jul-96 GMS <0-14600'>,,D-16,DOLLY VARDEN Platform 29-Jul-96 MSS <l1209-14850'>,,D-22,DOLLY VARDEN Platform 29-Jul-96 MSS <9482-12425'>,,D-2Rd,DOLLY VARDEN Platform 29-Jul-96 MSS <6927-12557'>,,D-2,DOLLY VARDEN Platform GMS <0-11356'>,,D-2ARd,DOLLY VARDEN Platform GMS <0-10628'>,,D-31Rd,DOLLY VARDEN Platform MSS <2450-10125'>,,D-31,DOLLY VkRDEN Platform GMS <0-13585'>,,D-24A,DOLLY VARDEN Platform PMSS <8988 - 12583'>,,M32St~2,STEELKEAD Platfo PMSS <12281 - 12660'>,,M32St#3,3TEEL/~EAD Platf PMSS <1386 q 9833'>,,M-32,STEELHEAD Platform PGMS <0-927'>,,Bl-10,STEELHEAD Platform PMSS <9365 - 10588'>,,M32ST#l,STEEL/{EAD Platfo PGMS <0-10938'>,,M-29,STEELHEAD Platform GSS <975-2660'>,,M~29,STEELHEAD Platform PMSS <10741-12018'>,,M-31St~l,STEELHEAD Platfo PMSS <10247-10355'>,,M-31,STEELHEAD Platform PGMS <0-14575'>,,M-30,STEELKEAD Platform PMSS <1334-3625>,,M-16,STEELHEAD Platform PMSS <1535-4500'>,,M-9,STEELHEAD Platform PGMS <0-6440'>,,M-7,STEELHEAD Platform PGMS <0-5185'>,,M~19,STEELHEAD Platform GSS <0-1421'>,,*M-4*,STEELHEAD Platform PGMS <0-7250'>,,M-3,STEELHEAD Platform PGMS <0-7419'>,,M-2,STEELHEAD Platform PGMS <0-7250'>,,M~lSt#1,STEELHEAD Platform PMSS <6595-6988'>,,M~1,STEELHEAD Platform PGMS <0-5600'>,,M-5,STEELHEAD Platform PGMS <500-928'>,,B1-2,STEELHEAD Platform PGMS <0-7434'>,,M-13,STEELHEAD Platform PGMS <O-785'>,,B1-6,STEELHEAD Platform PGMS <0-857'>,,B1-8,STEELHEAD Platform MSS <0-735'>,,OB #2,STEELKEAD Platform PMSS <808-1165'>,,RLF #2,STEELHEAD Platform PGMS <0-2310'>,,RLF #i,STEELHEAD Platform MSS <1363-1859'>,,RLF #2,STEEL/~EAD Platform PMSS <1006-1449'>,,M-15,STEELHEAD Platform PMSS <1006-7952'>,,M-15 St,STEEL/{EAD Platform PGMS <2700-9101'>,,M-14,STEEL~EAD Pl&tform MSS <l103-2265'>,,M-26,STEELHEAD Platform PGMS <12486-15276'>,,M-27,STEELHEAD Platform PGMS <3700-11700'>,,M-25,STEELHEAD Platform PGMS <0-12930'>,,M-28,STEELKEAD Platform MSS <2180-11319'>,,K-6Rd,KING SALMON Platform PGMS <0-13296'>,,K-6Rd, KING SALMON Platform PGMS <0-14325'>,,K-25,KING SALMON Platform 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 lO-Feb-98 29-Jul-96 29-Jul-96 29-Jul-96 10-Feb-98 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-SED-97 26-Aug-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul- 96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Ju1~96 29-Jul-96 29-Jul-96 29-Jul-96 14304.8 14304.8 13730.9 10839.7 10640.9 11642.0 13132.2 10452.2 12258.8 9763.8 10583.7 10352.5 14377.8 12563.3 9019.2 6679.1 9876.1 6990.1 7551.8 10471.4 13446 8 13446 8 9264 0 9087 9 9458 1 14483 2 14483.2 14027.0 14027.0 14027.0 14323.8 14323.8 10656.7 14532.9 14532.9 14644.5 10608.3 10946.8 11518.6 8822.2 10177.8 11678.5 2440.6 2440.6 3141.9 8025.6 2836.8 7450.0 7450.0 7450.0 7450.0 7450.0 7475.0 7450.0 7700.0 7462.5 7700.0 7450.0 7750.0 7450.0 7575.0 7700.0 7950.0 7450.0 7900.0 7900.0 7450.0 7450.0 7450.0 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11037.6 11037.6 11037.6 7450.0 7450.0 7450.0 7450.0 : 7450.0 9429.0 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 9558.0 7450.0 10320.1 11037.6 11037.6 11037.6 11037.6 10820.1 MSS <2063-10825'>,,K-16,KING SALMON tform GMS <0-12156'>,,K-9,KING SALMON P~ _zorm GMS <0-12900'>,,K-21,KING SALMON Platform GMS <10600-12540'>,,K-21Rd, KING SALMON Platfor PGMS <0-12130'>,,K-18,KING SALMON Platform G"MS <O-13370'>,,K-5,KING SALMON Platfoz-m GMS <2500-11240'>,,K-12,KING SALMON Platform PGMS <0-11400'>,,K-12Rd, KING SALMON Platform PGMS <0-10400'>,,K-22Rd, KING SALMON Platform MSS <5747-10904'>,,K-22,KING SALMON Platform GMS <8900-13463'>,,K-10,KiNG SALMON Platform GMS <0-12822'>,,K-10Rd,KING SALMON Platform GMS <2600-11767'>,,K-3,KING SALMON Platform GMS <0-13413'>,,K-3Rd,KING SALMON Platform MSS <l1494-13196'>,,K-30,KING SALMON Platform 29-Jul-96 29-Jul-96 30-Dec-97 30-Dec-97 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 MSS <2170-12600'>,,K-30Rd,KING SALMON Platform 29-Jul-96 GMS<O-21OO'>,,K-3ORd, KING SALMON Platform 29-Jul-96 PGMS <O-12120'>,,K-17,KING SALMON Platform 29-Jul-96 GMS <O-14700'>,,K-23,KING SALMON Platform 29-Jul-96 MSS <5028-8580'>,,K-20,KING SALMON Platform 29-Jul-96 MSS <10836~12447'>,,K-15,KING SALMON Platform 29-Jul-96 GMS <O-12200'>,,K~15Rd,KING SALMON Platform 29-Jul-96 MSS <10683~11439'>,,K~4Rd, KING SALMON Platform 29-Jul-96 MSS <2910~11772'>,,K-4,KING SALMON Platform 29-Jul-96 . GMS <O-2800'>,,K-4,KING SALMON Platform 29-Jul-96 MSS <2450~11094'>,,K-11,KING SA~ON Platform 29-Jul-96 MSS <5142-14016'>,,K-13,KING SALMON Platform 29-Jul-96 GMS <O-12173'>,,K-13Rd,KING SALMON Platform 29-Jul-96 GMS <2403-12915'>,,K-2Rd,KING SALMON Platform 29-Jul-96 GMS O-11288'>,,K-2,KING SALMON Platform 29~Jul-96 GMS <lO125~13990'>,,K-7Rd,KING SALMON Platform 29-Jul-96 GMS <0-10150'>,,K-7,KING SALMON Platform 29~Jul-96 MSS <10249-14700'>,,K-7,KING SALMON Platform 29-Jul-96 MSS <9725~13224'>,,K-1,KING SALMON Platform 29-Jul-96 MSS ¢2380-12570'>,,K-1Rd, KING SALMON Platform 29~Jul-96 GMS <0-2300'>,,K~lRd,KING SALMON Platform 29~Jul-96 PGMS <9300-14384'>OLD,,K-24,KING SALMON Platfo 29-Jul-96 Steering Tool,,K-24,KING SALMON Platform 29~Jul-96 PMSS <981~10956'>,,K~26,KING SALMON Platform 29-Jul-96 EMS <8955 ~ l1078'>,,K-26Rd,KING SALMON Platfo 29~Jul-96 GSS <492~855'>,,K-26,KING SALMON Platform 29-Jul-96 MSS <2622-13927'>OLD,,K-8,KING SALMON Platform 29~Jul-96 PGMS <0-2500'> NEW,,K-SRd,KING SALMON Platform 29-Jul-96 PGMS <2600~14548'>OLD,,K-8Rd,KING SALMON Platf 29~Jul-96 PGMS <0-13771'>,,K-19,KING SALMON Platform 9-Apr-98 GMS <0~lll60'>,,G-21Rd,GRAYLING Platform 14~May-98 PMSS <7938-10750>,,G-21Rd,GRAYLING Platform 1-Jun-98 GMS <0-11742'>,,G-23Rd,GR3%YLING Platform 30-Jul-96 GMS <0-12075'>,,G-23,GRAYLING Platform 30-Jul-96 MSS <8491-11420'>,,G-1,GRAYLING Platform 30-Jul-96 PGMS <0~l1430'>,,G-1Rd,GRAYLING Platform 30-Jul-96 GMS <0~10115'>,,G-ii,GRAYLING Platform 30-Jul-96 MSS <0~l1570'~,,G-32,GRAYLING Platform 30-Jul-96 GMS <0-11750'>,,G-SRd,GRAYLING Platform 30-Jul-96 MSS <7709-12175'>,,G-8,GP, AYLING Platform 30-Jul-96 MSS <0~16342'>,,G-14,GRAYLING Platform 30-Jul-96 GMS <0-8860'>,,G-IBRd,GRAYLING Platform 30-Jul-96 MSS <0~15330'>,,G-9,GP~AYLING Platform 30-Jul-96 GMS <1400-10400'>,,G-4Rd, GRAYLING Platform- 30-Jul-96 GMS <0-9000'>,,G-4,GRAYLING Platform 30-Jul-96 PGMS <0-10100'>,,G-7,GP~AYLING Platform 30-Jul-96 MSS <0-12007'>,,G-13,GRAYLING Platform 30-Ju!-96 MSS <0-12291'>,,G-19,GP~AYLING Platform 30-Jul-96 GMS <0-13661'>,,G-16,GRAYLING Platform 30~Jul-96 GMS <0-11900'>,,G-17Rd,GRAYLING Platform 30-Jul-96 MSS <3991-1§095'>,,G-17,GP, AYLING Platform 30-Jul-96 GMS <100-11050'>,,G-3Rd2,GRAYLING Platform 30-Jul-96 GMS <0-8800' (ll050)>,,G-3,GRAYLING Platform 30-Jul-96 MSS <9120~l1278'>,,G-3Rd,GRAYLING Platform 30-Jul-96 PGMS <0-10700'>,,G-2Rd,GRAYLING Platform 30~Ju1~96 MSS <10070-10975'>,,G-10,GRAYLING Platform 30-Jul-96 GMS <0~l1335'>,,G-22,GRAYLING Platform 30-Jul-96 GMS <0-11544'>,,G-26,GP, AYLING Platform 30-Jul-96 GMS <0~10400'>,,G-24,GP, AYLING Platform 30-Jul-96 GMS <0-10642'>,,G-20,GRAYLING Platform 30-Jul-96 GMS <0-12948'>,,G-27,GRAYLING Platform 30-Jul-96 PMSS <l1830-12453'>,,G-36,GP, AYLING Platform 30-Jul-96 PGMS <ll100-13380'>,,G-36DPN, GRAYLING Platform 30-Jul-96 MSS <2284-11655'>,,G-34,GRAYLING Platform 30-Jul-96 GMS <0-10268'>,,G-34Rd,GRAYLING Platform 30-Jul-96 6856.8 11037.6 3443.6 11037.6 2959.8 11037.6 2999.5 11037.6 7430.5 8725.0 5813.4 11037.6 7746.5 9970.1 8269.3 9408.0 9196.0 11037.6 9601.3 9920.1 7376.7 7450.0 7376.7 7450.0 5480.2 9670.1 6142.8 7450.0 4296.5 11037.6 4278.4 11037.6 9810.5 7450.0 5028.1 11037.6 7204.9 11037.6 6224.3 7450.0 6904.2 11037.6 6739.5 11037.6 1940.4 11037.6 1796.2 11037.6 9211.5 7450.0 4659.5 11037.6 9631.8 10870.1 8706.9 11037.6 6154.0 11037.6 5138.1 11037.6 7926.0 11037.6 7981.7 11037.6 7981.7 11037.6 6914.9 8475.0 6914.9 8475.0 9691.3 7450.0 4401.2 11037.6 4746.4 11037.6 10244.1 7450.0 10244.1 7450.0 10710.2 7450.0 4222.1 7750.0 9259.5 7450.0 6232.5 7450.0 6781.9 7450.0 3506.8 7450.0 3506.8 7450.0 4550.7 7450.0 4550.7 7450.0 3662.5 7450.0 3662.5 7450.0 3704.7 7450.0 1884.6 10720.1 4700.7 7450.0 4700.7 7450.0 5063.4 7450.0 4999.7 7450.0 5214.8 7450.0 2388.2 7450.0 1786.2 10120.1 2546.7 7450.0 3119.5 7450.0 1083.7 7450.0 4775.4 7450.0 4250.0 7450.0 4839.1 7450.0 3834.1 7450.0 3834.1 7450.0 3834.1 7450.0 3563.4 7450.0 2492.8 7450.0 3888.7 7450.0 4282.8 7450.0 3226.1 7450.0 2993.4 7450.0 3445.2 7450.0 4780.2 7450.0 4780.2 7450.0 3542.2 7450.0 1726.0 7450.0 1037.6 1037.6 11037.6 11037.6 8725.0 11037.6 9970.1 9408.0 11037.6 9920.1 7450.0 7450.0 9670.1 8125.0 11037.6 11037.6 9492.0 11037.6 11037.6 9970.1 11037.6 11037.6 11037.6 11037.6 9590.8 11037.6 10870.1 11037.6 11037.6 11037.6 11037.6 11037.6 11037.6 8475.0 8475.0 7450.0 11037.6 11037.6 10370.1 10370.1 7450.0 7750.0 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 11037.6 10820.1 7450.0 10720.1 7450.0 7450.0 7450.0 :10470.1 9590.8 9820.1 10120.1 7450.0 7450.0 7450.0 ~-~ 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 7450.0 9970.1 7450.0 7450.0 7450.0 7450.0 7450.0 MSS <0-10790'>,,G-33,GR~YLING PI ~rm PMSS <1395-12743'>,,G-14A Rd, GRAYLIB~__._~Iatform MSS <10250-13700'>,,G-12Rd, GP~AYLING Platform MSS <10250-13748'>,,G-12,GP-AYLING Platform GMS <O-13800,>,,G-12Rd2,GP. AYLING Platform PG~MS <iO0-11000'>,,G-6Rd,GRAYLING Platform GMS <0-9600'>,,G-6,GP, AYLING Platform GMS <0-12366,),,G-25,GRAYLING Platform GMS <O.12425'>,,G-28,GRAYLING Platform MSS <630-11451'>,,G-30,GRAYLING Platform MSS <O~12736'>,,G-31,GRAYLING Platform MSS <O-12885'>,,G-15,GR3%YLING Platform PGMS <O-9950'>,,G-5,GRAYLING Platform 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Dec-97 24-Apr-98 30-Jul-96 2183.4 7450. 4597.2 7450. 5593.1 7450. 5593.1 7450. 5593.1 7450. 3866.8 7450. 3866.8 7450. 3522.2 10970 3584.9 7450 3423.9 7450 3620.6 7450 3617.% 7450 0.0 7%50 0 0 0 0 0 o 0 1 0 0 0 0 0 7450.0 .~_~7450.0 7450.0 7450 0 7450 0 10470 1 7450 0 10970 1 7450 0 7450 0 9820 1 7450 0 7450 0 UNOCAL ._ Grayling G-5RD 06/11/98 Proposed Redrill Plan Grayling G-5RD Summary of Redrill Procedure G-5RD will commence with a whipstock set in the 9-5/8" casing of G-5 at 7450' MD. An 8-1/2" hole will be drilled to TD at 11,038'/10,000'-I-VD. A 7" liner will be run and cemented. The G- zone and Hemlock Benches 1-4 will be perforated with tubing conveyed guns. The well will be completed with a single 4-1/2" x 3-1/2" tapered tubing string and begin commingled injection into the G-zone and Hemlock. G-5redrill.doc 6/11/98 UNOCAL Grayling G-5RD 06/11/98 Proposed Redrill Plan Description Summary of Proposed G-5RD Redrill Operations Set whipstock at 7450'. 2 Mill window in 9-5/8" casing. 3 Perform leak-off test at 7460'. 4 Directionally drill 8-1/2" hole to TD of 11,038' MD/10,000' TVD using water-based mud 5 Run open hole logs: DITE/CNTH/LDTD/SDT/GR 6 Run 7" from 11,038' to 7200' MD. 7 Cement liner with appx 500 sx 15.8 ppg Class G cement with additives (yield= 1.15 cuft/sx). 8 Clean out liner with 6" bit to landing collar at 10,960'. 9 Run CET/CBT cement log. 10 RIH with tubing conveyed perforating guns and shoot G-1 thru Hemlock Bench 4 intervals. Estimated top of G-1 is 9562' MD/9000' TVD and base of HB-4 is 10,810' MD/9832' TVD.. 11 Pull TCP guns. 12 Run 4-1/2" x 3-1/2" tubing and 3-1/2" x 7" permanent packer. 13 Land hanger and set packer at appx 9400' MD/8907' -I-VD. 14 Pressure test annulus to 2300 psi. 15 ND BOPE and NU tree. 16 Perform MIT to 2300 psi with AOGCC witness. 17 Move rig and begin injection into G-5RD. G-5redrill.doc 6/11/98 UNOCAL Grayling G-5RD 06/12/98 Proposed Redrill Plan Maximum Anticipated Surface Pressure Estimated reservoir pressure is .44 psi Iff at 10,000' TVD for the Hemlock or 4400 psi. If a gas kick were encountered and the wellbore was ¼ ill, Led with gas: Maximum Surface Pressure = 4400~psi~(~OOO'x 9.4 ppg mud x .052)-(5000'x0.1 gas) = ~1~456 psi The Maximum Surf Press~u~e~'~or Fracturing the Shoe at 7319' TVD = (0.8 frac gra~t'~x 7319')- (9.4 MW x .052 x7319') = 2278 Therefore, maximum surface pressure is the lesser of the two calculations above or 1456 psi. G-5redrill.doc 6/12/98 Proposed Abandonment 7/98 Trading Bay Unit Well # Re-Completed 9/16/87 CASING AND TUBING D~TAtL RKB to TBG Hngr = 48.83' Tree connection: Dual 3" 5,000# SIZE WT GRADE CONN ID TOP BTM. CMT I6" 75 J-55 Butt Stlrf. 591' 1398 sx 1%3/8" 54.5 K-55 Butt 12615 Surf: 3078' 2600 sx 9-5/8" 47 P-110 Seal Lock 8.681 8519' 9657' 3000 sx %5/8" 47 N-80 Seat Lock 8.681 6925' 85 I9' " 9-5/8" 43.5 N-80 Seal Lock 8.755 5187 6925' " 9-5/8" 40 N-80 Seal Lock 8.835 79' 5187 9~5/8' 47 N-80 Seal Lock 8.681 Surf, 79' " 7" 29 N-80 8rd LT&C 6.184 9544' 10,302' 200 sx %5/8" DV Cotla 4376' 4378' 5" Scab 18 N-80 Butt 9719' 9803' Tubing: JEWELRY DETAIL Item 5 9587' 4.00 Baker 7" FB-1 Pk.r 6 9591' 4.00 Baker Seal Bore Ext., 9' long. 7 9600' Crossover, to 34/2" 8 9611' 2.75 Otis "X' ?rofile Nipple 9 9632' WLEG btm 9633' 10 9715 4.00 Baker "FB*I' pkr~ size 85-40 ii 9619' 4,276 5" 18#, N~80 12 9804 4,00 Anchor Latch Seal Assy. 13 9805' 4.75 X &00 Baker "FA4' pku, size 85-47 btm 9808' Cmt Retainer @ 9544' 9657~ I0 Reamed light spots on 12/2248i 13 9584' 7 8 9715' Mill thru w/ 3,75" mill on 9/2/87 FISH 2 Junked Retainer Junked Retainer STIMULATIONS Acidized w/2-I/2% HCL & 12-10 Mud acid 9/16/71 ~i l 0,244' 8/12/72 ~ 10,240' 11/18/7I B-l, B-2, B-3 & B4 B4 ~9985' _ )990' KB ELEV = 110.8' TD = 10,312' ETD = 9,985' HOLE ANGLE = 20.13° @ 2600' MiD PERF ANGLE = 6.5° G-5abdn2.doc PERFOR&TION DATA Last ~r, Pre~nt Condition ILEVISED: 06/12/98 DtL&Vv ~ BY: TAB RKB to TBG Hngr = 48.83' Tree connection: 4-1/Z' 5,000# 7200' Sideb'ack Whipstock KOP 7450' 9200' ,..,- Proposed G& Hemlock Perfs TD = 11,038' MAX HOLE ANGLE = 550 SIZE l 6" 13-3/8" Redrill Window 9-5/8" 9-5/8" 9-5/8" 9-5/8" DV Collar 9-5/8" 7" liner Tubing 4-1/2" 3-I/2" GRADE CASING AND TUBING DETAIL CONN ID Trading Bay Unit Well # G-5RD Proposed Redrill TOP BTM. CMT 75 54.5 47 43.5 40 47 29 12.6 9.3 J-55 Butt K-55 Butt 12.615 N-80 Seal Lock 8.681 N-80 Seal Lock 8.755 N-80 Seal Lock 8.835 N-80 Seal Lock 8.681 L-80 Bum'ess 6.184 L-80 Buttress Mod 3.958 L-80 8rd Mod 2.992 Surf, Surf, 7450' 591' 1398 sx 3078' 2600 sx 6925' 7450' " 5187 6925' " 79' 5187 4376' 4378' 7200' Surf 7200' 79' 11,038' 7200' 9200' JEWELRY DETAIL NO. Depth I___D Item I 9400 4.00 Baker "SAB-I" pkr, With anchored tubing 2 9440 2.813 "X" nipple 3 9470 2.992 3-1/2" tubing tail I PROPOSED PERFORATION DATA Accum. Dale Zone Top Btm Amt SPF Last Opr. Present Condition G-1 9,562' 4 Proposed G-2 4 Proposed G~3 4 Proposed G--4 4 Proposed G-5 4 Proposed B-1 4 Proposed B-2 4 ,Proposed B-3 4 Proposed B-4 10,810' 4 Proposed G-5redrill.doc DRAWN BY: TAB REVISED: 06/11/98 UNOCAL GRAYLING PLATFORM WELL G-5 RD DEPTH INTERVAL WINDOW @ 7450' MD (7319' TVD) DRILL 8 1/2" HOLE TO 11038' MD (10000' ']-VD) 7" LINER MUD TYPE GENERIC MUD #2 MUD ADDITIVES M-! GEL/M-I BAPJSODA ASH/ DRISPAC/GELEX/TAN NATH IN /CAUSTIC/FLO-VIS/LUBE 167/ TEKMUD 8588/SODIUM BICARBONATE/SOLTEX/ RESINEX/PHPA POTENTIAL PROBLEMS TIGHT HOLE/GAS KICKS/LOST CIRCULATION/COAL SLOUGHING/DIFFERENTIAL STICKING/HOLE CLEANING COST PER BARREL $25.00 ESTIMATED TREATMENTS/PROCEDURES . Build mud in fresh water with bentonite, Ddspac, PHPA, Soltex, and barite. Displace well to drilling fluid after setting whipstock. . Hole angles of less than 40 degrees should not cause significant problems. Higher hole angles increase the probability of cuttings bed formation. Elevated Iow shear rate rheology can be increased with Flo-Vis to inhibit the formation of cuttings beds. As angle building progresses, increase 3 RPM viscometer 06/11/98 . . . . . o Control density with barite, fresh water, and solids control equipment. Dump all sand traps as required. Keep mud weights as Iow as possible. Mud weight should range from 9.4 ppg to 9.6 ppg. Note: Higher mud weights may be required.4. Potential problems exist in coal sections. Soitex should be maintained @ 4ppb to minimize these problems. Add PHPA (^lcomer 60) to improve hole stability and increase solids encapsulation. Report drill solids analysis on mud check sheet. Report hydraulics calculations on mud check sheet. If torque is a problem. Lube 167 and Tekmud 8585 are both permitted for discharge. Do not exceed 2% by volume. Drill to 11038' T.D. Run 7" liner, Complete with 3% KCI. 8 % Hole Mud Formation Fresh Water Bentonite 10- 15 ppb Polypac .25- 1 ppb Soitex FIo-Vis PHPA 4 ppb .25- 1 ppb .25- .5 ppb ~, 06/10/98 2 ANTICIPATED 8 112" MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels APl Fluid Loss pH MBT Drilled Solids 9.4- 9.6 ppg 42-75 sec/qt 10 - 15 cps 10 - 20 #/100ft2 10115/20 #/100f~ 4-6cc 8.5 -9.5 <20 ppb <50 ppb Note: This mud program is a guideline only. Hole conditions should dictate actual mud properties. DO NOT EXCEED M.A.C. of products or use products not approved in the discharge permit. See letter requesting authorization for list of approved products and M.A.C. Stuck pipe contingency: Use mineral oil/kwikspot pill if required for differential sticking. Follow procedures outlined in N.P.D.E.S. Discharge permit. UNOCAL GRAYLING PLATFORM WELL G-5 RD ESTIMATED FLUID COST Estimated drilling fluid cost based on 9.6 PPG mud weights $90,000 Completion Cost 3% KCI Total estimated cost $2,500 $108,750 06/10/98 3 sco-o-o_ I (~'IV::)ONn NOIIYA3'13 )OVIS W31N363Wd J. nO M0"18 ~3.J,JVHS ~O31Vqd ONI],,L¥ ~0 ~0096 'I33NI ~DDD Y~WOJIVqd O Nl"l,kVW9 DNISIgOH '1¥2,S JO I'~0£J. O8 ':cS_,l' , ) ( dOB 31YO 39B1'100 B3J.,-'YHS L -, >IDB0, 991~0 ... *-~'"}t6-,t IOO8 N¥cl cJlB0 I40 BBLS PIT WIXING PIT IS A ONE LEVEL BELO~ THE ACTR/E SYSTEW ~ 85 BBLS VOLUWE PIT 185 BBLS SUCTION PIT 125 BBLS. 87 BBI_S 24-0 BBI_S iDEGASSER ! DESILTER I SHAKER TRIP TANK 45 BBLS RESERVE PIT 47 5 BBLS SHAKER ----CENTRIFUGE1 NOTE: THE SYSTEM WILL BE EQUIPPED WFFH A DRILLING PR' LEVEL INDICATOR AUDIO ~k VISUAL WARNING DEVICES. WITH EQUIPMENT LIST l) RESERVE PIT 2) DEOASSER 3) (2) SHAKERS 4) PIT LEVEL INDICATOR (VISUAL A AUDIO) 5) FLUID FLOW SENSOR 6) TRIP TANK 7) PiT AC;Il'Al'ORS DESILTER CENTRIFUGE 10) MIXING I"IT UNOCAL CRA'fi_lNG MUD PlY SCItEMAT C DRAWN BY: DAC APP'D: GSEI SCALE: NONE DATE: 11--30-B9 TO GAS BUSTER /\ TO OERRICK VENT ~_~/~,, CHOKE CHOKE ~-~/~,, ~-~/~s,, ~ o-~,/~s" ~-l/~,, FROk~ CHOKE LINE TO W~"LL CL~a,N TANK VALVES UPS'TRF~M OF CHOKES. ARE 1O,0OO PSl CATE TYPE VALVES' 00WNST'RS,-N.W OF CHOKES' ARE .5,gO0 PSI GATE TYPE UNION CHOKE MANIFOLD GRAYLING PLATFORM OIL COkfPAN"r' OF CALIFORNIA (dba UNOCAL) 0RAt, VN: 0AC APP'O' GSEt SCALE: NONE OAl%: ~ l/~/a~ ~47 ~614 -31-98 50~ 7 S 4. 3 RIV~ FIELD 840 AC I~AC rTE' 21~8 18777 ' ~-5~0~ 100~ tO~ ~ - --~;;¢-7---~ ..... 1' ,;%;. f' ~o&-~ '~ ~ ~ ~1 I ~ / ST~T ~ART i ~7 2 LES A.l~L-},877 6 2 10 Lt 14 ~7 I I i ! ! ! , ! Il i ! I 384~iC P ADL~8772 i5 U"N'O CALl ,100~. 27 AC~2 18718 A DL-37d, O.+6 ARCO 84 YRADI ~AYI UNIT LR, fOCt r.-!Oe2; 5~-"~ icl ADL-i75~ tt 374~ 14. um'T¢ EXHIBIT "A" !C, reotecl OF Sut~edond For: T Billin[miey Octe plotted : lO-Jun-~8 { Plot Reference ~s C-SRd Vets;on WELL PROFILE DATA ,dNOCAL Structure : GRAYLING Ploffarm Well : G-5 Field : McArfhur River Field Location : TBU, Cook inlet, Alaska UNOCAL ) East (feet) -> 6(]0 400 200 0 2(30 4.00 600 800 1000 1200 1 `*00 · I I I I I I I I I [ ! I I I I i I f I I I I I- 26co T.D. & End of Dro~ ,.~ ,~. ,.~. ~.. ,,~,, ~ ,~ 72 't KOP 7,*00 q 10.¢6 11.70 7600 I 1 / 18.05 78CO ] 20.50 ] 23.26 DLS: .5.00 de<] per ~C0 ft 8C00 t 25.98 8200 1 31.58 ~ J 34.42 37.29 (- 8~C0 86C0 ~_ 8800 ~ 9000 92C0 v 40.17 43.06 4-5.97 48.89 51.81 End of Build/Turn G-SRd GZT - 20-Apr-98 9400 End of Hold ; 54.00 ; 53.00 52.00 51.00 50.00 OLS: 1,00 dog per 100 ft 49.00 48.00 47.00 46.00 4-5.00 4-4.00 43.00 4-2.00 41.00 40.00 r.o. & End of Drop i i i i i i 0 200 ,*00 600 800 ,000 1200 ,,*00 ~600 ~800 2000 2200 2,00 2600 2~00 Verffc~l Secfion (feet) -> Azimuth 58.,57 with reference 0.00 S, 0.00 E from slot #4-17 9600 gBO0 IC000 10200 2`*C0 i2200 2COO ~ ~80o I O 1200 ifC00 L 8c0 p 8c0 L i L ~C0 FOR INQUIRIES CONTACT LOCATION WHERE INVOICES WERE SUBMITTED CHECK NO. . DATE . . INVOICE/CREDIT MEMO NO. 12 -JUN- 9 DRILLPERi~ITG5R£ FORM 4-2B181 (REV. 11-95) PRINTED IN U.S.A. DETACH STUB BEFORE DEPOSITING CHECK VOUCHER NO~ 0698300033 IVENDOR NO. DATE! :;'::i~.: :t: .' DISCOUNT NET 100.C 200266~ 100.o loo.o,o 100.0 CITIBANK DELAWARE 62-20 A Subsidiary of Citicorp 311 ONE PENN'S WAY NEW CASTLE, DE 19720 One Hundred Dollars An~ Union Oil Company of California Accounts Payable Field Disbursing 2002668 Pay To the order of STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DR ANCHORAGE, AK 99501 V 12-JUN-98 *******100. O0 Date Check Amount Void after six months from above date. FOR INQUIRIES CONTACT LOCATION WHERE INVOICES WEP~ SUBMITTED i · vE;:: 5 DAT~ ECKN '~.~- '~-03154 ~ 06-12-9[ 200266~ . ' i . , ~A!E ...... INvOIcF-JCREDIT MEMO N0· vOuCI-IERNO- . ~ROSS ' ! .Di~OU~ ~.' ' 12. Jl..~--9[ DRII,T,PERMITGSR£ 0698300033 i 100.0~) 100.0~ ..: · 100.0 ) 100.0£ · WELL PERMIT CHECKLIST FIELD&POOL COMPANY Umer..~l WELLNAME TF~u. ~..~- ~-/~ PROGRAM:expPIdevl-lredrll/l~servE]wellboresegllann. disposalparareqll INIT CLASS /)e ~,' ,2. - ~ ,' / GEOL AREA ~ ,,l,. ~ UNIT# ] ,,7 0 -? O ON/OFF SHORE ADMINISTRATION APPR DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to _.,~3c~ ~ .psig 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N !GEOLOGY AI~ DATE , . 30. Permit can be issued w/o hydrogen sulfide measures ..... ~ 31. Data presented on potential overpressure~~ ...... / Y N 32l Seismic anal,y.s.,is fsha~............. Y N 33. Seabed con~dj:t/~-SUT~--y (if off-shore) ............. Y N 34. C , name/phone for weekly progress repods ....... Y N lexploratory only] ANNULAR DISPOSAL APP% DATE 35. With proper cementing records, this plan (A) will contain waste~receiving zone; ....... Y N (B) will not cont~fifiate freshwater; or cause drilling waste... Y N to surfac/ce,-~, (C) wilt..~cfimpair mechanical integrity of the well used for disposal; Y N (D) ~f'not damage producing formation or impair recovery from a Y N C/pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: U I C/Anp/d' al'~r COMMISSION: JDH ~ RNC , ~ Comments/Instructions: M:chet~list rev 05/29/98 dlf: C:\msoffice\wordian\diana\ch<mMisl