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181-183
From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: TBU G-04RD (PTD 1811830) AIO AA 5.024 Cancellation Date:Wednesday, July 26, 2023 9:07:13 AM From: Wallace, Chris D (CED) Sent: Tuesday, September 24, 2019 10:02 AM To: Holly Tipton <hotipton@hilcorp.com> Subject: RE: TBU G-04RD (PTD 1811830) AIO AA 5.024 Cancellation Holly, I am progressing the AIO 5.024 cancellation application. Our records indicate the approved Sundry 319-089 has not been completed (we haven’t processed/received a 10-404) and that injection was still occurring in August 2019. Maybe the 10-404 just hasn’t been sent yet - but please ensure injection into G-04RD is completed before the AIO cancellation takes effect. We will adjust the webpage to correctly reflect the AA 5.020 cancellation. Thank you for pointing that out. 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: Holly Tipton <hotipton@hilcorp.com> Sent: Monday, September 23, 2019 10:39 AM To: Regg, James B (CED) <jim.regg@alaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: TBU G-04RD (PTD 1811830) AIO AA 5.024 Cancellation Good morning Jim and Chris, Hilcorp recently converted the G-04RD (PTD 1811830) from an injector to a producer. This well was previously injecting under AA 5.024, which is no longer needed as the well has been converted to a single completion oil well under Sundry #319-089. Hilcorp respectfully requests to cancel AA 5.024 and update the well class to “Development”. A copy of AA 5.024 and 10-403 for Sundry #319-089 are attached. In addition, it looks like the previous AA 5.020 was cancelled in May 2016, but is still listed on the AOGCC Orders Web Application as “active”. A copy of the cancellation for AA 5.020 is attached. Thank you! Holly Tipton Regulatory Tech - CIO Asset Team Hilcorp Alaska, LLC o: (907) 777-8330 | m: (281) 543-8964 e: hotipton@hilcorp.com The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. Inaddition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, pleasenotify the sender immediately by return e-mail and permanently delete the copy you received. 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Schwartz, Guy L (CED) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Wednesday, October 9, 2019 3:38 PM To: Schwartz, Guy L (CED) Cc: Juanita Lovett Subject: Re: [EXTERNAL] G-04RD gaslift tubing punches / convert to producer (PTD 181-183) This one was on an AA with tubing by IA communication so that was a combo MIT Yes the no flow was completed I will get you a copy Sent via the Samsung Galaxy $7, an AT&T 4G LTE smartphone ------- Original message -------- From: "Schwartz, Guy L (CED)" <guy.schwartz@alaska.gov> Date: 10/9/19 3:17 PM (GMT -09:00) To: Dan Marlowe <dmarlowe@hilcorp.com> Subject: [EXTERNAL] G-04RD gaslift tubing punches / convert to producer (PTD 181-183) Dan, I don't see in the work report where the IA was tested to 2500 psi. Looks like the tubing was tested however. Also, did a "no flow " test get completed as specified in the sundry 319-089 ? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793- 1226 ) or (Guy.schwartz@alaska.gov<mailto:Guy.schwartz@alaska.gov>). The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. Schwartz, Guy L (CED) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Wednesday, October 9, 2019 3:38 PM To: Schwartz, Guy L (CED) Cc: Juanita Lovett Subject: Re: [EXTERNAL] G-04RD gaslift tubing punches / convert to producer (PTD 181-183) This one was on an AA with tubing by IA communication so that was a combo MIT Yes the no flow was completed I will get you a copy Sent via the Samsung Galaxy $7, an AT&T 4G LTE smartphone ------- Original message -------- From: "Schwartz, Guy L (CED)" <guy.schwartz@alaska.gov> Date: 10/9/19 3:17 PM (GMT -09:00) To: Dan Marlowe <dmarlowe@hilcorp.com> Subject: [EXTERNAL] G-04RD gaslift tubing punches / convert to producer (PTD 181-183) Dan, I don't see in the work report where the IA was tested to 2500 psi. Looks like the tubing was tested however. Also, did a "no flow " test get completed as specified in the sundry 319-089 ? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793- 1226 ) or (Guy.schwartz@alaska.gov<mailto:Guy.schwartz@alaska.gov>). The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVE OCT 0 8 2019 r.�_'V510rI&T.-O. Form 10-404 Revised 412017 // w "10.1 A I i l° � RBDMS ±OCT 0 9 2019 Submit Original Only LJ rmy reaoranons LJ rracture Stimulate LJ Pull Tubing ❑ d"�'L.� [y�As�elTutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Convert to Producer / Tubina ED2. Punch Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑ Exploratory ❑ 181-183 3. Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic ❑ Service ❑� 6. API Number: Anchorage, AK 99503 50-733-20050-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 / ADL0018730 Trading Bay Unit G-04RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.0717 10. Field/Pool(s): N/A McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured 10,450 feet Plugs measured N/A feet true vertical 9,606 feet Junk measured N/A feet Effective Depth measured 10,330 feet Packer measured See Schematic feet true vertical 9,501 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor 621' 16" 621' 621' 2,630 psi 1,020 psi Surface Intermediate 3,043' 13-3/8" 3,043' 3,005' 3,090 psi 1,540 psi Production 5,970' 9-5/8" 5,970' 5,718' 5,750 psi 3,090 psi Liner 10,451' 7" 10,451' 9,607' 8,160 psi 7,020 psi Perforation depth Measured depth 9,295 - 10,392 feet True Vertical depth 8,618-9,555 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# & 13.55# / L-80 9,203 (MD) 8,539 (TVD) Packers and SSSV (type, measured and true vertical depth) See Schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13, Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 4803 810 840 Subsequent to operation: 0 0 945 815 229 14. Attachments (required per zo nnc 2s.mo, zs.o7t, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory ❑ Development ❑� Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WD Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-089 Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmadoweliDhilcoro com Authorized Signature: ! Date: k U g Contact Phone: (907) 283-1329 Form 10-404 Revised 412017 // w "10.1 A I i l° � RBDMS ±OCT 0 9 2019 Submit Original Only SCHEMATIC McArthur River Field, TBD Well: G-04RD n ro oAv �a�ti As Completed: 07-31-2015 RKB to Tubing Hgr = 41.34' DV'""' rl I I I 451V t Window ' I15,639 D 5970'032' 1 2 �> k +ba 3 4 Fill @ 10,330' G Perfs j HK -1,3,4,5 5 HK -5 & HK 6 6 HK -6&7 PBTD =10,420' TD =10,450' Max angle = 330 @ 9500' amg,c punas in rumng L �,w= IVu IuY/19/Zu19) Casing & Tubing Detail Open Jewelry Detail SIZE WT WT GRADE CONN ID TOP BTM 16" 75 J-55 8 Round 15.124 Surf 621 13-3/8" 61 J-55 Butt 12.515 Surf 3,043' 9-5/8" 47 N-80 Butt 8.681 Surf 79' 9-5/8" 40 N-80 Butt 8.835 79' 4,355- 9-5/8- 43.5 N-80 Butt 8.755 4,355' 5,970'(TOW) 7" 29 N-80 Butt 6.184 Surf 10,451' G-3 9,436' 9,456' Tubing: 8,7 55' 20' TC P 4-1/2" 12.60/13.55 L-80 BTC Ext Polycore 3.598 Surf 9,203' amg,c punas in rumng L �,w= IVu IuY/19/Zu19) Revised by: JLL 09/26/19 Open Jewelry Detail No Depth (MD) Depth (ND) ID OD Description Btm (MD) 42' 42' Amt SPF Hanger 1 7,240' 6,818' 3.995" 5.875" Hydroset Packer w/ 15.5' upper seal bore 2 9,176' 8,515' 3.995" 5.875" Hydroset Packer w/ 5' millout extension 3 9,194' 8,531' 2.813" 4.500" X nipple 4 9,203' 8,539' 2..992" 4.500" Wireline Re-entry Guide 5 10,153 9,347' 4.000" G-2 Baker Model FB -1 straddle packer, drill pipe 3-1/2" L-80 buttress tubing SC 6 10,312 9,486' 4.000" S Baker Model FB -1 straddle packer, E -line Revised by: JLL 09/26/19 Open Perforation Detail Zane Top (MD) Btm (MD) Top (618'ND) Btm (ND) Amt SPF Date Comments G-1 9,295' 9,320' 8, 8,639' 25' TCP 03/09/1998 Open G-1 9,300' 9,320' 8,622' 8,639' 20' 5 07/27/2015 G-2 9,345' 9,365' 8,661' 8,678' 20' TCP 03/09/1998 Open G-2 9,350' 9,365' 8,665' 8,678' 15' S 07/27/2015 G-3 9,436' 9,456' 8,738' 8,7 55' 20' TC P 03/09/1998 Open G-3 9,438' 9,456' 8,740' 8,755' 18' 5 07/27/2015 G-4 9,486 9,537' $780' 8,823' 51' TCP 03/09/1998 Open 64 9,491' 91496' 81785' 8,789' 5' 5 07/27/2015 G-4 9,501' 9,509' 8,793' 8,800' 8' 5 07/27/2015 G-4 9,520' 9,535' 8,809' 8,821' 15' 5 07/27/2015 G-5 9,587' 9,672' 8,865' 8,936' 85' TCP 03/09/1998 Open G-5 9,595' 9,610' 8,871' 8,884' 15' 5 07/27/2015 G-5 9,618' 9,639' 8,891' 8,908' 21' S 07/27/2015 G -S 9,645' 9,670' 8,913' 8,934' 25' S 07/27/2015 Block Sqz 9,758' 9,760' 9,009' 9,011' 2' 03/11/1982 Sqzd w/190sx HK -1 9,815' 9,840' 9,057' 9,079' 25' S 07/27/2015 HK -1 9,815' 9,843' 9,057' 9;081' 28' -z TCP 03/09/1998 Open Block Sqz 9,852' 9,854' 9,089' 9,090' 03/10/1982 Sqzd w/100sx HK -2 9,862' 9,882' 9,097 9,114' 20' 09/05/1983 Sqzd 04/20/85 Block Sqz 9,960' 9,962' 9,181' 9,183' 2' 03/09/1982 Sqzd w/100 sx 04/19/85 HK -3 9,965' 10,016' 9,185' 9,229' 51' TCP 03/09/1998 Open HK -3 9,968' 10,014' 9,188' 9,227' 46' 5 07/27/2015 HK -4 10,024' 10,146' 9,236' 9,341' 122' TCP 03/09/1998 Open HK -4 10,025' 10,058' 9,237' 9,265' 33' 5 07/27/2015 HK -4 10,067' 10,118' 9,273' 9,317' 51' 5 07/27/2015 Block Sqz 10,102' 10,104' 9,303' 9,305' 2' 04/19/1985 Sqzd w/100 sx HN -4 10,127' 10,145' 9,325' 9,340' 18' 5 07/27/2015 Block Sqz 10,162' 10,164' 9,355' 9,357' 2' 3/15/1982 Sqzd w/200 sx HK -5 10,182' 10,188' 9,373' 9,378' 6' 04/04/1997 Straddle pkr 3/98 HK -5 10,182' 10,198' 9,373' 9,386' 1 16' 5 07/27/2015 HK -6 10,300' 10,305' 9,475'9,479' S' 05/28/1996 Straddle pkr 3/98 HK -6 10,325' 10,355' 9,497' 9,523' 30' 12 03/09/1998 Open HK -7 10,364' 10,392' 9,531' 9,555' 28' 12 03/09/1998 Open Revised by: JLL 09/26/19 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Numher Start Date End Date Trading Bay Unit G-04RD Slickline 50-733-20050-01-00 181-183 9/15/19 1 9/19/19 Daily Operations: 09/15/19 -Sunday ARRIVE GRAYLING PLATFORM. TGSM JSA PERMIT. RIG UP SLICKLINE P/T LUB. TO 250PSI LOW 3000PSI HIGH. RIH W/ 2.83" SWEDGE TO 7499'KB SIT W/ TOOL FELL TO 9188'KB. TAG X -NIPPLE. POOH. RIH W/ 3 1/2" X -SELECTIVE PLUG TO 9157'KB SIT W/ TOOL WOULD NOT FALL - POSSIBLY SITTING IN X/0. STAND BY FOR PRODUCTION TO PUMP FLUID W/ TOOL. PRESSURE NOT HOLDING. POOH. INSPECT & CLEAN TOOL. LAY DOWN FOR NIGHT. 09/16/19 - Monday MORNING MEETING, JSA PERMIT. RIH W/ 3" GS W/ 3 1/2" X -SELECTIVE TOOL IN SELECTED POSITION TO 7499'KB SIT W/ TOOL FELL TO 9192'KB SIT W/ TOOL SET PLUG. P/T to 2500 PSIG FOR 30 MINUTEEE§, I RT, GOOD TEST. POOH W/ TOOLS. 'DOWN RIG CLEAN AREA. SECURE WELL FOR PRODUCTION. 09/17/19 -Tuesday No operations to report. 09/18/19 - Wednesday No operations to report. 09/19/19 - Thursday Arrive at Grayling. Sign in, obtain PTW, HWP, and hold PJSM w/ operations. Move and spot equipment, begin rig up. MU 1-9/16" tubing puncher with one shot, weight bars, kick over tool, CCL. Move to well and PT 500L/2000H. RIH (7.5' CCL to shot), log pass from 5750' and stop at 5627.5' CCL depth, placing shot at 5635' MD. (tubing collar @ 5631'). Confirm shot depth and monitor tubing and IA pressures (1250psi), fire gun w/ good indication of shot. Tubing pressure dropped 20 psi. POOH, Rig back to test gaslift. Confirmed Lift & Rig down. Depart platform. MEMORANDUM TO: Jim Regg 1 efq to13��� P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: 10/03/19 FROM: Guy Cook SUBJECT: No Flow Test Petroleum Inspector TBU G-04RD Hilcorp Alaska LLC PTD 1811830; Sundry 319-089 10/02/19: 1 arrived on the Grayling Platform and met with Jon Collins (Hilcorp Production Lead). We discussed the job and walked down the rig up of equipment for the no -flow test. The rig up was correct and the gauge for the tubing was currently calibrated and in good shape. There was a flow meter included in the rig -up, but Mr. Collins told me he didn't have a preference on which way the well was to be tested. After it was decided to shut the well in for 3 hours, then open it up to see if it would bleed to zero pressure within 5 minutes. I confirmed all valves were in the correct positions and the well was shut in for the 3 -hour build-up. After 3 hours the well was opened to bleed pressure. I watched the flow meter and recorded that it started at 800 SCFH, but within one minute it was down to zero flow. I then checked the end of the bleed hose for flow. At 1 minute and 36 seconds from the start of bleeding the well there was no detectable flow from the end of the bleed hose. No liquids observed at surface. The following table shows test details: Time Pressures' (psi) Flow Rate2 Gas — scf/hr Liquid — al/hr Remarks 11:00 0/0/0/3.5 0 0 Well shut in for 3 hr build u 11:15 .03/0/0/3.5 0 0 11:30 .05/0/0/3.5 0 0 11:45 .09/0/0/3.5 0 0 12:00 .10/0/0/3.5 0 0 12:15 .12/0/0/3.5 0 0 12:30 .15/0/0/3.5 0 0 12:45 .17/0/0/3.5 0 0 13:00 .19/0/0/3.5 0 0 13:15 .22/0/0/3.5 0 0 13:30 .24/0/0/3.5 0 0 13:45 .26/0/0/3.5 0 0 14:00 .28/0/0/3.5 800 0 Oen well to bleed pressure 14:02 0/0/0/3.5 0 0 No detectable flow ' Pressures are T/IA/OA/OOA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr The test meets the requirements for being able to be produced without a SSSV. Attachments: none 2019-1002_No-Flow_TBU_G-04RD_gc. docx Page 1 of 1 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY October 3, 2019 Mr. Stan Golis Operations Manager — CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No -Flow Verification Trading Bay Unit G-04RD PTD 1811830 Dear Mr. Golis: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a og c c. o l a s k a. g o v On October 2, 2019 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Trading Bay Unit G-04RD located on the Grayling Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10- 004 — was rigged up on Trading Bay Unit G-04RD prior to the test. The well was shut in for three hours then opened to flow, confirming tubing and tubing -casing annuls pressures bled to zero within five minutes. Within one minute, the gas flow declined from 800 standard cubic feet per hour to an undetectable rate; there were no liquids produced to surface during the flow monitoring period. Trading Bay Unit G-04RD may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit G-04RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no -flow test. Please retain a copy of this letter on the Grayling Platform. Sincerely, � �J21 James Regg Petroleum Inspection S pervisor ecc: P. Brooks AOGCC Inspectors • • Wallace, Chris D (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Wednesday, February 21, 2018 11:34 AM To: Wallace, Chris D (DOA) Subject: Grayling G-04RD Compliance Temp Survey AIO 5.024 (PTD#1811830) Attachments: G-04RD Temp Survey 2015-2016-2018.xls Hi Chris Attached is the two year compliance temp survey for the G-04RD well performed on 2/12/18. As we discussed below, the timing of this survey is a little later than the compliance anniversary date of the Admin Approval (1-15-16) but occurred late due to getting the downhole temperature profile re-established after the well had been offline for some time. The new survey confirms the stability of the heating anomaly first noted in the original request for this Admin Approval on 4-22-16(see below in blue). Where,for lack of a better explanation, the heating anomaly between the straddle packers was attributed to a geologic artifact. The new survey doesn't give any clearer explanation, but does demonstrate the stability of the anomaly and reconfirms that the colder injection fluids are exiting the casing at the perfs and are not migrating out of the approved injection strata. Thank you Larry To summarize the integrity issue for the Grayling G-04RD well: The G-04RD well was converted from a producer to an injector in July of 2015. Due to some downhole casing damage, a straddle packer completion was approved with modified MIT requirements (AIO 5.020). The well was brought on injection on 8/14/15 and passed an initial MIT on 8/27/15. In early September the well showed possible tbg x IA communication beyond thermal effects so on 9/17/15 the well was shut-in and the state was notified. A two week temporary injection diagnostic period was authorized (see bottom of this e- mail). The wellhead checked out as OK on 9/17/15 (see attached e-mail). A MIT-IA during the diagnostic injection period on 9/23/15 showed that the well would not pass a standard half-hour MIT- IA pressure test as a slow IA pressure drop was confirmed (see attached MIT-IA). A 12 hr SI temp survey was run on 9/28/15 and the baseline temp survey was run on 1/15/16, —100 days after shutting in the well at the end of the diagnostic period authorized by AOGCC (see attached temp survey overlay). The temp survey overlay demonstrates that the injected FIW is exiting the casing at the perfs. The heat anomaly between the straddle packers does not appear to be related to the injection fluids and seems to be some sort of geologic artifact. This can be confirmed during the next required temp survey. From: Larry Greenstein 1 • Sent:Wednesday,January 31, 2018 10:34 AM To:Chris Wallace @ AOGCC<chris.wallace@alaska.gov> Subject:Grayling G-04RD Compliance Temp Survey timing for AIO 5.024(PTD#1811830) Hi Chris As discussed yesterday, the G-04RD well has not been on injection for a while, but we'd like to keep the well available for injection on an as needed basis. To that end, we need to complete the two year compliance temperature survey(TS). This will require bring the well back online to establish a stable downhole temperature profile(1-2 weeks)and then perform the standard 12 hr shut-in TS. As this timeframe overlaps into February, we're asking for permission to allow this to occur in conjunction with another well on the platform. Recently a temporary injection window with a TS endpoint on the G-22 well was approved as the start point for requesting an Admin Approval for that well to continue EOR injection. The timing of the G-04RD well's injection and resulting TS (if approved)will tie in nicely with the timing of a similar injection window for the G-22 well. In that case, we'd be able to perform the TS on both wells on back to back days simplifying wireline and helicopter scheduling. If that is acceptable to the AOGCC, we'd like to proceed accordingly to complete the compliance TS for the G-04RD well in February(and adjacent to the TS for G-22). Thank you Larry 2 1110 • IHilcorp I Well:IG-04RD I FieId:IGrayling 102/12/2018 I Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 0 1000 111110"- 2000 /NW — . Pressure-Temperature Profile • _ 4111441p, - 1. 9/28/15 - 1/1 5/1 6-02/12/18 Overlay 3000IS 2. Static I 4000 — _ G) 412 5000 N.- _ D =I6000 L�� 1 - Q --1.. a — - 7000 11141-1-11-11"111111k 8000 l fx 9000 _ X - 11. NW MEI - 10000- En 11000 1 1 I I 1 1 1 1 I I 1 1 1 40 50 60 70 80 90 100 110 120 130 140 150 160 170 Temperature (Deg. F) 2-12-18 Pressure -- Perfs Valve —9 5/8" —7" 4 1/2" —2-12-18 Temp —9-28-15 Temp —Temp 1-15-16 \ 5 \- \ s • • Post Office Box 244027 Hilcorp Alaska,LLC Anchorage,AK 99524-4027 [fi ,Gblvt 3800 Centerpoint Drive n )017 Suite 100 � � :°- Anchorage,AK 99503 Phone: 907/777-8322 March 27, 2017 Fax:907/777-8310 Mrs. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED AF's' O ZO ? Re: McArthur River Field AIO #5 2016 G-04RD Annual EOR Surveillance Report Dear Commissioner Foerster: Attached for your review is the 2016 Annual EOR Surveillance for the McArthur River Field water injector according to AIO #5.024. Injection well G-04RD continues to act as expected and injection remained within confining layers based on a January 15, 2016 temperature survey and a relatively constant injectivity index. There has been no change in the wells mechanical condition, and as established by administrative approval 5.024 of AIO 5,the next temperature survey will be completed on or before January 15, 2018. Regards, jit Jim Young Jeff Allen Reservoir Engineer Reservoir Engineer Hilcorp Alaska Hilcorp Alaska Exhibit#1 —Daily average injection rates,tubing and annuli pressure plot • • • • 0 0 0 10 0 0 0 M o ! slgq 0 0 0 00 CO CI 17 N O R.04.....______.._. I I 1 I .-1 O — N 6Izoit rr F W de.... 4...._ . ,w O � – N G R gr ril." Q k ILI In 1E meltWit 0 • X 0 -4 H W u �— IN Q JIM O O 1/40O 0 M O � -111111111111111111111-4.1116 , I I I .. 0 M ____,.....................,...„.„..„.,,,JJ , i..ei t I reW O i .... ... .... I ....`.... , _.. j.. . .. O rel f e-1 N w• qiSd 'aanssaid 1 O • VI • . Pry Igl\ g30 IHilcorp Alaska,LLC I WeII:IG-04RD I Field:IGrayling 01/15/2016 I Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 0 1000 — 2000 Pressure-Temperature Profile 1. RI H 9-28-15 vs 1-15-16 Overlay 3000 2. Static 4000 I5000 6000 — a a) G l& 7000 8000 1 wir-k x 9000 X no 10000 NI A c..........„___ 11000 , I I I I I I I 1 I I I I 50 60 70 80 90 100 110 120 130 140 150 160 170 180 Temperature (Deg. F) -1-15-16 Pressure – Pens x Valve 9 5/8" -7" —4 1/2" 1-15-16 Temp —9-28-15 Temp SCANNED FEB 1 62017 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,September 22,2015 TO: Jim Regg P.I.Supervisor Z 717'4 S- C.)/ SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC G-04RD FROM: Jeff Jones _ TRADING BAY UNIT G-04RD Petroleum Inspector S ANNED __ i [ �rc� Src: Inspector Reviewed By: P.I.Supry JSIC-- NON-CONFIDENTIAL Comm Well Name TRADING BAY UNIT G-04RD API Well Number 50-733-20050-01-00 Inspector Name: Jeff Jones Permit Number: 181-183-0 Inspection Date: 8/27/2015 Insp Num: mitJJ150906055224 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Weill G-04RD Type Inj w 'TVD 8515 - Tubing 1540 1540 ' 1550 - 1550 • PTD 1811830 ` Type Test sPT Test psi 2129 - IA 320 2220- 2215• 2215 • L Interval INITAL - P/F P OA 7 6 J 6 - 6 • Notes: 1 well inspected,no exceptions noted. - Tuesday,September 22,2015 Page 1 of 1 • • Brooks, Phoebe L (DOA) PTV-1 I4)( 1(63Q From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Saturday, September 19, 2015 8:50 AM To: Brooks, Phoebe L (DOA) Subject: RE: MIT Grayling 08-27-2015 Attachments: G-04rd Schematic 2015-08-27.doc; G-07 Schematic 2015-08-26.doc; G-12RD3 Schematic 2015-09-18.doc; G-14ARD Schematic 2015-09-18.docx Just got them Phoebe. The G-04RD you should already have, but here are the rest. Larry SCANNED s Original Message From: Brooks, Phoebe L(DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Thursday, September 10, 2015 11:21 AM To: Larry Greenstein Subject: RE: MIT Grayling 08-27-2015 Larry, Would you please send me the schematics on these wells (G-04RD, G-07,G-12RD3, and G-14ARD) so I can verify the Packer TVDs? Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 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 Phoebe Brooks at 907-793- 1242 or phoebe.brooks@ialaska.gov. Original Message From: Larry Greenstein [mailto:lgreenstein@hilcorp.com] Sent: Tuesday,September 08, 2015 9:49 AM To: Regg,James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L(DOA); Wallace, Chris D (DOA) Subject: MIT Grayling 08-27-2015 1 Schematic ili McArthur River Field, TBU Well: G-04RD ""k"""a'""k° ''LC As Completed: 07-31-2015 RKB to Tubing Hgr=41.34' Casing&Tubing Detail SIZE WT WT GRADE CONN ID TOP BTM 16" 75 1-55 8 Round 15.124 Surf 621 13-3/8" 61 J-55 Butt 12.515 Surf 3,043' 9-5/8" 47 N-80 Butt 8.681 Surf 79' L / 9-5/8" 40 N-80 Butt 8.835 79' 4,355' 1' 9-5/8" 43.5 N-80 Butt 8.755 4,355' 5,970'(TOW) 7" 29 N-80 Butt 6.184 Surf 10,451' Tubing: 4-1/2" 12.60/13.55 L-80 BTC Ext3.598 Surf 9,203' Polycorei �ovcoiia, - � Jewelry Detail 4511' '- Depth Depth No (MD) (TVD) ID DD Description 42' 42' Hanger 1 7,240' 6,818' 3.995" 5.875" Hydroset Packer w/15.5'upper seal bore Window ,/2 9,176' 8,515' 3.995" 5.875" Hydroset Packer w/5'millout extension 5970%6032' 3 9,194' 8,531' 2.813" 4.500" X nipple L 1 4 9,203' 8,539' 2.992" 4.500" Wireline Re-entry Guide 5 10,153 9,347' 4.000" Baker Model FB-1 straddle packer,drill pipe 3-1/2" L-80 buttress tubing SC 6 10,312 9,486' 4.000" Baker Model FB-1 straddle packer,E-line R 2 3 it4 Open Perforation Detail i === Zone Top(MD) Btm(MD) Top(ND) Btm(TVD) Amt SPF Date Comments = G Perfs G-1 9,295' 9,320' 8,618' 8,639' 25' TCP 03/09/1998 Open 6-1 9,300' 9,320' 8,622' 8,639' 20' 5 07/27/2015 G-2 9,345' 9,365' 8,661' 8,678' 20' TCP 03/09/1998 Open - 6-2 9,350' 9,365' 8,665' 8,678' 15' 5 07/27/2015 1 G-3 9,436' 9,456' 8,738' 8,755' 20' TCP 03/09/1998 Open 6-3 9,438' 9,456' 8,740' 8,755' 18' 5 07/27/2015 HK-1,3,4,5 G-4 9,486' 9,537' 8,780' 8,823' 51' TCP 03/09/1998 Open _ 6-4 9,491' 9,496' 8,785' 8,789' 5' 5 07/27/2015 6-4 9,501' 9,509' 8,793' 8,800' 8' 5 07/27/2015 6-4 9,520' 9,535' 8,809' 8,821' 15' 5 07/27/2015 N Z 5 G-5 9,587 9,672' 8,865' 8,936' 85' TCP 03/09/1998 Open i -..=7. G-5 9,595' 9,610' 8,871' 8,884' 15' 5 07/27/2015 HK-5&HK-6 G-5 9,618' 9,639' 8,891' 8,908' 21' 5 07/27/2015 6-5 9,645' 9,670' 8,913' 8,934' 25' 5 07/27/2015 Block Sqz 9,758' 9,760' 9,009' 9,011' 2' 03/11/1982 Sqzd w/190sx g 6 HK-1 9,815' 9,840' 9,057' 9,079' 25' 5 07/27/2015 ei HK-1 9,815' 9,843' 9,057' 9,081' 28' TCP 03/09/1998 Open Fill @ 10,330'...; Block Sqz 9,852' 9,854' 9,089' 9,090' 2' 03/10/1982 Sqzd w/100sx ,1 4 HK-6&7 HK-2 9,862' 9;882' 9,097' 9,114' 20' 09/05/1983 Sqzd 04/20/85 %-,' - Sqzd w/100 sx Block Sqz 9,960' 9,962' 9,181' 9,183' 2' 03/09/1982 04/19/85 HK-3 9,965' 10,016' 9,185' 9,229' 51' TCP 03/09/1998 Open \ HK-3 9,968' 10,014' 9,188' 9,227' 46' 5 07/27/2015 HK-4 10,024' 10,146' 9,236' 9,341' 122' TCP 03/09/1998 Open PBTD=10,420' ID=10,450' HK-4 10,025' 10,058' 9,237' 9,265' 33' 5 07/27/2015 HK-4 10,067' 10,118' 9,273' 9,317' 51' 5 07/27/2015 Block Sqz 10,102' 10,104' 9,303' 9,305' 2' 04/19/1985 Sqzd w/100 sx Max angle=33°@ 9500' HK-4 10,127' 10,145' 9,325' 9,340' 18' 5 07/27/2015 Block Sqz 10,162' 10,164' 9,355' 9,357' 2' 3/15/1982 Sqzd w/200 sx HK-5 10,182' 10,188' 9,373' 9,378' 6' 04/04/1997 Straddle pkr 3/98 HK-5 10,182' 10,198' 9,373' 9,386' 16' 5 07/27/2015 HK-6 10,300' 10,305' 9,475' 9,479' 5' 05/28/1996 Straddle pkr 3/98 HK-6 10,325' 10,355' 9,497' 9,523' 30' 12 03/09/1998 Open HK-7 10,364' 10,392' 9,531' 9,555' 28' 12 03/09/1998 Open Revised:2015-08-27 by 1LL • • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Thursday, September 17, 2015 11:15 AM To: Wayne Johnson; Regg,James B (DOA) Cc: Dan Marlowe;Ted Kramer; Larry Greenstein;Juanita Lovett; Stan Golis Subject: RE: G-04rd PTD 181-183 Wayne, Testing plan including injection as below is approved. Regards, Chris Original message From: Wayne Johnson<wjohnson@hilcorp.com> ` CAMNn SUN 0 1 2016 Date: 09/17/2015 9:46 AM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg@alaska.gov>, "Wallace, Chris D (DOA)" <chris.wallace@alaska.gov> Cc: Dan Marlowe<dmarlowe@hilcorp.com>, Ted Kramer<tkramer@hilcorp.com>, Larry Greenstein <lgreenstein@hilcorp.com>, Juanita Lovett<jlovett@hilcorp.com>, Stan Golis<sgolis@hilcorp.com> Subject: G-04rd PTD 181-183 Gentleman we have a suspected Mechanical Integrity problem with G-04RD injector on the Grayling Platform. We have shut the well in and would like permission to do some testing on G-04RD to try and resolve this issue. The original temperature survey was conducted on July 31, 2015 and the State witnessed MIT was completed on August 27, 2015. At the present time we are unsure if the issue is at surface(tubing hanger void), packed annulus or if pressure is due to increased injection rate. This testing would require us to return well to injection for up to 2 weeks while monitoring. Please advise if we have permission to trouble shoot the well. Testing Plan: • Have a wellhead specialist visit the Grayling to check out the tubing hanger void • Check if IA pressure is gas • Conduct in-house MITIA • Bled down the outer casing and conduct another injecting Temperature Survey Thanks, Wayne Johnson 1 Production Foreman Grayling • • Work: 907-776-6630 Cell: 907-398-9942 2 •=. Orj 0 8 0 0 0 0 •-• .4C 4111111..W r STATE OF ALASKA , ALA.m‘A OIL AND GAS CONSERVATION COMMiaSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing El Operations shutdown Cl Performed: Suspend El Perforate ❑l Other Stimulate El Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Re-enter Susp Well❑ Other: Converted to Injector Ed 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 0 Exploratory❑ 181-183 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20050-01 7. Property Designation(Lease Number): 8.Well Name and Number: ADL018730 Trading Bay Unit G-04RD 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured • 10,450 feet Plugs measured N/Afeet E C I\E D true vertical , 9,606 feet Junk measured N/A feet AUG 2 8 2015 Effective Depth measured 10,330 feet Packer measured 4 Pkrs(See Schematic) feet 0��1. true vertical 9,501 feet true vertical 4 Pkrs(See Schematic) feet t Casing Length Size MD TVD Burst Collapse Structural Conductor 621' 16" 621' 621' 2,630 psi 1,020 psi Surface Intermediate 3,043' 13-3/8" 3,043' 3,005' 3,090 psi 1,540 psi Production 5,970' 9-5/8" 5,970' 5,718' 5,750 psi 3,090 psi Liner 10,451' 7" 10,451' 9,607' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet SCANNED SEP 1 7 2015, True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 9,203'(MD) 8,539'(TVD) Packers and SSSV(type,measured and true vertical depth) Packers(x4)-See Schematic SSSV: N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): r� ‘-17:-d /411- Treatment descriptions including volumes used and final pressure: iv- N/A .�V o -J 01.D '7('_'� -/ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1220 340 Subsequent to operation: 0 0 8,600 340 1539 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Development Service El Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data El GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ 3USP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 315-254 Contact Dan Marlowe Email dmarlowe(a�hilcorp.com Printed Name / Dan Marlowear /� /Title Operations Engineer Signature -)----::---M,"1-7`�-Z� W- / c - y &7 zehone (907)283-1329 Date 8/28/2015 I �'01 1 i ?01' Form 10-404 Revised 5/2015 ( / RBDM ' 1 0, „ Submit Original Only int Schematic McArthur River Field,TBU Well: G-04RD ""o`°Alaska, L` As Completed: 07-31-2015 RKB to Tubing Hgr=41.34' Casing&Tubing Detail SIZE WT WT GRADE CONN ID TOP BTM 16" 75 1-55 8 Round 15.124 Surf 621 13-3/8" 61 1-55Butt 12.515 Surf 3,043' L N 9-5/8" 47 N-80 . Butt 8.681 Surf 79' 9-5/8" 40 N-80 Butt _ 8.835 _ 79' 4,355' 9-5/8" 43.5 N-80 Butt 8.755 4,355' 5,970'(TOW) 7" 29 N-80 Butt 6.184 Surf 10,451' Tubing: BTC Ext 4-1/2" 12.60/13.55 L-80 3.598 Surf 9,203' L Po(ycore DV Collar - Jewelry Detail 4511' Depth Depth No (MD) (TVD) ID OD Description 42' 42' _ Hanger 1 7,240' 6,818' 3.995" 5.875" Hydroset Packer w/15.5'upper seal bore wndowY 2 9,176' 8,515' 3.995" 5.875" Hydroset Packer w/5'millout extension 5970'-6032' -7 .11) - a 3 9,194' 8,531' 2.813" 4.500" X nipple - 4 9,203' 8,539' 2.992" 4.500" Wireline Re-entry Guide 10,153 9,347' 4.000" Baker Model FB-1 straddle packer,drill pipe 3-1/2" ect-O`v 5 L-80 buttress tubing SC 6 10,312 9,486' 4.000" Baker Model FB-1 straddle packer,E-line - 2• _ / s _ ,a 374 �� 5 f4t- se�O0 z 0 1 621E 5 4 +( _ Open Perforation Detail Zone Top(MD) Btm(MD) Top(ND) Btm(ND) Amt SPF Date Comments G Perfs G-1 9,295' 9,320' 8,618' 8,639' 25' TCP 03/09/1998 Open G-1 9,300' 9,320' 8,622' 8,639' 20' 5 07/27/2015 G-2 9,345' 9,365' 8,661' 8,678' 20' TCP 03/09/1998 Open 6-2 9,350' 9,365' 8,665' 8,678' 15' 5 07/27/2015 G-3 9,436' 9,456' 8,738' 8,755' 20' TCP 03/09/1998 Open w = 6-3 9,438' 9,456' 8,740' 8,755' 18' 5 07/27/2015 HK-1,3,4,5 G-4 9,486' 9,537' 8,780' 8,823' 51' TCP 03/09/1998 Open i 6-4 9,491' 9,496' 8,785' 8,789' 5' 5 07/27/2015 6-4 9,501' 9,509' 8,793' 8,800' 8' 5 07/27/2015 ' 6-4 9,520' 9,535' 8,809' 8,821' 15' 5 07/27/2015 M 5 G-5 9,587' 9,672' 8,865' 8,936' 85' TCP 03/09/1998 Open I 9 9-5 9,595' 9,610' 8,871' 8,884' 15' 5 07/27/2015 _ 6-5 9,618' 9,639' 8,891' 8,908' 21' 5 07/27/2015 HK-5&HK-6 G-5 9,645' 9,670' 8,913' 8,934' 25' 5 07/27/2015 Block Sqz 9,758' 9,760' 9,009' 9,011' 2' 03/11/1982 Sqzd w/190sx 6 HK-1 9,815' 9,840' 9,057' 9,079' 25' 5 07/27/2015 HK-1 9,815' 9,843' 9,057' 9,081' 28' TCP 03/09/1998 Open Fill @ 10,330' - Block Sqz 9,852' 9,854' 9,089' 9,090' 2' 03/10/1982 Sqzd w/100sx Or J} HK-6&7 HK-2 9,862' 9,882' 9,097' 9,114' 20' 09/05/1983 Sqzd 04/20/85 Sqzd w/100 sx y l: Block Sqz 9,960' 9,962' 9,181' 9,183' 2' 03/09/1982 04/19/85 'i HK-3 9,965' 10,016' 9,185' 9,229' 51' TCP 03/09/1998 Open 2 \ HK-3 9,968' 10,014' 9,188' 9,227' 46' 5 07/27/2015 HK-4 10,024' 10,146' 9,236' 9,341' 122' TCP 03/09/1998 Open PBTD=10,420' TD=10,450' HK-4 10,025' 10,058' 9,237' 9,265' 33' 5 07/27/2015 HK-4 10,067' 10,118' 9,273' 9,317' 51' 5 07/27/2015 Block Sqz 10,102' 10,104' 9,303' 9,305' 2' 04/19/1985 Sqzd w/100 sx Max angle=33°@ 9500' HK-4 10,127' 10,145' 9,325' 9,340' 18' 5 07/27/2015 1 Block Sqz 10,162' 10,164' 9,355' 9,357' 2' 3/15/1982 Sqzd w/200 sx HK-5 10,182' 10,188' 9,373' 9,378' 6' 04/04/1997 Straddle pkr 3/98 HK-5 10,182' 10,198' 9,373' 9,386' 16' 5 07/27/2015 HK-6 10,300' 10,305' 9,475' 9,479' 5' 05/28/1996 Straddle pkr 3/98 HK-6 10,325' 10,355' 9,497' 9,523' 30' 12 03/09/1998 Open HK-7 10,364' 10,392' 9,531' 9,555' 28' 12 03/09/1998 Open Revised:2015-08-27 by 1LL Hilcorp Alaska, LLC IGIem")Alaska.1.1A Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-04RD 50-733-20050-01 181-183 6/30/2015 7/31/2015 Daily Operations: 06/30/15-Tuesday Modified handrail&installed on D/S landing.R/u Getronics.R/u lights under pipe rack.Ran circulating lines f/pump.R/u flare line. Ran remote control line f/accumulator.R/u air t/accumulator.Finished install service lines in cellar.Ran drain line f/rig floor pipe rack.Ran power t/test pump.R/u gas alarm sys,pvt sys.R/u walk&slide. Check rotation on equip.R/u derrick climber.Installed barrier on east walkway.Removed floor panels,H-beam, installed hand rails. Installed BPV, N/D tree,cleaned lift threads on hanger, thread pitted.Installed check valve on SSSV control line, pumped open&locked in. Cleaned lift threads on hanger,thread pitted. Installed check valve on SSSV control line,pumped open&locked in. N/U riser. 07/01/15-Wednesday Nipple up BOPE. Run flow line from gas-buster.Installed BOPE scaffolding,Tq bolts on stack. Modified flow nipple&installed.R/u accumulator lines.Changed upper rams t/2 7/8"x 5"var.Installed flow line.Serviced manifold valves.Ran pop off line t/pits/M/u 3%z test jt. 07/02/15-Thursday Filled stack&surface eq.Shell tested t/3000,_good.Called out for AOGCC inspector. Housekeeping.R/u stairs t/cellar.Clear& organize deck. Test BOPE as per Hilcorp&AOGCC regulations.Test witnessed by AOGCC,Lou Grimaldi. Tested w/3 1/2 TJ's. Test 250 low,3000 high,2500 high on annular,all good.Had a leak on TWC while testing blinds,pulled check,doped&Teflon.Re-ran, tested good. L/D test jt.Pull TWC.M/u landing jt.Clear floor. R/U e-line.RIH w/2.6"GR tag @ 5,945 WLM,POOH. M/U 2.5"jet cutter.Rih set @ 5,933'WLM,10'above collar.Attempt to fire cutter,no indication.POOH cutter not fired. Re-dress jet cutter.Rih set cutter @5,933'wlm,fire cutter,had indication cutter fired.POOH,cutter fired. Move e-line.R/d landing jt.M/u spear assembly- spear,xo,2 jts 3 1/2 PH-6.Rih,engage hanger, B/O L/D pins. Attempt t/pull hanger,no go.Worked pipe up t/100k no movement at hanger. Pull&I/d assy.P/u jarring assembly=spear,xo,oil jars,4 3/4 DC,accelerator jar,accelerator jar,pull&jar on hanger @ 25k over,pull t/45k over,no results. 07/03/15-Friday Cont.working t/free hanger,jarring @ 25k over&pulling 45k over while r/u steam t/tubing head. Parted mandrel in jars.P/u overshot while heating tubing head.Rih latch TOF. P/u on hanger w/45k over pull,slacked off,p/u-hanger came off seat @ 105. Cont pull dragging first 18' @ 80k.Pulled&l/d overshot,jar,spear BHA&hanger.Control line severed from hanger. POOH 1/d 159'3 1/2"Butt,L-80,9.2lb completion tubing.Started pulling heavy,worked,unable to pass,trying different parameters. Cont. troubleshoot.Discuss options. Mobe out e-line hands,wire grab tools&build inline wire grab pup. M/U tools.Rih placing sub @ 84', put 2 turns in pipe.Pooh w/no recovery.Rih t/99',put 3 turns in pipe.Pooh,recover SS control line bringing up scale on tools&line. RIH t/137'working through scale, up wt 68,dn wt 61. 07/04/15-Saturday Cont.TIH.P/u 3'/2 wk string f/4,158' t/tag @ 5,922',up wt 94k,dn 80k. CBU till clean @ 4bpm,530 psi. Attempt t/wk down.Rotate w/tongs making 8",no latch. R/u swivel.Test lower kelly valve 250 low,3000 high-good. Wash down t/5,925',unable t/latch. Pump 3.5 bpm 360 psi,1500 t/2500 tq,ROT wt. L/D swivel,POOH.L/D BHA,no indication of being on fish top. P/U BHA#3-Wavey BTM shoe,4 jts 5 3/4 w/p,top bushing,bumper jar,oil jar,6-4 3/4 DC,acc jar,xo=353.04'. C/O hyd valve bank in rig. Cont.TIH t/2,514',UP WT 56K,DN 53K. 07/05/15-Sunday Cont.TIH.P/u 3'/wk string f/4,158' t/tag @ 5,922',up wt 94k,dn 80k. CBU till clean @ 4bpm,530 psi. Attempt t/wk down.Rotate w/tongs making 8",no latch. R/u swivel.Test lower kelly valve 250 low,3000 high-good. Wash down t/5,925',unable t/latch. Pump 3.5 bpm 360 psi,1500 t/2500 tq,ROT wt. L/D swivel,POOH.L/D BHA,no indication of being on fish top. P/U BHA#3-Wavey BTM shoe,4 jts 5 3/4 w/p,top bushing,bumper jar,oil jar,6-4 3/4 DC,acc jar,xo=353.04'. C/O hyd valve bank in rig. Cont.TIH t/2,514',UP WT 56K,DN 53K. Hilcorp Alaska, LLC fla,urpAInska.l.l.l: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-04RD 50-733-20050-01 181-183 6/30/2015 7/31/2015 Daily operations: , �. 07/06/15-Monday Cont.TIH f/2,514't/5,902', up wt 94,dn 80k. P/U swivel.Install Halls head element. Wash&ream f/5,925' t/6,045',rot tq.3100, pump 3.5 BPM,320 psi. Pull halls head element.L/d swivel. POOH,L/D BHA. Clean&clear floor.C/o tongs. P/U BHA#4-Mill guide, lower ext,bowl,upper ext, top sub,bumper jar,oil jar,6-4 3/4 DC,Acc jar,xo=233.2'. TIH t/engage fish @ 5,930'up wt 96,dn 78k. P/u pup&change elevators. Wk pipe jarring @ 65k,pulling t/90k over.Moved 15'up hole. 07/07/15-Tuesday Cont.wk pipe,150k-200k, dragging up hole,racking back stands as free,t/5657'.Drag leveled out pulling 141k,pulling wet.Cont. POOH t/3272',started getting flow&gas breaking from tubing.R/u let bleed back t/pits,monitor annulus,static.Cont.POOH t/ 1350'.Started getting flow&gas breaking from tubing.R/u let bleed back t/pits,monitor annulus,static.Cont.POOH t/BHA+1 stand,monitor tubing till static.L/D BHA. Bleed off trapped pressure @ first connection of fish.L/d overshot&cut jt.L/d 3 jts 3 1/2" tubing, bleeding trapped pressure.Work on rig Hydraulics.C/o tongs.Cont.I/d fish bleeding trapped pressure as needed.Wire in tubing starting on jt 8. 07/08/15-Wednesday Cont.POOH.L/d 3 1/2 completion,bleeding trapped pressure off as needed,stripping over w/I clamping wire t/avoid losing w/I fish. Recovered 59 jts tubing,4 glm's, seal assembly,xn&mule shoe. Recovered w/I fish=48.5'. Cleared&cleaned floor,top pipe deck. P/U BHA#5=6"junk mill,bumper jar,string mill,oil jar,6-4 3/4"DC,acc jar,xo=232.32'.Tih t/8,311',tag, up wt 108k,dn wt 97. P/U swivel. 07/09/15-Thursday P/U swivel.Pump 20 bbls down tubing.Ensure string is clear.Install halls head element. Wash and ream f/8,311'to 8,683'pumping in reverse at 3 bpm at 350 psi w/ 0/2 WOB,4700 ft lb of torque w/55 rpm.Circ 62 bbls FIW at 4 bpm w/450 psi before making connection. Circ hole clean. Rig down power swivel. POOH w/7 stds.Remove pack off. R/up power swivel and set RTTS w/storm valve at 125'RKB, Pooh. Pull wear bushing. Rig up test plug and lines. Test bop's to 250 low and 3000 psi high.Held each test 5 minute on chart.Tested from the main station.Witness waived By Mr.Jim Regg on 7-08-15 at 10:30 AM.Held Kommey draw down test. Rig down test joint and install wear bushing. 07/10/15-Friday HSM&JSA. M/U storm retrieve tool and trip in hole.Unable to make up into the storm valve.Circ on top of storm valve at 2 bpm, wash trash and screw into same.Check for pressure pipe on vacuum.Pull RTTS loose and fill hole w/10 bbls FIW. POOH lay down storm valve. Trip in hole to 8,652'. P/u power swivel and install stripper rubber. Break circ and wash down to f/8,652'to 8,683'. Circ btm up at 4 bpm w/475 psi. Continue to wash and ream f/8,683'to 9,024'with 0/2 WOB,55 RPM,4800k ft lbs.torque,pumping in reverse at 3 bpm 350 psi.Circ 62 bbls after each jt down pumping at 4 bpm w/475 psi, rotating up wt 120k rotating down w 116, non-rotating up wt 142k non rotating down wt.90k. Change out stripper rubber. Continue to wash and ream f/9,024'to 9,150'with 0/2 WOB,55 RPM,4800k ft lbs.torque,pumping in reverse at 3 bpm 350 psi.Circ 62 bbls after each jt down pumping at 4 bpm w/ 475 psi, rotating up wt 120k rotating down w 116,non-rotating up wt 142k non rotating down wt.90k tagging packer at 9,150'. Circ hole clean at 9,150'.Pump out fluid tanks to Trading Bay. Clean fluid tanks and fill with FIW. Displace well with clean FIW pump 350 bbls fluid to Trading Bay. R/d swivel and rig up tongs and lay down 3 jts work string. Pooh w/work string to change out BHA. Hilcorp Alaska, LLC HiIrorpAlaska, \NeII Operations Summary Well Name API Number Well Permit Number Start Date End Date G-04RD 50-733-20050-01 181-183 6/30/2015 7/31/2015 Daily Operations: 07/11/15-Saturday Pooh w/work string&BHA#5-Bladed Junk mill,bumper Jar,String,Oil jar,6 4-3/4 drill collars Acc jar,x/o=232.32.Lay out jars and bladed and string mill,&jars.Make up BHA#6 -packer retriever& packer mill sub,canfield bushing,boot basket,boot basket,bit sub,string magnet,bumper jar,oil jar, (6)4-3/4 drill collars,x/over=249.85'. Trip in hole w/mill to 9,134'.P/u wt 150k,S/0 wt 98k. Brk circ,pumping at 3 bpm at 375 psi.Wash down tagging at 9,149'dpm. Milling f/9,149'w/5400 to 6000 ft lbs torque, at 65 rpm dn wt with rotation 112k.Made 11 inches. Circ out gas 500 units. Continue milling on production packer,9,148'. Made 14 more inches broke free and moved down hole 6 feet. Circ gas max gas 650 units. Pulled and laid down 50 ft of pipe.Worked fish f/110 dn to 167 up wt 16k over. 07/12/15-Sunday Finish Pooh slow-did not recover the fish.Shear ring on pioneer tool not sheared,grapple teeth rolled down. Break all of the cross over on the BHA.Clean the boot basket.Retrieve 40 lbs metal. Held discussion w/ops team.Mobe out slick line&tools.Off load boat. Rig up slick line,testing lubricator to 2500 psi(ok).Made 2 run w/4.3 magnet w/ tagging at 9,151' slm. Recovered 4 pieces of metal. Made 1 run w/ 3.4 magnet recovered shavings.Rig down slick line. Pick up BHA Spear,spear ext 2 3/8 grapple,spear ext 2- 3/8 reg, double pin sub 2-3/8 reg,stop sub 3-1/2 if box x 2-7/8 reg pin,bumper jar,6-4-3/4 drill collars,acc jar,x/over,=237.45'. 07/13/15-Monday Trip in hole slow with spear assembly to 9,091'. Had some problems with down drag due to stop hanging up on csg collars. Rig up power swivel and work on drillers control panel. Washing down f/9,091',locate top of fish at 9,152',engage spear and verify latch w/ 10k over up wt. Circ btm up max gas 498 units. Rig down power swivel. POOH with fish. Pooh w/spear assembly lay down fish(full recovery)14.75 seal bore extension and WLEG. Trip on hole w/bladed junk mill,bumper jar,string mill,oil jar,6 4-3/4 drill collars, acc jar,x/over,=232.32'. Rig up power swivel. 07/14/15-Tuesday Wash&ream f/9,148' to 9,170' pumping in reverse at 3 bpm 350 psi,55 rpm w/6300 ft lb of torque w/1/2 wob.Pump pressure increasing to 750 psi,pumping down tbg attempting to unplug same. Trouble shoot surface lines&unplug lines at shaker. Washing and reaming f/9,170'to 9,179'getting large amounts of scale back at shaker. Circ hole clean at 4 bpm 450 psi.Lay down power swivel and stripper head. Pooh w/work string. Pooh lay down mills. Made up 6"bit and started RIH.After making up the second stand of drillers,pulled slips and found slip die missing 8-1/4 x 1-1/4"x 3/8". Pooh w/drill collars. Mobe out slick line and crew and unit. Offload slickline unit and spot same. Rih w/3.4"magnet to 9,460'work same 3 times and pooh,no magnet. RIH w/4.5 magnet tagging at 9,450'pooh slow. 07/15/15-Wednesday Tagged at 9450 ft slm,worked magnet 3 times.Pooh w/same,recovered small slivers of metal&fine shaving. RIH to well head and work magnet around the hanger. Recovered small amount of fine shavings. Rig down slick line tools and lubricator. Make up BHA- 6"mill tooth bit,oil/bumper jar,(6)4-3/4 drill collars,acc jars x/over. Trip in hole to 9142'dpm. Installed stripping rubber.P/u power swivel.Broke circ in reverse,made connection,made adjustments to power swivel console and installed pvt and flow shoe monitor on drillers station. Establish perimeters P/u=152k,s/o=98k,ROTW=120K,p/U 122K,S/0=118K. Wash and ream tagging at 9179'dpm.Reverse circ at 3 bpm w/280 psi.Circ out gas as needed,max gas 4500 units,circ out tbg volume before each connection. Getting sand and white scale back at shaker.Depth at rpt time 9540 ft. Hilcorp Alaska, LLC HileorpAlaska.h.l.0 Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-04RD 50-733-20050-01 181-183 6/30/2015 7/31/2015 bay Operations: 07/16/15-Thursday Cont to wash&ream down f/9,538 ft to 9,565 ft DPM,reversing out at 3 BPM psi,ROT AT 55-70 RPM W/2500-4000 FT/LBS OF TROQUE,RUNNING 0/2 WOB.PUMP AT LEAST ON BTMS UP PRIOR TO MAKING CONNECTION OR AS NEEDED DUE TO PRESSURE. STARTED PRESSURING UP TO 600 PSI AT 9,565'DPM.L/U&BLEW LONG WAY W/1525 PSI.ATTEMPT TO REVERSE OUT,BUT PRESSURE STILL HIGHER THAN WAS.SHUT DOWN&CLEANED OUT RETURN LINE AT SHAKERS. CONTINUE TO WASH&REAM F/ 9,565 FT TO 9,588 FT DPM,REVERSING OUT 3 BPM 360 PSI AT 9,588 FT. DPM SET 5K DOWN. MADE SEVERAL ATTEPMTS TO DRILL PAST 9,588 FT DPM W/NO SUCCESS.REVERSE OUT 156 BBLS AT 4 BPM W/500 PSI UNTIL RETURNS CLEAN W/NO GAS(TOTAL FLUID LOST THIS TOUR=75 BBLS). L/D KELLY JT.R/D POWER SWIVEL&L/D SAME.PULLED STRIPPER RUBBER. POOH W/ WORK STRING TO 7,200 FT. HELD H2S&METHANE&ABANDON DRILL.EVERYONE MUSTERED AT PRIMARY STATION THEN TO BRUCKER. CONTINUE TO POOH W/WORK STRING&BHA.LAY OUT BIT T-8,B-I,INGAUGE )6"BIT,B/SUB,OIL JAR.BUMPER JAR(6)4-3/4 DRILL COLLARS,ACC JAR,X/OVER=232.32'. RIG UP PULL WEAR BUSHING. R/UP TEST JT&M/UP TEST PLUG.START TEST,HAD LEAK,TROUBLE SHOOT SAME FOUND TEST PLUG LEAKING.PULL SAME,CHANGE RUBBERS,LAND TEST PLUG.SHELL TEST BOPS.CONTINUE TESTING BOPS TO 250 &3000 PSI HIGH-REQUESTED AND RECIEVED PERMISSION FROM MR.JIM REGG W/AOGCC TO TEST BOPS'5 TO 6 HRS EARLY. MR.REGG ALSO WAIVED WITNESS BY E-MAIL ON 7/16/15 AT 3:27 PM. INSTALL WEAR BUSHING&LAY DOWN TEST JT. MAKING UP BHA-5-3/4 BLADED MILL,OIL JAR,BUMPER JAR, (6)4-3/4 D.C.'S,ACC JARS,X.O=226.66. 107/17/15-Friday Continue to P/U&rig up power swivel.Test ran swivel and check torque for proper torque(OK). Continue to tih w/3.5 PH6 and mill assembly to 9,578 ft DPM(p/u=148k s/o=98k). Install stripping rubber in head.P/U power swivel&r/up same.Make connection& broke circ in reverse&est perimeters.REV/OUT@ 3 bpm 200 psi,ROTW=120K,P/U=122K,5/0=118K TORQUE=6K @ 55-65 RPM. Wash &Ream f/9,588 FT- T/9,640 FT dpm w/0-2k WOB.Circ btm up every 15 ft or as needed due to pressure. Pressured up to 785 psi &pumped pack off up hole.Pump 95 bbls to clear tbg. Attempt to flush thru manifolds w/no success.Pressured up to 2000 psi at 1/2 bpm.Broke connections on reverse out line&found fitting on opossum belly that was packed solid w/control line&cuttings. Cleaned out&flush thru same.Troubleshoot power swivel unit.R/D&move unit closer to the rig floor to shorten control hoses. Change out stripper rubber&reinstall. Continue to wash&ream f/ 9,640 ft.f/9,795 ft. Pump at 3 bpm at 250/300 psi,55/65 rpm/ with 5500 torque. Circ btm up every 15 ft due to return line plugging,lines plugged off, circ down tbg.stripping rubber leaking,circ hole clean changing out stripper rubber. Hilcorp Alaska, LLC ilileorp Alaska. Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-04RD 50-733-20050-01 181-183 6/30/2015 7/31/2015 Daily Operations: 07/18/15-Saturday CONTINUE TO C/O STRIPPING RUBBER.SET PACK-OFF IN PLACE&RUN LOCK DOWN PINS. MAKE CONNECTION,BROKE CIRC.IN REVERSE @ 3 BPM 170 PSI&EST,PERMIETERS,ROTW=124K P/U=126K,S./0=122K,TORQUE=5K AT 65 RPM. ROT/WASH DOWN F/ 9,795'-T/9,852'DPM RUNNING 0-1K WOB.REV/OUT BTMS UP EVERY 15'OR AS NEEDED UNTIL CLEAN. AT 9,852'DPM STARTED TO TAKE WEIGHT&TORQUE UP.MILLED DOWN TO 9,857'DPM W/2-3K WOB,WORKING PIPE AS NEEDED DUE TO STALLING.CONT REV/OUT AT 3-1/2 BPM 250 PSI. PIPE TORQUED&STALLED OUT. WHILE P/U TO WORK PIPE FREE THE POWER SWIVEL UNIT SHUT DOWN AND THE ESD WAS TRIPPED. ATTEMPT TO RESET MURPHY SHUT DOWN SWITCH W/NO SUCCESS. CONSULT WITH MECHANICS. CONT'TO REV/OUT @ 3-1/2 BPM 240 PSI. FLUID LOST THIS HOUR=125 BBLS,ADDED 25 GALLONS OF CFS-520 TO SYSTEM. POOH TO 9,812'DPM.R/D POWER SWIVEL HYDRAULIC HOSES AND CTRL LINES. FUNCTION SWIVEL CONTROLS. RU SWIVEL HYD. UNIT AND HOSES.SWAP CONNECTIONS ON LINES. FUNCTION SWIVEL CONTROLS. PUMPED 20 BBLS TO FILL HOLE AND EST. PERIMETERS REV/OUT @ 3BPM W/345PSI P/U=154K S/O=124K ROTW=120K.TAGGED UP @ 9,857'DPM W/2K ON MILL WASHING DOWN EVERY 15'AND CIRC.BOTTOMS UP.RECOVERED LARGE PIECES OF ROCK AND SCALE OVER SHAKERS.PRESSURED UP TO 685 PSI AND BLEW STRIPPER RUBBER @ 9,919'DPM. BEGIN SURGING AND PUMPING LINES TO UNPLUG.LINE UP MANIFOLD AND CIRC. DOWN TUBING @ 4 BPM W/450 PSI TAKING RETURNS THRU FLOWLINE.CLOSE HYDRIL AND CIRC.REV/OUT 2 TUBING VOL.UNTIL CLEAR. B/0 HOLD DOWN PINS AND C/O STRIPPER RUBBER.R/U NEW RUBBER AND S/O.R/I HOLD PINS AND RUNNING TOOL WAS STUCK.B/0 PINS ON BUSHING AND PULL TO CHECK RUNNING TOOL.RESET RUNNING TOOL AND S/O.R/I PINS AND CIRC.TO CHECK RUBBER. S/O SWIVEL AND BEGIN MILLING @ 9,919'REV/OUT @ 3BPM W/280 PSI EOTD=9,919'P/U=154K S/O=12K. 07/19/15-Sunday Continue milling f/9,919 ft t/ 9,940 ft reversing at 3.5 bpm 350 psi,rotating @ 65 rpm w/5500 ft/lbs torque,running 0-1k wob, rotw=128k.p/u=130k,s/o=123k.Reverse out 55 bbl every 10 foot reamed due to pipe trying to plug. Pipe plugged&pressured up to 550 psi blowing stripping rubber.P/u off btm&change out same.Attempt to flush thru same.Re-route return line&removed 90° unions.R/u pulsation damper on mud pump. Continue milling f/9,940 ft to 10,043 ft dpm,rev/out at 3 bpm 300 psi,torque=6k,W.0- 2k wob.Rev/out 60 bbls every 10'or as needed due to plugging of return lines.Flush thru manifolds as needed. Line up&pumped cuttings out of tbg At 4 bpm 425 psi.Pumped 90 bbls total. Rev/out 3.5 bpm 250 psi until returns clean. Make connection,started pumping,surface lines plugged off,clean out surface lines. Continue milling at 10,043'w/5k torque&0/2k wob.Reverse out at 3 bpm 340 psi.P/u 154k,s/o 124k rotw 128k,circ at 4 bpm each 10 ft,washed down until btm up at(2100 stks)or until clean. Trouble shoot plug off&flush thru all lines. Continue washing&reaming f/10,058 ft to 10,154 ft dpm. Reverse circ out at 3 bpm on btm up increasing pump rate to 4.55 bpm 410 circ hole clean at 10,154 ft. Rigging down power swivel. 07/20/15-Monday Continue to pull stripping rubber.C/out elevators&prep to POOH. POOH laying down 10 jts ph-6 work string. Work BHA.Lay out 5- 3/4 junk mill(had very little wear)in gauge. Clear floor of misc equipment.Clean rig floor. P/u 1-1/2 wavy btm shoe,9 jts 1-1/2 CS pipe,x/over,oil jar/bumper jar,(6)4-3/4 drill collars,acc jars, x/o=513.44'. TIH w/3-1/2 PH-6&1-1/2 shoe assembly slow. Pick up power swivel an d install pack off. Make up power swivel at 10,154 ft dpm.Circ btm up. Wash down w/1-1/2 CS pipe.Unable to wash past 10,159',pick back up to 10,154'&wash and ream f/10,154'to 10,330'dpm at 28 rpm w/2500 t/3000k torque,pumping at 3 bpm at 250 psi.Circ btm up every jt.wash down. Hilcorp Alaska, LLC 111k OrpAla ka,LIA: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-04RD 50-733-20050-01 181-183 6/30/2015 7/31/2015 Daily Operations: 07/21/15-Tuesday ATTEMPT TO UN-PLUG PIPE WI NO SUCCESS.PREP TO L/D(6)JNTS OF PH6 TO GET ABOVE PKR.POOH&L/D(1)JNT OF 3-1/2"PH6. ATTEMPT TO POOH W/SECOND JNT WHEN HOSE FOR WEIGHT INDICATOR FAILED CAUSING WEIGHT INDICATOR TO MALFUNCTION. REPLACED HOSE&PUMPED UP PANCAKE ON DEADMAN ANCHOR. CONT'TO POOH TO 10,113'DPM W/3-1/2"PH6.(155 STNDS IN HOLE).L/U ON TBG&ATTEMPT TO UN-PLUG PIPE.PRESSURED UP T/1100 PSI WITH NO RETURNS. R/D POWER SWIVEL&L/D SAME. B/O PACK-OFF L/D PINS&PULLED SAME.R/U MUD BUCKET&DRAIN HOSES.PREP TO POOH WET. POOH W/3-1/2"PH6&1-1/2"CS PIPE USING MUD BUCKET DUE TO PIPE PULLING WET. L/D(6)JNTS OF 4-3/4"DC'S,OIL/BUMPER JARS,(9)JNTS OF 1-1/2"CS PIPE&1- 1/2"WAVEY BTM SHOE.CLEAN OUT SAND F/DC'S DOWN T/FIRST JOINT OF 1-1/2"PIPE.PIPE PLUGGED DUE T/GAS LIFT VALVE, BANDING MATERIAL&SLIP DIES STUCK IN PIPE. P/U&M/U RTTS TEST PACKER.C/O BACK UP DIES ON FOSTER TONGS(SLIPPING). OFFLOAD K.O.T.TOOLS&EQUIPMENT FROM RIG FLOOR.CLEAN RIG FLOOR&EQUIPMENT.HOOK UP HYD POWER PACK&FUNCTION SAME W/CLEANING.ROTATION WRONG ON UNIT. TIH w/3.5 PH6 WS OUT OF DERRICK @1 MIN PER/STD.AS HALLIBURTON& HILCORP REP.REQ.PU SUPERVAC TANK&WASHOUT TO CUTTING BOX.TIH w/148 STANDS. EST.PERIMETERS,PU=138K S/0=96K. SET PACKER @ 9,172'DPM.w/26K WOP.FILL HOLE(20 BBLS)&RU CHART RECORDER.RU GAUGE TO 9-5/8 CSG TO MONITOR. BEGIN TESTING 7"CSG.TO 2500 PSI,LEAKING OFF&INJECTING @ 1.5 BPM 1450 PSI.S/D PUMP& PRESSURE BLEED OFF F/1450 PSI-T/800 PSI IN 3 MINS.BLEED OFF PSI&CLOSE MANUAL VALVE ON STACK KILL SIDE&TEST.PRESSURE UP TO 1400 PSI(TEST GOOD).BLEED OFF&OPEN VALVE,ATTEMPT TO PRESSURE UP 7"CSG,PRESSURE DIDN'T EXCEED 1000 PSI @ 1.25 BPM.S/D PUMP.LEAK-OFF F/1000 PSI-T/500 PSI IN 2 MIN.INJECTED 5 BB. RELEASE PACKER&POOH w/1 JOINT,SET PACKER @ 9,141'DPM.w/25K WOP.FILL HOLE(16 BBLS)ATTEMPT TEST&PRESSURE UP TO 1100 PSI @ 1.5 BPM.LEAK-OFF F/1100 PSI-T/0 PSI IN 6 MIN. M/U JOINT&POOH +/-500'(8 STDS.) EST.PERIMETERS.PU=132K 5/0=92K.SET PACKER @ 8,674'DPM.w/24K WOP.FILL HOLE(20BBLS)ATTEMPT TO TEST 7"CSG.TEST w/NO SUCCESS.PRESSURED DIDN'T EXCEED 1100 PSI.LEAK OFF F/1100 PSI-T/0 PSI IN 5 MINS. POOH+/-1000' R/B. 07/22/15-Wednesday • `11 Working RTTS tool up hole setting_at 8,178';8,063';7,900';7,800';7,682';7,558'dpm,attempting to get a 2500 psi test on the 7"29#, " L-80 production csg.Ha nos cress. Set RTTS at 7,000'dpm,put 20k down on same,pressured up to 2500 psi&held 30t minutes on chart for 30 minutes, ood t t.Bleed pressure off. Pooh lay down RTTS tool. RIH w/35 stds(40k)p/u storm valve,set same @ 122k RKB W/24K DN. back side to 1500 psi(OK).Pooh w/running tool. Nipple down BOP's, &remove tbg spool. 07/23/15-Thursday CONT'TO KNOCK OUT HANGER LOCK DOWN PINS&PULL TBG HEAD TO FLOOR.UN-ABLE TO REMOVE STUDS F/7"WELL HEAD,CUT L`' Ivy &KNOCK OUT SAME. N/U 4-1/2"TBG HEAD,&CSG VALVES.ASST.CAMERON REP VOID TEST SAME 250 LOW FOR 5 MIN AND 2500 HIGH FOR 15 MINS"OK". N/U 13-5/8"BOP'S,RISER,SPACER SPOOLS,FLOW CROSS,WING VALVES,STRIPPING HEAD&BELL NIPPLE. TIGHTEN DRESSER SLEEVE ON BELL NIPPLE.INSTALL FLOW LINE&HOSES TO BELL NIPPLE.SET RIG FLOOR POLLUTION PANS,FALSE ROTARY,FLOOR PLATES&MATS IN PLACE. ATTACH ALL DRAIN LINES TO POLLUTION PANS.CHARGE ACCUMULATOR SYTEM& FUNCTION BOPS. M/U 3-1/2"BOP TEST ASSY&P/U SAME.RIH&SET TEST PLUG IN TBG HEAD.L/U&FILL HOLE W/8.5#F.I.W. FLUSHED THRU&FILL MANIFOLDS W/8.5#F.I.W.R/U BOP TEST EQUIPMENT&PREP TO TEST BOPS.ASSIST R&R REP BUILD SCAFFOLDING AROUND BOP'S. Attempt shell test.Hanger pins leaking,tighten same.Test BOP w/3.5&4.5 pipe to 250 low and 3000 psi high,held each test 5 minutes,on chart.Witness of test waived by Jim Regg,AOGCC. Rig down test equipment. SLIP AND CUT DRILL LNE 185 FT. CHANGING OUT (2)HYD VALVE ON DRAWORKS MOTOR AS PER SAFETY AUDIT. Hilcorp Alaska, LLC I liIcorp:Alaska•LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-04RD 50-733-20050-01 181-183 6/30/2015 7/31/2015 baily{Operations: 07/24/15-Friday PULL WRAPS OFF DEADMAN.SLIPPED 1,100'OF DRILL LINE ONTO DRUM&CUT SAME.INSTALL DOG KNOT&WRAPS ON DEADMAN. TIGHTEN ALL BOLTS&CHECK GAP IN ANCHOR BLOCK. PUMPED UP&SET WEIGHT INDICATOR.SET&CHECKED C.O.M.WITH DRILL LINE"OK". P/U TOOLS&CLEAR-OFF RIG FLOOR.P/U(2)JNTS OF 3-1/2"PH6&WEAR BUSHING.RIH&SET WEAR BUSHING IN PLACE. L/D R/R TOOL. P/U RTTS R/R TOOL&RIH W/SAME.STUNG INTO PKR&UN-SET SAME.L/U&PUMPED 21 BBLS TO FILL HOLE.R/U CIRC EQUIPMENT&PUMPED 76 BBLS LONG WAY @ 2 BPM 50 PSI. POOH W/(2)STNDS OF 3-1/2"PH6.L/D RTTS PKR ASSY.CONT'TO POOH W/3-1/2"PH6 TAIL PIPE. B/D RTTS PKR ASSY AS PER HALIBURTON REP. ASST.K.O.T.REP GATHER&STRAP BHA. P/U 6"BIT, 7"CSG SCRAPER,OIL AND BUMPER JARS,(2)4-3/4"DC'S AS PER K.O.T.(ASSY.=9,1.83'). TIH W/3-1/2"PH6&SCRAPER ASSY.CONT. TIH w/WS&BHA#12.POOH/TIH F/7,024'-T/9,250'TO WORK SCRAPPER THRU DEPTHS OF CSG.TEST FAILED.TIH TO BOTTOM w/BIT @ 9,257'DPM.P/U=158K F/7,024'-T/9,250'. R/U TIW VALVE&HOSE.WAIT ON PROD.TO CONFIRM CIRC.TO TRADING BAY FACILITY. CIRC.DOWN TUB.&REC.RETURNS @ 25 BBLS PUMPED. CIRC.FIW @ 4 BPM w/650 PSI SENDING RETURNS TO TRADING BAY UNIT.CLEAN RIG FLOOR&RU SUPERVAC TO CLEAN ACTIVE PIT.CIRC.14000 STKS.(500 BBLS)UNTIL CLEAN.RD TIW VALVE& HOSE.SHUT IN 7"CSG.&TRADING BAY PUMP LINE.R/D SUPERVAC HOSES&FILL MUD TANK w/75 BBLS OF FIW. POOH w/WS&BHA SLOW R/B AS PER.HILCORP REP.&K.O.T.UNTIL ABOVE BAD CSG.AREA. 07/25/15-Saturday L/D(2)4-3/4"DC's.Remove all P.H.E for BHA f/floor.L/U and pump 31 BBLS to F/U hole. R/D Foster tongs&remove f/floor.R/D HAK power swivel unit and B/L on boat to be sent to Steelhead for storage. R/U Expro E-line equipment.M/U Expro shooting nipple lubricator&P/U same. Locate blinds with shooting nipple and shut annular.R/U circ.equipment&test lubricator to 500 PSI"OK". P/up 1'-69"G.R,(2)roller centralizers and magnifying tool(total assy=15.06').RIH w/E-line to 9,232'WLM and attempt to log up w/ no success.No coms w/tool.POOH and trouble shoot same. M/U logging tool&TIH with same.At 5,800'WLM high strand broke on wireline. POOH w/wireline.L/dn tools.Asst.Expro spool off and cut 6,000'off e-line.Re-head rope socket and test tools"OK". P/up e-line logging tool string and RIH w/same. Cont.RIH w/logging tool string.RIH t/9,225'&log.N/U valve on cir.manifold&test.w/ rig pump.Pressure bleed off 200 PSI in 2:30.R/up test pump to top of manifold and test valves.Leaked off.POOH w/E-line& recovered slip dies from milled packer possibly in centralizers. R/dn E-line tools&shoot nipple.Fill hole.Took 32 BBLS to fill. Held safety meeting w/Tri-point reps.&Hilcorp reps on P/U TCP assy and pipe tally. Wait on crane to move e-line unit&equipment to 404 rig. Begin P/up and M/up TCP assy.M/U(9)2"perf guns(total=128'),XO to 4.5"guns.M/up(42)4-1/2"perf guns(total=845'). M/up firing head w/2.875"8rd EUE pup jt.P/U 1 joint of C/O elevators&R/up 3.5 drift onto bells(total TCP assy=1117.15'). Begin TIH w/3-1/2"WS out of derrick,drifting stands. 07/26/15-Sunday Continue making up TCP BHA assembly. BHA=Bottom of assembly at 10,312.80' with bottom shot at 10,310'&top 2"gun top shot at 10,182'with the 4.5 gun assembly btm shot at 10,154'&the top shot at 9,300'. Total length of assembly 1117.14'. Continue RIH W/TCP assembly on 3.5 PH-6 work string,drifting each stand. Tagged with 32k down at 10,278'dpm(36ft high)took 8k to pull loose. Spot Expro E-line unit and rig up same.Test lubricator to 1500 psi(ok). P/up gamma Ray CCL,7'weight bar&RIH w/same to check depth of guns.Parked RA sub at 9,151'ELM (45 ft high).Pooh&lay down E-line tools/equipment. Pooh w/TCP assembly. Held HSM w/Tripoint and crew on lay in down gun assembly.Rig up and lay out TCP gun assembly. P/U(3)2"perf guns.P/U(42)4- 1/2"perf guns.P/U(1)jts 2.875"8rd EUE&pup jt w/firing head. Hilcorp Alaska, LLC HiliorpAlaska. Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-04RD 50-733-20050-01 181-183 6/30/2015 7/31/2015 Daily Operations: 07/27/15-Monday _ P/U RA MARKER SUB&M/U SAME.TIH W/3-1/2"PH6&TCP ASSY.TO 10,207'DPM.DRIFT EACH STAND RAN OUT OF DERRICK. R/U EXPRO E-LINE EQUIPMENT.P/U GAMMA RAY CCL,&7'WEIGHT BAR.M/U LUBRICATOR& TEST SAME TO 1500 PSI"OK". RIH W/E- LINE TO CORRELATE GUNS ON DEPTH.MARKED RA SUB @ 9,194.58'WLM(+/-1'HIGH).POOH W/E-LINE&R/D SAME. WORKED PIPE DOWN THEN BACK UP TO CORRECT DEPTH.RA SUB @ 9,195.58'DPM.L/U&PUMP 18 BBLS TO FILL HOLE.SHUT ANNULAR& DROPPED BAR TO FIRE GUNS.FIRED GUNS.TOP SHOT @ 9,300'DPM,BTM SHOT @ 10,198'DPM.L/U&PUMPED DOWN BACKSIDE @ 3 BPM.TOOK 28 BBLS TO FILL.REV/OUT 220 BBLS @ 3 BPM 125 PSI UNTIL CLEAN. POOH W/3-1/2"PH6&TCP ASSY TO 9,299'DPM (TOP OF PERFS). FILL HOLE(37 BBLS)&CLOSE ANN.REV/OUT @ 3.5 BPM w/175 PSI ABOVE TOP PERFS @ 9,299'DPM. CIRC.150 BBLS (4200 STKS.)&MONITOR WELL.R/D TIW VALVE&HOSE. POOH w/3-1/2"PH6 WS R/B&TCP ASSY. B/O&L/D 2.875 8RD EUE&PUP JOINT w/FIRING HEAD.HSM w/TRIPOINT. BEGIN L/D(42)4.5"PERF GUNS&(3)2"PERF GUNS(ALL SHOTS FIRED).FILL HOLE. R/D FOSTER TONGS&R/U HILCORP FOSTER TONGS.SWITCH HOSES TO HYD.POWER PACK.C/O SLIP INSERTS TO 4-1/2"INSERTS.C/O DIE'S TO HILCORP TONGS&R/U AIR HOSES TO BACKUPs.OFFLOAD BOAT&SPOT PIPE RACKS. 07/28/15-Tuesday continue to off-load 4-1/2"BTC poly core tubing and un-bundle same.strap/tally 40 jts.of tubing.;P/U 3-1/2"WLEG,8'pup,x-nipple, XO sub,5"mill out ext.,7"hyd set packer,8'pup,&(2)XO subs,M/U as per Tripoint Alaska rep.(BTM packer assy.=48.45'DPM);P/U and TIH with 4-1/2"BTC tbg.out of v-door. drifted each jt. (40 jts);off load 4-1/2"BTC tbg.and un-bundle same. strap and tally 20jts;P/U and TIH with 4-1/2"BTC tbg.out of v-door. drifted each jt. (20 jts).total of(60)jts.4-1/2"tbg=(1873.89'DPM);P/U(2)XO subs,7"hyd set packer,8'pup,15'x 5"seal bore receptical w/5"running nut,XO sub,bumper jar,&XO sub.M/U as per Tripoint y{ Alaska rep.(TOP PKR ASSY=58.99 DPM);C/O P.H.E&tong heads to 3-1/2"clear 4-1/2"P.H.E F/floor &prep to TIH.;TIH w/3-1/2" /1 PH6&dual pkr assy slow as per Tripoint rep.Drifting stands out of derrick.;TIH w/3-1/2"PH6 and dual pkr assy slow as per Tripoint rep.drifting stands out of the derrik.B/D stand#117&L/D single.TIH w/total of 116 stands&single.M/up pup jt.and S/O to mark ►( and pull out strech.;R/U E-line sheaves&equipment.test lubricator to 1500PSI(OK);RIH w/1-11/16"gamma ray&CCL.correlate packers on depth.Marked top of pkr @ 7250'WLM&bottom pkr @ 9154'WLM.consult w/Hilcorp rep on depths.POOH w/E-line& 4 Hilcorp rep decided to lower 2'on packers safely from CSG collar.;R/D e-line sheaves&equipment;Latch onto stump&S/O 4'..P/U 2' of strech and set slips.fill hole(35 bbls).drop bar&R/U kelly hose.pressure up tbg to 3800 PSI&hold for 30min.;bleed off pressure& perform push/pull test.S/0 30K on pck T/80K&P/U 30K over T/162K.fill backside(24BBLS)&close pipe rams.;test backside to 2500 PSI&hold for 30min.,pressure leaked off 150 PSI in 20min.,bleed off pressure&pressure up to 2500 PSI.pressure leaked off 250 PSI in 30 min.,;changed out valve on circ.manifold.;P/U on tubing and set 15K down on tubing.pressure up to T/2500 PSI&pressure bleed off 50 PSI in 15min.,bleed off pressure&set 35K down on tubing.pressure up to 2500 PSI&held for 30 min.(good test) 07/29/15-Wednesday CONT'TO TEST PACKER ON CHART.RELEASED F/PACKER AS PER TRI-POINT REP.L/D(2)PUP JNTS, POOH W/3-1/2"PH6 WORK STRING. L/D PACKER RUNNING ASSY.P/U WEAR BUSHING R/R TOOL&RIH W/SAME.PULLED W/B&L/D SAME. CLEAR ALL 3-1/2"& OTHER MISC P.H.E.FROM FLOOR.R/D FOSTER TONGS&REMOVE F/FLOOR.P/U MCCOY TONGS&DRESSED FOR 4-1/2"TBG.R/U TONGS&POWER PACK.TROUBLESHOOT MCCOY'S.TONGS HAD MISSING OR WORN OUT PARTS.R/D MCCOY TONGS&REMOVE FROM FLOOR.P/U FOSTER TONGS,R/U&DRESS OUT SAME.STRAP/TALLY 4-1/2"PROD TBG. P/U SEAL BORE ASSY AS PER TRI-POINT REP.(ASSY LENGTH=26.57'). P/U 4-1/2"EXT BTC POLYCORE PROD TBG OUT OF V-DOOR&TIH W/SAME.DRIFT EACH JOINT. CONT. P/U 4-1/2"EXT BTC POLYCORE PROD.TBG.DRIFTING&TALLYING. R/D HILCORP FOSTER TONGS&R/U K.O.T.MCCOY TONGS,C/O FITTINGS FOR TONG CYLINDER. CONT.P/U 4-1/2"EXT BTC POLYCORE PROD.TBG.DRIFTING&TALLYING PUMPED OUT 35 BBLS OF FIW OUT OF MUD TANK,L/D 1 JOINT(BAD POLYCORE). Hilcorp Alaska, LLC IliIcor)Alaska LLI: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-04RD 50-733-20050-01 181-183 6/30/2015 7/31/2015 Daily Operations: 07/30/15-Thursday Cont.RIH f/5,255't/7,239'tag top of seal bore w/4-1/2"Ext.BTC polycore prod.Tubing,drift w/3.4"drift,up wt 98k,do 79k,cont in t/no go @ 7,252'. RU tested back side&seals t/2,500 f/30 min good. POOH LD 3 jts,measure f/space out,pulled 2 stands c/o 2 jts, RIH t/7,200'placing space out pups below top jt. R/U,pump&spot packer fluid in IA,@ 2 BPM,90psi. M/U hanger&landing jts,RIH land hanger PU 10k over verify latch,re-land hanger,putting 10k down on seals,run in L/D pins. R/U pressure test IA t/2,500'chart f/30 min.good. R/U W/L,test lubricator t/1,500 psi good,RIH w/JDC,tagged @ 9,200'wlm, POOH,no recovery,check tool,re-run, POOH no recovery,redress JDC&re-run. POOH retrieve dart. M/U 2.813" PRGS, RIH latch plug&wk free @ 9,209'wlm,POOH recover plug,r/d w/l. 07/31/15-Friday R/U e-line,p/u PLT, GR&CCI tools,test lubricator t/1,500 psi good, log in f/42't/10,100',log out f/1Q100't/42'.Taking stationary 5 1 readings every 1,000',r/d e-line,(prep rig t/skid while logging). Pull&breakdown landing jt,set BPV. Pull floor panels,Hbeam&flow G nipple,install hand rails,pull drip pan,r/u BOPE lift beam,breakdown scaffold,n/d BOP stack&hang under floor,pull riser. N/U tree, test void t/5,000,test tree good. Remove rear master skid ext.clamps,r/d scafolding,r/d service lines jt/dog house&remove same, remove DS roof panels,r/d flow line,lossen front&cellar master skid clamps,r/u jacks t/master skid,install hanging scafolding f/rear clamps. OF Ty, wP\ 1/j' THE S"IAI'11 Alaska Oil and Gas &��� v f' Conservation Commission (iO\ l-I:NOR Bill. ‘V \i ki R A OF ALARA ADMINISTRATIVE APPROVAL AREA INJECTION ORDER NO. 5.020 Mr. Larry Greenstein Regulatory Compliance Manager Hilcorp Alaska, LLC. P.O. Box 244027 Anchorage, AK 99524-4027 Re: Docket Number: AIO-15-034 Request for administrative approval to allow well G-04RD (PTD 1811830)to be online in water only injection service with known production casing integrity issues. Trading Bay Unit(TBU) G-04RD (PTD 1811830) McArthur River Field McArthur River Middle Kenai G and Hemlock Oil Pools Dear Mr. Greenstein: By email dated August 3, 2015, Hilcorp Alaska, LLC. (Hilcorp) requested administrative approval to continue water only injection in the subject well. In accordance with Rule 9 of Area Injection Order (AIO) 05.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS the Hilcorp request for administrative approval to continue water only injection in the subject well. Hilcorp reported a potential Inner Annulus pressure communication to AOGCC while completing wellwork under Sundry 315-254. Hilcorp performed diagnostics and determined production casing damage is present between approximately 7,410 ft and 9,090 ft MD. Hilcorp plans to install a straddle packer to isolate the damaged casing, but this will result in a packer depth of approximately 7,250 ft MD with the upper water injection perforation of approximately 9,295 ft MD. The surface casing shoe is 3,043 ft MD. A passing state witnessed Mechanical Integrity Test of the Inner Annulus (MITIA) will be required to ensure that G-04RD exhibits at least two competent barriers to the release of well pressure. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. Rule 9 of AIO 5.000 allows administrative amendment of any rule stated as long as the operator demonstrates to the AOGCC's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. A10 5.020 August 14,2015 Page 2 of 2 Finding 4 of AIO 5.000 states that the portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the Trading Bay Unit are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B)and 20 AAC 25.440(c). AOGCC's approval to continue water injection only in TBU G-04RD is conditioned upon the following: 1. I-lilcorp shall record wellhead pressures and injection rate daily; 2. Hilcorp shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3. Hilcorp shall perform a mechanical integrity test of the inner annulus (MITIA) every 2 years; 4. Hilcorp shall perform a temperature survey every 2 years to confirm injection is confined to the authorized injection zone; 5. Hilcorp shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. After well shut in due to a change in the well's mechanical condition. AOGCC approval shall be required to restart injection; and 7. The MIT anniversary date will be set as the date of the AOGCC witnessed MITIA that is to be completed once the well is returned to injection and stabilization is achieved. AOGCC must be provided the opportunity to witness the MIT for the test that will establish the new MIT anniversary date. DONE at Anchorage,Alaska and dated August 1 , 2015. Ati�ok-ql, , , 'e: 4 Cathy . Foerster a niel T. Seamount. Jr. 4, Chair, Commissioner Commissioner •p• >. 0A.c( RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a).within 20 days alter written notice of the entry of this order or decision.or such further time as the AOGCC grants for good cause shown.a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed.then the period of time shall be 23 days. An application ti.r reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is tiled. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration.upon denial.this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes. the order or decision denying reconsideration. UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days atter the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather.the order or decision on reconsideration will be the FINAL order or decision of the AOGCC.and it may be appealed to superior court. That appeal MUST be tiled within 33 days after the date on which the AOGCC mails.OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default alter which the designated period begins to run is not included in the period;the last day of the period is inckhded,unless it falls on a weekend or state holiday.in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday,July 23, 2015 11:38 AM To: 'Dan Marlowe' Cc: Juanita Lovett;Ted Kramer;Trudi Hallett;Wallace, Chris D (DOA) Subject: RE:G-04rd PTD 181-183, Sundry 315-254 Dan, The changes to the sundry as written below are approved. If the straddle is required then an Admin Approval (AA) authorization will be required before long term injection can commence.The request will also require a variance for packer depth per 20 AAC 25.412(b). It would be best to start on the AA approval as soon as possible once you know the straddle is going to be needed. Guy Schwartz Senior Petroleum Engineer AOGCC SCANNED JUL 2 7 2015 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Dan Marlowe [mailto:dmarlowe@hilcorp.com] Sent: Thursday, July 23, 2015 11:18 AM To: Schwartz, Guy L (DOA) Cc: Juanita Lovett; Ted Kramer; Trudi Hallett Subject: G-04rd PTD 181-183, Sundry 315-254 Guy as discussed here is our G-04rd plan forward: Procedure: 1. RU HAK Rig 1 over G-04rd. 2. RU and circulate hydrocarbons from well. 3. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 3,000 psi HIGH. 4. PU landing joint and make-up to tubing hanger. 5. Attempt to pull tubing free from packer, if unsuccessful, RU and cut tubing as deep as possible. 6. POOH laying down completion. 7. Fish remaining tubing. 8. Mill out and recover production packer at 9,150'. 9. Cleanout to top of straddle packer at 10,153' 10. Cleanout straddle packer assembly and recover straddle packer assembly and cleanout to +/- 10,420' or cleanout through it to+/- 10,420'. PU RIH with RTTS to 9,150' Pressure test casing to -2,500 psi and chart for 30 minutes. • Casing issues found • Tested to 2500 psi at 7,000' (MD)/6,611' (TVD) and charted for 30 minutes on 07/22/15 1 • Set storm packer tested to 1500 psi, Swap out tubing spool,test BOP's—PRESENT OPERATION • RIH with scraper to+/-9,250' and circulate well with clean FIW • Run caliper log to inspect casing • CBL bond log from March 07, 1982 shows sufficient bond/isolation above the top perforation. The top of cement is estimated @ 7,640'MD confirming sufficient cement isolation and containment above the perforations. The current top perf is @ 9,295' MD — yielding us at least minimum of the recommended 500' isolation above. 12. PU TCP guns and RIH and re-perforate the G and Hemlock zones per the Perf Recommendation. 13. After detonation, circulate perf gas, confirm well is static, POOH. 14. PU and run injection string ,/ c radldle nackers depth to he determined by caliper log—Alternate packer depth per 20 AAC25.412IR1 15. Set packer and pressure test to"'2,500 psi and chart for 30 minutes. 16. Conduct work-over MIT-IA Set BPV. NU tree,test same. Run a baseline pre-injection temperature log 18. Schedule initial MIT-IA with AOGCC within 2 weeks of stable injection as per regulations. Run a baseline flowing temperature survey to confirm integrity of lower packer Follow up surveys will be required every two years to monitor integrity of lower packer Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe(c�hilcorp.com Hilcorp A Company Built on Energy 2 II PROPOSED McArthur River Field, TBU Well: G-04RD Hiker,""`'"X As Completed: Future RKBtoTubingHgr=41.34' Casing&Tubing Detail SIZE WT WT GRADE CONN ID TOP BTM \ / 16" 75 J-55 8 Round 15.124 Surf 621 13-3/8" 61 1-55 Butt 12.515 Surf 3,043' L N 9-5/8" 47 N-80 Butt 8.681 37' 79' 9-5/8" 40 N-80 Butt 8.835 79' 4,355' 9-5/8" 43.5 N-80 Butt 8.755 4,355' 5,970'(TOW) 7" 29 N-80 Butt 6.184 41' 10,451' Tubing: 4-1/2" 12.60/13.55 L-80 BTC Ext 3.598 Surf ±9,170' L Polycore _ DV Collar - Jewelry Detail 4511' Depth Depth No (MD) (TVD) ID OD Description 42' Hanger window 1 ±7,000' ±6,611' Hydroset Packer w/upper seal bore 5970'-6032' 2 ±9,150' ±8,493' Hydroset Packer 3 ±9,160' ±8,502' X nipple 1 a 4 ±9,170' ±8,510' Wireline Re-entry Guid D 5 10,153 9,347' 4.000" Baker Model FB-1 straddle packer,drill pipe 3-1/2" I L-80 buttress tubing SC TOC 1-...., 6 10,312 9,486' 4.000" Baker Model F13-1 straddle packer,E-line 2 X 3 - 4 -. Open Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(ND) Amt SPF Date Comments G Perfs G-1 9,295' 9,320' 8,618' 8,639' 25' - TCP 3/9/1998 Open G-1 ±9,300' ±9,320' 18,622' ±8,639' ±20' Future G-2 9,345' 9,365' 8,661' 8,678' 20' TCP 3/9/1998 Open G-2 ±9,350' ±9,365' ±8,665' ±8,678' ±15' Future _ G-3 9,436' 9,456' 8,738' 8,755' 20' TCP 3/9/1998 Open G-3 ±9,438' ±9,456' ±8,740' ±8,755' ±18' Future -1-} HK-1,3,45 G-4 9,486' 9,537' 8,780' 8,823' 51' TCP 3/9/1998 Open • = G-4 ±9,491' ±9,496' ±8,785' ±8,789' ±5' Futw, G-4 ±9,501' ±9,509' ±8,793' ±8,800' ±8' Future G-4 ±9,520' ±9,535' ±8,809' ±8,821' ±15' _ Future 2' E 5 6-5 9,587' 9,672' 8,865' 8,936' 85' TCP 3/9/1998 Open lG-5 ±9,595' ±9,610' ±8,871' ±8,884' ±15' Future ' 1 HK-5&HK-6i G-5 ±9,618' ±9,639' ±8,891' ±8,908' ±21' Future G-5 ±9,645' ±9,670' ±8,913' ±8,934' ±25' Future Block Sqz 9,758' 9,760' 9,009' 9,011' 2' 3/11/1982 Sqzd w/190sx 6 HK-1 ±9,815' -10' ±9,057' ±25' Future y HK-1 9,815' 9,843' 9,05T 9,081' 28' TCP 3/9/1998 Open 1 Block Sqz 9,852' 9,854' 9,089' 9,090' 2' 3/10/1982 Sqzd w/100sx J( HK-6&7 HK-2 9,862' 9,882' 9,097' 9,114' 20' 9/5/1983 Sqzd 4/20/85 Fill @ 10,320'-. Sqzd w/100 sx Block Sqz 9,960' 9,962' 9,181' 9,183' 2' 3/9/1982 4/19/85 HK-3 9,965' 10,016' 9,185' 9,229' 51' TCP 3/9/1998 Open / \ HK-3 ±9,968' ±10,014' ±9,188' ±9,227' ±46' Future HK-4 10,024' 10,146' 9,236' 9,341' 122' TCP 3/9/1998 Open PBTD=10,420' TD=10,450' HK-4 ±10,025' ±10,058' ±9,237' ±9,265' ±33' Future HK-4 ±10,067' ±10,118' ±9,273' ±9,317' ±51' Future Block Sqz 10,102' 10,104' 9,303' 9,305' 2' 4/19/1985 Sqzd w/100 sx Max angle=33°@ 9500' HK-4 ±10,127' ±10,145' ±9,325' ±9,3 ±18' Future Block Sqz 10,162' 10,164' 9,355' 9,357' 2' 3/15/1982 Sqzd w/200 sx HK-5 10,182' 10,188' 9,373' 9,378' 6' _ 4/4/1997 Straddle pkr 3/98 HK-5 ±10,182' ±10,198' ±9,373' ±9,386' ±16' Future HK-6 10,300' 10,305' 9,475' 9,479' 5' 5/28/1996 Straddle pkr 3/98 HK-6 ±10,303' ±10,310' ±9,478' ±9,484' ±7' Future HK-6 10,325' 10,355' 9,497' 9,523' 30' 12 3/9/1998 Open HK-7 10,364' 10,392' 9,531' 9,555' 28' 12 3/9/1998 Open Revised:2015-07-22 by.ILL Pro ►t l ►g3c,' Regg, James B (DOA) From: Howard Hooter- (C) <hhooter@hilcorp.com> ?I Z 3�- Sent: Monday, July 20, 2015 9:00 AM f` To: Regg,James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: Dan Marlowe;Juanita Lovett Subject: Test report for Moncla 301 MRF TBU G-04RD W/TEST CHARTS Attachments: Moncla 301 7-17-15.xlsx; BOPE test charts 7-17-2015.pdf STATE OF ALASKA Ifv71V3V� OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim reggCa�alaska qov AOGCC.Inspectors(a�alaska.gov phoebe.brooksCa alaska.gov Contractor: Moncla Rig No: 301 DATE: 7/17/15 - Rig Rep: Courtlin Greis Rig Phone: 776-6639 Operator: Hilcorp Op Phone. 776-6754 Rep.: Howard Hooter E-Mail hhooter@hilcorp.com Well Name. TBU G-04RD PTD# 1811830 - Sundry# 315-254 Operation Drilling Workover: X Explor.: Test' Initial: Weekly: x Bi-Weekly: Test Pressure(psi): Rams. 250/3000 Annular: 250/2500 Valves: 250/3000 MASP. 0 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P Upper Kelly 0 _ NA Housekeeping P Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Ball Type 1 • P Standing Order Posted P Misc. NA Inside BOP 1 P ' FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P 1 Annular Preventer 1 - 13 5\8" P • Pit Level Indicators P - P _ #1 Rams 1 • 2 7/8x5 var • P - Flow Indicator P P #2 Rams 1 Blind P • Meth Gas Detector P P • #3 Rams 0 NA H2S Gas Detector P P • #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 - 3 1/8 - P . Inside Reel valves 0 NA HCR Valves 2 - 3 1/8 - P Kill Line Valves 2 . 3 1/8 2 1/16 . P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 3000 • P - CHOKE MANIFOLD: Pressure After Closure(psi) 1850 • P ' Quantity Test Result 200 psi Attained (sec) 30 ' P ' No.Valves 11 • P Full Pressure Attained(sec) 153 P Manual Chokes 1 - P , Blind Switch Covers: All stations Yes Hydraulic Chokes 1 _ P - Nitgn. Bottles Avg (#and psi): 4@2150 P • CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures 0 Test Time: 7.0 '/ Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks' Tested w/3 1/2"TJ , MASP calculation based on alternate pressure gradient as approved in Sundry 315-254, Total safety check Methane&H2S GAS Detector 7-17-15, test#1 test plug leaded pulled same and changed rubbers, ON 7-16-15 received approval from Mr. Jim Regg to start the bop early AOGCC Inspection 24 hr Notice Yes DatelTime 7-15-15/9:10pm Waived By Jim Regg Test Start Date/Time: 7/16/2015 20:30 (date) (time) Witness Test Finish Date/Time: 7/17/2015 3:30 Form 10-424(Revised 06/2014) 2015-0717_BOP_Moncla301_TBU_G-04RD.xlsx )1)6 -r"' t - Airc(A, 3b 55 1 _:4 60/ _ __ _ — - , -----___ /0 Tgtk G-0421) IN(630 , — ------ _• •& „...--------.17..---- ____--:------7-7—--------- -----... 'N.. 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' \ \ '-:• ' 0 , ------.- , 0' 0 1.,/ ' le '-'\ • . . ,..._______,L ___- . _ • 00,--,-- __ _ , /, /... • . z • . .,,oc 2 / \ "------:-___ oogi•_______ o ---""' • / ,. ,„,c., i ••• _______________ 44/ / • . ,__- -,..., N.,......,,..::,.. ---- 00s?---------------', , —• — -- , _--.--- ,---‘4..." , / 4 / --. ' - '' Z / ooc-, , - ..„ . ) ,v---___ . ----..... ------,..._._ . ./ 1, o __ —› ; '• 0 . , . .., .. . , ------ .. _.- _, ---- . ---- . --------____ _--! Pci 1/4_ `$pft 'rasa- —/4.4 30 c.--/4 00 �_ _'-_ �, Ss PSD �'6t u3o Af -------. / / soon --- �.` \� 3500 .• . — ________ ,''7/( -- "1 "/ 2000 \ Js °O 00 % i \\000 �S 00 ° . ,\ \ . .yPp / i \ ',.,...• c-----1-------------S—,,, 0 *s \ i / /.. ''Z? 8 li. C4f 1, W ,-- \-- 111...11111 ,.i. \'', ,(y IbO J v3��9 �yti AI I v t g4 , so If' , • _ I. , . 3.,0.,,S, o• ° I i • i , o 1 - 4', r j o ' G.. / jp# of U \ .- 00as ...1140: o 0 °o„ '''---7,4_.„ 1 . .----t, . 0. . -- . 40r o o AN "---- / /1/ / t. / • ' z • /o /o \ T ` 00g` _post./ �, - OZ . 3/4 , V OFA T �s THE STATE Alaska Oil and Gas OfA AAsKA Conservation Commission 41 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 LASilg'P „ Fax. 907.276 7542 SCANNED MAY 1 4 [Mi www.aogcc alaska gov Dan Marlowe Operations Engineer 3 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU G-04RD Sundry Number: 315-254 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster / Chair gA— DATED this to day of May, 2015 Encl. RECEIVED • STATE OF ALASKA APR 2 8 2015 ALASKA OIL AND GAS CONSERVATION COMMISSIONAOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate 0 Pull Tubing El Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Convert to Injector 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC . Exploratory ❑ Development El- 181-183 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20050-01 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 228A• Will planned perforations require a spacing exception? Yes ❑ No 0 / Trading Bay Unit G-04RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730• McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,450 - 9,606 - 10,420 . 9,580 N/A 9,241 Casing Length Size MD TVD Burst Collapse Structural Conductor 621' 16" 621' 621' 2,630 psi 1,020 psi Surface Intermediate 3,043' 13-3/8" 3,043' 3,005' 3,090 psi 1,540 psi Production 5,970' 9-5/8" 5,970' 5,718' 5,750 psi 3,090 psi Liner 10,450' 7" 10,450' 9,607' 8,160 psi 7,020 psi Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 3-1/2" 9.3#/L-80 9,241 Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft)• , FB-1 Packer(x3)See Schematic/ TE-5 TRSSSV • 9,150'(MD)8,493'(ND),10,153'(MD)9,347'(ND),10,312'(MD)9,486'(ND)/372'(MD)372'(ND 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development❑ Service 0 • 14.Estimated Date for 15.Well Status after proposed work: 6/1/2015 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 0' GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: I GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signatuidf:;2— Phone (907)283-1329 Date 4/27/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 I c -2541 Plug Integrity ❑ BOP Test (►J� Mechanical Integrity Test Location Clearance ❑ Other: 2( 3 Q©C% r Sc th r -r;-_, t C `v 14-Si / / Spacing Exception Required? Yes ❑ No Lb Subsequent Form Required: /o -L/o 1 APPROVED BY / Approved by:0 P COMMISSIONER THE COMMISSION Date: 5-4 -7 S y.1Sr Do -?it 41/4/is- .60. �4 RBDMS-,�- MAYd 1 1 2015 Submrt Form Form 10-403( evised 10/2012) �irbvldlalacit0r 4112r 12 months from the date of approval. Attachments in Duplicate Well Work Prognosis Well: G-04rd tiac„ri) u�..��.r.i.c Date: 04/27/2015 Well Name: G-04rd API Number: 50-733-20050-01 Current Status: Gas-Lift Producer Leg: Leg#2 (NE corner) Estimated Start Date: 06/01/15 Rig: HAK#1 _ Reg.Approval Required? 403 Date Reg.Approval Received: Regulatory Contact: Juanita Lovett Permit to Drill Number: 181-183 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Ted Kramer Office: 907-777-8420 Cell: 985-867-0665 Current BHP: -3,542 psi ©9,450'TVD 0.37 psi/ft,(7.22 ppg)Mid-Pert Max.Expected BHP: -3,542 psi @ 9,450'TVD 0.37 psi/ft,(7.22 ppg)No new perforations Max.Possible SP: 0 psi Well will not flow based on an expected oil and water gradient of 0.437 psi/ft Brief Well Summary /1"47 c L / � , zii A 47- (.)(44) ti �- G-04rd is a shut-in gas-lift producer completed in the Hemlock and G ones. Scale is plugging the tubing below 5,930'. This work-over will remove the current completion cleanout the well to PBTD, re- perforate, and complete as an injector. AOR(status of wells within 1/4 mile radius of injection zone): APIWellNo Permit Well CurrentStatus Zonal isolation (method) >70' good cement above G-zone 507332005001 1811830 G-04rd S/I 3/9/82 CBLNDL �� 507332018001 1850780 K-25 Suspended -50' good cement above G-zone, 8/23/85 CBLNDL >500' good cement above G-zone, 507332026100 1740100 G-20 Producing 4/19/74 CBLNDL Cement 9-5/8" above & 7" across 507332019801 1690860 G-32 Producing West-foreland, Block sqz'd cement above & below Hemlock 507332021200 1700110 G-33 Producing >150' good cement above G-zone, • 3/14/70 CBL 507332042800 1910270 M-29 P&A below 8467' Bands of good cement above G-zone (6/27/91 CET/CBT) >70' good cement above G-zone 507332042801 2120500 M-29A Producing (7/2/12 USIT) Cement 7" casing with 1200sx, 507332039100 1870860 M-25 Suspended Squeeze 9484'/9762' (above/below coal 39) • 507332045700 1931900 M-31 P&A below 9107' Cemented 9-5/8" at base coal 39, FIT to 14ppg EMW Cement Squeeze at 9566' (base GO6 507332046200 1941360 M-32 P&A below 9392' gas sand), unable to locate 2/4/1995 CET/CBT, cement unlikely above 9566'. SI gas-well, with multiple Cemented to window/liner top at 507332046201 1999701 M-32RD plugs & cement sqz into 9392'/9301', FIT to 11.2ppg at window E7 gas perfs at 7372' (G03 gas sand) CoyGv� 74 wet( jr; Pr° cee 7g/ Mq?l `�/f �Lj�'e 4 a ( eQC/�fi4f- Gvc7,&& Ct,-i t•-/1 eh 14 e l✓C 1/ d117 �P C�!`i!�^f a- G, .r .2007 Q AI !'°►'lei‘46fl d gf'v' i-a < i rr'lcv btij tr/ 6'/ vv“ 9 'f J. recemt a1 Pt 76 ,rod ce Tye ttiet V! T �i -1/Q'7`N`, G'e�.,�'t r..f J ti.GGf , ae 'n ee/w, f�ov/q/ q'l/v.t' for.;m'°✓e�/ /ecave^r 1"" 1 • Well Work Prognosis • Well: G-04rd Hileorp Alaka,LLCDate: 04/27/2015 Procedure: 1. RU HAK Rig 1 over G-04rd. 2. RU and circulate hydrocarbons from well. 3. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 3,000 psi HIGH. 4. PU landing joint and make-up to tubing hanger. 5. Attempt to pull tubing free from packer, if unsuccessful, RU and cut tubing as deep as possible. 6. POOH laying down completion. 7. Fish remaining tubing. 8. Mill out and recover production packer at 9,150'. 9. Cleanout to top of straddle packer at 10,153' 10. Cleanout straddle packer assembly and recover straddle packer assembly and cleanout to +/- 10,420' or cleanout through it to +/- 10,420'. 11. PU RIH with RTTS to 9,150' Pressure test casing to "2.500 psi and chart for 30 minutes. 12. PU TCP guns and RIH and re-perforate the G and Hemlock zones per the Perf Recommendation. 13. After detonation, circulate perf gas, confirm well is static, POOH. 14. PU and run injection string. 15. Set packer and pressure test to -2,500 psi and chart for 30 minutes. - 16. Conduct work-over MIT-IA 17. Set BPV. NU tree,test same. 18. Schedule initial MIT-IA with AOGCC within 2 weeks of stable injection as per regulations. Attachments: 1. Area of Review Map 2. Current Well Schematic 3. Proposed Well Schematic 4. Current Wellhead Diagram 5. Proposed Wellhead Diagram 6. BOP Stack 7. Rolling BOP Test Procedure U p Q J iiii— JW 5 0. > 53 a tea= K z aLL ith}HH �1. Lt o I- , LL J Q 84#•*VAN '83 = U m i I1 '.4 I I ---------- --------- N . I N I i---------- CD YiI iIM I ,^W o I I Iq • i I 1 I� I . cD f -- -- C el i Ni I I I b � I 1 z r ' I I Not l r - '4111145:* - V s , pr It-- E 4 O2 N N I I I 1 —1 N o m N I I N ,'�, �.1ill" N 1 • ‘< co •rl')....,,iblfrrl j (5 ' ( 4 N C 0 C O I I I �_./.,1114 Y O O 41 O O I O > V1 O > to I I— m I I — I , ir / 0r, O .4‘th al aJ 'Es I ri4 o `� I 0 6 `O N 7 O ro IA t 4- S cc U64 crto Y O1 p i r6 7 ME _ () ~ A a 'N. McArthur River Field,TBU Well: G-04RD El Hdrorp Akaxka,I.IA: As Completed: 11/09/98 RKB to Tubing Hgr=41.34' SIZE WT GRADE CONN TOP BTM 16" 75 J-55 8 Round Surf 621' I IA 13-3/8" 61 J-55 Butt Surf 3043' Zi 9-5/8" 47 N-80 Butt 37.00' 78.94' B 9-5/8" 40 N-80 Butt 78.94' 4355.21' 1 1 9-5/8" 43.5 N-80 Butt 4355.21' 5970' (TOW) 7" 29 N-80 Butt 41.00' 10451.00' 1 2 Tubing: 3-1/2" 9.3 L-80 BTC SC Surf 9241' 1 3 L 1 4 DV Collar 1 5 JEWELRY DETAIL 4511.48' 0 1 NO. Depth Item 6 A 42 4-1/2"ASL hgr top&btm w/3-1/2"Butt xover below B 372 3-1/2"TE-5 TRSSSV,5.380"OD J 7 1 2522 Macco 3-1/2"GLM w/1"GLV and BK-2 latch 2 4126 Macco 3-1/2"GLM w/1"GLV and BK-2 latch Window 1 8 3 5444 Macco 3-1/2"GLM w/1"GLV and BK-2 latch 5970'-6032' 4 6163 Macco 3-1/2"GLM w/l"GLV and BK-2 latch Li 1 9 ,�, 5 6692 Macco 3-1/2"GLM w/1"GLV and BK-2 latch 6 7186 Macco 3-1/2"GLM w/l"GLV and BK-2 latch 1 10 7 7619 Macco 3-1/2"GLM w/1"GLV and BK-2 latch TOC @ 8800' 8 8083 Macco 3-1/2"GLM w/l"GLV and BK-2 latch 9 8610 Macco 3-1/2"GLM w/1"GLV and BK-2 latch ?G 10 9106 Macco 3-1/2"GLM w/1"orif and BK-2 latch 12 12 9150 9156'tbg tally, Model FB-1 pkr with 4.00"bore X 13 13 9207 3-1/2"X nipple,2.813"ID G Perfs 14 9241 3-1/2"Tubing Tail Wireline Re-entry Guide 14 9295'-9320' 15 10153 Baker Model FB-1 straddle pkr,4.000"ID,drill pipe 9345'-9365' 3-1/2"L-80 buttress tubing SC ▪ 9436'-9456' 16 10312 Baker Model FB-1 straddle pkr,4.000"ID,E-line = 9486'-9537' 9587'-9672' Open Perforations TOP BTM ZONE SPFDATE COMMENTS Reperf 3/9/98 G-1 9295-9320 3/9/98 TCP H-1.3.4 G-2 9345-9365 3/9/98 TCP 9816'-9843' G-3 9436-9456 3/9/98 TCP = 9968'-10016' G-4 9486-9537 3/9/98 TCP - 10024'-10146' G-5 9587-9672 3/9/98 TCP g15 H-1 9815-9843 3/82 Last Reperf 3/9/98 TCP H-3 9965-10016 3/82 Last Reperf 3/9/98 TCP Straddle Pkr H-4 10024-10146 4/85 Frac'd 4/85,Last Reperf 3/9/98 TCP H-5&H-6 H-6 10325-10355 3/8/98 12 spf 4-1/2"casing guns H-7 10364-10392 3/8/98 12 spf 4-1/2"casing guns $ B 16 Abandoned Perforations H-6&7 TOP BTM ZONE SPFDATE COMMENTS 10325'-10355' 9758 9760 3/11/82 Sqzd w/190 sx 10364'-10392' 9852 9854 3/10/82 Sqzd w/100 sx 9862 9882 9/5/83 Sqzd 4/20/85 j L 9960 9962 3/9/82 sqz w/100 sx 4/19/85 10102 10104 4/19/85 Sqzd w100 sx 10162 10164 3/15/82 Sqzd w/200 sx PBTD=10,420' TD=10450' 10182 10188 H-5 4/4/97,(straddle pkr,3/98) 10300 10305 H-6 5/28/96,(straddle pkr,3/98) Max angle=33°@ 9500' 11/12/06 to 12/5/06: Attempting to clear scale from tail,parted wire,dropped tools. Fished some wire,but left wire&tools in tubing tail REVISED:2015-03-19 by DEM PROPOSED McArthur River Field, TBU Well: G-04RD """'"""`' ''' As Completed: Future Casing&Tubing Detail SIZE WT WT GRADE CONN TOP BTM RKB to Tubing Hgr=41.34' 16" 75 J-55 8 Round Surf 621 13-3/8" 61 J-55 Butt Surf 3,043' 9-5/8" 47 N-80 Butt 37' 79' Ip 9-5/8" 40 N-80 Butt 79' 4,355' L 9-5/8" 43.5 N-80 Butt 4,355' - 5,970'(TOW) 7" 29 N-80 Butt 41' 10,451' Tubing: 4-1/2" 12.6 L-80 BTC Ext Surf ±9,170' L N Jewelry Detail DV Collar - No Depth Description 4511' - 42' Hanger 1 ±9,150' Packer 2 ±9,160' X nipple 3 ±9,170' Wireline Re-entry Guide Window • r,^-Sr' 5970'-6032' Z , .-Ba 16L' Open Perforation Detail N° : rZone Top(MD) Btm(MD) Top(TVD) Btm(ND) Amt SPF Date Comments TOC @ 8800 SG G-1 9,295' 9,320' 8,618' 8,639' 25' TCP 3/9/1998 Open SOF: -»`°' t 4t G-1 ±9,300' 19,320' ±8,622' ±8,639' ±20' Future G-2 9,345' 9,365' 8,661' 8,678' 20' TCP 3/9/1998 Open A 2 G-2 ±9,350' ±9,365' ±8,665' ±8,678' ±15' Future G-3 9,436' 9,456' 8,738' 8,755' 20' TCP 3/9/1998 Open 3 G-3 ±9,438' ±9,456' ±8,740' ±8,755' ±18' Future G-4 9,486' 9,537' 8,780' 8,823' 51' TCP 3/9/1998 Open G-4 ±9,491' ±9,496' ±8,785' 18,789' ±5' Future = GPerfs 0-4 ±9,501' ±9,509' ±8,793' ±8,800' ±8' Future 0-4 ±9,520' ±9,535' ±8,809' ±8,821' ±15' Future G-5 9,587' 9,672' 8,865' 8,936' 85' TCP 3/9/1998 Open F.---- s 0-5 ±9,595' ±9,610' ±8,871' ±8,884' ±15' Future 0-5 ±9,618' ±9,639' ±8,891' ±8,908' ±21' Future o HK-1,3,4,5 0-5 ±9,645' ±9,670' ±8,913' ±8,934' ±25' Future a HK-1 ±9,815' ±9,840' ±9,057' ±9,079' ±25' Future HK-1 9,815' 9,843' 9,057' 9,081' 28' TCP 3/9/1998 Open HK-3 9,965' 10,016' 9,185' 9,229' 51' TCP 3/9/1998 Open HK-3 ±9,968' ±10,014' ±9,188' ±9,227' ±46' Future sHK-4 10,024' 10,146' 9,236' 9,341' 122' TCP 3/9/1998 Open HK-5&HK-6 } HK-4 ±10,025' ±10,058' ±9,237' ±9,265' ±33' Future 1 HK-4 ±10,067' ±10,118' ±9,273' ±9,317' ±51' Future HK-4 ±10,127' ±10,145' ±9,325' ±9,340' ±18' Future HK-5 ±10,182' ±10,198' ±9,373' ±9,386' ±16' Future HK-6 ±10,303' ±10,310' ±9,478' ±9,484' ±7' Future HK-6&7 HK-6 10,325' 10,355' 9,497' 9,523' 30' 12 3/9/1998 Open HK-7 10,364' 10,392' 9,531' 9,555' 28' 12 3/9/1998 Open Abandoned Perforation Detail Z. "4 9,758' 9,760' 9,009' 9,011' 2' 3/11/1982 Sqzd w/190sx 9,852' 9,854' 9,089' 9,090' 2' 3/10/1982 Sqzd w/100sx PBTD=10,420' TD=10,450' 9,862' 9,882' 9,097' 9,114' 20' 9/5/1983 Sqzd 4/20/85 Sqzd w/100 sx 9,960' 9,962' 9,181' 9,183' 2' 3/9/1982 4/19/85 Max angle=33°@ 9500' 10,102' 10,104' 9,303' 9,305' 2' 4/19/1985 Sqzd w/100 sx 10,162' 10,164' 9,355' 9,357' 2' 3/15/1982 Sqzd w/200 sx HK-5 10,182' 10,188' 9,373' 9,378' 6' 4/4/1997 Straddle pkr 3/98 HK-6 10,300' 10,305' 9,475' 9,479' 5' 5/28/1996 Straddle pkr 3/98 Revised:2015-04-27 by 11.1. Grayling Platform G-04RD Current 03/20/2015 IHilrnrr ‘14i4kn.1.1A. G-04RD Tubing hanger,CIW-AP- 13 3/8 X 9 5/8 X 7 X FBB,11X4'Armco Seal 3 1/2 lock lift and susp,w/4" type H BPV profile,7" EN,'A"non continuous control line BI-ITA,CIW,4 1/16 5M FE X Internal Acme knockup rcls L Tree,Block,CIW-F,11 5M FE f I$ o`� r. X 4 1/16 SM,single master and swab,w/7"FBB pocket, r A control line exit,EE trim f— digetti; rtll� 111 Tubing head,CIW-AP,13 5/8 3M X 11 5M,w/2-2 1/16 5M ► irii If SSO,X-bottom prep, _,," lei= 1'A VR profile i 11 • i I I Valve,CIW-F,2 1/16 5M FE, HWO,AA o i -I irir;ill ell No(,iiilfr/All)1111rni-i• III ;r� Valve,CIW-F,2 1/16 3M FE, III ! 1 III HWO,AA Casing spool,CIW-WF, . 13 5/8 3M X 13 5/8 3M, �1 LSIll4IIJhoiJIu. I. w/2- 1/ ° i� Casing head, Shaffer KD, III fl I I 13 5/8 3M X 2"LP CIW ball valve 13 3/8 SOW,w/2-2" UR 111 ? LPO, Grayling Platform • Iii G-04RD Proposed 03/20/2015 Hilonrp Ataxia.LI.t: G-04RD Tubing hanger,Cactus,11 X 133/8 X 95/8 X 7 X 431 EUE lift and 434 BTC 4 1/2 susp,w/4"Type H BPV profile,2-3/8 CCL,634 extended neck,17-4PH stainless steel BHTA,Bowen,4 1/16 5M X 7"-5 SA Bowen Union Full Stainless Steel ma Valve,Swab,WKM-M, 0 4 1/16 5M FE,HWO,FF trim 0 0'' 0 0 q Valve,Wing,WKM-M, ... 3 1/8 5M FE,w/15"Safeco operator,FF trim N 7 r Full Stainless Steel ... r.. 1111 Valve,Master,WKM-M, o O - 4 1/16 5M FE,HWO,FF trim ,_,Q o 0 ' Adapter,Cactus,11 5M stdd ,.,1110,., X 4 1/16 5M,w/6''A pocket, 2-'A CCL exits,Full Stainless Steel -i . 1-1 Tubing head,Cactus, 161 UI• 161 135/83Mx115M,w/2- - '` 0 2 1/16 5M SSO,w/8G bottom,w/1-2 1/16 5M lin M 10.4101111111.1-I- WKM-M valve - - - 161 I 1 161 IIIValve,CIW-F,2 1/16 3M FE, Casing spool,CIW-WF, III — gigI HWO,AA 13 5/8 3M X 13 5/8 3M, w/2-21/165MSSO � I I t 1111(10(3rd II Illmi-i- 111 ,I, IIII .- Casing head, Shaffer KD, I 1 I III 2"LP CIW ball valve 135/83MX 13 3/8 S0W,w/2-2" Ali Mlle op-I. LPO, Grayling Platform 2015 BOP Stack (HAK#1) !Henri, tIa La.i.i.i. 01/15/2015 Grayling Platform 2015 Workovers BOP Drawing(HAK#1) Quail Tool Rental Stack Jnim fit riunntti 3.42' Shaffer 11"5M -i,w i1tlJi 4.54' .-.1:11 CI U QUO- - = � 1117 111.10 iii""iiiii l •2 2.00' ��f . r` {"`�� ��� 50111 ,srl : iii ui IiFO r• . Kill Side _ Choke side 1.00'to 2.00' 21/16 5M w/HCR and Unibolt line a 21/16 5M w/HCR and Unibolt line 1connection 1U�U��� ��� connection Drill deck Riser 11 5M FE X 16.00' 11 5M FE 1 ii INUUDLI 3.00' Spacer spool 11 5M FE X 11 5M FE Hilcorp HAK#1 BOP Test Procedure Hilcorp;Unekn, Attachment#1 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Hilcorp HAK #1, Dolly Varden WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test)joint to lift-threads d) For ESP wells - Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure Hilcorp HAK#1 BOP Test Procedure t, ��p.usk,.i.cc Attachment#1 c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-2 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. Hilcorp HAK#1 BOP Test Procedure Hilcorp al"Fk"_,.,,1 Attachment#1 d) Open C-2. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high, for 5 minutes each,as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test,open same. ii) Valves, 3,4, 9. After test,open valves 3 &4. Leave 9 closed. iii) Valves 5, 6,9. After test,open valves 5 & 6, leave 9 closed. iv) Valves, 7, 8, 9. After test,open all valves. e) Close C-3. This is the HCR(the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test,open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test C-1, C-2, and C-4 on the kill (pump-in) side by pressuring up on tubing.Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW(or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2' set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not"Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. Ima¢ ect Well History File Cover le XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. /- ~ L -/-- ~'~ Well History File Identifier Organizing RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERLY'~INCENT SHERYL MARIA WINDY Project Proofing Scanning Preparation ~ x 30 = .,J,_~ + ,,~.~(~ = TOTAL PAGES BY: BEVER~VINCENT SHERYL MARIA WINDY DATE: .... ~..~/ Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: __/y__ YES Stage 2 IF NOIN STAGE 1, PAGE(S)DISCREP~S'~ERE FOUND:/ [, YES (SCANNING IS COMPLETE AT THIS POINT UNLESS sPEcIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUAUTY, GRAYSCAI..E OR COLOR IMAGES ) NO NO RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /SI Quality Checked 12/10102Rev3NOTScanned.wpd AI#ASIiA OIL AND GAS CONSERVATI ON COMMISSION f ! I / ! I I ¡ ! ¡ í FRANK H. MURKOWSKI, GOVERNOR $u~uŒ (ffi~ ~~~$æ~ 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501.3539 PHONE (907) 279.1433 FAX (907) 276-7542 May 4, 2004 Dwight Johnson Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 RE: N 0- Flow Verifications Well G-03RD2, PTD 183-010 Well G-04RD, PTD 181-183 Well G-B, PTD 168-057 Dear Mr. Johnson: On April 23, 2004, AOGCC Petroleum Inspector Chuck Scheve witnessed 3 "no flow tests" on Unocal's McArthur River Field, Trading Bay Unit, Grayling Platform: Well G- 03RD2, Well G-04RD, and Well G-B. Each well was opened to atmosphere through flow measurement equipment with suitable range and accuracy after being shut in and monitored for several hours. There was no flow of gas or liquid to surface during the tests. Based on the results of these no-flow tests, the subsurface safety valves may be removed from service in Wells G-03RD2, G-04RD, and G-B. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in each of the wells as required in 20 AAC 25.265. The subsurface safety valve must be returned to service in any well that demonstrates an ability to flow unassisted to surface. Please retain a copy of this letter on the Grayling platform. Sincerely, r:-, :D r:J \'-JQ1!~ D- ~&7 James B. Regg '{ { Petroleum Inspection Supervisor cc: Bob Fleckenstein @~Ir Æ.^\ Ií~ t51) Ù ~J U lb (ill~ !Æ~!Æ~[ß!Æ ¡ ¡ l ! ¡ ¡ I / / i FRANK H. MURKOWSKI, GOVERNOR AI#ASIiAOILAND GAS COlfSERVATI ON COMMISSION April 26, 2004 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dwight Johnson Field Superintendent Unocal 260 Caviar Street Kenai, Alaska 99611 RE: No-Flow Verifications Well G-03RD2, PTD 183-010 Well G-04RD, PTD 181-183 Well G-13, PTD 168-057 Dear Mr. Johnson: On April 23, 2004, AOGCC Petroleum Inspector Chuck Scheve witnessed 3 "no flow tests" on Unocal's McArthur River Field, Trading Bay Unit, Grayling Platform: Well G- 03RD2, Well G-04RD, and Well G-13. Each well was opened to atmosphere through flow measurement equipment with suitable range and accuracy after being shut in and monitored for several hours. There was no flow of gas or liquid to surface during the tests. Based on the results of these no-flow tests, the subsurface safety valves may be removed from service in Wells G-03RD2, G-04RD, and G-13. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in each of the wells as required in 20 AAC 25.265. The subsurface safety valve must be returned to service in any well that demonstrates an ability to flow unassisted to surface. Please retain a copy of this letter on the Grayling platform. Sincerely, $ ~b~d~ Jame~. R~gg ( ( Petroleum Inspection Supervisor cc: Bob Fleckenstein MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg . ~eqq 'r/z¡",/ot P. I. Supervisor ( DATE: April 23, 2004 FROM: Chuck Scheve, Petroleum Inspector SUBJECT: No Flow Trading Bay Unit G-03 RD2 183-01 0 G-04RD 181-183 G-13 168-057 Friday. April 23. 2004: I traveled to Unocal's Grayling Platform and witnessed no-flow tests on wells G-03 RD2, G-04RD and G-13. I arrived on location and found all three wells bled off and opened to atmosphere with no flow of gas or fluid evident. All three wells were shut in and observed for several hours with no pressure build up observed. I recommend Wells G-03 RD2, G-04RD and G-13 on the Grayling Platform be approved no flow status for the purpose of removing the Sub Surface Safety Valve. SUMMARY: Wells G-03 RD2, G-04RD and G-13 meet the AOGCC requirements for no flow status. Attachments: ALASKA OIL /LND GAS CONSERVATION COMMISSION PETROLEUM WELL RECORD - Commission use only - o5/08/98 NUMBER NUMBER NAME NUMBER SRT NUMBER - CODE 81-0183-0 7332005001 TRADING BAY UNIT G-04RD 335 ADL0018730 18424 CODE I NAME CODE I AREA HOREI CMP ............ i 145000 UNION OIL CO OF CALIFORNIA 820 COOK INLET BASIN OFF 1 FLDPOL FIELD AND POOL -CODE I NAME 520120 MCARTHUR RIVER, HEMLOCK MULTIPLE POOLS 520150 000000 000000 000000 000000 + . ELEVATIONS UNIT' UNIT ..... ................ '~12070 TRADING BAY RT 99 10450 9606 194 + ............................... ..................... 1882 S 1389 E 29 09N 013W S 2046 S 4658 W 29 09N 013W S + + FOOTAGE DRILLED PERM SSSV 82 4475 DEV 1-OIL DEV 1-OIL NO NO RCV NO 50002 + -+ APPROVED ISSUED SPUDDED COMP, ETC DATE LAST UPD 03/22/82 12/17/81 12/17/81 02/10/82 04/23/98 + + ALASKA INDIVIDUAL WELL PRODUCTION AS OF .. 05/08/98 1988 JAN METH GAS LIFT DAYS 31 OIL 10,401 WTR 3,863 GAS 2,430 1988 TOTALS OIL 1989 JAN METH SHUT- IN DAYS OIL WTR GAS 1989 TOTALS OIL 1990 JAN METH . GAS LIFT DAYS' 9 OIL 993 WTR 2,.139 GAS 855 1990 TOTALS' OIL 1991 JAN METH' GAS LIFT DAYS 26 OIL 4,503 WTR' 12,325 GAS 1991 TOTALS OIL 1992 JAN METH 'GAS LIFT DAYS 31 - OIL 8,594 WTR 21,075 GAS 4,738 1992 TOTALS OIL 1993 JAN METH GAS LIFT DAYS 31 OIL 6,326 WTR 22,254 GAS 7,220 1993 TOTALS OIL 1994 JAN METH GAS LIFT DAYS 31 OIL 4,224 WTR 18,231 GAS 2,284 1994 TOTALS OIL FEB MAR GAS LIFT GAS LIFT 29 31 8,752 8,747 3,142 3,092 3,283 6,534 70,636 WATER APR MAY GAS LIFT GAS LIFT 30 31 6,974 7,898 3,158 3,584 434 31,419 FEB MAR APR SHUT-IN SHUT-IN SHUT-IN 46,174 WATER FE~ ~' GAS-LIFT GAS LIFT 3 335 652 24 14,049 9 ' 1,337 1,919 WATER- FEB GAS LIFT 30 9,751 17,300 4,268 WATER GAS LIFT 28 9,074 18,641 4,648 103,892 FEB MAR GAS LIFT GAS LIFT 29 31 9,160 9,365 20,598 19,900 7,913 4,969 92,019 WATER FEB MAR GAS LIFT GAS LIFT 28 31 5,601 5,251 18,682 18,532 5,691 3,226 60,988 WATER FEB MAR GAS LIFT GAS LIFT 28 31 3,839 4,225 16,247 19,763 2,289. 2,657 59,255 WATER 32,071 ~'. APR SHUT-IN 22,82'4 GAS LIFT 28 8,160 15,044 5,527 209,355 APR GAS LIFT 30 8,244 19,201 3,221 241,657 APR GAS LIFT 3O 5,871. 20,474 235,413 APR GAS LIFT 3O 4,088 18,475 2,655 266,500 JUN JUL AUG SEP GAS LIFT GAS LIFT GAS LIFT GAS LIFT 30 31 31 30 7,483 6,856 6,859 6,522 3,581 3,478 3,878 3,572 616 1,108 2,477 1,497 18,441 CUM OIL CUM WATER 1,313,411 MAY' JUN JUL AUG SEP SHUT-IN SHUT-IN GAS LIFT GAS LIFT GAS LIFT 24 31 30 7,257 9,206' 8,608' 4,347 5,375 4,847 1,314 1,960 1,898 GAS 11,659 CUM OIL 1,359,585 CUM WATER .. MAY JUN JUL AUG SEP SHUT-IN SHUT-IN SHUT-IN GAS LIFT GAS LIFT 7 29 534 3,086 '1,655 4,781 6,546 GAS 12,708 CUM OIL -1,373,634 CUM WATER MAY JUN JUL AUG -SEP GAS LIFT GAS LIFT GAS LIFT GAS LIFT -GAS LIFT 31 30 31 30 28 9,699 9,727 8,933 8,152 8,479 17,478 16,506 16,351 17,533 17,333 6,024 1,866 7,005 3,607 6,112 GAS 67,941 CUM OIL 1,477,526 CUM WATER MAY JT3N JUL AUG SEP GAS LIFT .GAS LIFT GAS LIFT GAS LIFT GAS LIFT 31 30 29 31 30 8,304' 7,579 6,530 7,161 6,396 20,518 19,847 18,728 20,902 19,333 4,840 3,204 6,388 8,168 1,811 GAS 50,126 CUM OIL 1,569,545 CUM WATER MAY JUN JUL AUG SEP GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT 31 30 31 22 30 5,981 5,566 5,482 3,559 4,734 21,133 21,855 23,606 14,589 17,756 1,884 2,481 1,873 GAS 30,762 CUM OIL 1,630,533 CUM WATER MAY JUN JUL AUG SEP GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT 31 30 31 31 30 4,560 4,663 5,552 5,556 5,785 21,901 21,310 22,348 22,968 28,780 3,258 2,044 2,973 2,809 4,077 GAS 36,223 CUM OIL 1,689,788 CUM WATER OCT GAS LIFT 3 144 71 62 548,517 OCT GAS LIFT 31 8,574 5,578 3,581 580,588 OCT GAS LIFT 31 2,559 4,344 3,048 603,412 OCT GAS LIFT 31 9,462 17,854 13,093 812,767 OCT GAS LIFT 31 6,776 20,049 900 1,054,424 OCT GAS LIFT 31 4,326 18,839 2,500 1,289,837 OCT GAS LIFT 31 5,958 27,847 3,366 1,556,337 NOV SHUT-IN CUM GAS NOV GAS LIFT 30 7,598 5,856 1,835 CUM GAS NOV GAS LIFT 30 2,627 3,733 2,143 CUM GAS NOV GAS LIFT 3O 8,971 21,838 10,763 CUM GAS NOV GAS LIFT 30 6,542 19,317 1,475 CUM GAS NOV GAS LIFT 30 4,084 18,490 3,764 CUM GAS NOV GAS LIFT 30 5,490 26,797 3,551 CUM GAS DEC SHUT-IN 361,705 DEC GAS LIFT 29 4,931 6,068 1,071 373,364 DEC GAS LIFT 31 2,578 3,601 92 386,072 DEC GAS LIFT 31 8,981 21,152 5,028 454,013 DEC GAS LIFT 31 7,368 22,189 2,499 504,139 DEC GAS LIFT 31 4,207 19,203 2,123 534,901 DEC GAS LIFT 31 5,315 21,833 4,260 571,124 ALASKA INDIVIDUAL WELL PRODUCTION AS OF 05/08/98 1995 JAN FEB MAR METH GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 OIL 4,803 5,215 5,264 WTR 24,895 24,107 21,437 GAS 3,143 4,473 4,247 1995 TOTALS OIL 64,804 WATER 1996 JAN FEB MAR'. METH GAS LIFT GAS LIFT GAS LIFT DAYS 31 29 31 OIL 5,025 4,729 5,632 WTR 22,646 22,292 26,499 GAS 3,870 3,346 4,782 1996 TOTALS. OIL 68,850 WATER APR MaY JUN JUL AUG SEP OCT NOV GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT 30 31 30 31 31 30 31 30 5,623 6,355 6,050 5,315 4,702 4,678 5,934 5,593 26,938 26,450 24,868 26,547 28,976 27,390 28,356 19,510 6,025 4,326 5,165 3,920 3,740 4,167 3,163 4,278 303,252 GAS 50,574 CUM OIL 1,754,592 CUM WATER 1,859,589 CUM GAS APR MaY'' JTJN JUL AUG SEP OCT NOV GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT 30 31 30 31 31 30 31 30 5,182 6,064 7,392' 6,121- 5,876 5,489 5,294 5,295 25,688 30,041 29,791 32,633 33,906 32,065 32,251 32,177 3,843 6,263 6,303' 5,780 5,022 3,422 3,419 3,351 359,924 'GAS 54,943 CUM OIL 1,823,442 CUM WATER 2,219,513 CUM GAS 1997 JAN FEB MAR- APR METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 28 OIL 6,410 5,504 6,031 4,666 WTR 43,969 38,801 42,727 47,277 GAS 4,984 4,470 4,570 6,198 1997 TOTALS OIL 58,117 WATER 569,412 1998 JAN FEB MAR. APR' METH GAS-LIFT GAS LIFT GAS LIFT DAYS 31 25 19 OIL ._ 3,996 2,921 3,825 WTR 40,977 31,140 19,043' GAS 3,586 1,992 2-,012 1998 TOTALS OIL 10,742 WATER 91,160 FIELD/POOL: MCARTHUR RIVER, MIDDLE KENAI G 1998 JAN FEB MAR APR METH GAS LIFT DAYS 19 OIL 4,675 WTR 6,691 GAS 2,460 1998 TOTALS OIL 4,675 WATER 6,691 MaY JUN JUL 'AUG SEP GAS LIFT GAS LIFT GAS LIFT'- GAS LIFT GAS LIFT 31 ' 30 30 31 30 -5,341 5,914 4,886 4,024 4,088 45,809 48,304 52,640 61,680 46,174 3,033 4,404 2,879' 2,765 1,722 GAS 40,795 CUM OIL 1,881,559 CUM WATER MAY' JUN 0-U-L' AUG SEP DEC GAS LIFT 31 5,272 23,778 3,927 621,698 DEC GAS LIFT 31 6,751 39,935 5,542 676,641 GAS 7,590 CUM OIL SALES CD - 50 ACCT GRP - 002 ** OIL PRODUCTION ** MaY JUN JUL OCT NOV DEC GAS LIFT GAS LIFT GAS LIFT 31 30- 31 3,793 3,688 3,772 51,350 48,648 42,033 2,622 1,536 1,612 2,788,925 CUM GAS 717,436 OCT NOV DEC GAS 2,460 CUM OIL 1,892,301 CUM WATER 2,880,085 CUM GAS FINAL STATUS: DEV 1-OIL CURRENT STATUS: AUG SEP OCT NOV DEC 4,675 CUM WATER 6,691 CUM GAS 725,026 2,460 . .. ALASKA INDIVIDUAL WELL PRODUCTION AS OF 05/08/98 WELL-NAME: TRADING BAY UNIT G-04RD API: 733-20050-01 LEASE: ADL0018730 OPERATOR: UNION OIL CO OF CALIFORNIA FIELD/POOL: MCARTHUR RIVER, HEMLOCK SALES CD - 50 ACCT GRP - 002 FINAL STATUS: DEV 1-OIL CURRENT STATUS: ** OIL PRODUCTION ** 1982 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 11 30 31 . -30 31 31 30 31 30 .. OIL 15,7511 51,375 50,678 45,032 45,051 42,166 41,759 41,477 36,853 WTR 4,400 9,358 9,571 9,201 10,024 10,446 9,512 8,939 8,588 GAS 4,263 9,920 9,037 ' 10,203 11,353 13,050 6,405 14,097 11,850 1982 TOTALS OIL 407,171 WATER 89,647 GAS 106,522 CUM OIL . 407,171 CUM WATER 89,647 CUM GAS 1983 JAN ' FEB' MAR METH GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 OIL 36,574 32,449 32,813 WTR 8,509 7,258 8,962 GAS 19,293 24,493 7,171 1983 TOTALS OIL 318,572 WATER APR MAY JUN JUL AUG SEP OCT NOV GAS LIFT GAS-LIFT GAS LIFT GAS LIFT GAS'LIFT GAS LIFT GAS LIFT GAS LIFT 30 31 30 31' 31 30 31 30 . . 31,263 30,733 26,226 28,197 16,418' .20,227 22,208 19,963 9,571 9,849 10,534 9,713 17,004 18,588 18,964 16,542 968 350 2,156 3,372 8,074 5,596 4,764 5,387 151,683 GAS 85,426 CUM OIL -725,743 CUM WATER 241,330 CUM GAS 1984 JAN FEB MAR METH GAS LIFT GAS LIFT GAS LIFT DAYS .31- 29 31 OIL 19,347 15,536. 13,703 WTR 14,787 ' 14,479 15,809 . GAS 1,526 443 1984 TOTALS OIL 117,708 WATER 1985 JAN FEB MAR METH GAS LIFT GAS LIFT GAS LIFT DAYS 31' 28 31 OIL 6,159 '6,112 7,096 WTR 11,053 12,074 13,403 GAS 2,727 8,457 -8,335 1985 TOTALS OIL 66,758 WATER APR MAY JUN 0-U-L GAS LIFT. GAS LIFT GAS LIFT'GAS-LIFT 30 31 -30' 31 11,.181' 9,336 6,372 6,566' 14,462 13,728 8,918 7,501 276 824 1,381 534 151,162 GAS 8,613 CUM OIL AUG- SEP GAS LIFT GAS LIFT -31 30 6,385 8,354 8,446 13,591 290 843,451 'CUM WATER DEC GAS LIFT 31 37,029 9,608 16,344 106,522 DEC GAS LIFT 31 21,501 16,189 3,802 191,948 1986 JAN FEB MAR METH GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 OIL 20,460 - 16,745 18,323 WTR 1,890 2,033 2,493 GAS 3,280 6,385 10,215 1986 TOTALS OIL 189,822 WATER 1987 JAN FEB MAR METH GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 OIL 12,124 11,363 12,903 WTR 4,090 2,752 3,205 GAS 1,786 1,756 1,455 1987 TOTALS OIL 142,744 WATER OCT NOV DEC GAS LIFT GAS LIFT GAS LIFT 31 30 31 8,182 6,594 6,152 14,529 12,823 12,089 244 187 2,908 392,492 CUM GAS 200,561 APR MAY JUN JUL AUG SEP OCT NOV GAS LIFT GAS LIFT SHUT-IN SHUT-IN SHUT-IN SHUT-IN GAS LIFT GAS LIFT 11 8 9 30 2,498 1,276 3,765 18,252 5,513 3,032. 661 558 1,910 2,984 2,315 9,334 48,118 GAS 40,215 CUM OIL 910,209 CUM WATER 440,610 CUM GAS APR MAY JUN JUL AUG SEP OCT NOV GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT 30 31 30 31 31 30 31 30 16,234 14,655 15,491 17,288 16,806 14,757 13,653 13,081 4,188 3,607 3,577 4,595 4,046 3,191 2,949 3,744 3,733 7,313 8,191 7,255 3,340 3,821 4,309 6,725 40,509 GAS 67,049 CUM OIL 1,100,031 CUM WATER 481,119 CUM GAS APR MAY JUN . JUL AUG SEP OCT NOV GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT 30 31 30 31 31 30 31 30 10,174 14,333 14,493 14,918 13,458 9,609 8,599 7,981 3,230 3,199 3,430 3,854 1,878 2,310 2,333 2,050 2~037 2~283 2~214 3,105 2,352 3,760 5,201 5,881 35,979 GAS 35,439 CUM OIL 1,242,775 CUM WATER 517,098 CUM GAS DEC GAS LIFT 31 21,600 1,824 4,153 240,776 DEC GAS LIFT 31 12,329 4,196 2,482 307,825 DEC GAS LIFT 30 12,789 3,648 3,609 343,264 STATE OF ALASKA ( ALASKA(,..,.- AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: X Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: X KB: 103' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, AK 99519 Service: Trading Bay Unit 4. Location of well at surface 8. Well number 1882' FSL, 1389' FEL, Sec. 29, T9N, R13W, SM G-4RD At top of productive interval 9. Permit number/approval number 2295' FSL, 1352' FWL, Sec. 28, T9N, R13W, SM 81-183 At effective depth 10. APl number 2040' FSL, 1875' FWL, Sec. 28, T9N, R13W, SM 50- 733-20050-01 At total depth 11. Field/Pool 2033' FSL, 1888' FWL, Sec. 28, T9N, R13W, SM McArthur River/Hemlock 12. Present well condition summary ; Total depth: measured 10450 feet Plugs (measured) true vertical 9617 feet Effective depth: measured 10420 feet Junk (measured) Junk @ 10,392' true vertical 9591 feet Casing Length Size Cemented Measured depth True vertical depth Structural 362' 26" Driven 362' 362' Conductor 621' 16" 1200 sx 621' 621' Surface Intermediate 3043' 13-3/8" 3100 sx 3043' 3003' Production 5970' 9-5/8" 1300 sx 5970' 5715' Liner 10450' 7" 725 sx 10450' 9601' Perforation depth: measured true vertical Please see attachment.ORIGINAL Tubing (size, grade, and measured depth) 3-1/2",9.3#, L-80 @ 9,241' 3-1/2",9.3#, L-80 from 10,153 to 10,312' Packers and SSSV (type and measured depth) Baker FB-1 perm. pkr. @ 9,150'; FB-1 straddle pkrs. @ 10,153~1~3~'~;)t~s~¢~@ 372' 13. Stimulation or cement squeeze summary Intervals treated (measured) ~ 10 998 Treatment description including volumes used and final pressure ".j~a$~ 0~1 & Gas C0[IS. Anchorage 14. Representative Daily Averaoe Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2/14/98 145 77 1309 1370 100 ,., Subsequent to operation 3/19/98 590 376 1516 1290 85 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: ,)( Oil: x Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: /~ ~,~ ~1/,,,'-''~ Dale A. Haines Title: Drilling Manager Date: April 4, 1998 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLI CATE PERFORATION DATA SHEET GRAYING G-4RD Reperforate Hemlock W/4-5/8 TCP Guns, 6HPF, 60 Phase. Date Zone Interval MD Interval TVD 3/8/98 HB-1 9,815' - 9,843' 3/8/98 HB-3 9,965' - 10,016' 3/8/98 HB-4 10,024' - 10,146' 9,051' - 9,075' 9,179' - 9,223' 9,230'- 9,336' Perforate Hemlock W/4-1/2 H. Carrier Guns, 12HPF, 30 Phase. 3/8/98 HB-6 10,325' - 10,355' 9,491' - 9,518' 3/8/98 HB-7 10,364' - 10,392' 9,526' - 9,550' Isolated 3/98 W/straddle pkrs. 4/4/97 HB-5 10,024' - 10,146' 5/28/96 HB-6 10,300' - 10,305' 9,367' - 9,372' 9,469' - 9,474' SPF 12 12 Perforate Tyonek W/4-5/8 TCP Guns, 6HPF, 60 Phase. Date Zone Interval MD 3/9/98 G-1 Zone 9,295' - 9,320' 3/9/98 G-2 Zone 9,345'- 9,365' 3/9/98 G-3 Zone 9,436' - 9,456' 3/9/98 G-4 Zone 9,486' - 9,537' 3/9/98 G-5 Zone 9,587' - 9,672' Interval TVD 8,612' - 8,633' 8,654' - 8,671' 8,731' - 8,748' 8,773' - 8,816' 8,857'- 8,929' SPF 1 4/3/98 UNOCALe Grayling G-4RD Workover Daily Summary 3/1/98 to 3/13198 G-4RD Workover Daily Summary 3/1/98 3/2/98 3/3/98 3/4/98 3/5/98 Set BPV, ND tree, NU BOPE. Test BOPE to 250 psi and 5000 psi, annular preventer to 3500 psi. Pulled tubing seal assembly from BWD perm packer. POOH laying down 2-7/8" gas lift completion. MU packer milling assembly. PU 3-1/2' drill pipe and RIH with packer milling assy. Mill packer from 9,722'-9,724' dpm. Packer feel free, unable to determine if was latched. RIH and tag with packer at 10,322'. Circ and POOH with packer. Recovered packer plus 35' of slickline wrapped around packer stub. RIH with 2- 7/8" tbg stinger, wash and work stinger from 10,314' to 10,363'. Circ small amount of sand to surface, reverse circ with minimal sand to surface. POOH with stinger, tight hole from 10,287' to 10,256'. Junk baskets recovered 2' slickline and 34# metal (packer slips pieces, perf debris, ground metal) 3/6/98 RIH with washover assembly with 2 sets of Bowen fingers. Tag fish at 10,349', wash down to 10,356'. Circ hi-vis sweep. Packed off when sweep turned calmer and stuck drill pipe. Jar pipe free.. Continue washing down to 10,420'. Circ hole clean. POOH, tight spots at 8858'-8919'. Jarred free and circulated to free pipe. Recovered frac sand at surface. Continued POOH with more tiqhts spots all the way up (junk on top of washpipe is being dragged out of the hole)~ 3/7/98 Continued slow trip out of hole. Recovered 5' of one wireline tool fish and 8" of another wireline tool fish. Washpipe badly scarred. 3/8/98 RIH with junk mill and casing scraper. Tag bottom at 10,412', wash and ream to 10,416' with erratic torque. Circ and POOH with no problems. RU Schlumberger and perforate 10,364'-10,392' (Hemlock Bench 7, guns were as on bottom and could not' be run any deeper). Perforate 10,325'-10,355' (Hemlock Lower Bench 6). RD Schlumberger. 3/9/98 RIH with TCP perf guns, tie-in with GR through drill pipe. Perforate underbalanced G-1 9295'-9320', G-2 9345'-9365', G-3 9436'-9456', G-4 9486'-9537', G-5 9587'- 9672', H-1 9816'-9843', H-3 9968'-10016', H-4 10024'-10146'. Circ, POOH with spent guns. 3/10/98 RIH with cleanout assembly. Tag at 10,405', wash to 10,416'. POOH. RU Schlumberger and set Baker Model FB-1 perm packer at 10,312'. Test BOPE. Clean debris from ram cavities. Finish BOP test.~ F IV ,,3998 Ala, s'k~ Oil & Gas Cons. Commissl.o,a ?~chorage 4/3/98 UNOCALe Grayling G-4RD Workover Daily Summary 311/98 to 3113/98 G-4RD Workover Daily Summary (Cont.) 3/11/98 RIH with upper FB-1 straddle packer and tailpipe. Stab into lower packer at 10,312' ans set upper packer at 10,168' dpm. POOH with setting tool and drill pipe. RIH with Baker FB-1 permanent injection packer on drill pipe and set at 9150'. 3/12/98 RIH with 3-1/2" tubing and gas lift mandrels. Stab into packer seal bore. PU and circ annulus to 3% KCL/fresh water with 1% corrosion inhibitor. 3/13/98 Space out and land tubing. Set BPV and ND BOPE. NU and test tree to 5000 psi. Move rig from G-12RD2 to G-16. 2 4/3/98 Trading Bay Unit, Grayling Platform We[l G4RD As Completed, 3/12/98 RKB to tubing hgr = 41.34' T()(i (w 8800' i G Peris 9295'0320' 9345'-9365' 15 9436' -!1456' 9486'-953T G~ l 9587'-9672' Reperf 3/9/98 (}-3 [1-I,3,~ (}-4 9816' -9843' (7-5 9968~- 10016' H-I 10024'd014C 14 H-6 Sm~ddle Pkr H~7 I5 H-6 & 7 10364'- 10392' Wireline Tool Pieces T()F (~ 10,392' ELM PBTD = 10,42{P 'I'D = 1045{P Max angle = 33° @ 9500' SIZE WT GRADE CONN TOP BTM I,ENGTH 16" 75 J~55 Surf 62 I' t 3-3/8" 61 N-gO Surf 3043? %5/8" 40~47 N-80 Surf 5970' (fop ot Window) 7" 29 N-gO St~rf 10450' 10450' Tubing: 3-1/2" 9.3 1,-80 ][3ult SC Surf 9241' 9241' JEWELRY DETAIL NO. Depl[h Item A 42 4-1/2" ASL hgr trip & btm w/3-l/2"Butt xover below B 372 3-1/2" i'1!-5 TRSSSV, 5,380" OD 1 2522 Macco 3-t/2" Gl .M w/I' GIV and B K-2 latch 2 4126 Macco 3-1/2" GLM w/l" GI.V and BK-2 taich 3 5444 Macco 3-1/2" Gi,M w/l' Gt.V iuld BK-2 talch 4 6163 Macco 3-1/2" GI,M w/l" G1 ~V and BK-2 latch 5 6692 Macco 3-1/2" GLM w/l" GLV and BK-2 latd~ 6 7186 Macco 3-1/2" GluM w/l' G/,V and BK-2 latch 7 7619 Macco :3-1/2" G] ,M w/l' GI.V and B K-2 latch 8 8083 Macco 3-1/2" GLM w/l' GLV ~md BK-2 latch 9 8610 Macco 3d/2" GLM w/[' GLV and BK-2 latch 10 9106 Macco 3--1/2" GLM w/l' orif and BK-2 latch 11 9150 9156' tbg rally. Model FB-I pkr with 4.00" bore 12 9207 3d/2' X nipple. 2.81Y' Ill) 13 9241 3-1/2' Tubing Tail Wireliue Re-entry Guide 14. 10153 Baker M~KIet },'B-1 straddle pkr, 4.000" iD, drill pipe 3-1/2" I.-80 butlress robing SC Baker M(×iet VB-1 straddle pkr, 4.000" tD. E-line Qpen Hemlock Perforatio~ks 10312 929%9320 3/9/98 TCP 9345-9365 3/9/98 TCP 9436-9456 3/9/98 TCP 9486-9537 3/9/98 TCP 9587-9672 3/9/98 TCP 9815-9843 3/82, Last Reperf 3/9/98 TCP 9965-10016 3/82. Last Reperf 3/9/98 TCP 10024-i0146 4/85, l?aced 4/85, Last Reperl 3/9/98 T(P 10325d0355 3/8/98, 12 spf4-l/2" casiug guns 103(~-I0392 3/8/98. 12 spf4-1/2" casing guns ABANDONED HEMLOCK PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 9758 9760 3/11/82 Sqzd w/190 sx 9852 9854 3/10/82 Sqzd w/100 sx 9862 9882 9/5/83 Sqzd 4/20/85 9960 9962 3/9/82 sqz w/100 sx 4/19/85 10102 10104 4/19/85 Sqzd wi00 sx 10162 1016~ 3/15/82 Sqzd w/200 sx 10182 10188 ]kt~5 4/4/97, (straddle pkr, 3/98) 10300 10305 tt-6 5/28/96. (straddle pkr~ 3/98) SchfinalG4.doc RIiVISED: 4/3/98 DRAWN BY: TAB MEMORANDUM TO: David Jo~ Chairman THRU: Blair Wondzell, d~~ P. I. Supervisor /~!~-~ ~'~' State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 16, 1997 FILE NO: 1 ujkdpee. DOC FROM: Chuck Scheve, Petroleum Inspector Wednesday April 16,1997: test on Wells G-4 & G-26. SUBJECT: No Flow Test McArthur River Field Grayling Platform Wells G-4 & G26 ~-~R ~l-t~ I traveled to Unocals Grayling Platform and a NO-FLOW The subject Wells had been bled down prior to my arrival on the platform. The wells were lined up to the well clean tank and observed for 3 hours with no gain in volume observed. Both Wells were then shut in for 1 hour with no pressure build up observed. I recommend approval of NO-FLOW status for these two wells .SUMMARY: I witnessed a successful NO-FLOW test on Unocals G-4 & G26 Wells (Grayling Platform ) in the McArthur River Field. ' - - - X Unclassified Classified .... Unclassified with Document Removed Unocal Corporatil( Oil & Gas Operatio~ 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (90?) 276-7600 UNOC, February 29, 1996 Alaska Mr. Dave Johnston, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Re: Grayling Platform Well, G-4RD ~'/-/~'= APl Number 50-733-20050-01 On July 14, 1993 Unocal terminated the coil tubing cleanout (requested by Application for Sundry Approval and approved 6/17/93 No. 93-152). The operation was abandoned after the CTU tagged a fish in fill at 10,382', and couldn't clean past it. Please cancel the Sundry Request as this project is no longer considered practical. Very truly yours, . Candace Williams Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 March 13, 1995 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 On September 5, 1994 the following intervals were perforated in well G-4RD (API 50-733-20050-01) in the McArthur River Field: BENCH TOP (MD) BoTroM (MD) HBI 9815 9842 27 HB3 9965 10,015 50 TOTAL 77 FEET Sincerely, STATE OF ALASKA _ ALASI<~i'I'~' )IL AND GAS CONSERVATION,,r'~ 'MISSION REPO( ,.,3F SUNDRY WELL 0.._ _RATIONS 1. Operations performed: Operation shutdown Stimulate Plugging __ Perforate X 2. Name of Operator Unocal Pull tubing __ Alter casing__ Repair well __ Pull tubing ~ Otherm Location of well at surface 1882' N, 1389' W of SE Cor., Sec. 29, T9N, R13W, SM At top of productive interval 2183' N, 1592' E of SW Cor., Sec. 28, TgN, R13W, SM At effective depth 2042' N, 1888' E of SW Cot., Sec. 28, TgN, R13W, SM At total depth 2045' N, 1880' E of SW Cot., Sec. 28, TgN, R13W, S< 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. 5. Type of Well: Development X_ Exploratory ~ Stratigraphic __ 6. Datum elevation (DF or KB) KB: 103' 7. Unit or Property name Trading Bay Unit 8. Well number G-4RD feet 9. Permit number/approval number 81-183/94-231 10. APl number 50-733-20050 -01 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured true vertical 10,450 feet 9617 feet Effective depth: measured 10,420 true vertical 9591 feet feet Plugs (measured) Junk (measured) 0 ; 1Gii iAL,, Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented 362' 26" Driven 621' 16" 1200 sx Measured depth 362' 621' 3043' 13- 3/8" 3100 sx 3043' 5970' 9- 5/8" 1300 sx 5970' 10,450' 7' 725 sx 10,450' 9815-9842, 9862-9882, 9965-10015, 10027-10145 True vertical depth 362' 621' 3003' 5715' 9601' true vertical 9067 -9090, 9107-9124, 9195 -9238, 9249 -9351 Tubing (size, grade, and measured depth) 2-7/8", 6.4#, N-80 @ 9772' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Otis BWD perm. pkr. @ 9720', Otis BXE SSSV @ 369' 14. Intervals treated (measured) APR 2. 0 1995 Treatment description including volumes used and final pressure ~taska Oil & Gas Cons. Commission Representative Daily AveraRe Production or Injection Data An~0ra!)~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 183 155 715 1170 110 257 255 1074 1230 1230 ~ 5. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations _ Oil X_ Gas m Suspended -~ 7. I here, by certify that the foregoing is true and correct to the best of my knowledge. !:orm 10-404 Rev 06/15/88 Service Date ("1 I(~ (~ SUBMIT IN DUPLICATE .{ Unocal North Ame~' -- Oil & Gas Divisio¥ Unocal Corporation I. P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 IJNOCAL ) Alaska Region Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 August 19, 1994 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: This is to inform you of Unocal's intent, upon your approval, to perforate the following intervals in well G-4RD (API# 50-733-20050-01) on the Grayling platform. BENCH TOP (MD) BOTTOM (MD) FEET I-lB1 9,815 9,842 27 HB3 9,965 10,015 50 . TOTAL 77 Sincerely, RECEIVED AUG 2 4 1994 Oil & Gas Cons. Commission Anchorage, STATE OF ALASKA ALA,~K-' '~IL AND GAS CONSERVATION APPLI{. ., ION FOR SUNDRY "41SSION , ROVALS 1. Type of request: Abandon __ Suspend __ Alter oaaing__ Repair well __ Change approved program __ Operstione shutdown __ Re-enter suspended well__ Plugging __ Time extension __ Stimulate __ Pull tubing __ Vadanoe __ Perforate X_ Other 2. Name of Operator Unocal 3. Address . P.O. Box 196247 Anchorage, Alaska 99519-6247 Location of well at surface 1882' N & 1389' W from SE cor., Sec. 29, T9N, R13W, SM At top of productive Interval 2183' N & 1592' E from SW cor., Sec. 28, T9N, R13W, SM At effective depth 2042' N & 1888' E from SW cor., Sec. 28, T9N, R13W, SM At total depth 2045' N & 1880' E from SW cor., Sec. 28, T9N, R13W, SM 5. Type of Well: ~X_ SaaUgm~h~ __ 6. Datum elevation(DF or I~) KB 103' above MSL 7. Unit or Property name Trading Bay Unit 8. Well number G-4RD feet g. Permit number ~ ~J'/~ G' 10, APl number 50-733-20050-01 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured 10450 feet true vertical 9617 feet Effective depth: measured 10420 feet true vertical 9591 feet Casing Length Structural 362' Conductor 621' Surface Intermediate Production Uner Plugs (measured) Junk (measured) ORIGINAL Size Cemented Measured depth True vertical depth 26' Driven 362' 362' 16' 1200 sx 621' 621' 3043' 13-3/8" 3100ex 3043' 3003' 5970' 9-5~" 1300ex 5970' 5715' 10450' 7' 725sx 1045~ 9601' Perforation depth: measured 9815 - 9842, 9862 - 9882, 9965 - 10015, 10027 - 10145 true vertical 9067 - 9090, 9107 - 9124, 9195 - 9238, 9249 - 9351 Tubing (size, grade, and measured depth) 2-7/8", 6.4#, N-80 buttress @ 9772' Packers and SSSV (type and measured depth) Otis BWD perm. pkr. @ 97313', Otis BXE SSSV @ 369' RECEIVED 13. Attachments Description summary of proposal X_ Detailed operations program~__ BOP sketch Questions? Call Hal Martin (~ 263-7675 or Ralph Holman (~ 263-7838 . 14. EStimated date for commencing operation ri 5. Status of well classtr~ation as: September 5, 1994 / ' 16. If proposal was verbally approved / Oil X_ Gas __ Suspended __ Name of approver Date approvedI Service 17. I here{~t(.cerlif~that the ~re.qoir~ is,true aj3~l~orrect to the best of my knowledge. Conditions of approval: Notify Commission so representative may witness Plug Integrity _ BOP Test_ Location clearance _ Mechanical Integrity Te~__ Subsequent form required 10- FOR COMMISSION USE ONLY Oavid W. Johnston Approved by the order of the Commission Commissioner Form 10-403 Rev 06/15/88 ~.,.t.IO 2 4 1994 .l~.,~l~a t.,,, ~, Gas Cons. C0mm Anchor~,ee IApproval No. Date ~ --~ ~ ~ SUBMIT IN ~IPECA~ ;sion August 19, 1994 Grayling Platform, Well G~RD Perforating Procedure 1. Hold safety meeting. 2. Rig up electric line unit. 3, Pressure test lubricator to 2500 psi for five minutes. Note: A pump-in sub with a valve is required. 4. Shut down all welding and radio transmissions. . Run in hole and perforate intervals as instructed by Unocal wimess. (When gun is 200' below surface, welding and radio transmissions may resume.) Pull out of hole. (When gun is 200' below surface, shut down all welding and radio transmissions.) 7. Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH INTERVAL FEET HB1 9,815-9,842 27 HB3 9,965-10,015 50 TOTAL: 77 RECEIVED AUG 2 4 1994. A~aska Oil & Gas Cons. Commission Anchor~.~ 1. Type of request: A STATE OF ALASKA f'lop AND GAS CONSERVATION COMIC, ,ION AP P LI · ON FOR SUNDRY APPROVALS Abandon ~ 8uepend __ Operations ~hutdown __ Re-enter ~uspended well__ Alter ~asing__ Repair well __ Plugging __ 'nme extension __ Stimulate __ Change approved program __ Pull tubing __ Va~n~e __ Perforate x__ OtherX__ 2. Name of Operator 15. Type of Well: I UNION OIL COMPANY OF CN. IFORNIA (UNOCAL) r=xr~xatow __ 3. Address Sa'a~.~hic P.O. BOX 196247 ANCHORAGE. AK 99519 Sen,be ~ 4. Location of well at suface LEG #2 CONDUCTOR #39, GRAYUNG PLATFORM 1882' N & 1389'W F/SE corner, Sec. 29, R9N, R13W, SM At top of productive intewal 2183'N, 1592'E F/SW corner, Sec. 28, T9N, R13W, SM At effective depth 2042'N, 1888' E F/SW corner, Sec. 28, T9N, R13W, SM At total depth 2045'N, 1880' E F/NW corner, Sec. 28, T9N, R13W, SM 6. Datum elevation (DF or K~/ 103 KB above MSL feet 7. Unit or Property name TRADING BAY UNIT 8. Well number G-4RD 9LPermit number ~/89-259 10. APl number 50 -733 -20050 -01 11. Field/Pool MCARTHUR RIVER/HEMLOCK Present well condition summary Total depth: measured true vertical 10,450' feet Plugs (measured) 9,601' feet Effective depth: measured true vertical 10,420' feet Junk (measured) 9,575' feet Casing ,.. Length Structural 362' Conductor 621' Surface Intermediate 3043' ' ' Production 5970' Uner 10,450' Perforation depth: measured true vertical Size Cemented Measured depth True vertical depth 26" Driven 362' 362 16" 1200 sx 621' 621' 13-3/8' 9-5/8" 7" Uppermost 9815' Lowermost 10,145' Uppermost 9051' Lowermost 9335' 3100 sx 3043' 1300 sx 5970' 725 sx 10,450' Tubing (size, grade, and measured deplh) 2-//8", 6.4#, N-80 Buttress @ 9772' Packers and SSSV (type and measured depth) 3003' 5715' 9601' RECEIVED J UN 1 4 1993 Nas.~.OJi & Gas Cons. Commission Otis "BWD" pe.rm packer @ 9720'/Otis "BXE" SSSV #~10~§~ 13. Attachments Description summary of proposal _ _ Detailed operations prOgramX__ BOP sketch X_ 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver I 5. Status of well classification as: 011 X_ Gas _ Date approved Service Suspendedm 17. I hereby~ '~~nd correct to the best of my knowledge. Signed G. Russell Schmidt Title Drilling Manager FOR COMMISSION USE ONLY Date June 8r 1993 Conditions o1 approval: Notify Commission so representative may witness Plug Integrity m BOP Test Location clearance Mechanical Integrity Testm Subsequent form required 10- "~ ¢~ ~ Original Signed By Approved by the order of the Commission David W. Johnston IApproval No. Approved Copy (o j r ,~ /' ~_ '~, Commissioner , uam~'-- Form 10-403 Rev 06/15/88 SUB MIT IN TRIPLICATE ( ! ~6"@ 621'i 3043' Z 9-5/8" @ 5970' TOP OF WINDOW A II1 _1 o'4 Illsfl is ii ii i il IB~I II III lB lB lB lei Bi B IIIII&U lille n · A) KELL~ BVSHXNG AT 0.00' B) CAMERON TUBXNG RAHGER AT 41.34' C) 16', 75~, J-55 CASING AT 621' D) 13-$18', 61~, N-80 CASING AT 3043' D £) 9-5/8', 40#, 43.5#° 47#, N-80 CASZNG AT 5970e (TOP OF WINDC)#J F! 7', 29#, N-80 CASING AT 10450* G) C~IENT R~P~AZNER AT 10420e ?UBZNG DETAIL 2-7/8*m 6,4#, N-80, EVT'fRE$8, SC CPLGS 4-1/2" ASL x 2-?/8" BOTT X-OVER A? 42.34' 2) 2-7/8" OTIS BALL VALVE AT 368.91' 3) 2-7/8' PlACeD GL~I #1 AT 2536.28' 4) 2-7/8' MACED GLH #2 AT 4484.33* 5) 2-7/8' H~cco GLM 13 AT $761.97' 6) 2-?/8' KA¢CO GLM #4 AT 5768.73t 7) 2-7/8' MACVAC) GL.u( #5 AT 7466.36* 8) 2-7/8' r~ACCO GT~! #6 AT 8216.42' ' 9) 2-?18' ~A¢CO GLH #7 AT 8746.65t 20) 2-7/8' MACC:O GL)I #8 AT 9708.39' 2-718' OTIS "XA' SLER'v'B AT 9727.18" 22) 2-7/8" CTTZS 'X" HXPPLB AT 9770.40' 2-718' GTXS W2REZ.:F~ RERHTR~ GUXDE BOTTOHAT 9772.01° 14J OTIS MODEL "Eid)" PBBMA-DRXLL PACKER&T 9720* UL~I A) OTXS SBZLL BORE BXTB~IEZOll PRGll 9723.94' TO 9731.66e DPN B) (:~XS $BJLT, AHE~ NZTR STRA2GBT '~' ZZ:)C~TCI~ FIWII9730.S2e TO 9740.90' TH 7" @ 10450' Z 14 ~F PBRFOBATZOM RBC~ORD ~mmmmmm.tlmmmmmlmlm 2/06/82 6070'-6072' SQUEEZED 5960'-5962' SQUEEZED 3/09/82 9960'-9962' ~/ ATTRt4~ SQZ 10162'-10164'v SQUEEZED 3/10/82 9852°-98540V SQUEEZED 3/11/82 g788'-9760' SQUBBZBD 3/21/82 9965'010015' PROD - OPEl 3/22/82 9815'-9842e PROD - OPEl 9/08/03 9965t-10018t PROD - OPEl 9818'-9842' PROD - OPEl 9862'-9882' PROD - OPEl 4/18/85 10X02'-10104' SQUEEZED 4/19/85 9965'-10015' SQUEEZED 4/20/85 9862'-9882' SQUEEZED 9815'-9842' SQUEEZED 4/22/85 x0070'-10080' ' ATTEm~ FRAC 4/24/85 10080'-10082' SQUEEZED 10060'-10070e SQUEEZED 4/28/0S 10060'-10070' SQUEBZED 5/01/85 10068'-10075~ ' SQUEEZED S/02/88 g824'-9834° PROD - OPEl $/06/08 10060'-10080' PROD - OPEl 7/04/89 9018'-9842t PROD - OPEN ~0027'-10145' PROD - opEl WELL TBUS G-4RD COMPLETION ( 7-6-89 ) UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE D J UN 1 4 199~ Alaska Oil & Gas Cons. Commission Anchorage General Work Procedure Coil Tubing Cleanout G-4RD 1. RU & test 1-1/2" coil tubing unit (maximum depth 10,420'). m RIH w! jet nozzle & tubing tail Iocator. Locate tubing tail & tag fill. Clean out fill to cement retainer at 10,420'. 3. RD CTU & release to E-line unit for HB7 perforating. 4. RU E-line & jet perforate 10,372' - 10,392'. JUN 1 4 1993 Alaska 0il & Gas Cons. Commission Anchorage TUE 14. : 16, ,~,' RRCTZC PZPE I'NSP P. 02 ~RCTIC -~ECOI/ Arctic Recoil, Inc. (907) 283-1980 P.O. BOX 2595 Kenai, Alaska 99611 RECEIVED J UN 1 4199a Alaska 0il & Gas Cons. Commission Raohorage ALASKA OIL AND GAS CONSERVATION COMMISSION n ,, i ,?. ~.:.i APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved orogram __ Operation shutdown __ Re-enter suspended well ~ Plugging m Time extension ~ Stimulate ~ Pull tubing __ Variance __ 'Perforate ~ Other 2. Name of Operator Union Oil Company of California (Unocal) 3. Address PO Box 190247, Anchorage, AK 99519-0247 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at sudace Cond. 39, Leg ~/2 1882' N & 1389' W FR SE CDr., Sec. 29, T9N, R13W, SM At top of productive interval 2183' N & 1592' E FR SW CDr, Sec. 28 T9N, R13W, SM At effective depth 2042' N & 1888' E FR SW CDr., Sec. 28, T9N, R13W, SM At total depth 2045' N & 1880' E FR SW CDr., Sec. 28, TgN, R13W, SM 12. Present well condition summary Total depth: measured 10,450 feet Plugs(measured) true vertical 9,617 feet Effective depth: measured 10,420 feet true vertical 9,591 feet 6. Datum elevation (DF or KB) KB 103' Above MSL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 362' 26" 621' 16" 7. Unit or Property name Trad~n~ Ball Unit 8. Well number 9. Permit number 67-61/9-259 10. APl number 50-- 733-20050-01 11. Field/Pool ~E~EI V LI~ feet 0CT 2 5 1991 Junk (measured) Alas.~{a-0il & Gas Cons. C0m~issi0n Anchorage Cemented Measured depth True vertical depth Driven 362 ' 362 ' 1,200 sx 621' 621' 3,043' 13 3/8" 3,100 sx 3,043' 3,003' 5,970' 9 5/8" 1,300 sx 5,970' 5,715' 10,450' 7" 725 sx 10,450' 9,601' measured 9815'-9842'; 9862'-9882'; 9965'-10,015'; 10,027'-10,145' true vertical 9067'-9090'; 9107'-9124'; 9195'-9238'; 9249'-9351' Tubing (size. grade, and measured depth) 2 7/8", 6.4~'~, N-80 Buttress @ 9772' Packers and SSSV (type and measured depth) Otis "BW'D" Perm. Pkr. @ 9720', Otis "BXE" SSSV @ 369' 13. Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal was verbally approved Oil Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of myknowledge. Signed .~--~, (~...~,.. Title ~, ,=,,..,~' % , { - - FOR COMMiS~ON USE ONLY r'~3' Conditions of ap'l~oval."Rotify Commission so representative may witness Plug integrity m BOP 'rest ~ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- Returned Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. RMITFt Suspended Date I Approval No. ?//...~'~.z// Commissioner Date SUBMIT IN TRIPLICATE . . . . , . , . October 21, 1991 G-4RD Perforatinq Procedure RU slick line, run gauge and tag bottom. Hold saftey meeting. RU electric line unit. Pressure test lubricator to 2,500 psi for five minutes. Shut down all welding and radio transmissions. RIH and perforate intervals as instructed by Unocal representative (welding & radio transmissions may resume when gun is 200' below surface). POOH (shut down all welding and radio transmissions). Repeat steps 5, 6 & 7 as needed to perforate in the following intervals: HB#1 Measured: 9,815'-9,842' 27' HB#4 Measured: 10,040'-10,150' 110' ~. 137' RECEIVED 0CT § 1991 Alaska Oil & Gas Cons. Commission AnchoraDe ,, ALASKA OIL AND GAS CONSERVATION COMMISSION 0 ~ REPORT OF SUNDRY WELL OPERATIONS Stimulate __ Plugging __ 1. Operations performed: Operation shutdown__ Pull tubing __ Alter casing ~ Repair well __ / m~nio~ ~z~ Company of California (UNO~AL) DevelopmentA Na of.O er to 5..'rypeofWelh ! Exploratory 3'Addr~s. SO. Box 190247, Anch, Ak., 99519-02~.7 Stratig..rap.hic ~ervlce Pedorate __ Other _~X 4. Location of well at sudace Grayling Platform, Leg 2, Conductor 39 1882' N, 1389' W f/SE cor., Sec. 29, T9N, R13W, S.M. At top of productive interval 2183' N, 1592' E f/SW cor., Sec. 28, T9N, R13W, S.M. At effective depth 2042'N, 1888' E f/SW cor., Sec. 28, T9N, R13W, S.M. At total depth 2045' lq, 1880' E f/SW cor., Sec. 28, Tglq, R13W, S.N. 6. Datum elevation(DF orMsKB)L 103' KB ABOVE 7. Ur~t or P.r. ooertv..name.. _ 'z'raozng ~ay un~ 8. Well number G-4RD feet 9. Permit numbgr/approval number 10. APl numl:fer 507--33-20050-01 11. Field/Pool McArthur River Field 12. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet Casing Length Structural . 362' Conductor 621' Surface Intermediate 3043' Production 5970' Liner 10450' Perforation depth: measured Size 26" 16" 13-3/8" 9-5/8" 7" true vertical Uppermost 9815' Lowermost 10145' Uppermost 9051' Tubing (size, grade, and measured depth:~°werm°st 9335' Cemented Driven 1200sx 3100sx 1300sx 725sx 2 7/8", 6.4#, N-80, Buttress @ 9772' Pac~rsandSSSV(~peandmeasureddepth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Measured depth True vertical depth 362' 362' 621' 621' 3043' 3003' 5970' 5715' 10450' 9601' RECEIVED DE0201989 Oil.& Gas Cons, Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mol Water-Bbl Casing Pressure Shutin prior to work Tubing Pressure 345 121 422 1180 105 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas_ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ROBERTS Title ENVIRONMENTAL ENGINEER Form 10-404 Rev 06/15188 SU BM IT IN DUPLICATE 16"@ 621' 3043' A 9-5/8"@ 5970' E TOP OF' WINDOW 1 2 o 3 o 4 o 5 o 6 o 7 o 8 ~o 9 o 10 XA 11 X 12 '"'"13 -- . 14 G 7" @ 10450' ~ % F lB C CASING AND AB~DON~IENT DETAXL · l· I····ll I·l · A) KELLY ROSRZNG AT 0.00' B) CAHERON TDRZNG RANGER AT C) 16°, 754, J-SS CASING AT 621' D) 13-3/8', 614, N-80 CASXNG AT 3043' D E) 9-5/8', 4Or, 43.5#, 47t, ~-80 CAS/NG AT 5970' ('lOP OF WINDOW) F) 7', 294, H-80 CASXNG A? %0450* G) CEHEI~RETAINER AT 1D420' TUBING DETAIL mmmmmm·mmmmmm 2-?/8'' 6.4#, N-80, BUTTRESS° SC CPLGS 4-%/2" ASL x 2-7/8" BUT'/' X-OVER AT 42.34' 2) 2-7/8" OTIS BALL VALVE AT 368.91' 3) 2-7/8" I,',ACCC) Gl,PI 41 AT 2536.38* 4) 2-7/8' MACCO GI~ 42 AT 4484.33' ' S) 2-7/8' HACCO GLt4 43 A? 576%.97' 2-7/8' HAC¢O GI24 d4 AT 5768.73' 7) 2-7/8' MACCO GLM tS AT 7460.36' 8) 2-7/8' I~C~O Gl,P/ #6 AT 82%6.434'-.' 9) 2-7/8' L~ACCOGLP/ ~7 AT 8746.65' 2-7/8' HACCO GL,~ 48 AT 9708.39'" 2-7/8' OTIS 'XA' SLEEVE AT 9727.~8' 2-7/8' OTIS 'X' N~PPLE AT 9770.40' %3) 2-7/8' OTiS W2RELINE REENTRY G~IDE BO"~"tOH AT %4) OTiS HODEL 'EKD' PERPIA-DR~L PACKER AT 9720' DPH A) OTIS SEAL BORE ~XTENSZON FROM 9723.94' TO 973%.66' DPH B) OTIS SEAL ASSY W~?H STRAIGHT '~' LOCAl'OR FROH 9730.52' TO 9740.90' TM PERPORATION RECORD 2/06/82 6070'-6072' SQUEEZED 5960'-5962' SQUEEZED 3/09/82 99604-9962* ATTEMPT ~0162'-%0264' SQUEEZED 3/%0/82 9852'-9854' SQUEEZED 3/%%/82 9758'-9760e SQUEEZED 3/2%/82 9965'-%00%5' PROD - OPEN 3/22/82 98%5'-9842' PROD - OPEN 9/05/83 9965'-~00%5t PROD - OPEN 98%5'-9842' PROD - OPEN 9862'-9882' PROD - OPEN 4/18/85 %0~02'-~0204' SQUEEZED 4/%9/85 9965'-%00%5' SQUEEZED 4/20/85 '9862'-9882' SQUEEZED 98%5'-9842* SQOEEZED 4/22/85 %0070'-%0080' ' ATTEMPT FRAe 4/24/85 10080'-10082' SQUEEZED 10060*-10070' SQUEEZED 4/28/85 %0060*-%0070* SQUEEZED 5/0%/85 %0065*-~0075~ ' SQUEEZED 5/02/85 98~4'-9834' PROD - 5/06/85 %0060*-%00800 PROD - OPEN 7/04/89 98%5*-9842~ PROD.- OPEN %0027~-%0%45~ PROD - OPEN WELL TBUS G-4RD COMPLETION ( 7-6-89 UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) DRAWN: DAC SCALE: NONE DATE: 10- 15-89 LEASE MCARTHUR RIVER , ALASKA REGION PAGE NO. i of WELL NO. G-4RD FIELD TRADING BAY UNIT DATE E.T.D. JOINTS Pup 31 17 24 24 31 41 63 70 10 Pup Pup XO DETAILS OF OPERATION, DESCRIPTIONS & RESULTS TUBING DETAIL DESCRIPTION LENGTH BOTTOM Otis Wireline Re-entry Guide 2-7/8" Otis "X" Nipple 2-7/8" 6.4~ N-80 Buttress Otis Locator Sub & Seal Assy 2-7/8" Otis "XA" SSD (Sleeve) 2-7/8" 6.4# N-80 Buttress 2-7/8" MACCO GLM TVD 8950' 2-7/8" 6.4# N-80 Buttress 2-7/8" MACCO GLM TVD 8300' 2-7/8" 6.4# N-80 Buttress 2-7/8" MACCO GLM TVD 7650' 2-7/8" 6.4# N-80 Buttress 2-7/8" MACCO GLM TVD 7000' 2-7/8" 6.4# N-80 Buttress 2-7/8" MACCO GLM TVD 6350' 2-7/8" 6.4# N-80 Buttress 2-7/8" MACCO GLM TVD 5500' 2-7/8" 6.4# N-80 Buttress 2-7/8" MACCO GLM TVD 4300' 2-7/8" 6.4# N-80 Buttress 2-7/8" MACCO GLM TVD 2500' 2-7/8" 6.4~ N-80 Buttress Otis Ball Valve Assy 2-7/8" 6.4# N-80 Buttress 2-7/8" 6.4~ N-80 Buttress 2-7/8" 6.4# N-80 Buttress 4-1/2" ASL x 2-7/8" Buttress C.I.W. Tubing Hanger Land Below Zero .72 9772.01 .89 9771.29 29.50 9770.40 10.38 9740.90 3.34 9730.52 12.01 9727.18 6.78 9715.17 954.98 9708.39 6.76 8753.41 523.48 8746.65 6.74 8223.17 743.31 8216.43 6.76 7473.12 740.84 7466.36 6.76 6725.52 950.03 6718.76 6.76 5768.73 1270.89 5761.97 6.75 4491.08 1941.20 4484.33 6.75 2543.13 2165.00 2536.38 2.47 371.38 304.71 368.91 13.50 64.20 7.86 50.70 0.50 42.84 1.00 42.3'4 41.34 41.34 TOP 9771.29 9770.40 9740.90 9730.52 9727.18 9715.17 9708.39 8753.41 8746.65 8223.17 8216.43 7473.12 7466.36 6725.52 6718.76 5768.73 5761.97 4491.08 4484.33 2543.13 2536.38 371.38 368.91 64.20 50.70 42.84 42.34 41.34 --0-- NOTES: 1) Tubing is 2-7/8", 6.4#, N-80, Buttress with special clearance couplings. 2) Drift and Hydrotest tubing to 4000 psi. 3) Otis 7" BWD Perma-Drill packer with "SBE" hyrdraulic set at 9720'. 4) Ran: 312 Jts tubing 3 pups 5) CIW "FBB" tubing hanger is 4-1/2" ASL top and bottom. RECEIVED Anchorage L DRILLING RECORD '{ ALASKA REGION PAGE NO. 1 of LEASE WELL NO. FIELD DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS PACKER DETAIL DESCRIPTION LENGTH BOTTOM TOP Otis "BWD" Perma-drill. Set on DP w/Hydraulic setting tool, 7" 26-32# (P/N 212 BWD 70400-A) Otis Seal Bore Extension (P/N 212 C 7060) 3.94' 9723.94'DPM 9720' DPM 7.72' 9731.66'DPM 9723.94' DPM UNOCAL WELL RECORD SHEET A PAGE NO. LEASE Tradinq Bay FIELD McArthur River WELL NO. G-4RD LOCATION: Conductor 39, Leq ~2, 1882'N, 1389' W f/SE Corner, Sec. 29, T9N, R13W, S.M. PERMIT NO. SERIAL NO. TD 10450' TVD 9592' DEVIATION (BHL) 156'N & 3282'E F/Surf Loc. COMPANY ENGINEER Chudanov, Harness, Leon SPUD DATE 6-22-89 COMP. DATE 7-07-89 CONTRACTOR Pool Arctic Alaska RIG NO. 54 TYPE UNIT National 1320 DRILL PIPE DESCRIPTION 3 1/2", 15.5~, E&S ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR RT TO MLLW RT TO DRILL DECK RT TO PRODUCTION DECK APPROVED 125' 228' 103' 23.3' 46.6' CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 16" 75~ Butt J-55 621' Cmt'd w/120Osx 13-3/8" 61~ Butt J-55 3043' Cmt'd w/3100sx 9-5/8" 40,43.5 & 47~ " N-80 5970' 7" 29~ " N-80 10451' Cmt'd w/1300sx Cmt'd w/725sx PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 2/06/82 2/06/82 3/09/82 6070'-6072' 9287'(Ret) Isolation 5960'-5762' 6050'(Ret) Isolation 9960'-9962' 10060'(Ret) Isolation Sqzd w/200 sx Sqzd w/100 sx No breakdown w/6500 psi surf press (69 pcf mud) 3/09/82 10162'-10164' 10420' Isolation 3/10/82 9852'-9854' 10420' Isolation 3/11/82 9758'-9760' 9796'(Ret) Isolation 3/21/82 3/22/82 9965'-10015' 10280'(Pkr) 9815'-9842' 10280'(Pkr) Product ion Production 9/05/83 9965'-10015' 10280'(Pkr) Production 9/05/83 9815'-9842' 10280'(Pkr) Production 9/05/83 9862'-9882' 10280'(Pkr) Production 4/18/85 10102'-10104' 10420' Isolation 4/19/85 9965'-10015' 10090'(Ret) Production Sqzd w/200 sx Sqzd w/100 sx Sqzd w/200 sx Open HB-3 8 SPF Open HB-1 8 SPF Open HB-3 4 SPF Open HB-1 4 SPF Open HB-2 4 SPF Sqzd w/32 sx Sqzd w/41 sx INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS 7/9/89 HB-1 & HB-4 345 45% 32 1180 105 196/64 121 350 8/21/89 HB-1 & HB-4 303 38.9% 32 1180 110 196/64 106 350 WELL HEAD ASSEMBLY TYPE: Cameron Iron Works - Shaffer CASING HEAD: Shaffer 13-3/8"-SOW x 12"-3M "KD" Housinq CASING SPOOL: CIW !2"-3M x 12"-3M "WF" Anchora:qe- TUBING HEAD: CIW Type "F" 12"-3M x 10"-5M TUBING HANGER: CIW FBB Hanqer, nominal 10" x 4-1/2" ASL Top & Bottom TUBING HEAD TOP: 10"-5M x4", 5M Sinqle Solid Block Valve Tree MASTER VALVES: 4"-5M CHRISTMAS TREE TOP CONN: 4-1/2" 8rd UNOCAL WELL RECORD SHEET A PAGE NO. LEASE Tradinq Bay FIELD McArthur River WELL NO. G-4RD LOCATION: Conductor 39, Leq ~2, 1882'N, 1389' W f/SE Corner, Sec. 29, T9N, R13W, S.M. PERMIT NO. SERIAL NO. TD 10450' TVD 9592' DEVIATION (BHL) 156'N & 3282'E F/Surf Loc. COMPANY ENGINEER Chudanov, Harness, Leon SPUD DATE 6-22-89 COMP. DATE 7-07- CONTRACTOR Pool Arctic Alaska RIG NO. TYPE UNIT National 1320 DRILL PIPE DESCRIPTION 3 1/2", 15.5#, E& ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR RT TO MLLW RT TO DRILL DECK RT TO PRODUCTION DECK APPROVED 125' 228' 103' 23.3' 46.6' CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION ~/20/85 9862'-9882' 9949'(Ret) Production Sqzd w/83 sx 4/20/85 9815'-9824' 9855'(Ret) Production Sqzd 4/20/85 9834'-9842' 9855'(Ret) Production w/46 sx ~/22/85 10070'-10080' 10090'(Ret) HB-4 Frac No breakdown w/7500 ps surf press 4/24/85 10080'-10082' 4/24/85. 10060'-10070' 4/28/85 10060'-10070' 5/01/85 10065'-10075' .5/02/85 9824'-9834' 5/06/85 10060'-10080' 7/04/89 9815'-9842' 7/04/89 10027'-10055' 7/04/89 10055'-10090' 7/04/89 10090'-10145' 10090'(Ret) 10Q90'(Ret) 10090'(Ret) 10090'(Ret) HB-4 Frac 10090'(Ret) HB-1 Frac 10420' Production 10420' Production 10420' Production Isolation ...... HB-4 Frac Sqzd HB-4 Frac w/100 sx 10420' Production 10420' Production Sqzd w/100 sx Open HB-1 4 SPF Open HB-4 4 SPF Open HB-1 4 SPF Open HB-4 8 SPF Open HB-4 4 SPF Open HB-4 8 SPF INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS WELL HEAD ASSEMBLY TYPE: CASING HEAD: CASING SPOOL: TUBING HEAD: TUBING HANGER: TUBING HEAD TOP: MASTER VALVES: Aias_lm.Oil & cons. CHRISTMAS TREE TOP CONN: LEASE TRADING BAY STATE UNOCAL DRILLING RECORD. ALASKA REGION PAGE NO. 1 of WELL NO. G-4 FIELD GRAYLING PLATFORM DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 06/22/89 10420' Began Operations at 0001 Hours 6/22/89. Off load 405 joints 3-1/2" drill pipe from supply boat. Checked out racking board in derrick. Hooked up accummulator lines and choke control panel. Rigged up pipe spinners. Finished choke manifold installation. Set back pressure valve in G-4. Break out flowline and gas injection lines. Changed out back pressure valve-had slight low pressure leak. Pressured annulus to 1000 psi to test back pressure valve-held ok. Nipple down tree. 06/23/89 10420' Set riser & BOPE. Install kill & choke line valves. Build 6" gun line for mud pits. Pick up swivel, kelly spinner and kelly. Hook up all service lines to same. Change out rig tongs. 06/24/89 10420' Set mouse hole. Hook up choke manifold bypass line. Mix 400 BBL of 3% KCL FIW. Hook up 6" gun line. Haliburton line, Kelly blow down line & choke control console. 06/25/89 10420' Install gas buster. Plumb fresh & filtered inlet water to shakers. Pick up 10' Pup & one joint drill pipe with bull plug sub & hanger crossover. Screw into hanger & test BOPE. 06/26/89 263' Continue testing BOPE, trouble with leak @ hanger crossover sub. Tested bottom & top pipe rams, & two outside valves on kill & choke line. Isolate choke manifold & tested all valves. Tested rig floor safety valve, stand pipe valve, upper & lower kelly cock. Rig down test joint. Make up drill pipe with hanger crossover sub & screw into hanger. Circulate top 250' of hole. Pull hanger free, observe well, gas breaking out of annulus. Pull & lay down 250' of 3-1/2", 9.3#, N-80 plus 2" of crossover on top of ball valve. Well started to unload. Shut well in. Bull head 60 bbl of filtered inlet water against CSO rams. Rig up to run safety valve in each stand. Run in hole & engage fish @ 263'. 6/27/89 263' Rig up Schulumberger. Run in hole & punch tubing @ 9677' tubing measurement. Circulate filtered inlet water to well clean tank. Shut down & check well for flow, negative. Circulate filtered inlet water with 3% KCL. R~C~V~ Gas percolating to surface. Shut in well. Pressure built to 15 psi, but able to bleed ~9 down to zero. Pumped 20 barrels lite-esl ~C~ . ~pill. Had'lite-eel pill returns @ 250'. Shut ~&~$C0n$.~$~-~own displacement. Bra~den head 84 barrels ziltered inlet water. ~irculate well to ~.n~o~8~" active system. Some gas to surface. 6/28/89 9693' Circulate well through choke. Pull tubing with 165,000#. Circulate & pull out of hole. Lay down tubing & accessories. Make up test plug & test BOPE. Make up Baker Packer bore receptacle retrieving tool on drill collars. Pick up 3-1/2" drill pipe & stage in hole. Break circulation every 1000'. Pick up drill pipe. LEASE TRADING BAY STATE UNOCAL DRILLING RECORD . ALASKA REGION ~ PAGE NO. 2 of WELL NO. G-4 FIELD GRAYLING PLATFORM DATE E.T.D. 6/29/89 9693' 6/30/89 10048' 07/01/89 10372' 07/02/89 10395' 07/03/89 10395' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Ran in hole to Baker PBR @ 9711'. Engaged packer bore receptacle & released with 15 right hand turns. Circulate one hole volume. Pulled out of hole & down packer bore receptacle, 100% recovery. Made up milling assembly and ran in hole to Baker "SAB" packer @ 9693' DPM. Mill packer 4 hours. Shut down for rig repairs. Finish brake repairs on rig. Jarred on Baker "SAB" packer for one hour @ 9608'. Pulled free with 50K overpull. Continued pulling out of hole with "SAB" packer. Layed down packer and jewerly-100% recovery. Made up milling assembly and ran in hole to Baker "FB-i" packer @ 10048'. Slip & cut drilling line. Mill packer 4 hours. Circulated one hole volume & observed well-no flow. Pulled out of hole with "FB-i" packer. Continued to pull of hole with Baker FB-1 packer & lay down same-100% recovery. Ran in hole with 6" bit & 7" casing scraper to 10372'-No restrictions. Cleaned out fill to 10395' ETD (Junk). Worked on TOTCO equipment. Ran in hole with HOWCO 7" RTTS packer & set @ 9725'. Pressure tested 7" casing to 2000 psi for 30 minutes (OK). Released packer and circulated one hole volume. Observed well-no flow. Pulled out of hole and layed down RTTS packer. Rigged up Schulumberger for velocity survey. Continued rigging up for velocity survey. Hung Schlumberger air gun off east side of platform. Logged from 10350' to 650' (25 stations @ 500 ft intervals). Rigged down Schulumberger. Velocity survey charges of $39,941 .to AFE 391420. Ran in hole with 6" bit & 7" scraper to 10355'. Broke circulation and washed to 10395' ETD. Circulated hole clean. Rigged up D.E. filter & 2 micron cartridge filters. Mixed & filtered 430 BBL 3% KCL fluid. Displaced hole with filtered inlet water. Pumped contaminated fluid through oil line to onshore facility. Circulated well clean with filtered inlet water. Displaced hole with filtered 3% KCL completion fluid. Circulated & filtered fluid to 28 NTU's. Pulled out of hole with 7" casing scraper. Made up Vann system tubing conveyed perforating assembly. Ran in hole with TCP guns filling every 10 stands with 3% KCL fluid. LEASE TRADING BAY STATE UNOCAL DRILLING RECORL ALASKA REGION PAGE NO. 3 of WELL NO. G-4 FIELD GRAYLING PLATFORM DATE E.T.D. 07/04/89 10395' 07/05/89 10395' 07/06/89 10395' 07/07/89 10395' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Continued to run in hole with TCP guns. Rigged up & ran gamma ray correlation log for depth control. Set champ packer @ 9776'. Cycled Omni valve open. Pressured Annulus to 3400 psi to fire TCP guns. No surface indication that guns had fired. Dropped bar to fire TCP guns. Perforated well as follows: 9815'-9842' DIL, 4SPF; 10027'-10055' DIL, 8SPF; 10055'-10090' DIL, 4 SPF; 10090'-10145' DIL, 8 SPF. Cycled Omni valve to bypass position. Reversed out drill pipe capacity. Circulated one casing volume through choke. Opened Hydril & circulated another casing volume. Observed well-no flow. Released packer & pulled out of hole with perforating assembly. NOTE: TCP guns had fired by annular firing head. Ran 6" bit with 7" casing scraper to 10365'. Broke circulation & washed from 10365'-10395'. Circulated one casing volume. Observed well-no flow. Pulled out of hole and laid down bit & scraper. Made up & ran in hole with 7" Otis "BWD" perma-drill packer with "SBE" hydraulic set to 9720'. Dropped ball & pressured up to 2300 psi to set packer. Released from packer & circulated one casing volume. Pulled out of hole & laid down setting tool. Changed top pipe ram from 3-1/2" to 2-7/8". Set test plug & tested bonnet seals to 1500 psi-OK. Rigged up hydrotest. Ran in hole with 2-7/8" gas lift completion..Tubing drifted & hydrotested to 4000 psi. Continued running 2-7/8" gas lift completion with tubing drifted & hydrotested to 4000 psi. Made up ball valve nipple & tested control line to 5000 psi-OK. Spaced out & landed tubing hanger. Pressure test to 450 PSI-OK. Rigged up wireline & pulled dummy valve. Installed 2-1/2" otis "DK" ball valve @ 370'. Installed backpressure valve. Removed BOPE. Continued removing BOPE. Install CIW production tree. Pressure test bonnet seals to 5000 psi. Retrieved back pressure valve. Returned well to production. RELEASED RIG AT 0700 HRS., 7/7/89. BIT RECORD COUNTY FIELD STATE SECTION Cook Inlet McArthur River AK TOWNSHIP RANGE LOCATION WELL NO. G-4 CONTRACTOR RIG NO. OPERATOR Pool Arctic Alaska ~54 Unocal SPUD REACHED T.D. PUMP NO. 1 LINER TOOLPUSHER PUMP NO. 2 LINER PUMP POWER TYPE MUD DRILL PIPE Size Type O.D. NUMBER O.D. TOOL DRILL JOINTS COLLARS I.D. LENGTH DRAWWORKS POWER JET ACCUM WT. PUMP SPM 32nd DEPTH DRLG 1000 PUMP OPER- NO. SIZE MAKE TYPE IN SERIAL OUT FEET HOUR FT/HR HRS LBS R P M PRESS PUMP ~ ~ MUD DULL. COND. FORMATIONS WT VIS WL ~ ~ G OTHER REMARKS 1 6" SEC S33F 387921 10395' 1 1 I c/o Bit 1RR~i 6" SEC S33F 387921 10395' 1 1 I Scraper run UNOCAL .~LASKA DRILLING G~Y~ ING PI~ATFOR~ T4ELL# G-4 7-6-89 Note: Well reworked and went back with same equipment. Z" 5k CTW = -- CIW / ] lq ~./~" 3000 Rx-57 ~IW %.. ,t T,TF,, Iq 5/A" ~n~ Rx-57 Shaff erda lvo 13 3/8" 9 5/8" 1! 4L'' C_rom.~.~.~ ~.v~r t,c~ 2 7/R" ], · Unocal Oil & Gas Division INVENTORY · G-4 Workover Beginning Inventory REceived KC1 (100#) 64 320 Baravis 30 0 Barazan 10 0 Caustic 4 0 Litesal 50 0 Liteplug-R 72 0 Li tepl ug-F 48 0 Liteplug-X 84 0 Polytec-S 6 0 Sapp 2 0 SDI Defoam 5 0 Salt 318 384 CaC12 0 35 Ending Used Inventory 313 71 0 3O 0 10 0 4 10 40 6 66 6 42 4 8O I 6 0 2 1 4 8 694 0 35 Order Document Numbers: Charges: Q27003 Q27004 Q27005 Q27006 Q27007 Q27009 Q27015 Q27023 Credits: Q27016. Q27018 Amount $ 1,877.52 23,848.30 7,269.63 3,485.74 6,074.64 4,971.44 2,845.00 2,125.00 Total Charges $21,431.56 14,632.12 Total Credits RECEIVED c2oI989 A chorage - $52,497.27 $36,063.68 Total Well Cost - $16,433.59 Baroid Drilling Fluids, inc. July 21, 1989 Mr. Don Chudanov Unocal.Oil & Gas Division P.O. Box 190247 Anchorage, Alaska 99519-0247 Re: Workover Fluids Recap G-4 W/O (Grayling) Dear Mr. Chudanov: Attached is the workover fluid recap for the above referenced well. While operations generally went very well, please note the following comments as they may apply: 1. A 65 pcf FIW/3% KC1 brine provided adequate hydrostatic head to control the well. 2. A Litesal pill (20 barrels) was used during the initial stabilization of the well. 3. The 31,300 pounds of KCl used on this well represents approximately 2,845 barrels of 3% KC1 brine. 4. No overboard discha'rges 'occurred on this workover"as all waste fluids were shipped ~o the beach for disposal. 5. Brine losses to the open hole were kept to a minimum as only 452 barrel's of fluid' were documented as lost to the formation. 2000 West Int'l. Airport Rd., Suite A-10 (99502) · RO. Box 102492 · Anchorage, Alaska 99510 (907) 248-3511 · Fax (907) 248-5390 Page 2 Mr. Don Chudanov Unocal Oil & Gas Division Re: Workover Fluids Recap G-4 W/O {Grayling} July 21, 1989 Please refer to the recap for more specific details. We at Baroid would like to thank you for the opportunity to provide our services to the Grayling Workover and Redrill program. If additional information is required, please advise. Very truly yours, BAROID DRILLING FLUIDS, INC. d. G. Rose District Engineer cc: Bush Neve ' Ri g Copy File Attachments ..:.:.~.':.:...~:......!'.'.'.......:". '..:."~i,.":" ...~iL:. . ,.h., .....'"'~':"' :",'"'-', '.. ::' . · ..!"..'..~: ....' .. 2.'..: .... '.F ' ? 11 -1 10 11 12 13 14 15 16 17 18 19 2O 21 22 23 24 25 26 27 28 29 30 431/1008/01/'89 July 7, 1989 PiNE 24. ~ Joint 25. ~ ~x~- Slidir~ Side n~.,n (p/N 12x x~ 26. ~ ~. SI~ ~ ~ly A. ~. Sl~ ~~ (P~ ~U S 400~-A) B.~~y (P~ ~u ~ 1000~A) C. (~ ~u x 40O0~A) D. ~ (p~ ~u ~ 4000~A) (m~ aU X 4000~A) F. ~ ~ly .. (P~ ~u ~ looo~) G. ~ ~ly 2-7/8" ~ P~ ~s. ~ (1) Jo~ of ~ Ni~e (P~ ~ X 2310~A) 30. ~ ~ ~ W~~ (p~ ~u ~ ~) I.D. O.D. L~ I~ 2.44" 3.50" 12.10' 9714.40' 2.313" 3.75" 3.35' 9726.50' 9.68' 9729.85' 2.44" 4.47" (1.44') 2.97" 4.04" (1.04') 2.97" 3.96" (2.04') 2.97" 4.04" (1.04') 2.97" 3.96" (2.04') 2 · 97" 4.04" (1.04 ' ) 2.97" 4.04" (1.04') 2.44" 3.8" .70' 9739.53' 2.44"' 3.50" 29.48' 9~40.23' 2.313" 3.24" .91' '9769.71' 2.44" 3.85" .73' 9770.62' 9771.35' I.D. .O.D. L~ ~ A. Otis "'~' Perma-Drill 4.0" Set on D~ill Pipe w~ic setti~ 7" 2~-32 LB B. Otis Seal Bore Extensi~ 4.0" (p/~ 212 c 7060) Bottom Of Packer and Seal Seal ~ore Extansi~ * I~'ill Pipe 5.88" 3.94" 5.03" 7.72 ' of Packer 9720.00'* 9723.94' 9731.66' Baroid - Petroleum Services Alaska CASING PROGRAM 13 3/8 , inch at 3043 COMPANY Unocal 0i 1 & Gas Divi sion STATE Cook Inlet 9 5/8 inch WELL G-4 Workover COUNT~ CONTRACTOR Grayling Platform LOCATION Cook Inlet SEC TWP RNG 7 inch at 1045'1..ft' Redford, Kerr TOTAL DEPTH 10,393 Rig Tenders Dock DATE '07/07/89 BAROIOENGINEER ~ ~H ~EIGHT VISCOSI~ Yp GELS FILTRATION R~ORT ~ANO CEO pH FILTRATION ANALYSIS ] b/ ~c APl PV mi HTHP Cake , ~lids Oil Water % Mud Strip ~ ~ p~p~ .R~TMc..' feet ~ 3 "F 'F 10 se~ (S~ Operations S~~ 1989 ~ TI - 10rain' APl 'F 32ntis % 1% % me/mt Metera Mf I .pm ppm KJ11ed ~eil -'~ 6-27 i 9670 63.5 FILTIRED INLIT WATEi ~ 8.0 6-28 ~ 9677 63.5 FIL~I:RED' INLI:T WATEi 8.0 Spo~ Lites~ 6-29 ~65 FZW I~ITH 3~ I',C1 - TR 8.0 ~~ 65 FIW I)ITH 3% I~ ~ ~ m 8.0 ~~~ NEW I~IITH ~ ~ --~-- --~ ~ ~ ~ ~~~ ~ -- ~ -- ~ ~ Run t~~ ...... __ tree~ _ ~ ~ ~ ............ ~ ~ CO~T CO~T ~ATERIAL A~OUNT ~ATERIAL A~OUNT $ ~ATEfllAL A~OUNT $ KC1 313 9,133.34 Workover Acditives 11,413.5g Sal~ 8 87.44 lech..Service N~III Baroid L itesal 10 866.30 Days ~ $405/Day/Man~ mmmmm~ Petroleum 8~i~ Liteplug-F 6 390.30 Kenai Borough Tax k~teplu~-R 6 390.30 .7 ~ $10.00 70.00 kiteplu~-X 4 260.20 S~I Cefoamm '1" ~4.37 1 ~ ~90.00 " 90.00 ~1~1~0 ~ ~fi~O~ ,o~t ~o~! 16,433..59 :r'. ve Rte 6-26 6-27 6-28 6-29 6-30 Depth~ Ft. Tour OPERATIONS · Unocal Oil & Gas Division .G :.4...W.?r.k.?ver Test BOP and surface liners~ pump FIW down tubinq with returns taken to wellhead G-8 (to production facility at Tradinq Bay), pick up overshot and DP. and stand in derrick, pump 43 barrels FIW down tubing with returns to well clean tank (goes to production facility), pull tubing free, pull hanger to floor, pump 25 bbls FIW down tubing with returns to well clean tank, lay down 210' of tubing {tubing was parted 210' down) well ,, , kicked, 76 psi SICP, while out of hole. Bullhead 60 bbls FIW thru kill line, relieve pressure to 500 psi thru choke line, RIH to top .of fish at 263' {rest of tubing string), with 33" ' DP and .overshot,. wi'th TIW valves on each stand, latch on to fish Rig up Schlumberger and test lubricator to 1000 psi, RIH with"W.L, perf gun and shoot tubing at 9677', pump FIW down tubing, taking returns l~o prodUction (pumped' tbbing vol, .monitored well, pumped annulus volume), displaced well with 3% KC1/FIW brine, taking returns to production, monitor well, still have show of gas. Circulate hole to production {433 bbls), monitor well, mix 20 barrels Litesal pill and pump some but part or all pill returned early, evidently thru bad pack off at top of. fish or hole in tubing near top. Bullhead 84 bbls FIW down tubing/annulus into formation, circulate thru choke with 1000 psi back pressure, monitor well. Circulate thru open choke and add 3% KC1 to system to raise wt. from 63.5 pcf to 65 pcf, monitor well, appears dead finally, pull tubi'ng Out of seal core and POH with tubing assembly, 'LD, test BOP to 3000 psi, pick lup 33" DP and RIH. Finish RIH with 33" DP (circ DP volume every 1000'), tag packer @ 9678', release seal barrel, circulate one com'plete circulation, POH and lay down seal barrel, PU TSA packer plucking tool and ,, RIH, tag packer ~ 9693' (SLM), mill on slips to free packer, Circulate out gas bubble, work fish loose, rig repair, fix brake adjustments. Finish brake adjustment repair, work packer free, POH and LD · packer and 2 ,]ts' of 33" tubing, nipple and wireline re-entry im Date Depth~ Ft. 6-30 (Continued) Tour 7-1 7-2 7-4 7-5 OPERATIONS · Page 2 Unocal Oil & Gas. Division G-4 Workover guide, change qrapple and RIH with PBT and PRT, tag "FR-I" packer at 10,048', mill on packer slips, Circ 4000 strokes, .POH with packer. Finish POH, LD packer and f.ishing tools, pick up 6" bit, casing' scraper and 14 its 3~" DP 'and RIH, tag fill ~ 10,372', clean out, fill f/10,372' - 10,395', Circ h'ole clean, one hour, POH, LD BHA, RIH with RTTS; set RTTS @ 9725' (SLM) pressure , test 7" csg to 2000 psi for 30 min., OK, circ 4000 strokes, POH, LD RTTS, Rig up schlumberger and start velocity survey log. Finish velocity survey log and r.ig down Schlumberger, RIH with 6" bit and csq scraper to 10~353' circ and clean out to 10,393', rig up Baker sand control filter press~ circ hole and buiid 356 bbls new filtered 3% KC1/FIW brine in reserve tank (75 bbls already there). Displace hole with FIW until pits tapped, off with. dirty KC1/FIW Brine, ship pit volume to production facility at Trading Bay and continue displacement with FIW, circ hole with FIW for one additional hour, taking returns to production, displace hole with filtered. 3% KC1/FIW brineland finish cleaning pits while taking returns to production. Circulate reserve volume to hole and take returns to active pits until turbidity of returns was "l~e~ow 4(J N1U, PL)H, rig up surtace equipment for pert gun run and make .up Vann guns. RIH with Vann guns on 3~" DP, SLM, fill p.ipe very 10 stands but leave top 2108' dry, rig up Schlumberger and RIH with DIL to locate RA'sub, set top shot at 9815 DIL, rig down Schlumberger, test Hallibuton chicksan lines and manifold, pressure to to' 3400 psi to fire down hole perf guns, reverse circulate 500 strokes to production,'circ 2700 strokes (bottoms up) thru choke line, then circulate 2700 more strokes with returns to active pits, POH with spent guns. Lay down spent guns, RIH with bit and casing scraper, wash from 10,350' to 10,395', circ 3000 stroker, POH, LD bit and BHA, make up Otis packer ~nd RIH to 9719', circ to clean seals, drop ball, Date Depth, Ft. Tour 7-5 (continued) 7-6 7-7 Page 3 Unocal 0il & Gas Division G-4 Workover OPERATIONS · Set packer at 9720'. circ 3000 strokes~ POH with settinq tools pull wear bushing, change rams. .Run 2 7/8 6.4// N-80 buttress tubing, GLM's seals etc., to re-complete well. Hydrotest to 4000 psi every 3 joints, space out and land tubing in hanger, rig up slikline unit and RIH with wireline, pull dummy valve, RIH with wireline and set .. .ball valve in SSSV, rig down slik line unit and landing joint, install back pressure valve in tubing hanger, nipple down BOP. , Finish nipple down BOP, nipple up tree and flow valve and choke, test tree to 5000 psi, release rig from G-4 Workover @ ~ , 7'00 hours. '. ,,, , ! ; ! · · Date Tour 6-26 6-27 6-28 6-29 6-30 7-1 . . 7-2 7-3 7-4 7-5 7-6 7-7 MATERIALS Date Tour Unocal Oil & Gas Divisic G-4 Workover DSR LOW PROFILE 1~ 5/0~ 5o000~r W.P. BOP STACK 50 KILL ' __ .. '-'' 1 I iii ~- $000~ CHOKE Y.~~ o/2jgjjj; DOP ~tde OUtletl ere 4"- , i Adapter~ to hubbed or lower pressure w$1lhead$ are avoilel)le. ~ · ,! / / / t / / / ! i ! i ! I I I :/ ; I ! · - i": ! - · ..' .: .,- ..-/ Exl;endecl Page 4, 1 _ I e I , AnnulAr l~reven~tAL_.. . P~pe Rem ...... B~nd hmm ...... ~.=. _. _ Choke L~ne Va z~ L~ne Valves TeK~am~3,t:et ~a~lu%es,, .Tem~_,P~*emeute. '00 ~'ulX ~emmu~a 'After Clo~ure]~O~,,, _ .,_ pmL Pump ~ull Chazse P~emmuro A~CaLnmd:~m~~mmc ~gtf e Valves ~pp..geHy h~l TypA ~ ' ~,mc ~remmute gO~_.~ ~oke ~anifold ~" Tem~ ~eesmure~~ ...... ~0, Valves _ , . ....... iced Qhok~ ..... Test ~e ......... , h~o, , ,,,,-... hpeAf ox* hplaeen~e~,~ of hL:l. ed equLpmdnt: co be mede wit:h:l.n dAye And lnmpeetor/ A'~tl, - AO&GCO ne - Superv&mo: " STATE OF ALASKA ~' .... %.., ..,~,A OIL AND GAS CO'NSERVATION COI~.....,,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon m Suspend __ Alter casing w Repair well ~ Change approved program w Pull tubing ~ Variance __ of Operator 5. Type of Well: 2'Nameunion 0il Company of California (UN~)CAL) Developments | Exploratory __ 3. Address ! Stratigraphic P.O. Box 190247, Anch, Ak., 99519-0~47 Service 4. Location of well at sud.a~e ........ uray.L..l, ng I-'.La~:rorm. Leg Z, uonouc'r, or 39 1882' N, 1389' W f/SE cDr., Sec. 29, TgN, R13W, S.M. At top of productive interval 2183' N & 1592' E f/SW CDr., Sec. 28, TgN, R13W, S.M. At effective depth 2042' N & 1888' E f/SW CDr., Sec. 28, T9N, R13W, S.M. At total depth 2045' N & 1880' E f/SW CDr., Sec. 28, TgN, R13W, S.M. 12. Present well condition summary Total depth: measured 10450 ' feet Plugs (measured) true vertical 9601 ' feet Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pedorate X,' Other __ 6. Datum elevation (DF or KB) 99' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. We~n._u4[n ber 9. Permit number 67-61 10. APl number 50- 733-20050-01 11. Field/Pool McArthur River Field Effective depth: measured 10420' feet Junk (measured) true vertical 9575 ' feet Casing Length Structural. 362 ' Conductor 621 ' Surface Intermediate 3043 ' Production 5970 ' Liner 10450 ' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Size Cemented Measureddepth ~ueve~icaldepth 26" Driven 362' 362' 16" 1200sx 621' 621' 13-3/8" 3100sx. 9-5/8" 1300sx 7" 725sx 5970' 10450' 9824' - 9834'; 10060' - 10080' i'3. Attachments 9058' - 9067'; 9261' - 9277' 3-1/2" 9.'21t, N-80 ~ 9798' ' ,, ',, ~ 9725' B~r,,Dj~OBss~r~ 2P~! · Detailed operations prog'rarn w Description summary of proposal __ 3003' 5715' 9601' RECE .VED ;~!!:J~sJ~.Oii & Gas Cons. Commission ..',.~i., ~chorage BOP sketch ~ 14. Estimated date for commencing operation"' J 15. Status of well classification as: May 9, 1989 16. If proposal was verbally approved Oil ~ Gas.__ Suspended __ Name of approver Date approved". Service' 17. I hereby cerIify tha~he f..c~egping i~ true and correct to the best of my knowledge. " Signed (/ Roy D. Robe, r.ts Title Environmental Engineer Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness " Plug integrity ~ BOP Test' Location clearance Mechanical Integrity Test ~ Subsequent form required 10-. ORIGINAL SIGNED BY Approved by order of the CommissionerI. ONNIE O. SMITH " .----- ...... Commissioner Form 10-403 Rev 06/15/88 .. 04'/06/89 J Approva, No..¢_.,,:=,~,j.,- 2 Date '"/TL'/~ "'~' SUBMIT IN TRIPLICATE l) 4) 6) 7) 10) ll) 12) 15) 14) Grayling Platform G-4 Workover Procedure Move Rig # 54 over TBUS G-4, Leg #2, Conductor #59. Kiii weiI. Instali BPVs, remove tree, instali and test BOPE. PuiI and iay down 5-1/2" tubing string. Miii over and recover Baker "SA8" permanent packer. Packer set at 9728'. Mill over and recover Baker "FB-i" permanent packer and tail assembly. Packer set at 10052' DIL. Clean out to 10,420' ETD (cement retainer) with 6" bit and 7" casing scraper. Run casing inspection log from TD to surface. Pressure test 7" iiner. Reperforate Hemlock benches 1 and 4 (9815' - 9842'; 10,055' - 10,090' DIL) with tubing conveyed guns at 4 SPF. Reperforate (if directed) Hemlock benches 5, 6 and 7 (10,180' - 10,271'; 10,500' - 10,565'; 10,571' - 10,400' DIL) with tubing conveyed guns at 4 SPF. Run single 2-7/8" completion assembly. Remove BOPE and install single tree. Return well to production. O019n NOTE: SBHP anticipated to be 4025 PSI 2" KILL LINE WITH (2) z' su VA,-¥~S I. .'b ',', '.'b KILL LINE FROM MUD PMP ~ CEMENT UNIT I I ,, BELL }, NIPPLE 12" 3000 PSI ANNULAR J ! , ,I ,, BLIND RAMS ,I ,J ! PIPE RAMS I FLOWLINE 13-5/8" 3M FLANGE ADAPTER 3M x 5M 13-5/8" 5M FLANGE DOUBLE GATE 5M PIPE RAMS 1, ! 13-5/8" 5M FLANGE ,I 4" CHO~E LINE WITH ONE REMOTE , , , ! ~ 1 MANUAL 4" 5M VALVE ! . ',U . (L~' I CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) 13-5/8" 5M FLANGE SINGLE GATE 5M 13-5/8" 5M FLANGE I RISER i I ' ii I J 10" 5M x 13-5/8" 5M ADAPTER CAMERON 5M DCB SPOOL 15-5/8" DOPE SM. STACK ALL DRILLING OPERATIONS UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLL APP'D: GSB SCALE: NONE , Form D-lOO1-A LEASE Trading Bay Unit FIELD McArthur River Field ORI. GlfiAL UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET A Page No. WELL NO. G-4 CONTRACTOR Conservative D~illing TYPE UNIT 1320 National BEGAN 4/11/85 COMPLETED 5/11/85 ELEVATIONS: WATER DEPTH 125' RERMi~'NO. ~l-D183 SERIAL NO~ 'ADL ~87~ '" RT TO OCEAN FLOOR 224' COMPANY ENGINEER Spiro/ Graham/ McAllister RT TO MLLW 99' APPROVED ~.~ RT TO DRILL DECK19.30' RT TO PRODUCTION DECK 42.60' CASING & TUBING RECORD SIZE DEPTH WEIGHT GRADE REMARKS 16" 13 3/8" 9 5/8" 7" 3 1/2" 621' 3043' 61# 0-55 Buttress 5970' 40,43.5, 47# N-80 Buttress 10451' 29# N-80 Buttress 9730' 9.3# N-80 Buttress See Previous History See Previous History See Previous History See Previous History Rkr ~ 9725'. Isol Rkr ~ 10032 See Detail DATE INT'E'RgAL' E.T.D. ' PERFORATING RECORD REASON ~RESENT CONDITION 4/18/85 10102-10104' 4/19/85 9965-10015' 4/20/85 9862- 9882' 4/20/85 9815- 9824' 4/20/85 9834- 9842' 4/22/85 10070-10080' 4/24/85 10080-10082' 4/24/85 10060-10070' 4/28/85 10060-10070' 5/01/85 10065-10075' 5/02/85 9824-9834' 10420' Isol Sqz lO090'(ret) Prod Perfs 9949'(ret) Prod Perfs 9855'(ret) Prod Rerfs Prod Rerfs lO090'(ret) B-4 Frae lO090'(ret) Isol Sqz lO090'(ret) B-4 Frac lO090'(ret) B-4 Frac lO090'(ret) B-4 Frac lO090'(ret) 8-1 Frac Sqzd w/ 32 sx "G" cmt Sqzd w/ 41 sx "G" cmt Sqzd w/ 83 sx "G" cmt Sqzd w/ 46 sx "G" cmt Sqzd No breakdown ~ 7500 ps Sqzd w/ 100 sx "G" cmt Sozd w/ 100 sx "G" cmt Open for production 4 HPF INITIAL PRODUCTION AFTER REPAIR DATE INTERVAL NET OIL CUT GRAV. C.R. T.P. CHOKE MCF GOR REMARKS 5/06/85 10060-10080' Production Rerfs Open for production 4 HRF WELL HISTORY PRIOR TO REPAIR COMPLETION DATE: LAST COMPLETION NO. PRODUCING INTERVAL: INITIAL PRODUCTION: LAST REGULAR PROD. & DATE: CUMULATIVE PRODUCTION: REASON FOR REPAIR: Well was experieDcing...a .very high decline rat~ WELL HEAD ASSEMBLY TYPE: Cameron Iron Works CASING HEAD: Shaffer - 13 3/8" SOW x 12" 3K KD Housing CASING SPOOL: CIW - 12" 3K X 12" 3K WF' TUBING HEAD: CIW Type F - 12" 3K X 10" 5K TUBING HANGER: 4 1/2" ArmeD Seal Lock Top/ Btm TUBING HEAD TOP: 10" 5K X 4" 5K Single Solid Block Valve Tree MASTER VALVES: 4" 5K · "~:~.s,,,a ;.,.: ~, ~as Con's- Anchorage CHRISTMAS TREE TOP CONN.: 4 1/2" 8rd UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Trading Bay Unit 733-20050-01 WELL NO. G-4 FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS TBUS G-4 RD (UOCO 40.95%) 10280' ETD i DAY 4/11/85 7" 8 10451' DAILY COST: $ 28,624 CUM COST: $ 28,624 AFE ANT: $1,230,000 10280' ETD RKR 2 DAY 4/12/85 7" ~ 10451' DAILY COST: $ CUM COST: $ 47,924 AFE ANT: $1,230,000 10280' ETD PKR 3 DAY 4/13/85 7" ® 10451' DAILY COST: $ 24,455 CUM COST: $ 72,379 AFE AMT: $1,230,000 10280' ETD PKR 4 DAY 4/14/85 7" ~ 10451' DAILY COST: $ 32,542 CUN COST: $ 104,921 AFE ANT: $1,230,000 10280' ETD PKR 5 DAYS 4/15/85 7" ~ 10451' DAILY COST: $ 24,996 CUM COST: $ 129,917 AFE ANT: $1,230,000 AFE #341431 RIGGED UP RIG #54 ON WELL G-4. FILLED WELL WITH 6% KCL FLUID. BULLHEADED 40 BBLS 6% KCL W/ 20 LB/ BBL CACO3 DOWN TBG TO PERFS, INSTALLED CHOKE, RN DIALOG i 3/4" TBG GUN 4 SPF TO 9700', PERFED TBG. CIRC WELL. ND TREE. NU BOPE. NADE UP LANDING OT IN HANGER. TESTED BOPE TO 3000 PSI, OK. PULLED TBG FREE. ROH LAYING DN 3 1/2" TBG. RIH PICKING UP 3 1/2" DP W/ FISHING BHA #1. BURNED OVER PKR ~ 9720'. CHASED SAME TO 9728'. POH. RIH W/ FISHING BHA #2 TO RECOVER PKR. RECEIVED 1 2 1986 6as Oons. Anchorage UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Trading Bay Unit 733-20050-01 WELL NO. G-4 FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 10280' ETD PKR 6 DAYS 4/16/85 7" 8 10451' DAILY COST: $ 25,204 CUM COST: $ 155,121 AFE AMT: $1,230,000 10420' ETD PKR 7 DAYS 4/17/85 7" $ 10451' DAILY COST: $ 25,584 CUM COST: $ 180,705 AFE AMT: $1,230,000 10420' ETD 8 DAYS 4/18/85 7" $ 10451' DALLY COST: $ 46,540 CUM COST: $ 227,245 AFE AMT: $1,230,000 10420' ETD 9 DAYS 4/19/85 7" $ 10451' DAILY COST: $ 55,035 CUM COST: $ 282,280 AFE AMT: $1,230,000 10420' ETD lO DAYS 4/20/85 7" $ 10451' DAILY COST: $ 37,795 CUM COST: $ 320,075 AFE AMT: $1,230,000 10420' ETD ll DAYS 4/21/85 7" $ 10451' DAILY COST: $ 21,895 CUM COST: $ 341,970 AFE AMT: $1,230,000 RECOVERED 1ST PKR F/ 9733' ON 2ND ATTEMPT. RIH W/ FISHING BHA #3 TO 2ND PKR ~ 9733'. BURNED OVER & RECOVERED SAME. RIH W/ FISHING BHA #4. REAMED THRU SCALE F/ 9766-10026'. RIH TO PKR $ 10290'. BURNED OVER PKR. PKR FELL FREE TO 10295'. POH. RIH W/ FISHING BHA #5 (OVERSHOT). RECOVERED 3RD AND LAST RKR F/ 10295'. ROH. RIH W/ BHA #6. .CO SCALE/ FILL F/ 10295' TO 10420' ETD. CIRC. TRIPPED FOR 9 5/8" SCRAPER. TAGGED ETD $ 10420'. POH. RAN DIALOG MAXIMUM ID CALIPER F/ 10420' TO SURFACE. (CSG 91% OR BETTER). RAN GO GUNS & SHOT 4 HRF F/ lOl02-10104' CBL/DIL FOR ISOLATION SQUEEZE. RAN SUNK BASKET TO 10300'. RAN & SET BAKER RKR $ 10090' CBL/DIL. RIH W/ STINGER ON 3 1/2" DP. STUNG INTO PKR $ 10099' DPM. SQZD PERFS $ 10102-10104' W/ 32 SX CMT ~ 5700 PSI. POH. RIH W/ BAKER K-1 RETAINER TO 9949' DPM. SQZD EXISTING PERFS 8 9965-10015' W/ 41SX CMT 8 5900 PSI. POH. RIH W/ BAKER K-1 RETAINER. SET 8 9855' DPM. RIH W/ STINGER ON 3 1/2" DP. SQZD EXISTING PERFS ~ 9862-9882' W/ 83 SX CMT $ 5700 PSI. POH. RIH W/ BAKER K-1 RETAINER SET ~ 9798' DPM. S~ZD EXISTING PERFS 9815-9824', 9834'- 9842', W/ 46 SX CMT $ 4300 PSI. POH (ALL SQZS W/ "G" CMT MIXED W/ 1% CFR-2, 3% KCL, 0.6% HALAD 22A). WOC. RIH. CO'CMT F/ 9770-9790', RET F/ 9790'- 9792', CMT F/ 9792-9832! All DIL. CO CMT F/ 9842-9847'. PRESS TST CSG TO 3100 PSI - OK. DRLD RET ~ 9847'. CO CMT F/ 9849-9947'. TST CSG TO 3100 PSI BLED TO 290) PSI. POH. 1 CONE MISSING. RIH W/ BLADED OUNK MILL. DRLD RET ~ 9941'. CO CMT TO 10077'. TST CSG TO 3000 PSI. FELL TO 2500 PSI IN 40 MIN. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Trading Bay Unit 733-20050-01 WELL NO. G-4 FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 10420' ETD 12 DAYS 4/22/85 7" 8 10451' DAILY COST: $ 26,505 CUM COST: $ 368,475 AFE AMT: $1,230,000 10420' ETD 13 DAYS 4/23/85 7" ~ 10451' DAILY COST: $ 104,755 CUM COST: $ 473,230 AFE AMT: $1,230,000 10420' ETD 14 DAYS 4/24/85 7" 8 10451' DAILY COST: $ 48,536 CUM COST: $ 541,766 AFE AMT: $1,230,000 10420' ETD 15 DAYS 4/25/85 7" ~ 10451' DAILY COST: $ 91,702 CUM COST: $ 613,468 AFE AMT: $1,230,000 10420' ETD 16 DAYS 4/26/85 7" ~ 10451' DAILY COST: $ 20,636 CUM COST: $ 634,104 AFE AMT: $1,230,000 POH. RIH W/ 6" BIT. CO CMT F /10077-10091' DIL. POH. RIH FOR DST W/ 4000' OF CUSHION. SET HOWCO RTTS ~ 9935'. OPENED TOOL - NO FLOW - 31MIN TEST. RESET RTTS ~ 9841' - NO FLOW, 35 MIN. TST, RESET RTTS ~ 9781'. NO FLOW, 50 MIN TEST. REV OUT FLUID CUSHION IN STRING - NO HYDROCARBONS. CHARTS SHOW ALL ZONES TO BE DRY. RU GO. PERF 4 SPF 10070-10080'. RIH W/ RTTS ON 3 1/2" DP W/ SPERRY SUN PRESS RECORDERS. SET RTTS ~ 10024'. RU DOWELL TO FRAC. PUMP-IN RATE - 5 BPM ~ 7100 PSI, 3000 PSI ON ANNULUS. FRACD HEMLOCK BENCH #4 PERFS (10070-10080') BY PUMPING 300 GAL 15% HCL, 2000 GAL PAD, 1125# SAND, 1000 GAL SPACER, 2000# PAD, & 23000# BAUXITE. SANDED OUT WELL ~ 8000 PSI SURF W/ 9000# BAUXITE IN FORMATION. PRESS. DROPPED TO 800 PSI. IN PLACE ~ 0730 HRS. RELEASED RTTS. RIH & CLEANED OUT FILL. SAND POH. RAN TEMP LOG F/ 10090-9900'. SHOT 4" CSG GUN 4 HPF 120° ~ 10082-10080'. RIH W/ HOWCO RTTS. SET ~ 10058' DRM. ATTEMPTED TO BREAK DOWN FOR SQZ OF B-4 (10070-10082') DIL. COULD NOT BREAK ~ 7500 PSI. RIH W/ 4" CSG GUNS & SHOT 4 HRF 120° ~ 10060-10070' DIL. MADE UP FRAC BHA. RIH W/ HOWCO RTTS. SET ~ 10030' DPM. RU DOWELL & TSTD. ATTEMPTED BREAKDOWN FOR FRAC. ATTAINED i BPM ~ 7500 PSI FIRST ATTEMPT & 1.1 BPM ~ 7500 PSI SECOND ATTEMPT. PUMPED 15% HCL = W/ 20 BBLS PUMPED ~ 5.5 BPM, 5100 PSI. FLUID BROKE AROUND THRU B-3 PERFS ~ 9965'- 10015' DIL. REVERSED TO CLEAN OUT ACID. RAN GO GAGE RIG & OUNK BASKET TO 10070'. RIH W/ HOWCO EZSV & SET ~ 10025' DIL. RIH W/ 2ND EZSV & SET @ 9925' DPM. SQZD B-3 W/ 30 SX CMT THRU PERFS, FINAL PRESS OF 7000 PSI. REVERSED OUT EXCESS CMT. POH. WOC. CO CMT & RETAINER FROM 9925-10025' DIL. TST CSG TO 3000 PSI-OK. POH. RIH FOR DST. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Trading Bay Unit 733-20050-01 WELL NO. G-4 FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 10420' ETD 17 DAYS 4/27/85 7" ~ 10451' DALLY COST: $ 32,701 CUM COST: $ 666,805 AFE AMT: $1,230,000 10420' ETD 18 DAYS 4/28/85 7" $ 10451' DAILY COST: $ 86,886 CUM COST: $ 753,691 AFE AMT: $1,230,000 10420' ETD 19 DAYS 4/29/85 7" ~ 10451' DAILY COST: $ 20,933 CUM COST: $ 774,624 AFE AMT: $1,230,000 10420' ETD 20 DAYS 4/30/85 7" ~ 10451' DAILY COST: $ 25,454 CUM COST: $ 800,078 AFE AMT: $1,230,000 10420' ETD 21 DAYS 5/01/85 7" $ 10451' DAILV COST: $ 82,592 CUM COST: $ 882,670 AFE AMT: $1,230,000 RIH. SET PKR ~ 9940'. NO BLOW. HELD 1 HR. POH. WHILE BREAKING DOWN TOOLS, MANDRIL OF RTTS BY-PASS BROKE. LOST BUNDLE CARRIER, RTTS, & BODY PORTION OF BY-PASS DOWN HOLE. RIH W/ OVERSHOT. RECOVERED FISH F/ 926'. RIH. CO RETAINER ~ 10033'. CHASED TO 10099'. POH. RIH W/ 4" GUNS 4 HPF 120° PHASE. FIRED GUN $ 10060-10070' DIL. RIH W/ FRAC ASSY. SET PKR ~ 10030". PUMPED INTO FORMATION AT 3.5 BPM ~ 7300 PSI. PUMPED 300 GAL 15% HAL FOLLOWED BY 13 BBLS FRAC PAD WHEN FLUID BROKE THRU TO B-3 PERF. REVERSED OUT FLUID. POH. RAN GAGE RING & OUNK BASKET. RIH W/ HOWCO EZ DRILL F/ 10020' DIL. STABBED INTO EZ DRILL W/ 3,. 1/2" DP. SQZD B-4 & B-3 (10060-10082' &~'9965-10015') DIL. SQZD W/ 100 SX "G" CMT.. WOC. WOC. CO CMT F/9685' T/10028' TST CSG T/3000 PSI-OK. RIH W/ HOWCO DST TOOLS. SET RKR ~ 9940'. TEST - DRY. RERAN TST DUE TO PRESS CHART FAILURE. DRILLED OUT RETAINER ~ 10028'. CO CMT F/ 10031-10080'. PERFD F/ 10065'- 10075' DIL W/ 4 HRF, 120°, 4" GUNS. TRIPPED W/ BIT & SCRAPER TO lO091' DIL. RIH W/ RTTS & SET ~ 10022' DIL. RU DOWELL FOR B-4 FRAC. PUMPED 300 GAL OF 15~ HCL FOLLOWED BY 66 BBLS OF GEL PAD. AFTER 20 BBLS PUMPED INTO FORMATION - BROKE THRU Tn B-3 RERFS. REVERSED OUT FLUIDS. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SNEET D PAGE NO. LEASE Trading Bay Unit 733-20050-01 WELL NO. G-4 FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 10420' ETD 22 DAYS 5/02/85 7" 8 10451' DAILY COST: $ 51,250 CUM COST: $ 933,920 AFE AMT: $1,230,000 10420' ETD 23 DAYS 5/03/85 7" $ 10451' DAILY COST: $ 200,205 CUM COST: $1,134,125 AFE AMT: $1,230,000 10420' ETD 24 DAYS 5/04/85 7" ® 10451' DAILY COST: $ 29,340 CUM COST: $1,163,465 AFE AMT: $1,230,000 10420' ETD 25 DAYS 5/05/85 7" $ 10451' DAILY COST: $ 21,550 CUM COST: $1,185,015 AFE AMT: $1,230,000 10420' ETD 26 DAYS 5/06/85 7" $ 10451' DAILY COST: $ 40,290 CUM COST: $1,225,305 AFE AMT: $1,230,000 RIH W/ HOWCO EZSV & SET ~ 10020'. STABBED IN W/ 3 1/2" DP. CIRC 1 3/4" BRM ~ 2800 PSI B-4 TO B-3. HOWCO PUMPED 77 CF HoO FOLLOWED BY 100 SX "G" CMT MIXED W/ HALAD 22A, 1% CFR-2, 3% KCL. DISR W/ 23 CF H20 & 370 CF KCL FLUID. FINAL SQZ RATE- i 3/4" BRM ~ 3800 PSI. POH ~ STDS. REV OUT 27 SX CMT. POH i STD. RUT BRADENHEAD SQZ ON CMT TO 3000 PSI. PRESS HELD STEADY. ROH. RIH W/ BIT & SCRAPER. CO CMT F/ 9750-9852' DIL. POH. RIH. PERFED F/ 9824-9834' DIL, 4 HPF, 120°, 4" GUNS. RIH W/ HOWCO EZSV & SET 8 9843' DIL. RIH W/ RTTS & SET 8 9775'. RU DOWELL. PUMPED INTO B-l,'9.1BPM 8 7300 PSI. FRAC'D B-1 W/ 126 BBLS PAD FOLLOWED BY 20500# BAUXITE 8 ll-12 BPM, 5700-7300 PSI W/ 3000 PSI BACKSIDE. SHUT WELL IN 6 HOURS. POH W/ RTTS. RIH. TAGGED FILL ® 9769'. 'CO SAME TO 9843'. POH. RIH W/ GO TEMP LOG. LOGGED F/ 9500-9837'. RIH W/ ECONOMILL. CO CMT & RETAINERS F/ 9843-10020'. TRIPPED FOR BIT. CO RETAINER AT 10020'. RIH W/ RETAINER 8 lO091'. TRIPPED FOR BIT. CO STRINGERS TO 10420' ETD. CHANGED & CONTAMINATED FLUID W/ FIW. POH LAYING DOWN DC'S & HWDP. RIH W/ RTTS FOR DST'S. SET RTTS ~ lO120-10090'-DRY, 10033' (B-4) & 9911' (8-3) BOTH SHOWED FLUID INFLUX F/ THE B-4 ZONE. PERFED 4 HRF, 120°, 4" GUNS F/ 10060-10080' DIL. RIH W/ BAKER FB-1 PERM RKR & TBG TAIL. SET SAME 8 10032' DIL. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Trading Bay Unit 733-20050-01 WELL NO. G-4 FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 10420' ETD 27 DAYS 5/07/85 7" 8 10451' DALLY COST: $ 267,135 CUM COST: $1,492,440 AFE ANT: $1,230,000 10420' ETD 28 DAYS 5/08/85 7" ~ 10451' DAILY COST: $ 23,637 CUM COST: $1,516,077 AFE ANT: $1,230,000 10420' ETD 29 DAYS 5/09/85 7" 8 10451' DAILY COST: $ 21,890 CUM COST: $1,537,967 AFE AMT: $1,230,000 10420' ETD 30 DAYS 5/10/85 7" 8 10451' DAILY COST: $ 26,157 CUM COST: $1,564,124 AFE AMT: $1,230,000 10420' ETD 31 DAYS 5/11/85 7" 8 10451' DAILY COST: $ 38,913 CUM COST: $1,603,037 STABBED IN & PRESS TSTD ISOLATION RKR TO 500 PSI - OK. ROH LAYING DOWN DP, KELLY, SWIVEL, & TOOLS. RIGGED & RAN 312 OTS 3 1/2", 9.2#, N-80 TBG COMRL ASSY W/ BAKER SAB RKR. (SEE DETAIL). INSTALLED SSSV. LANDED TBG. PULL BALL VLV. CAMCO PLUG- RUNNING TOOL NOT FUNCTIONAL. RUN TBG PLUG BASE. SET ® 9742' WLM. RUN PLUG & SET ON TOP TBG PLUG BASE. UNABLE TO SHEAR OFF PLUG. PRESS TBG TO 3000 PSI (TWICE). BLED TO 0 IN i2 SEC. GOT RETURNS IN ANNULUS TO SURF. PULL TBG PLUG. RIH WITH SLEEVE TOOL. SLEEVE CLOSED. RIH W/ TBG PLUG. RESET - SHEARED, OFF PLUG ~ WL. PRESS UP TO 3500 PSI. BLED OFF W/ ANNULAR RETURNS 8 SURFACE, PULL THE TBG PLUG, PULL TBG PLUG BASE, PULLED TBG HNGR. SET BACK DOWN - PKR IS SET. PRESS UP TO 1500 PSI - RETURNS TO SURFACE. ROH W/ TBG. SENT ALL GLM TO BEACH FOR TESTING. FOUND I GLM W/ FAULTY VALVE. RIH W/ BAKER SEAL ASSY & X-NIPPLE ON TBG. TST RKR & TBG TO 2500 PSI - OK. ROH. RIH W/ 3 1/2" COMRL ASSY. STABBED TBG INTO PKR. PRESS TST TO 600 PSI - BLED TO ZERO IN 3 1/2 MIN. SET TBG PLUG BELOW RKR 8 9743'. PRESS TST TO 2500 PSI - BLED TO ZERO. PULLED TBG PLUG. ROH W/ TBG. CHANGED OUT GLV'S W/ DUMMY'S. RIH W/ 3 1/2" TBG COMPL ASSY. STABBED INTO RBR. PRESS TST TBG TO 600 PSI - OK. PULLED TBG PLUG STOP. ND BORE, NU TREE. RELEASED RIG FOR MOVE TO G-lO ® 1200 HRS, 5/11/85. MYERS WL TO REPLACE DUMMY'S W/ GLV'S. AFE ANT: $1,230,000 WELL TBUS G'4.RD . . · ... IV.) v.) 15 :.1. 2-12. CASING & ABADONMENT DETAIL 13. 14. I.) II.) III.) IV.) V.) VI.) Rotary Table at 0.00' Tubing Hanger at 37.20' 16.' 75~ J-55 Casing at 621' ' '- 13 3/8' 61~ J-55 Casing at 3043' 9 5/8' 40~, 43.5~, 47~ N-80 Casi'ng to Retainer at 5970'~ Wind~3w From 5970' to 5980' _. 7' 29~. N-80 Casing at 10,451' . . Cmt'd wl725 sxs 'G' w/additives ~ . TUBING. DETAIL 3-1/2", 9.2 ~, N-8 0 TUBING. 15. Otis ~DK' Ball Valve at 298.11° Camco 'KBUG' Gas Lift Mandrels at 2) 2,311.02' 3) 3,266.88';--4) 4,224.40' 5) 5,258.65' 6) 6,165.54' 7) 7,002.77' 8) 7,682.83' 9) 8,218.70' 10) 8,649.37' 11) 9,084.09' 12) 9,461.44' Camco ~WBID' Sliding Sleeve at 9,652.68' .. Camco 'KBUG-CV-LTS" Modified Gas Lift '- Mandrel at 9,692.02' Baker 'SAB' Pemane~t Packer W/Mill-Out Ext. at 9,724.58' Camco 'D-2' No-Go Nipple W/Integral ., Mule Shoe at 9,728.56' Camco ~WD-I" Lamding Nipple at 9,764.58' Baker W.L. Re-entry Guide at 9,796.86' 16. .17. 18. VI.) PERFORATION RECORD DATE March, 1985 INTERVAL 10,060'-10,080' 10,102'-10,104' 9,965'-10,015' 9,862'-9,882' 9,834'-9,842' 9,824'-9,834' 9,815'-9,824' CONDITION HB ~4, Frac'd Production Isolation Sqz. HB ~3, Sqz'd HB ~2, Sqz'd HB ~1, Sqz'd HB ~1, Frac'd Production HB ~1, Sqz'd ~EV. ~ :ATE 10/86 B.A.W. j 4/1___5_/86 I I I ELL TBUS G- RD WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA ANCHORAGE t ALASKA , DRAWN M. E, G. CKO. APP'D. SCALE NONE DATE 10/30/85 ii , SHEETS [ SHEET FORM V 247 A 5/56 750 BAD BODY SEALS 1100 PSI INJ. PRESS. 4' 5K 'WILLIS 10' 5000~ '- GOOD 0 PSI GOOD 0 PSI ClW 'WF' , 12' 3000~ · t3 12' O000~ HAFFER KD! 13 3i8// 9 5/8' // 4 1/2' 2// 5K FEGV ClW . .2' 5K FEGV. ClW '. 2' 3K": SE BV ClW DATE WELL TBUS G-.4 GRAYLING PLATFORM LEG ~2 UNION OIL COMPANY OF CALIFORNIA ANCHORAGE, ALASKA Dr~AWN J F P CKD. ~ APP"D, SCALE N 0 N E DATE 711185 SHEETS SHEET · 2 ~ 12" :3 ,&' Y /Z" 7 /L) // /$ , __ .,v. ""' WELL TBUS G'/~ ':::',~.,, ~'.:"~., D.~'r r.. 711185 GRAYLING PLATFORM LEG ~2 UNION OIL COMPANY OF CALIFORNIA ,, , -- ANCHORAGE, ALASKA SHEETS I SHEET A Division of HALLIBURTON Company 2400 West Loop Soulh, P.O. Box 22605 Houslon, Texas 77027 A/C 713 671-4800 COMPLETION REPORT COMPANY Union Oil Company ADDRESS P.O. Box 6247; Anchorage, AK CONTRACTOR Conservative Drilling Company ADDRESS 99502 REPORT FOR MR. REPORT FOR MR. J. Callender WELL NAME & NO. FIELD T.B.U. G-4 W/O McArthur River COUNTY Kenai STATE Alaska DESCRIPTION OF LOCATION S29, T9N. R13W IMCO WAREHOUSE -; Kenai .... WELL DATA DATE SPUDDED 4/].0185 CSG. SIZE FROM TO HOLE 51ZE FROM TO · L SIZE FROM TO TOTAL DEPTH CSG SIZE FROM TO HO E Workover O.D. . DATE TD REACHED CSO. SIZE FROM TO HOLE SIZE FROM TO NA O.D. TOTAL DAYS CSG. SIZE FROM TO HOLE SIZE FROM TO NA o.D. BITS: NUMBER AND SIZE '' NA MUD UP DEPTHS FINAL DELIVERY TICKET NO. NA 400758 TYPE MUD '. FINAL RETURN TICKET NO. KC1 - COMMENTS No Problems. IMCO FORM HOUSTON MARKETING D. F. Doescher/W. K. Wallace/bf IMCO REPRESENTATIVE I SUMMARY OF DRILLING FLUID OPERATIONS IPAGE I OF 1 I OPERATOR SECTION TOWNSHIP IRANGE MUD TYPE CONDUCTOR SIZE ,DEPTH BIT SIZE Union Oil Company 29 9N I 13W 67. KC1 :WELL FIELD SPUD DATE SURFACE IMCO Services :~.]~.~J. State c-4 ~/o Mc^rthur ~iver 4/10/S~ A Or~,~ of N~J. tSuR'roN C~nmW !CONTRACTOR COUNTY/PARISH T.D. DATE INTERMEDIATE ~.,. ~. ,~, ~c ,,, ,,,.~- Conservative Drilling Co. Kenai W/O ENGINEERS STATE DAYS TO T.O. LINER(S) Doescher/Wallace Alaska 7" 10,451 ' MUD VIS. MUD GELS PH APl MT- HP ALKALINITY SALT CALCIUM SAND OIL WATER WT. SEC/ TEMP. ~JSTRIP FLUID FLUID I-INaCI r-IpPM %VOL. %VOL. %VOL. I']PPG. QT. ~-IF.L. "]METEF LOSS LOSS r-Ici. [] ION DATE DEPTH []PCF. []SMPL PM YP TEMP~ CAKE Pf Mf Pm []PPM CEC 1985 r-icol-lFc / MIN [] Gr,IG,q 4/10 W/O 65 / Mix 720 bbl 6% KC1 to W/O C-4 well. 4/z~ I w/o I 65 I I I I I / I I I I I I I I I I I I I I I I Mix 50 bbl pill w/20 ppb Safe Seal & 2p XCio/~iiP 1yme in 6% KC1 base fruid 4/~2 I w/o I 65 I I I /~b RIH w/Dialog & perf csg. POH w/Dialog &circ well out. 4/~3 I w/o I 65 I I I I I / I I I I I I I I I I I I I I I I Circ well out, ~TD tree & ~T~ BOP, Mix 150 bbl volume to all active system, 4/14 I w/o I 65 I I I I I / I I I I I I I I I I I I I I I I Pull PP tubinR. NU & PU Kelly. Prep to PUDP. 4/15 I w/o I 65 I I I' I I / I I I I I I I I I I I I I I I I PUDP & mill over packer @ 9720. POH w/mill & PO Spider & RIH to catch packer. 4/16 Mill packer. Spot 50 bbl pill of KC1 water, 25# XC, 30 ppb Safe Seal. Latch on packer. POM. TIM to mill bottom packer. ~/~7 I w/o I ~5 I I I I I / I I I I I I I I I I I I I I I I Mill ~acker, POM, PO retrievia~ tool & retrieve packer, 4/18 I w/o I 65 I I I I I / I I I I I I, I I I I ' I I I I I 1 PU 6" bit. TIH & POH. PU scraper. TIH. POM. Wireline. IMCO FORM NO. 131 (Rev. 1/79) I SUMMARY OF MUD MATERIAL USAGE I PAGE 1 OF I COMPANY LOCATION FIE LD IMC0 ~dces Union Oil Co. of California S29~ T9N~ R13W McArthur River A m.~..,~u.~u~o.r.~,.;~,,~ ,,.,* ~, ~..~,. o .,.~ WELL COUNTY STATE WAREHOUSE ............. G-4 W/O Kenai Alaska Ke_nai DATE DEPTH DAILY CUMULATIVE COST COST 1985 5/10 W/O 4,815.2C 4,815 20 159 1 5/11 W/O 2,150.36 6,965 56 ' 2 30 1 5/12 W/O 395.0G 7,360 56 1 5/13 W/O 1,312.4C 8.672 96 33 1 5/14 W/O 395.0C 9,067 96 1 ,.5/15 W/O 1,924.0~ 10~991 96 55 1 ..5/16 W/O 2,294.76 13,286 72 3 2 32 1 5/17 W/O 1,006.6~ 14~293 32 22 1 5/18 W/O 395.0~ 14~688 32 1 5/19 W/O 395.0G 15~083 32 1 TOTAL PRODUCTS: 272 4 62 10 ,. MATERIA REMAIN] NG ONBOAK ): 43 10 · IMCO FORM NC)_ 13:2 (R~v_ UNION OIL COMPANY Summary of IMCO Mud Material Usage GRAYLING PLATFORM G-4 W/O Product KC1 Safe Seal XC Polymer Eng. Services Total Sacks Cost 272 27.80 62 30.50 4 420.18 10 395.00 Total $7,561.60 1,891.00 1,680.72 3,950.00 $15,083.32 Cost of Well Less Eng. Services Material Left Onboard Total of Delivery Tickets $15,083.32 3,950.00 11,133.32 1,500.40 $12,633.72 Delivery Tickets Breakdown Date · 4/].0/85 4110185 4/15/85 5/4/85 Products Ticket# 400748. 140 400747 400749 140 400758 35 Safe XC KC1 Seal Polymer 27.80 30.50 420.18 72 Total $3,892.00 3,876.72 '3,892.00 973.00 Total of Delivery Tickets $12,633.72 Union Oil and Gas Division: Western Region '. Union Oil Company'" 'ifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union 3une 18 1985 Mr. Chat Chatterton Alaska Oil and Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 SUNDRY NOTICE'S Dear Mr. Chatterton: Attached for your approvaI is a Sundry Notice of Intention for G-iORD, and .Subsequent's for G-4RD & A-22. PIease return the approved G-iORD Sundry Notice of Intention to the undersigned. Very truly yours, Lawrence O. Cutting. ENVIRONMENTAL SPECIALIST LOC/tJ Attachments RECEIVED JUN2 0 Alaska Oil & Gas Cons. Commission Anchorage .." STATE Of ALASKA £~ ' ALAS( ._,L AND GAS CONSERVATIOI~ ~.,...IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL ~,. OTHER [] 2. Name of Operator UN[ON 0IL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well Cond.#39, Leg #2, 1882'N & 1389'W of SE Cot., Sec. TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) RT 99' MSL 7. Permit No. 81-1183 8. APl Number 5o233-20050-01 9. Unit or Lease Name Tradina Ray Unit 10. Well Number 12. 6. Lease Designation and Serial No. ADL-18730 G-4RD 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe (Submit in Duplicate) [] Altering Casing [] [~ Abandonment [] [] Other [] Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed 1.) 2. e 7.) 8.) 9.) 10.) work, for Abandonment see 20 AAC 25.105-170). Rigged up over Cond. #39, Leg #2, Well TBUS G-4RD. ) Killed Well, installed BPV, removed tree, installed & tst'd BOPE to 3000 psi. ) Cleaned out Scale f/10295-10420' ETD. ) Sqz'd f/lOl02-10104' 8 4/HPF w/32 sxs cl "G". ) Sqz'd and isolated existing Benches #1, #2 & #3. Sqz'd f/10060-10082' f/9965-10015' f/9965-10015' · 4/HPF w/41 sxs cl "G". f/9862-9882' 0 4/HPF w/42 sxs cl "G" f/9815-9824' f/9834-9842' Co Cmt f/lO077-10091'. Rerf'd & Frac'd Bench #1 f/9824-9834 ~ 4/HPF w/20500 # Bauxite. Perf'd & Frac'd Bench #4 f/lO070-10080' ~ 4/HPF w/23000 # Bauxite Perf'd f/10065-10075' ~ 4/HPF f/10060-10080' ~ 4/HPF Released Rig 05/11/85. 14. I hereb~a~e f~i~and correct to the best of my knowledge. Signed Lawrence O. Cutt'ghg RECEIVED JUN 2 o 1985 Alaska Oil & Gas Cons. C0mmi,, Annhor~. The space below for Commission use Conditions of Approval, if any: Title ENVIRONMENTAL SPECIALIST Date 06-18-85 Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SI0n Union Oil and Gasip""ision: Western Region Union Oil Company[ .'" 'ornia P.O. Box 6247, Anchor~e, Alaska 99502 Telephone: (907) 276-7600 union June 10, 1985 Mr. Chat Chatterton Ak 0tl and Gas Conservation Commission 300i Porcupine Drive Anchorage, AK 9950I Dear Mr. Chatterton: MONTHLY REPORTS Attached are Monthly Reports for G-lORD, G-4RD, and D-29RD for you information and file. If you have any questions, please feel free to contact me at the telephone number listed above. Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST LOC/tj Attachments Alaska Oil & Gas Cons. Com~tsslon Anchorage ' k~ '" STATE Of ALASKA (~ ALAS ,',LAND GAS CONSERVATION _ .,..,fiSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. UNION OIl COMPANY Of CALIFORNIA 81-183 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 5o- 733-20050-01 4. Location of Well at surface Cond. #39. Leg #2, 1882'N & 1389'W of SE Cor. Sec. 29, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ET 99' MSL ADL-18730 9. Unit or Lease Name T~'mdino R~y liner 10. Well No. G-4RD 11. Field and Pool McArthur River Field For the Month of May ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks DEOM=lO,420 ETD Release Rig ~ 1200 hrs. 05-11-85 13. Casing or liner ru.n and quantities of cement, results of pressur~ tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run Ran Temp Log f/9500-9837' 16. DST data, perforating data, shows of H2S, miscellaneous data Perf'd f/ 9824-9834' ~ 4/HPF i0060-10080' 8 4/HPF frac'd B-1 w/20QSO0# Bauxite 17. I hereby c~oi~correct,, to the best of my knowledge. SIGNED Lawrence O. Cuttzng TITLE ENVIRONMENTAL SPECIALIST DATE 06-06.85 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· Form 10-404 Submit in duplicate Rev. 7-1-80 Union Oil and G~.qivision: Western Region Union Oil Compan~ :ifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union · May 9, 1985 Mr. Chat Chatterton Ak Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: MONTHLY REPORTS Attached are Monthly Reports for D-29RD and G-4RD for you information and file. If you have any questions, please feel free to contact me at the telephone number listed above. ,, LOC/tj Attachments Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST · RECEIVED UAY I o J985 Alaska Oil & Gas Cons. CommissioD Anchorage ~. . ' ,. /' STATE OF ALASKA ALASK ....AND GAS CONSERVATION C'~ .... ,/IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS !1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 81-183 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50-733-200.50-01 4. Location of Well at surface Conductor 39, Leg #2, 1882'N & 1389'W of SE CDr. Sec. 29, TgN, R13W, SN. 5. Elevation in feet (indicate KB, DF, etc.) RT 99' MSL 6. Lease Designation and Serial No. ADL-18730 9. Unit or Lease Name Trading Bay Unit 10. Well No. G-4Rd 11. Field and Pool McArthur River Field For the Month of April ,19~5 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced Operations 04-11-85 DEOM = 10,420 TMD Recovered Fish f/926' 13. Casing or liner ru.n and quantities of cement, results of pressure tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run Ran Temp Log f/10090-9500' a 4/HPF ID Caliper f/10420 to Surface -'"-,-L ~ V EL/ Alaska Oil & Gas Co~s. CommJ~ion Anchorage 16. DST data, perforatingdata, shows of H2S, miscellaneous data Sqz'd f/lO101-10104' w/32 sxs cl "G" Resqz'd f/ 9965-10080' w/30 sxs cl "G" 9965-10015' w/41 sxs cl "G" 10060-10082'\ 9862- 9882' w/83 sxs cl "G" 9965-10015'-'w/100 sxs cl "G" 9815- 9824 ',.~ 9834- 9842 w/46 sxs cl "G" Perf'd f/10070-10080' $ 4/HPF Frao'd Hemloc Bench #4 w/ll25# Sand & 23000# Bauyite 17. I hereby certify t~t the forego~g~js~ true~.~j~ correct to the best of my knowledge. SIGNED Lawrence O. Curt'inn TiTLENVTRnNMFNT/3,1 gPF£TAITST NOTE--Report on this form is required for each' calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 Union Oil and G~ ision: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union September 5, 1984 Mr. C.V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Mr. Chatterton: SUNDRY NOTICE - TBU G-4RD (23X-28) Attached for your further handling is Union Oil Company's Notice of Intention to Perforate, Stimulate and Pull Tubing in Well TBU G-4RD (23X-28). Should you have any questions, please advise. Very truly yours, Lawrence O. Cutting Environmental Technician LOC: cwl Attachment RECEIVED SEP 0 ? Alaska Oil & Gas Cons. commission Anchorage STATE OF ALASKA ALASK,-, ,,.)IL AND GAS CONSERVATION',,.,,oMMISSION SUNDRY NOTICES AND REPORTS ON WELLS ,/ DRILLING WELL [] COMPLETED WELL / OTHER [] 2. Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 81-1183 3. Address 8. APl Number P0 BOX 6247 ANCHORAGE AK 99502 ~33-20050-01 4. Location of Well Cond 39, Leg 2, 1882' N & 1389' W of SE Cot, Section 29, TgN, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) RT 99' MSL 6. Lease Designation and Serial No. ADL 18730 9. Unit or.Lease Name Trading Bey Unit 10. Well Number 11. Field and Pool McArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION 'TO: (s~,~it in Triplicate) Perforate Alter Casing [] Perforations Stimulate [~ Abandon [] Stimulation Repair Well [] ,,/ Change Plans [] Repairs Made Pull Tubing [~ Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing" [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any pr°p~w~ru~a~e~a~~5~7'~eg #2, Well TBUS G-4 RD. 2. Kill well, install BPV, remove tree, install and test BOPE to 3000 Psi. 3. Clean out to_+10420' ETD with 6" bit and 7" casing 'scraper. 4. Squeeze and isolate the.bottom of Bench #4. a. Perf from +lOl02' to +lOl04'. b. Set retainer at +10090' and squeeze. 5. Sqz and isolate existing Bench #1, #2, and #3 perf's. a. Set ret at +_~920' and squeeze perf's f/ 9965' to lOO15'. b. Set ret at +_~850' and squeeze perf's f/ 9862' to 9882'. c. Set ret at +9775' and squeeze perf's f/ 9815' to 9842'. 6. Clean out to ret e 10090'. a. Test squeeze's to 3000 psi and resqueeze as indicated. 7. Frae Hemlock Bench #4. a. Rerf 4 HRF from +10070' to +10080'. b. RECEIVED Set packer at +10025'. c. Frac as indicated from Reservoir Rrocedu're. d. Hold fra'c in place minimum of 12 hours. , ~ Alaska Oil & Gas Cons. Commission 'Anchorage , Sut:~.;e(m~t W(,r'k Repo~t4~ CONTINUED ON REVERSE SIDE 14. I hereb~hat the foregoing is true and correct to the best of my knowledge. Signed ~,-~__1~_¢_~'"~~*~"'"~ ~ t~l~lt~,Title ENVTRONHENTAL TECH. Date 9/4/84 ,. The space belo~'~J~31~n~ssgfl u~u I I i U~ ~ ....... Conditions of Approval, if any: ~RIGIN~L SIGN[D ~p~ov~ C~y ~fur~ BT [DN~I[ C. SMITI . ~ By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent RePorts." in Duplicate # TBU G-4RD (23X-28) ~ELL {~ ' ..,1. 8. Frae Hemlock Bench #1. a. Rerf 4 HPF f/+9824' to +9834'. b. Set RTTS ~ +9750'. c. Frac as indicated from Reservoir Procedure. d. Hold frae in place minimum of 12 hrs. Clean out to +10420' ETD. lC. Run single 3 1/2" completion assembly as per completion design. ll. Install BRV, remove BORE, install and test tree. 12. Rlace well on production. a. Release rig. 13. After well has cleaned up, run production profile. 14. Reperforate as needed by profile log Benches #1, #3 and #4. TBUS G-4 RD OI 288' 3 1/2" Otis Ball Valve 13 3/8" '61~ J-55 c. 3043' Camco GLM'S 1967' 3784' 5352' 6866' 8129' 9058' 9648' 9 5/.8" Window 5970-6032' Cml ret 6050,~ Cmt ret 9287' 9679' Otis "XA" sleeve 9720' Baker model' F-1 pkr 9750' "X" nipple 9751' mule shoe 10293' Baker model FB-1 pkr 10313' Otis "X" nipplQ(~)~'C-~'~£ E 10323' Mule shoe '/V~,,~ s£po . ~l~ska Oil & ~as Coas. ., , ~ ~achorage C°~xSSioa 10451' 7" ~9# N-80 Butt &'. C ¥.,,, I DAlE _ l GRAYLING PLATFORM' TBUS G-4 RD McArthur River Field UNION OIL COMPANY OF CALIFORNI^ DP. AWN ~ O~.TE PROPOSED COMPLETION (H.B. # 1 Squeezed) 9815'-9824' ~ 9834'-9842' ~ 9965'-10,015' ~, -, (H.B.#3 Squeezed) ~ 10, 102'- 10, 104' (Isolation Squeeze) Al ESTIMATED TOTAL' DEPTH 10,420' RECEIV SEPO 7~(, ska Oil & Gas Cons. 9 5/8", 47~ CASING AT 5970' PERMANENT PACKER AT 9730' 9824'-9834' - (H.B.# 1 Fracture Stimulated) 9862'-9882' (H.B.#2 Squeezed) ISOLATION PACKER AT 10,030' 10,070'-10,080' (H.B.#4 Fracture Stimulated) ISOLATION PACKER AT 10,150' ED HEMLOCK BENCH #7 Commission ~- 7', 29~ CASING AT 10,451' . / ' , ¢ , · ALASKA OIL AND GAS CO#SERVATION CO~JMISSiO# '... Permit No. gl-' Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501.:-3192 TELEPHONE (907) 279.- 1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed .~?- ~, --oo',_~' .) Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a.drilled well. Please submit the above missing material. Sincerely, _ C. V. Chatter on~ Chairman RECEIVED Alaska Olf ~, Gas ~;oa$, gomrnlssh)!i Union Oil and Gas ~on: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union DOCUMENT TRANSMITTAL Sanuary 16, 1984 HAND DELIVERED TO: Fran Oones FROM: LOCATION: 3001 Porcupine Drive LOCATION: Anchorage, Alaska 99504 . ALASKA OIL & GAS CONSERVATION COMMISSION R. C. Warthen Alaska District Transmitting: Two (2) magnetic tapes - Trading Bay Unit G-4RD ....... ~ ...... .:.~.,.~ .... ~.. ~ ,~4 ..~ t ? ..... (1) f~6261~ (with Verification listing) ~¢-/~/~$'~0/'~,/'''$-'''~'~'': ...... "'~ '" (2) ff62715 (with verification listing) _ ,,~' ;~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. DATED: ~Al'~ '-. ',' ,,.~W STATE OF ALASKA " ALAS[i".. ,alL AND GAS CONSERVATION( ~.,,.)MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1, DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA 3. Address 4. Location of Well Alaska 99502 Cond. #39, Leg #2, 1882' N, & 1389' W of SE corner of Sec. 29, TgN, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 12. I 6. Lease Designation and Serial No. 7. Permit No. 81-183 8. APl Number s0- 733-20050-01 9. Unit or Lease Name Trading Bay Unit 10. Well Number G-4 RD 11. Field and Pool ADL 18730 McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: Perforate Stimulate Repair Well (Submit in Triplicate) (Submit in Duplicate) ~ Alter Casing [] Perforations [] Altering Casing [] [] Abandon [-] Stimulation [] Abandonment [] [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed to perforate the following intervals: 9,815' - 9,842' (existing) 9,862' - 9,882' (new) 5;,965' - 10,015' (existing) SEP .'[ 9 Alaska 0il & Gas Cons. Cummissio~. Anchorage 14. I her~~e foregoing is true and correct to the best of my knowledge. ' Signed ~_~~~~")_1~",~'/,~?~'~ -- ,, _ Title District Engineer The space bel---ow 'foUr Co~lmission use Conditions of Ap~v'~,'if a~VPe Date Sept. 15, 15 Approved by_ Form 10-403 ORIGINAL $1Gli[9 BY LONNI£ C. SMITH Appr(~ved Copy _~2eturned' _ _ By Order of COMMISSIONER the Commission Date .'~'" '~5~" f'-~ Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~' STATE Of ALASKA ~ ; ALASI~,-, OIL AND GAS CONSERVATION OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. Persrr~t ~o83 UNTON 0IL COMPANY OF CALTFORNIA - 3. Address 8. APl Number P. O. Box 6247, Anchorage, Alaska 99502 so- 733-20050-01 4. Location of Well Cond. #39, Leg #2, 1882' N, & 1389' W of SE corner of Sec. 29, TgN, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) RT 99' above MSL 12. I 6 . Lease Desionationand Serial No. /~DL i8730 9. Unit or Lease Name Trading Bay Unit 10. Well Number G-4 RD 11. Field and Rool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form t0-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170).' The following intervals were perforated on September 7, 1983: 9,815' - 9,842' (existing) 9,862' - 9,882' (new) 9,965' - lO,O15' (existing) *Verbal approval was received from Russ Douglas .on September 2, i983. 14. I here~~~t~for_egoing is true and correct to the best of my ~:~d~.ct Engineer Signed -- ~ V~u~,~ C~o-- ' Title Sept. 15, 19 The space below for Commission use Date -,.-?__ / Conditions of Approval, if any: , By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ALAS~. ,.,~'AND GAS CONSERVATION L ..... ~llSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG -' 1. Status of Well Classification of Service Well OIL~[] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Union Oil Co. of California 81-183 3. Address 8. APl Number P.O. Box 6247. Anchoracre. AK 99502 50-733-2nn50-0] ~ . 4. Locat'ion of well at surface Cond 39, Leg 2, 1882' N & 1389' W of S~_ Cor, 9. Unit or Lease Name Sec. 29, T9N, R13W, S.M. _D Trading Bay Unit At Top Producing ~nterva~ 2351' NSL & 4023' EWL Sec. 29, T9N, ~O3W~TIONS 10. WellNumber (SM) VERIF~ED TBU G-4RD (23X-28) At Total Depth 20~6' NSL & 4658' EWL Sec. 29, T9N, R13W (SM Surf. ~._~__ 11. Field and Pool ~ B.H.~ ..5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RT 99' MSL ADL 18730 ~ur River Field 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 2-10-82 3-2-82 3/22/82J 143 feet MSLJ 1 ..17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10,450ND & 9606~ 10,420ND & 9580~D'ESE~ NO[]I ----- feetMD 22. Type Electric or Other Logs Run DIL-Sonic-GR-FDC-CSU~-CBL-VDL · 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED · _ 7" 29~ N-80 .~urface 10,450 8 1/2" "725 sxs CT_, "G" . '. . · . ,, · . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SlZ~:, DEPTH SET (MD) PACKER SET (MD) ' "' __MD TVD ..: HPF .. 3 1/2" 9720 9815-9843 9057-9081 8 .. ' 9965-10015 9185-9228 ': 8 ~6. . ACID, FRACTIJRE, CEMENT SQUEEZE, ETC. 9960-9962 '9181-9182 4 .'. . . . DEPTH INTERVAL (MD). A~UNT&KINDO.FMATERIALUSED . Sxs ,,G,, .. ... ,6070-,6072 200 " . . · ~ ..' ,.9758-9760" "" 200 " .:..,., , ""~ , ", 9852-9854 .. 100 " 27. .PR~ODUCTI~)N TEST 101'62-10164 200 "" , Date First Production Method of OpEration '(FIo.wing~ ges'!ift, etc.).. '" 3-21-82 Gas Lift ' ':i ...... ~,, 'Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS[MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO · ' 3/27/82 12 TEST PERIOD. I~, 1043 . ,... 330.5. ',' 129... 317 Flow Tubing Casing Pres~L~re ' cALCuLATED . OIL-BBL .. .G.AS-MCF WATER-BBL OIL GRAVITY-APl (c0'rr) · 'Press. 120 1130 24-HOUR RATE ~ 2086 ..' '1'661' .' 258 ... . ' ' 28. coREDATA '"' ' ' "Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · None . . ,...,,,. ,, '.' '. ? ..... .,. ' ... , .:/~J,qska 0il & Gas [,0ns. u0mrmsskm L Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .. GEOEOGIC 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. T/"G" Zone 8970 8337 None T/Hemlock 9807 9050 B/Hemlock 10,4 06 9567 31. LIST OF ATTACHMENTS 32. I hereby~'~y that the foregoing is true and correct to the be'st of my knowledge /' / '-" .... ? (7 ' ,' ' NSTRUCTIONS General' This form. is designed/Cor submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other'elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool~ ',':.:-...-v, :.i".:": ,'.;';~-.',:-',,.'....'~ ,:'-:!: O~'.~r..'.r'c~';';c:.;"~" Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- . ,,... .i~..~.:":; ::':,:'~...:-. :.:'..~,; ;'~. ;.':',..:,~.:,,..,:';, St'Jut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 . .......... :..,.~-~4~...~..~..._.__~_,.. ,... .............. ~..,... -~'~ i_ZZ'Z Z m, '"' ~'~ ;8 8 ,,, _ ,,. FIELD McArthur River Field IN OIL COMPANY OF CALIFORNIA WELL RECORD -4 RD LOCATION: Conductor #39~ Leg Room #2~ Grayling Platform~ 1882'N & 1389' W of SE corner~ Sec. 29~ TgN~ R13W~ SM. PERMIT NO. 81-183 SERIAL NO. ADL 18730 TD 10451' TVD 9607' DEVIATION (EHL) 3252' ~ N87E COMPANY ENGINEER Wagonhoffer~ Criswell SIZE WEIGHT THREAD ~HEET A PAGE NO. SPUD DATE 2/3/82 CONTRACT~ Parker TYPE UNIT 1320 National DRILL PIPE DESCRIPTION 5" E COMP. DATE 3/22/82 RIG NO. 54 ELEVATIONS: WATER DEPTH 125' RT TO OCEAN FLOOR 224' RT TO MLLW 99' ~ RT TO DRILLx~DECK 19.30' RT TO PR~~ON ~CK 4,2~[~ APPROVEDU ~./.,.~'~ ....... CASING & TUBING RECORD GRADE DEPTH REMARKS 16" Drive Pipe 621' See previous history 13 3/8" 61# Butt 0-55 3043' " 9 5/8" 40~ 47~ 43.5 Butt N-80 5970' " 7" 29# Butt N-80 3 1/2" 9.3 Butt N-80 9751' Pkr ~ 9720' 10451' Cmt'd w/ 725 sxs "G" w/ additives 3 1/2" 9.3 Butt N-80 10293-10323' Isolation pkr ® 10280' CBL PERFORATING RECORD DATE INTERVAL E.T.D. REASON 2/6/82 6070-6072' 9287' (Ret) Isolation 2/6/82 5960-5962' 6050' (Ret) " 3/9/82 9960-996~' 10060' (Ret) " PRESENT CONDITION Sqz'd w/ 200 sxs cl "G" Sqz'd w/ 100 sxs cl "G" Could not break down w/ 1500.-psi - -- '-~'-- " (69 pcf mud) 3/9/82 10162-10164' 10420' " 3/10/82 9852-9854' 10420' " 3/11/82 9758-9760' 9796 (Ret) " 3/21/82 9965-10015' 10280' (Pkr) Production 3/22/82 9815-9842' 10280' (Pkr) " Sqz'd w/200 sxs "G" w/ additives Sqz'd w/ 100 sxs "G" w/ additives- Sqz'd w/ 200 sxs "G" w/ additives Bench 3 open for production 8 HPF Bench 1 open for production 8 HPF Note: Ail Hemlock perfs in original well bore sqz'd w/ 200 sxs cl "G" INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR' REMARKS . . ~ WELL HEAD ASSEMBLY TYPE: CASING HEAD: Shaffer model KD 12" series 900 to 13 3/8" SOW .. CASING HANGER: Shaffer 12" Nominal - 9 5/8" model KD KS CASING SPOOL: ClW 12" 3M x 12"-3M Type "WF" TUBING HEAD: CIW 12" 3M X 10" 5M DC-B Spool TUBING HANGER: 3 1/2" Single ~,~ TUBING HEAD TOP: 3 1/2" EUE MASTER VALVES: SEP 2 1 1982 AJas.~a Oil & Gas Cons. Commission Anchorage CHRISTMAS TREE TOP CONN: 4 1/2" EVE UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT WELL NO. G-4 RD FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1 2/3/82 10164' TD 9910' ETD (RET) 9 5/8" C. 9563' 7" L. 10164', Top ~ 9449' FIW DAILY COST: $ 19,850 ACC COST: $ 19,850 AFE AMT: $3,000,000 2 2/4/82 DAILY COST: ACC COST: AFE AMT: 3 2/5/82 DAILY COST: ACC COST: AFE AMT: 10164' TD 9910' ETD (RET) 9 5/8" C. 9563' 7" L. 10164', TOP ~ 9449' FIW $ 26,013 $ .45,863 $3,000,000 10164' TD 9010' ETD (EST TOC) 9 5/8" C. 9563' 7" L. 10164', Top $ 9449' FIW $ 44,800 $ 90,743 $3,000,000 Commenced operations $ 00:01 hrs 2/3/82 over conductor #39, leg #2, TBUS G-4. RU Myers WL & pulled ball valve ~ 273'. Could not get below 2468' w/ shifting tool. POOH w/ WL. RIH w/ 2.5" OD swage to 9400'. POOH & RD WL. Fill annulus w/ FIW & bullhead 150 bbls of FIW down tbg. Well is dead. Could not find BPV. RU Myers WL to reinstall'ball valve. RIH & set ball valve in tbg $ 273'. Removed'tree. Installed & tested BOPE to 2500 psi. Pulled on 4 1/2" tbg - unstabbed f/ prod pkr. Cite btms up & POOH. LD 299 jts of 4 1/2" tbg & GLM's. RIH w/ 8 1/2" bit on 9 5/8" csg scraper while picking up 5" DP. Continued to PU 5" DP. Tagged prod pkr $ 9350'. Circ & POOH. RIH w/ 9 5/8".Howco cml ret & set ~ 9287' DPM. Broke down Hemlock parrs f/ 9600' to 9628' & 9648' to 9898' w/ 3500 psi. Pumped in w/ 20 CFM ~ 3200 psi. Mixed & sqz'd Hemlock perfs for abandonment w/ 200 sxs cl "G" w/ .75% CFR-2L & .1% HR6L. Displ 174 sxs below ret w/ a final press of 4000 psi. CIP ~ 15:30 hrs. Pulled 3 stds of DP to 9010' & rev circ - had no cmt back. POOH. RU & ran SDC gyro survey f/ surf to 9000'. SE'P 2 ,I. Alaska Oil & Gas Cons. Commission ^~chorao~ LEASE TRADING BAY UNIT ""-~' SHEET D --- PAGE NO. UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. G-4 RD ,2 FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4 2/6/82 DAILY COST: ACC COST: AFE AMT: 5 2/7/82 DAILY COST: ACC COST: AFE AMT: 6 2/8/82 DAILY COST: ACC COST: AFE AMT: 10164' TO 5900' ETD (Est TOC) 9 5/8" C. 9563' 7" L. 10164', Top $ 9449' FIW $ 44,915 $ 135,658 $3,000,000 10164' TD 6050' ETD (RET) Window f/ 5970' to 5980' 9 5/8" C. 9563' 7" L. 10164', Top $ 9449' 64 PCF 165 SEC $ 25,707 $ 161,365 $3,000,000 10164' TD' 6050' ETD (RET) Window f/ 5970' to 6013' 9 5/8" C. 9563' 7" L. 10164', Top $ 9449' 64 PCF 145 SEC $ 28,956 ' $ 190,321 $3,000,000 RD SDC gyro. RIH on APRS WL w/ perf gun & perfed 4-1/2" HPF f/ 6070 to 6072' DIL. RIH & set ret ~ 6050. Broke down perfs w/ 20 CFM ~ 2200 psi. Mixed & sqz'd for csg stabili- Zation w/ 200 sxs cl "G" w/ .75% CFR-2L & .3% Halad 22A. Had a final press of 2600 psi. CIP ~ 05:20 hrs. Pulled out of ret & rev circ 5 sxs cmt..POOH. Tested BOPE - WAA by AOGCC. RIH w/ perf gun & parred 4-1/2" hPF f/ 5960' to 5962' DIL. RD WL. RIH w/ RTTS pkr on 5" DP & set pkr ~ 5764'. Broke down perfs w/ 12 CFM ~ 2700 psi. Mixed pumped 100 sxs cl "G" w/ .75% CFR-2L & .3% Helad 22A. Had final press of 3000 psi. CIP ~ 16:50 hrs. Held press on sqz until 20:30 hrs. Released RTTS & POOH. LD extra 5" DP. Cleaned active mud tanks.' RIH w/ 8 1/2" bit & tagged top of cmt ~ 5912' Drld cmt f/ 5912' to 6050'. CJrc & POOH. RIH w/ 9 5/8" Servco section mill. Cut thru 9 5/8" csg ® 5970' & cut window f/ 5970' to 5980'. Continued to mill window in 9 5/8" csg f/ 5980' to 6007' (37' total). Circ & POOH. RIH w/ mill #2 & milled window f/ 6007' to 6013'. Circ clean. Sfp 2 1 A!ar~ka Oil & Gas Cons. C0mm!ss/ou /~ pChnrmn~ UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE TRADING BAY UNIT WELL NO. G-4 RD SHEET D PAGE NO. ,3 FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 7 219/82 DALLY COST: ACC COST: AFE AMT: 8 2/10/82 10164' TD 5766' ETD (CMT) Window f/ 5970' to 6032' 9 5/8" C. 9563' 7" 1. 10164', Top ~ 9449' 63 PCF 44 SEC $ 31,415 $ 221,736 $3,000,000 10164' TD 5975' ETD (CMT) Window f/ 5970' to 6032' 9 5/8" C. 9563' 7" L. 10164', TOP ~ 9449' 63 PCF 45 SEC DAILY COST: $.. ACC COST: $ 253,485 AFE AMT: $3,000,000 9 2/11/82 DAILY COST: ACC COST: AFE AMT: 10 2/12/82 DAILY COST: ACC COST: AFE AMT: 6206'/231' Window f/ 5970' to 6032' 9 5/8" C. 5970' 66 RCF 60 SEC 36,433 289,918 $3,000,000 6470'/264i 13 3/8" C. 3043' 9 5/8" C. 5970' 67 PCF 82 SEC $ 46,672 $ 336,590 $3,000,000 POOH. RIH w/ section mill #3 & milled window in 9 5/8". csg f/ 6013' to 6032'. Circ& POOH. RIH w/ OEDR to 6045'. Pumped 50 bbls of caustic-.. water ahead of 100 sxs cl "G" w/ 3% NEC1, .75% CFR-2, & 10% sand. Displ w/ 585 F3 of mud. CIR ~ 17:00 hrs. Pulled 3 stds to 5766' & rev circ l0 .F3 of cmt. POOH. WOC. Changed seats & heads in #1 mud pump. Changed seats & heads in #1 mud pump. RIH w/ bit #1RR #1 & tagged cmt ~ 5895'. Washed down to 5900'. WOC. CO firm cmt f/ 5900' to 5975'. Circ hole clean & dump cmt-contam mud. C&C mud. POOH & LD 30 jts of DR. RIH w/ bit #2 on BHA #2 for Dyne drill run #1. RIH w/ SDC steering tool. Oriented dyna drl &dyna drld 8 1/2" hole f/ 5975' to 6038' (6' below csg stub). POOH for bit change. RIH w/ bit #3 on BHA #2 for Dyne drill run #2. Oriented dyne drl & dir drld 8 1'/2" hole f/ 6038' to 6206'. RD SDC. POOH w/ dyna-drl. POOH w/ dyne drl - bit #3 wes mis- sing ell 3 cones. RIH w/ 8 1/4" OD shoe on OB. Cut over junk & POOH - rec ell three cones. RIH w/ bit #4 on BHA #3 (30' belly) & reamed dyna- drl run f/ 5975' to 6206'. Dir drld 8 1/2" hole f/ 6206' to 6470'. Surveys: 6265' 30° 30' N74°E 6438' 30° 15' N77 1/2°E SEP 2 1 Ak~.ska 0il & Gas 0OHS. (]omm!ssioD Anchorag~ ..._. -.,_,~.. SHEET D UNION OIL COMPANY OF CALIFORNIA WELL RECORD PAGE NO. 4 LEASE TRADING BAY UNIT WELL NO. G-4 RD FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 11 2/13/82 DAILY COST: ACC COST: AFE AMT: 12 2/14/82 DAILY COST: ACC COST: AFE AMT: 13 2/15/82 DAILY COST: ACC COST: AFE AMT: 14 2/16/82 DAILY COST: ACC COST: AFE AMT: 15 2/17/82 DAILY COST: ACC COST: AFE AMT: 6822'/352' 13 3/8" C. 3043' 9 5/8" C. 5970' 68 PCF 58 SEC $ 25,917 $ 362,507 $3,000,000 7131'/309' 13 3/8" C. 3043' 9 5/8" C. 5970' 67 PCF 60 SEC 31,436 393,943 · 000,000 7246'/115' 13 3/8" C. 3043' 9 5/8" C. 5970' 66 PCF 55 SEC $ 45,958 $ 439,901 $3,000,000 7421'/175" 13 3/8" C. 3043' 9 5/8" C. 5970' 69 PCF 48 SEC $ 25,765 $ 465,666 $3,000,000 7767'/346' 13 3/8" C. 3043' 9 5/8" C. 5970' 70 PCF 45 SEC $ 32,761 $ 498,427 $3,000,000 Dir drld 8 1/2" hole f/ 6470' to 6602'. POOH. RIH w/ bit #5 on BHA #3 (30' belly). Reamed f/ 6527' to 6602' & dir drld 8 1/2" hole f/ 6602 to 6822'. Pumped dry job & POOH. RIH w/ bit #6 on BHA #4 (locked up essy) & reamed f/ 6775' to 6822'. Surveys: 6589' 31° N80E 6726' 31° 30' N77E 6802' 32° N79E Dir drld 8 1/2" hole f/ 6822' to 7131'. Circ& POOH. RIH w/ bit #7 on BHA $5 for dyne-drl run #3. RU & RIH w/ SDC steering tool. Steering tool did not work. POOH - left por- tion of steering tool in hole. POOH w/ dyne-drl. Surveys: 7071' 31° N77E POOH w/ dyne drl. Retrieved 15' of steering tool. RIH w/ BHA #5 for Dyne-drl run #3. RIH w/ SDC steer- ing tool - could not get tool to work. POOH w/ steering tool. RD SDC. RU Sperry Sun steering tool. Dyna-drld 8 1/2" hole f/ 7131' to 7246'. POOH w/ Wt. POOH w/ dyne- drl. POOH w/ dyne drl. RIH w/ bit #8 on BHA #6 (30' belly follow essy). Reamed dyne-drl run f/ 7126' to 7246'. Dir drld 8 1/2" hole f/ 7246' to 7421'. Circ& POOH. RIH w/ bit #9 on BHA #7 (locked up assy). SurveyS: 7270' 30° 15' N89E 7357' 30° % RIH w/ bit #9 on BHA #7 (locked up) & reamed f/ 7348' to 7421'. Dir drld 8 1/2" hole f/ 7421' to 7608'. Circ& trip for bit change. drld 8 1/2" hole f/ 7608' to 7767'. Circ & POOH. Surveys: 7565' 29° S86E 7659' 28° 30' S84E 7732' 280 30' S83E Ab.r3:c* 0il & Gas Gons, comm!ssion 'F UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT WELL NO. G-4 RD FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 16 2/18/82 7950'/183' 13 3/8" C. 3043' 9 5/8" C. 5970' 69 PCF 47 SEC DAILY COST: $ 28,119 ACC COST: $ 526,546 AFE ANT: $3,000,000 17 2/19/82 DAILY COST: ACC COST: AFE AMT: 18 2/20/82 8310'/360' 13 3/8" C. 3043' 9 5/8" C. 5970' 70 PCF 45 SEC $ 33,639 $ 560,185 $3,000,000 8621'/311' 13 3/8" C. 3043' 9 5/8" C. 5970' 72 PCF 48 SEC DAILY COST: $ 25,267 ACC COST: $ 585,452 AFE AMT: $3,000,000 19 2/21/82 DAILY COST: ACC°COST: AFE AMT: 8955'/334' 13 3/8" C. 3043' 9 5/8" C. 5970' 73 PCF 48 SEC $ 27,611 $ 613,063 $3,000,000 Trip for bit change. RIH w/ bit #11 on BHA #7 (locked up). Reamed f/ 7705' to 7767' & dir drld 8 1/2" hole f/ 7767' to 7950'. Circ & POOH. RIH w/ bit #12 on BHA #8 (30' belly). Reamed f/ 7911' to 7950'. Dir drld 8 1/2" hole f/ 7950' to 8137'. Trip for bit change. RIH w/ bit #13 on BHA #9 (45' belly) & dir drld 8 1/2" hole f/ 8137' to 8310'. Circ & trip for bit change. Surveys: 7845' 27° 30' S82 1/2E 7915' 27° S82E 8107' 27° S80E 8272' 29° $72E Trip for bit change. RIH w/ bit #14 on BHA #10 &.reamed f/ 8280' to 8310'. Dir drld 8 1/2" hole f/ 8310 to 8568'. Trip for bit change. RIH w/ bit #15 on BHA #lC & reamed f/ 8514' to 8568'. Dir drld 8 1/2" hole f/ 8568' to 8621'. Dir drld 8 1/2" hole f/ 8621' to 8805'. Trip for bit change. RIH w/ bit #16 on BHA #10 & reamed f/ 8761' to 8805'. Dir drld 8 1/2" hole f/ 8805' to 8955'. SEP 2 ! 1_ 8_2 !~,!:.~!',~ Oi! & G;ts Cons. Comm!ssion UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT WELL NO. G-4 RD FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 20 2/22/82 9120'/165' 13 3/8" C. 3043' 9 5/8" C. 5970' 73 PCF 45 SEC DAILY COST: $ 43,324 ACC COST: $ 656,387 AFE AMT: $3,000,000 21 2/23/82 9319'/199' 13 3/8" C. 3043' 9 5/8" C. 5970' 73 PCF 35 SEC DAILY COST: $ 27,048 ACC COST: $ 683,435 AFE AMT: $3,000,000 22 2/24/82 DAILY COST: ACC COST: AFE AMT: 23 2/25/82 DAILY COST: ACC COST: AFE AMT: 9432 '/113 ' 13 3/8" C. 3043' 9 5/8" C. 5970' 73 PCF 57 SEC $ 41,217 $ 724,652 $3,000,000 9497'/65' 13 3/8" C. 3043' 9 5/8" C. 5970' 72 PCF 61 SEC $ 52,701 $ 777,353 $3,000,000 Trip for bit change. RIH w/ bit #17 on BHA #10 & reamed f/ 8890' to 8955'. Dir drld 8 1/2" hole f/ 8955 to 9120'. Circ & POOH. Changed out jars in BHA. RIH w/ bit #18 on BHA #11 (30' belly) & reamed f/ 9060' to 9120'. Dir drld 8 1/2" hole f/ 9120' to 9291'. Circ & POOH. RIH w/ BHA #12 to 7500'. POOH for dyne drl Oriented dyna-drl +80° left ~f high side (to correct steady rt hand walk). Dyna-drld 8 1/2" hole f/ 9291' to 9319'. Dyna-drld 8 1/2" hole f/ 9319' to 9355'. Circ'& POOH. RIH w/ bit #20 on BHA #13 for Dyne-drl run #5. Reamed f/ 9288' to 9355'. Oriented tool 70° left of high side & dyna- drld 8 1/2" hole f/ 9355' to 9420'. Ciro & POOH. RIH w/ bit #21 on BHA #13 for Dyna-drl run #6. Attempted to orient tool - steering tool failed. POOH w/ WL & changed tools. Oriented dyna-drl +60° left of HS & dyna-drld 8 1/2'~hole f/ 9420' to 9432'. Dyna drld 8 1/2" hole f/ 9432' to 9463'. POOH w/ WL. Cite & POOH w/ D/D. RIH w/ bit #22 on BHA #14 (30' belly follow assy). Reamed dyne drl run f/ 9291' to 9463'. Dir drld 8 1/2" hole f/ 9463' to 9497'. Circ & POOH. RIH[w/ bit #23 on BHA #15 (locked up a§sy). Reamed f/ 9463' to 9497'. Survey: 9477' 32°'S70E SHEET D UNION OIL COMPANY OF CALIFORNIA WELL RECORD PAGE NO. 7 LEASE TRADING BAY UNIT WELL NO. G-4 RD FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 24 2/26/82 9803'/306' 13 3/8" C. 3043' 9 5/8" C. 5970' 73 PCF 55 SEC DAILY COST: $ 32,931 ACC COST: $ 810,284 AFE AMT: $3,000,000 25 2/27/82 DAILY COST: ACC COST: AFE AMT: 26 2/28/82 9972'/169' 13 3/8" C. 3043' 9 5/8" C. 5970' 73 PCF 68 SEC $ 38,859 $ 849,143 $3,0.00,000 13 3/8" C. 3043' 9 5/8" C. 5970' 73 PCF 62 SEC DAILY COST: $ 44,609 ACC COST: $ 893,752 AFE AMI: $3,000,000 27 3/1/82 DAILY COST: ACC COST: AFE AMT: 10425'/277' 13 3/8" C. 3043' 9 5/8" C. 5970' 73 PCF 62 SEC $ 34,235 $ 927,987 $3,000,000 Dir drld 8 1/2" hole f/ 9497' to 9803'. Survey: 9629' 32° 30' S74E Dir'drld 8 1/2" hole f/ 9803' to 9855'. Trip for bit change. RIH w/ bit #24 on BHA #15 & reamed f/ 9795' to 9855'. Dir drld 8 1/2" hole f/ 9855' to 9972'. Survey: 9815' 31° 30' S73E Dir drld 8 1/2" hole f/ 9972' to 10148'. Circ& trip for bit chg. Survey: 10108' 30° S73E RIH w/ bit #25 on BHA #15 & reamed f/ 10048' to 10148'. Dir drld 8 1/2 hole f/ 10148' to 10425'. Circ& POOH. Had 1 tight spot ~ 10113'. SEP 2 i iS82 A.~,.~,~-~' ~""' Oil & Gas Cons. Comm!ssion l¥~chora[D UNION OIL CONPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT WELL NO. G-4 RD FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 28 3/2/82 DAILY COST: ACC COST: AFE ANT: 29 3/3/82 10450'/25' 13 3/8" C. 3043' 9 5/8" C. 5970' 73 PCF 55 SEC $ 25,603 $ 953,590 $3,000,000 10450' TD 13 3/8" C. 3043' 9 5/8" C. 5970' 73 PCF 55 SEC DALLY COST: $ 113,078 ACC COST: $1,066~_.~68 AFE ANT: $3,000,000 30 3/4/82 10450' TD 13 3/8" C. 3043' 9 5/8" C. 5970' 73 PCF 55 SEC DAILY COST: $ 21,005 ACC COST: $1,087,673 AFE ANT: $3,000,000 31 3/5/82 DAILY COST: ACC COST: AFE ANT: 10450' TD 13 3/8" C. 3043' 9 5/8" C. 5970' 73 PCF 55 SEC $ 53,510 $1,141,183 $3,000,000 POOH. RIH w/ bit #26 on BHA #15. Reamed f/ 10376' to 10425' & dir drld 8 1/2" hole f/ 10425' to 10450. Circ& made 14 std wiper trip - had slightly tight hole. Circ& dropped survey. POOH - trip was smooth. RU Schlum. Ran DIL-Sonic-GR log f/ 10436' to 8500' when Sonic tool failed. POOH & changed tool. RIH & completed logging f/- 8500' to 5970'. Ran FDC-CNL-GR log f/ 10436' to 5970'. Completed running FDC-CNL-GR log f/ · 10436' to 5970'. Perform necessary rig repairs. LD monel DC's & RIH w/ 8 1/2" blt to 10447'. CO to 10450'. Circ & made short trip to check hole condition - ok. POOH w/ DP. Ran FDC-CNL-GR log f/ 5970' to 3CO0. RD Schlum. RIH & set RBP ~ 1025'. POOH w/ DP. Remove BORE & Shaffer tbg spool. Installed CIW 12" 3M X 12" 3M csg spool & 12" 3M X 10" 5M DCB spool. Reinstalled BORE. Reinstalled BORE & tested to 2000 psi. RIH w/ OS & retrieved RBP ~ 1025'. RIH w/ 8 1/2" blt to 10450' & circ clean. POOH & LD 5" DP & BHA. Changed pipe rams to 7". RU & ran 7" csg. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT WELL NO. G-4 RD FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 32 316182 DAILY COST: ACC COST: AFE AMT: 33 3/7/82 10450' TD 9200' ETD (EST TOC) 9 5/8" C. 5970' 7" C. 10450' 73 PCF 55 SEC $ 413,622 $1,554,805 $3,000,000 10420' ETD (CMT) 9 5/8" C. 5970' 7" C. 10450' 69 PCF 34 SEC DAILY COST: $ 22,550 ACC COST: $1,577,355 AFE AMT: $3,000,000 34 3/8/82 DALLY COST: ACC COST: AFE AMT: 10450' TD 10420' ETD (CMT) 9 5/8" C.' 5970' 7" C. 10450' 69 PCF 34 SEC $ 51,029 $1,628,384 $3,000,000 Ran 10461' (242 jts) of 7" 29# N-80 butt csg w/ shoe @ 10450', FC ~ 10362'. Circ csg & pumped 10 bbls of mud sweep ahead of 425 sxs of cl "G" w/ .5 gal/sx econolite, .3% HR6-L, & .25#/sx flocele to 102 pcf followed by 300 sxs cl "G" w/ 1% CFR-2, 3% Halad 22A, 3% KCL, & .25# /sx flocele to 118 pcf. Displ plug w/ mud. Discovered leak'in line to cmt head w/ 1900 F3 displaced (2160 F3 required). Shut down to repair-line (5 min). Attempted to continue pumping but could not get cmt to move again. Bled off pressure - floats held ok. CIP ~ 12:15 hrs. Removed BOPE & set in csg slips. Tested osg hanger to 3000 psi - ok. RIH w/ 6" bit while PU 3 1/2" DP. Tagged cmt ~ 9068'. Cleaned out cmt f/ 9068' to 10420'. Cite &'strapped out of hole. RU DA to run CBL-VDL- GR. Had a tool problem. Replaced tool & RIH. Ran CBL-VDL-GR log f/ 10410' to 5900'. RU Sperry Sun DA & RIH w/ gyro survey - could not get below 9750'. POOH w/ gyro. RIH w/ GR & OB to lO150' - could not get deeper. POOH. RIH w/ 6" bit on 7" csg scraper to 10420' &circ clean. POOH. -. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. lO LEASE TRADING BAY UNIT WELL NO. G-4 RD FIELD TRADING.BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 35 3/9/82 10450' TD 10420' ETD (CMT) 9 5/8" C. 5970' 7" C. 10450' 69 PCF 36 SEC DAILY COST: $ 60,047 ACC COST: $1,688,431 AFE AMT: $3,000,000 36 3/10/82 10,450' TD 10,420' ETD (CMT) 9 5/8" C. 5970' 7" C. 10,450' 69 RCF 36 SEC DAILY COST: $~0,891 ACC COST: $1,729,322 AFE AMT: $3,000.000 Reran gyro survey f/ 10400' to 5600. RIH w/ 4" csg guns & parred 4-1/2" HRF f/ 10162' to 10164' DIL for BS #1. RIH & set ret e 10060' & at- tempted to break down perfs w/ 4500 psi (.93 psi/ft grad.) - would not break down. ROOH w/ DR. RIH w/ 4" csg guns & perfed 4-1/2" HPF f/ 9960' to 9962' DIL..RIH.& set ret ~ 9906' & attempted to break down perfs w/ 6500 psi (1.19 psi/ft grad) - press bled to 5700 psi in 10 min. POOH w/ DP. RIH w/ 4" csg gun and perf'd 4-1/2" HPF for BS #3 f/ 9852' to 9854' DIL. RIH w/ RTTS pkr and set $ 9800' DPM. Tested surface lines-OK. Broke down formation w/ 5100 psi--(1.04 psi/ft.) Pumped in w/ 3 BPM ~ 5400 psi. Released pkr and POOH. RIH and set ret ~ 9796' DIL. RIH w/ DP and stabbed into ret ~ 9810' DPM. Tested surface lines to 6500 psi. Pumped into formation w/ 3BPM $ 5600 psi. Mixed and squeezed w/ 100 sx cl "G" w/ 3% kcl, 3% Halad 228, 1% CFR-2 w/ a final rate of 3BPM ~ 5400 psi. SQZ held 2800 psi w/ pumps off l0 min. CIR ® 20:15 hrs. Reversed out 5 sx cmt. POOH. SEP 2 1 i982 A!ask~ Oil & Gas Cons. CommJssior~ /\nchorago .. UNION OIL COMPANY OF CALIFORNIA WELL RECORD PAGE NO. 11 LEASE TRADING BAY UNIT WELL NO. G-4 RD FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 37 3/11/82 DALLY COST: ACC COST: AFE AMT: 38 3/12/82 DAILY COST: ACC COST: AFE AMT: 10450' TD 9700' ETD (RET) 9 5/8" C. 5970' 7" C. 10450' 64 RCF 32 SEC $ 62,532 $1,791,854 $3,000,000 10450' TD 10060' ETD (RET) 9 5/8" C. 5970' 7" C. i0450' 64 PCF 33 SEC $ 23,155 $1,815,009 $3,000,000 RU DA. Perfed 4-1/2" HPF f/ 9758' to 9760' DIL for BS ~4. RD DA. RIH w/ RTTS pkr on DR & set 8 9650' DRM. Broke down perfs w/ 5400 psi. Rumped in W/ 4 BRM 8 4900 psi. Form held 2500 psi w/ pumps off l0 min. Bled off press & ROCH w/ RTTS pkr. RU DA. RIH & set ret 8 9685' DIL. ROOH & RD DA. RIH w/ stinger on DR & tagged ret 8 9700' DRM. RU Howco' & tested surf lines to 6000 psi. Broke down perfs w/ 5400 psi. Pumped in w/ 4 BRM 8 5600 psi. Form held 3500 psi w/ PO l0 min. Mixed & sqz'd w/ 200 sxs cl "G" w/ 1% CFR-2, 3% Halad 22A, KCL. Displ 190 sxs below ret w/ a final rate of 3 BPM 8 5500 psi. Sqz held 4100 psi after l0 min. Rev out l0 sxs omt. CIR ~ 14:28 hrs. ROOH. RIH w/ bit #28 to 9000' & WOC. hfs to 05:00 hrs. RIH & tagged cmt $ 9698'. CO to 9700'. Drld ret ® 9700' & cmt f/ 9702' to 9775'. RIH to 9810'. Drld ret $ 9810' & RIH to 9853'. Drld cmt f/ 9853' to 9871'. RIH to ret $ 9906'. Trip for bit change. RIH w/ bit #29 & drld ret $ 9906'. RIH to 10060'. SEP 2 1 ifiSZ Oil & Gas Cons. Commission !',,p, chora~e UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE TRADING BAY UNIT WELL NO. G-4 RD SHEET D - . PAGE NO. 12 FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 3113182 DAILY COST: ACC COST: AFE AMT: 40 3/14/82 DAILY COST: ACC COST: AFE AMT: 10450 ' TD 10420' ETD (CMT) 9 5/8" C. 5970' 7" C. 10450' 64 PCF 35 SEC $ 24,700 $1,839,709 $3,000,000 10450 ' TD 10420 ' ETD (CMT) 9 5/8" C. 5970' 7" C. 10450' 63 PCF 35 SEC $ 27,335 $ !, 867,044 $3,000,000 Drld ret ~ 10060' & RIH to 10420'. Circ & POOH. RIH w/ bit & csg scrpr to 10420'. Circ& POOH. RIH w/ RTTS pkr-& hydrospring tester & set RTTS @ 9660'. Opened hydrospring to"--.-. dry test-perfs. Had blow for i hr. Released pkr & reset e 9912' Opened hydrospring'to dry te~t BS #1 & BS #2 perfs - had week blow then dead. Reset RTTS pkr ~ 9814' & opened hydrospring to dry test BS #1, BS #2, & BS #3 perfs - had intermittent bubbling. Reset RTTS ~ 9660' & opened hydrospring to dry test all BS perfs - had very weak blow. Released RTTS & pulled 3 stds. Dropped bar to open circ port & rev out gas cut mud & oil. POOH. POOH. RIH w/ RT.TS & hydrospring on dry DP. Set RTTS ~ 10098' & opened hydrospring to test BS #1 perfs f/ 10162' to 10164' D%L. Had vigorous blow & ann dropped. Released pkr & rev circ oil & gas cut mud. POOH. Found reversing sub had failed. RIH w/ RTTS and hydrospring w/ dry DR set RTTS ~ 10,098'. Opened hydro- spring-had slight blow which increased to strong blow in 35 min. Filled DP-took 51Bbls. Had 24 Bbl entry. Pressured up to 7000 psi- form would not break down. Pressure bled to 5100 psi in 48 min. Bled off pressure and reverse circ. Rec oil w/ 12% water cut. POOH-found 2' of sand in DP above hydrospring. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. _$' .13 -. LEASE TRADING BAY UNIT WELL NO. G-4 RD FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 41 3/15/82 DAILY COST: ACC COST: AFE AMT: 42 3/16/82 DAILY COST: ACC COST: AFE AMT: 10,450' TD 10,097' ETD (Ret) 9 5/8" C 5970' 7" C 10,450' 63 PCF 35 SEC $ 29,425 $1,896,469 $3,000,000 10,450' TD 10,420' ETD (CMT) 9 5/8" C 5970' 7" C 10,450' 63 PCF 34 SEC $ 49,543 $1,946,012 $3,000,000 RIH w/ bit and csg scraper to 10,420'. Circ btms up-had some sand across shakers. POOH. RIH w/ cmt ret on DR and set ret ® 10,097' DRM.--- Tested surface'lines to 6500 psi. Broke down formation w/ 5200 psi. Pumped in w/ 3 BRM 8 5400 psi. Formation held 3700 psi w/ RO l0 min. Mi-xed and squeezed w/ 200 sx cl "G" w/ 3% kol, 3% Haled 22A, 1% CFR-2. CIP $ 14:20 Hrs. Reversed out l0 sx cmt. POOH w/ d.p. RIH w/ RTTS pkr and hydrospring on dry DR. Set pkr $ 9912'. Opened hydrospring to dry test 8S #2 perfs F/ 9960' to 9962' DIL. Had light blow for 14 min, dead for 25 min, then light blow for 65 min. Filled DR-had total entry of 2 bbls. Pressured up to 6500 psi-could not break oown perfs-pressure bled to 4800 psi in 3 min. Opened tiro sub and reverse circ-had no gas-cut muO or oil. Circ an~ POOH. RIH w/ test tools on dry DP an~ set RTTS 8 9812'. Opened hydrospring to dry test BS perfs f/ 9960' to 9962' DIL and 9852' to 9854' DIL. Had very weak blow for i hours (less then previous test). Reset RTTS et 9660' and opened hydrospring to dry test BS perfs f/ 9960' to 9962' DIL, 9852' to 9854' OIL, and 9758' to 9760' DIL. Had very weak blow for 1 hour. Filled DR-had +2 bbls of entry. Reverse circ and' POOH. RIH w/ bit #30 and tagged cmt. ~ 10,095'.-~Cleened out to 10,097'. Drilled ret ~ 10,097' and cleaned out firm cmt f/ 10,099' to 10,276'. Cleaned out cmt stringers to 10,360'. RIH to 10,420' and circ. clean POOH. of SEP 2 ! 1982 Oil & G~, Oons. Commission !',.;lchoraGo UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE TRADING BAY UNIT WELL NO. G-4 RD SHEET D PAGE'NO. 14 FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 43 3/17/82 10450 ' TO 10420' ETD (CMT) 9 5/8" C. 5970' 7" C. 10450' 63 PCF 34 SEC DAILY COST: $ 57,776 ACC COST: $2,003,778 AFE AMT: $3,000,000 44 3/18/82 DAILY COST: ACC COST: AFE AMT: 45 3/19/82 10,450' TD 10,420' ETD (CMT) 9 5/8" C 5970' ?" C 10,450' FIW $ 27,060 $2,030,838 -$3,000,000 10450' TD 10420' ETD (CMT) 9 5/8" C. 5970' 7" C. 10450' FIW DAILY COST: $ 202,848 ACC COST: $2,233,686 AFE AMT: $3,000,000 46 3/20/82 DAILY COST: ACC COST: AFE AMT: 10450' TD 10420' ETD (CMT) 9 5/8" C. 5970' 7" C. 10450' FIW 30,509 $2,264,195 $3,000,000 POOH W/ bit. RIH W/ bit & csg scrpr to 10420'. Changed hole over to FIW. Spotted 50 bbl kcl pill on btm. POOH. RIH w/ GR & OB to 10420'. POOH. RIH w/ Baker "FB-i"-"- --.. pkr w/ millout extension, 3 1/2" pup "x" nipple, 3 1/2" pup, & WL re- entry shoe. Set pkr ® 10280'. RIH w/ seals on DP to test isolation pkr S 10,280' DIL. Tested to 1000 psi-OK. POOH. RIH w/ Baker Model "F-l" pkr and set $ 9720' DIL. RIH w/ seals on 3 1/2" DR and attempted to test pkr-would not test. Set 30,000# on top. of pkr-would not move POOH. RIH w/ Baker Model "F-l" pkr on 3 1/2" DP. Set pkr ~ 9720' DPM (14' high to DIL). Trip for seals. Tested pkr w/ 750 psi-OK. Pooh and laid down 3 1/2" DP. LD 3 1/2" DP. RU & ran 314 jts of 3 1/2" 9.2# N-80 butt tbg. Stabbed into & tested "F-i" pkr 8 9720'. Landed tbg. Removed BOPE. Installed tree. Repaired leaking swab valve. Tested tree to 5000 psi. Pull ball valve dummy. Rerouted FL & GL water out of tbg. Tested lub to 3000 psi. RIH w/ 20' of 2.625" DA perf gun ' could not get gun thru isolation pkr 8 10280'. POOH. RIH w/ 1 3/8" tool on 20' of 1 1/2" S~nker bars & centralizer to 10350' - had no indication of re- striction. RIH w/ lC' of 2.625" perf gun - stopped ~ 10280'. RIH w/ 2 1/8" carrier-type perf gun - stuck gun .0 10280' Worked gun free & POOH. RIH ~/ 2.625" perf gun to perf HB #3. LEASE TRADING BAY UNIT SHEET D -- UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. G-4 RD PAGE NO. '15 FIELD TRADING BAY FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 47 3/21/82 DAILY COST: ACC COST: AFE AMT: 48 3/22/82 DAILY COST: ACC COST: AFE AMT: 10450' TD 10420' ETD (CMT) 9 5/8" C. 5970' 7" C. 10450' FIW $ 20,460 $2,284,658 $3,000,000 10450' TD 10420' ETD (CMT) 9 5/8" C. 5970' 7" C. 10450' FIW $ 82,985 $2,367-/6/-r3 $3,000,000 Perfed Bench #3 w/ 2 5/8" slim cone perf guns f/ 9965' to lOO15' DIL. Had difficulty pulling each gun thru "x" nipple after firing. Rerfed w/ -- 8-1/2" HRF. GL & prod tested B-3 perfs. Well made 2328/2025 BRD, 13% cut of 33.1° ARI oil. Perfed HB'#1 f/ 9815' to 9843' w/ 2 5/8" perf guns ~ 8 HPF. Put well back on test - well made 2400/2112 BPD, 12% cut. Released rig ~ 24:00 hrs. 3/22/82. SEP 2 1 'c,_, l,~dZ A!a~,ka Oil & Ga~ Cons, Commission /~r,.chorag9 'V UNION OIL COWRANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. G-4 RD (All depths are DP) FIELD McArthur River DATE ETD DETAILS OF ORERATIONS, DESCRIRTIONS & RESULTS BTM TOP 10323.55 10322.90 10322.90 10312.93 10312.93 10311.53 10311.53 10301.53 10301.53 10300.83 10300.83 10295.40 10295.40 10293.00 ISOLATION RKR LENGTH JTS .65 9.97 1 1.40 10.00 1 ~70 5.43 2.40 DESCRIPT. ION Wireline entry guide 3 1/2" N-80 9.3# butt pup Otis "X" nipple 3 1/2" N-80 9.3# butt pup XO 5" 8md box X 3 1/2" butt pin Mill out extension Baker model FB-1 pkr BTM TOP ,, 9750.92 9750.32 9750.32 9748.82--_.~-~ 9748.82 9738.33 9738.33 9720.00 9720.00 9719.55 9719.55 9714.55 9714.55 9683.87 9683.87 9679.17 9679.17 9648.12 9648.12 9642.04 9642.04 9057.53 9057.53 9051.42 9051.42 8128.60 8128.60 8122.50 8122.50 6866.17 6866.17 6860.06 6860.06 5351.87 5351.87 5345.78 5345.78 3783.79 3783.79 3777.69 3777.69 1966.71 1966.71 1960.63 1960.63 290.20 290,20 287.90 287.90 42.81 42.81 38.81 38.81 37.20 37.20 -0- 3 1/2" TUBING DETAIL LENGTH .60 1.50 10.49 18.33 3TS · .45 5.00 30.68 4.70 1 31.05 1 6.08 584.51 19 6.11 922.82 30 6.10 1256.33 41 6.11 1508.19 49 6.09 1561.99 51 6.10 1810.98 59 6.08 1670.43 55 2.30 245.09 8 4.00 1 1.61 Landed below R.T. DESCRIPTION Mule shoe _._ "X" nipple 3 1/2" N-80 9.3# butt pup Baker model F-1 pkr w/ seal assy Locator 3 1/2" N-80 9.3# butt pup 3 1/2" N-80 9.3# butt Otis "XA" sliding sleeve 3 1/2" N-80 9.3# butt Camco GLM 3 1/2" N-80 9.3# butt Camco GLM 3 1/2" N-80 9.3# butt Camco GLM 3 1/2" N-80 9.3# butt Camco GLM 3 1/2" N-80 9.3# butt Camco GLM 3 1/2" N-80 9.3# butt Camco GLM 3 1/2" N-80 9.3#-butt Camco GLM ~ 3 1/2" 9.3# N-80 butt Otis ball valve 3 1/2" 9.3# N-80 butt 3 1/2" 9.3# N-80 butt pup Tubing hanger 10451.00 10449.40 10449.40 10362.96 10362.96 10361.50 10320.50 41.00 41.00 -0- 7" CSG DETAIL 1.60 86.44 2 1.46 10279.50 239 Landeo below R.T. Float Shoe 7" 29# N-80 butt Float collar 7" 29# N-80 butt TBUS G-4 RD O! 288' 3 1/2" Otis Ball Valve 13 3/8"-61'~ J-55 C. 3043' Camco GLM' S 1967 3784 5352 6866 8129 9058 9648 9 5/8" Window 5970-6032' Cmt ret 605(~ Cmt ret 9287' 9679' Otis "XA" sleeve 9720' Baker model' F-1 pkr 9750' "X" nipple 9751' mule shoe 10293' Baker model FB-1 pkr 10313' Otis "X" nipple 10323' Mule shoe 10451' 7" ~9# N-80 Butt ,. r.C¥. J DAlE .,"..."?':!~:.,r~.!:':~ GRAYLING PLATFORM' TBUS G-4 RD McArthur River Field UNION OIL COMPANY OF CALIFORNIA DLA~FN ~ C, KO; AI'~'D. DATE .._ __ NL SPERRY-SUN, INC. PAGE I UNION OIL CO. OF CA. G-4 RD (SEC29 T~N R13W) TOTAL DIRECTION ANGLE DEPTH DEG DEG MIN 1500 TIE COORDINATE8 1600 N 42.1E 5 0 1700 N 46..3 E 8 0 1800 N 52.4 E 11 30 1900 N 60.3 E 13 0 2000 2100 2200 2300 2400 N 60.5 E 13 0 N 62.2 E 13 0 N 61.3 E 13 30 N 61.4 E 13 30 N 63.5 E 14 0 2500 2600 2700 2800 2900 N 63.6 E 14 0 N 63.7 E 14 0 N 66.7 E 14 15 N 65.8 E 14 4.5 N 68.9 E 14 30 3000 3100 3200 3300 3400 N 6?. 0 E 14 45 N 69.0 E 15 15 N 71.9 E 18 0 N 70.9 E 19 30 N 72.9 E 20 0 3500 3600 3700 3800 3900 N 74.4 E 21 0 N 74.5 E 21 15 N 74.5 E 22 15 N 65.3 E 24 0 N 56.3 E 26 0 4000 4100 4200 4300 4400 N 55.6 E 27 0 N 47.8 E 28 45 N 48.0 E 29 15 N 48.1E 28 15 N 49.1E 28 0 4500 4600 4700 4800 4900 N 48.3 E 27 30 N 50.1E 26 0 N'48.1E 23 0 N 49.9 E 20 30 N 52.8 E 19 0 5000 5100 5200 5300 5400 N 54.7 E 19 15 N 53.9 E 19 0 N 56.0 E 19' 0 N 57. i E 18 30 N 58.2 E 18 45 VERTICAL LATITUDE DEPARTURE DEPTH FEET FEET 1499.98 1.10 N 1.36 E 1599.76 5.43 Iq 5.64 E 1699.08 13.47 N 13.59 E 1797.59 24.36 N 26.52 E 1875.31 36.02 N 44.19 E 1992.74 47.13 N 63.75 E 2090.18 57.91N 83.48 E 2187.52 68.76 N 103.67 E 2284.75 79.96 N 124.16 E 2381.89 90.94 N 145.23 E 2478.92 101.72 N 166.89 E 2575.95 112.45 N 188.57 E 2672.92 122.68 N 210.72 E 276?.74 132.77 N 233.63 E 2866.50 142.49 N 256.92 E 2?63.26 151.56 N 280.49 E 3059.85 160.84 N 304.65 E 3155.64 170.35 N 331.61 E 3250.32 180.61 N 362.07 E 3344.44 191.10 N 394.19 E 3438.10 200.95 N 427.79 E 3531.38 210.61 N 462.51 E 3624.26 220.51 N 498.22 E 3716.21 234.07 N 584.94 E 3806.83 254.73 N 571.65 E ~'~A 32 279 72 N 608.62 E 3784.71 308.69 N 645.16 E 4072.17 341.20 N 681.13 E 4159.84 373.35 N 716.90 E 4248.03 404.52 N 752.26 E 4336.52 435.25 N 787.24 E 4425.81 464.67 N 821.29 E 4516.78 491.78 N 852.65 E 4609.63 516.10 N 880.59 E 4703.74 537.22 N 906.95 E 4798.22 556.59 N 4892.70 575.71N 4987.25 594.40 N 5081.94 612.12 N 5176.70 629.21N BOSS-16981 MARCH 9, 1982 VERTICAL DOG SECTION LEG 1.42 0.00 5.92 3.04 14.29 3.04 27.78 3.64 46.05 2.25 66.17 0.'04 86.46 0.38 107.19 0.54 128.25 0.02 149.88 0.71 172.08 0.02 1'94.30 0.02 216.96 0.77 240.38 0.55 264.16 0.82 288.17 0.25 312.80 0.50 340.23 2.87 371.19 1.53 403.82 0.84 437.90 1.13 473.09 0.25 509.27 1.00 546.67 4.01 584.43 4.29 622.67 1.05 660.71 4.04 698.37 0.51 735.80 1.00 772.77 0.53 809.34 0.62 844.92 1.70 877.67 3.11 906.87 2.59 994.32 1.79 933.37 E 961~73 0.67 959.97 E 989.32 0.36 986.62 E 1016.93 0.68 1013.44 E 1044.65 0.61 1040.4.2 E 1072.50 0.43 NL SPERRY-SUN, INC. PAGE 2 UNION OIL CO. OF CA. G-4 RD (SEC29 T~N R13W) TOTAL DIRECTION ANGLE DEPTH DEG DEG MIN 5500 N 55.5 E 18 30 5600 N 63.2 E 17 29 5700 N 65.5 E 17 37 5800 N 66.3 E 18 3 5900 N 68.0 E 18 17 6000 N 72.8 E 20 35 6050 N 77.1E 23 9 6100 N 81.0 E 25 7 6150 N 81.3 E 26 32 6200 N 79.9 E 28 51 6300 N 80.6 E 30 53 6400 N 81.3 E 31 19 6500 N 82.4 E 31 40 6600 N 83.8 E 32 2 6700 N 84.3 E 31 35 6800 N 82.4. E 31 57 6900 N 82.8 E 31 15 7000 N 83.4 E 31 25 7100 N 83.9 E 30 7 7200 S 88.5 E 30 23 7300 8 82.7 E 30 33 7400 S 80.6 E 30 14 7500 S 78.0 E 28 47 7600 S 78.1E 29 1 7700 S 77.3 E 28 32 7800 $ 77.1 E 27 38 7900 8 75.7 E 27 3 8000 S 75.1E 26 46 8100 8 73.2 E 26 48 8200 S 70.2 E 27 47 8300. 8 65.0 E 28 57 8400 $ 64.0 E 29 20 8500 8 62.5 E 28 19 8600 S 62.2 E 28 4 8700 8 61.3 E 28 23 8800 S 59.8 E 28 53 8900 8 58.3 E 29 41 9000 S 57.1,E 30 16 9100 S 55.8 E 30 22 9200 8 53.9 E 31 1 VERTICAL LATITUDE DEPARTURE DEPTH FEET FEET 5271.46 646.66 N 1067.15 E 5366.57 662.42 N 1093.63 E 5461.91 675.47 N 1120.81 E 5557.10 687.97 N 1148.77 E 5652.11 700.08 N 1177.50 E 5746.39 711.15 N 1208.84 E 5792.79 715.94 N 1226.81 E 5838.41 719.80 N 1246.87 E 5883.41 723.15 N 1268.39 E 5927.67 726.95 N 1291.30 E 6014.38 735.37 N 1340.37 E 6100.00 743.50 N 1391.38 E 6185.27 750.90 N 1443.09 E 6270.21 757.23 N 1495.47 E 6355.19 762.70 N 1547.90 E 6440.21 768.80 N 1600.18 E 6525.38 775.55 N 1652.14 E 6610.79 781.79 N 1703.76 E 6696.71 787.46 N 1754.59 E 6783.09 789.46 N 1804.82 E 6869.28 785.57 N 1855.32 E 6955.54 778.23 N 1905.36 E 7042.56 769.11N 1953.74 E 7130.11 759.10 N 2001.02 E 7217.76 748.85 N 2048.04 E 7305.98 738.43 N 2098.94 E 7394.81 727.63 N 2138.58 E 7483.98 716.23 N 2182.37 E 7573.25 703.92 N 2225.70 E 7662.12 689.51 N 2269.21 E 7750.11 671.39 N 2313.07 E 7837.45 650.43 N 2357.02 E 7925.05 628.74 N 2400.07 E 8013.18 606.81N 2441.92 E 8101.29 584.42 N 2483.59 E 8189.05 560.86 N 2525.31 E 8276.27 535.70 N 2567.25 E 8362.88 508.99 N 2609.49 E 8449.21 481.10 N 2651.55 E 8535.20 451.72 N 2693.26 E B058-16981 MARCH 9, 1982 VERTICAL DOG SECTION LEG 1100.13 0.90 1127.41 2.59 1155.25 0.71 1183.83 0.49 1213.17 0.58 12 5. o6 2.'79 1263.26 6.05 1283.50 5.05 1305. 16 2.85 1328.25 4.82 1377.70 2.06 14'29.07 0.57 1481.09 0.67 1533.74 0.83 1586.38 0.53 1638.91 1.07 1691.16 0.73 1743.04 0.35 1794.10 1.32 1844.37 3.84 1894.59 2.94 1944.17 1.11 1991.99 1.93 2038.67 0.24 2085.08 0.62 2130.35 0.90 2174.35 0.87 2217.47 0.40 2260.09 0.86 2802.77 1.69 2345.60 2.73 2388.36 0.62 2430.20 1..24 2470.82 0.29 2511.23 0.53 2551.'64 0.87 2592.18 1.09 2632.93 0.83 2673.44 0.66 2713.53 1.17 NL SPERRY-SUN, INC. PAGE 3 UNION OIL CO. OF CA. G-4 RD (SEC29 TgN R13W) TOTAL DIRECTION ANGLE DEPTH DEG DEG MIN 9300 9400 9500 9600 9700 S 53.0 E 30 31 S 61.5 E 31 22 S 66.6 E 33 37 S 66.7 E 33 11 S 65.7 E 32 21 9800 9900 10000 10100 10200 S 65.0 E 31 41 S 64.9 E 31 29 S 64.2 E 30 44 S 63.9 E 30 11 S 64. I E 29 45 10300 10400 64.1E 29 29 65.0 E 28 36 VERTICAL LATITUDE DEPTH FEET 8621.13 421.26 N 8706.89 393.56 N 8791.22 370.15 N 8874.70 348.33 N 8958.79 326.49 N 9043.57 304.38 N 9128.75 282.20 N 9214.36 260.01 N 9300.55 237.82 N 9387.18 215.92 N 9474.12 194.33 N 9561.54 i73.47 N B08S-16981 MARCH 9, 1982 DEPARTURE VERTICAL DOG FEET SECTION LEG 2734.36 E 2752.94 0.67 2777.51 E 2794.55 4.45 2825.78 E 2841.51 3.54 2876.32 E 2890.81 0.42 2925.85 E 2939.10 1.00 2974.03 E 2986.04 0.76 3021.48 E 3032.24 0.22 3068.14 E 3077.64 0.82 3113.73 E 3121.98 0.57 3158.62 E 3165.65 0.45 3203.08 E 3208.89 0.27 3246.90 E 3251.54 0.98 THE DOGLEG SEVERITY IS IN DEGREES PER ONE HUNDRED FEET. THE VERTICAL SECTION WAS COMPUTED ALONG N 86 57 E BASED UPON TRAPEZOIDAL TYPE CALCULATIONS. THE BOTTOM HOLE DISPLACEMENT IS 3251.54 FEET, IN THE DIRECTION OF N 86 57 E BOTTOM HOLE DISPLACEMENT IS RELATIVE TO WELLHEAD. VERTICAL SECTION IS RELATIVE ]'0 WELLHEAD. Union Oil of California Our Boss Gyroscopic Survey Job No. Boss-16981 Well: G-4 RD (SEC29 T9N R13W) McArthur River Field Kenai, Alaska Date of Survey: March 9, 1982 Operator:o Marvin Milam Scale: 1" = 500' TRUE NORTH Surface Location (1882FSL 138~ ~-500.00 HORIZQNTRL PROJECTION 10400 Union Oil Of California Our Boss Gyroscopic Survey Job No. Boss-16981 Well: G-4 RD (SEC29 T9N R13W) McArthur .River Field Kenai, Alaska Survey Date: March 9, 1982 Operator: Marvin Milam Scale: 1" = 2000' 0.00 2000. O0 4000. O0 6000. O0 8000. O0 lO000.00, 3251.54 ' @ N86o 57' E 2'060. oo 1o~.oo I 4000. O0 VERT I CRL PR"OJECT I ON NL SPERRY-SUN, INC. PAGE i UNION OIL CO. OF CA. G-4 RD (SEC2? T~N R13W) TOTAL DIRECTION ANGLE VERTICAL DEPTH BEG DEG MIN DEPTH 1500 TIE COORDINATES 1600 N 42.1E 5 0 1700 N 46.3 E 8 0 1800 N 52.4. E 11 30 1900 N 60.3 E 13 0 2000 N 60.5 E 13 0 2100 N 62.2 E 13 0 2200 N 61.3 E 13 30 2300 N 61.4 E 13 30 2400 Iq 63.5 E 14 0 2500 N 63.6 E 14 0 2600 N 63.7 E 14. 0 2700 N 66.7 E 14 15 2800 Iq 65.8 E 14 45 2900 N 68.9 E 14 30 3000 Iq 69.0 E 14 45 3100 N 69.0 E 15 15 3200 Iq 71.9 E 18 0 3300 N 70.9 E 19 30 3400 Iq 72.9 E 20 0 3500 N 74.4 E 2.1 0 3600 Iq 74.5 E 21 15 3700 N 74.5 E 22 15 3800 N.65.3 E 24 0 3900 N 56.3 E 26 0 4000 N 55.6 E 27 0 4100 N 47.8 E 28 45 4200 N 48.0 E 29 15 4300 N 48.1 E 28 15 4400 N 49.1E 28 0 4500 N 48.3 E 27 30 4600 Iq 50.1E 26 0 4700 N 48.1E 23 0 4800 N 49.9 E 20 30 4900 N 52.8 E 19 0 5000 Iq 54..7 E 19 15 5100 N 53.9 E 19 0 5200 Iq 56.0 E 19 0 5300 N 57.1 E 18 30 54.00 N 58.2 E 18 4.5 1499.98 1599.60 1698.63 1796.62 1894.06 1991.4.9 2088.93 2186.17 2283.40 2380.43 2477.46 2574.49 2671.41 2768.12 2864.93 2961.64 3058.12 3153.22 3247.49 9341.46 3434.81 3528.01 3620.57 3711.92 3801.80 3890.90 3978.58 4065.83 4153.91 4.242.20 4330.90 4420.78 4512.83 4606.49 4701.04 4795.45 4890.00 4984.55 5079.38 5174.07 LATITUDE FEET 1.10 N 7.57 Iq 17.18 N 29.35 Iq 40.49 N 51.57 Iq 62.06 N 73.27 N 84.45 N 95.24 N 106.00 N 116.72 N 126.45 N 136.89 N 145.90 N 155.03 N 164.45 N 174.05 N 184.98 N 195.03 N 204.67 N 214.36 N 224.47 N 241.47 N 265.79 N 291.44 N 323.75 N 356.45 N 388.06 N 418.79 Iq 449.51N 477.63 N 503.72 N 526.28 N 545.97 N 565.02 N 584.20 N 602.40 N 619.64 N 636.58 N DEPARTURE FEET B085-16981 MARCH 9, 1782 VERTICAL DOG SECTION LEG i76.37 E 181.43 0.02 198.06 E 203.63 0.02 220.67 E 226.69 0.77 243.89 E 250.40 0.55 267.25 E 274.18 0.82 291.02 E 298.38 0.25 315.57 E 323.37 0.50 344.95 E 353.19 2.87 376.49 E 385.23 1.53 409.18 E 418.38 0.84 443.69 E 453.34 1.13 478.62 E 488.70 0.25 515.1,1 E 525.65 1.00 552.06 E 563.40 4.01 588.53 E 601.04 4.29 625.99 E 639.73 1.05 661;62 E 676.92 4.04 697.93 E 714.82 0.51 733.16 E 751.58 1.00 768.65 E 788.55 0.53 803.12 E 824.51 0.62 836.75 E 859.50 1.70 865.84 E 889.85 3.11 892.62 E 917.73 2.59 918.56 E 944.61 1.79 945.46 E 972.43 0.67 971.77 E 999.66 0.36 998.76 E 1027.52 0.68 1025.40 E 1054.'99 0.61 1052.72 E 1083.12 0.43 72.18 E 74.66 0.04 92.08 E 95.05 0.38 112.55 E 116.06 0.54 133.05 E 137.09 0.02 154.70 E 159.25 0.71 1.36 E 1.41 0.00 7.20 E 7.57 3.04 17.26 E 18.10 3.04 33.06 E 34.48 3.64 52.60 E 54.55 2.25 IqL SPERRY-SUIq, INC. PAGE 2 UNION OIL CO. OF CA. G-4 RD (SEC29 T9N R13W) TOTAL DIRECTION ANGLE DEPTH DEG BEG MIN 5500 N 55.5 E 18 30 5600 N 63.2 E 17 29 5700 N 65.5 E 17 37 5800 N 66.8 E 18 3 5900 N 68.0 E 18 17 6000 Iq 72.8 E 20 35 6050 N 77.1 E 23 9 6100 Iq 81.0 E 25 7 6150 N 81.3 E 26 32 6200 Iq 79.9 E 28 51 6300 N 80.6 E 30 53 6400 N 81.3 E 31 19 6500 N 82.4 E 31 40 6600 Iq 83.8 E 32 2 6700 N 84.3 E 31 35 6800 N 82.4 E 31 57 6900 N 82.8 E 31 15 7000 N 83.4 E 31 25 7100 N 83.9 E 30 7 ,7200 $ 88.5 E 30 23 7300 S 82.7 E 30 33 7400 S 80.6 E 30 14 7500 8 78.0 E 28 47 7600 $ 78.1E 29 1 7700 8 77.3 E 28 32 7800 S 77.1E 27 38 7900 S 75.7 E 27 3 8000 $ 75.1 E 26 46 8100 8 73.2 E 26 48 8200 S 70.2 E 27 47 8300 S 65.0 E 28 57 8400 $ 64.0 E 29 20 8500 8 62.5 E 28 19 8600 S 62.2 E 28 4 8700 8 61.3 E 28 23 8800 S 59.8 E 28 53 8900 8 58.3 E 29 41 9000 S 57.1 E 30 16 9100 8 55.8 E 30 22 9200 S 53.9 E 31 VERTICAL DEPTH 5268.91 5364.29 5459.59 5554.67 5649.61 5743.23 5789.20 5834.48 5879.21 5923.00 6008.83 6094,25 6179.37 6264.14 6349.32 6434.17 6519.66 6605.00 6691.50 6777.76 6863.88 6950.27 7037.92 7125.37 7213.23 7301.82 7390.88 7480.17 7569.43 7657.90 7745.40 7832.58 7920.61 8008.84 8096.82 8184.38 8271.25 8357.61 8443.90 8529.61 LATITUDE FEET 654 ~ N 668.09 N 680.65 N 693.10 N 704.86 N 715.25 N 719.64 N 722.96 N 726.34 N 780.57 N 738.95 N 746.81N 753.75 N 759.48 N 764.68 N 771.68 Iq 778.18 N 784.17 N 789.51N 788.18 N 781.72 N 773.50 N 763.49 N 753.49 N 742.99 N 732.64 Iq 721.40 N 709.83 N 696.79 N 681.01N 660.55 N 639.08 N 617.17 N 595.22 N 572.39 N 548.10 N 522.07 N 494.69 N 466.28 N 435.93 N BOSS-16981 MARCH 9, 1982 1078.87 E 1110.13 0.90 1105.68 E 1137.58 2.59 1133.23 E 1165.72 0.71 1161.60 E 1194.67 0.49 1190.69 E 1224.32 0.58 1224.27 E 1258.37 2.79 1243.43 E 1277.73 6.05 1264.39 E 1298.83 5.05 1286.47 E 1321.04 2.85 1310.22 E 1344.98 4.82 1360.85 E 1395.97 2.06 1412.24 E 1447.68 0.57 1464.26 E 1499.98 0.67 1517.00 E 1552.95 0.83 1569.11E 1605.25 0.53 1621.57 E 1657.99 1.07 1673.03 E 1709.71 0.73 1724.81E 1761.72 0.35 1774.70 E 1811.82 1.32 1825.27 E 1862.26 3.84 1875.69 E 1912.29 2.94 1925.36 E 1961.49 1.11 1972.45 E 2008.03 1.93 2019.91E 2054.93 0.24 2066.50 E 2100.94 0.62 ~111 71 E 2145.57 0 90 2155.77 E 2189.03 0.87. 2199.28 E 2231.91 0.40 2242.45 E 2274.87 0.86 2286.30 E 2317.38 1.69 2330. i7 E 2360.18 2.73 2374.20 E 2403.08 0.62 2416.28 E 2444.01 1.24 2457.90 E 2484.49 0.29 2499.60 E 2525.01 0.53 2541.35 E 2565.49 0.87 2583.49 E 2606.28 1.09 2625.81E 2647.19 0.83 2667.61 E 2687.53 0.66 2709.24 E 2727.59 1.17 DEPARTURE VERTICAL DOG FEET SECTION LEG UNION OIL CO. OF CA. G-4 RD (SEC29 TgN R13W) TOTAL DIRECTION ANGLE DEPTH DEG BEG MIN 9300 9400 9500 9600 9700 53.0 E 30 31 61.5 E 31 22 66.6 E 33 37 66.7 E 33 11 65.7 E 32 21 9800 9900 10000 10100 10200 65.0 E 31 4.1 64.9 E 31 29 64.2 E 30 44 63.9 E 30 11 64.1 E 29 4.5 10300 10400 64.1 E 29 29 65.0 E 28 36 NL SPERRY-SUN, INC. VERTICAL LATITUDE DEPTH FEET 8615.75 405.36 N 8701.13 380.52 N 8784.41 358.54 N 8868.09 336.89 N 8952.57 314.87 N 9037.66 292.67 N 9122.94 270.51N 9208.89 248.27 N 9295.32 '226.14 N 9382.14 204.47 N 9469.20 182.97 N 9556.99 162.74 N PAGE 3 BOSS-16981 MARCH 9, 1982 DEPARTURE VERTICAL DOG FEET SECTION LEG 2749.80 E 2766.57 0.67 2795.55 E 2811.03 4.45 2846.85 E 2860.67 3.54 2896.62 E 2909.81 0.42 2945.39 E 2957.42 1.00 2993.00 E 3003.86 0.76 3040.29 E 3049.99 0.22 3086.31E 3094.85 0.82 3131.47 E 3138.85 0.57 3176.11 E 3182.35 0.45 3220.38 E 3225.50 0.27 3263.76 E 3267.82 0.98 THE DOGLEG SEVERITY IS IN DEGREES PER ONE HUNDRED FEET. THE VERTICAL SECTION WAS COMPUTED ALONG N 87 9 E BASED UPON TANGENTIAL TYPE CALCULATIONS. THE BOTTOM HOLE DISPLACEMENT IS 3267.82 FEET, IN THE DIRECTION OF N 87 9 E BOTTOM HOLE DISPLACEMENT IS RELATIVE TO WELLHEAD. VERTICAL SECTION IS RELATIVE TO WELLHEAD. Union Oil of California Our Boss Gyroscopic Survey Job No. Boss-16981 Well: G-4 RD (SEC29 T9N R13W) McArthur River Field Kenai, Alaska Date of Survey: .March 9, 1982 Operator: Marvin Milam Scale: 1" = 500' TRUE NORTH surface Location (1882FSL 1389FEL) -50{3. O0 -500. O0 ' l_500. O0 3267.82' ._ @ N87° 9' E soo'. oo,oobl oo ,sob. oo ~oob. oo ~sob. oo ~oob. oo HORI ZONTFIL PROJECTION 104CC 0.00 2000.00 4000.00 6000.00 8000.00 lO000. O0~ 3267.82' N87° 9'E Union Oil of California Our Boss Gyroscopic Survey Job No. Boss-16981. Well: G-4 RD (SEC29 T9N R13W) McArthur River Field Kenai, Alaska Survey Date: March 9, 1982 Operator: Marvin Milam Scale: 1" = 2000' 2oho. oo ~.o5o. oo VERT I CRL PROJECT I ON IqL SPERRY-SUN, INC. PAGE 1 UNION OIL CO. OF CA. 6-4 RD (SEC29 TgN R13W) TOTAL DIRECTION ANGLE VERTICAL DEPTH BEG DEG MIN DEPTH 1500 TIE COORDINATES 1600 N 42.1E 5 0 1700 N 46.3 E 8 0 1800 N 52.4. E 11 30 1900 N 60.3 E 13 0 2000 N 60.5 E 13 0 2100 N 62.2 E 13 0 2200 N 61.3 E 13 30 2300 N 61.4 E 13 30 2400 N 63.5 E 14 0 2500 N 63.6 E 14 0 2600 N 63.7 E 14 0 2700 N 66.7 E 14 15 2800 N 65.8 E 14 4.5 2900 N 68.9 E 14 30 3000 N 69.0 E 14 45 3100 N 69.0 E 15 15 3200 N 71.9 E 18 0 3300 N 70.9 E 19 30 3400 N 72.9 E 20 0 3500 N 74.4 E 2I 0 3600 Iq 74.5 E 21 15 3700 N 74.5 E 22 15 3800 N 65.3 E 24 0 3900 N 56.3 E 26 0 4000 Iq 55.6 E 27 0 4100 N 47.8 E 28 45 4200 Iq 48.0 E 29 15 4300 N 48.1E 28 15 4400 Iq 49.1E 28 0 4500 N 48.3 E 27 30 4600 Iq 50.1E 26 0 4700 N 48.1 E 23 0 4800 Iq 49.9 E 20 30 4900 N 52.8 E 19 0 5000 Iq 54.7 E 19 15 5100 N 53.9 E 19 0 5200 Iq 56.0 E 19 0 5300 N 57.1E 18 30 5400 Iq 58.2 E 18 45 1499.98 1599.79 1699.15 1797.71 1895.43 1992.87 2090.30 2187.64 2284.88 2382.01 2479.04 2576.07 2673.05 2769.86 2866.62 2963.38 3059.97 3155.79 3250.49 3344.60 3438.27 3531.55 3624.43 3716.40 3807.03 3896.52 3984.92 4072.38 4160.05 4248.24 4336.74 4426.04 4517.03 4609.91 4704.03 4798.51 4892.99 4987.54 5082.23 5176.99 LATITUDE FEET 1.10 N 5.30 N 13.41N 24.45 Iq 36.20 N 47.31 N 58.10 N 68.95 N 80.14 N 91.13 Iq 101.91N 112.65 N 122.88 N 132.97 Iq 142.69 N 151.76 N 161.04 N 170.61N 180.86 N 191.36 Iq 201.22 N 210.88 N 220.78 N 234.28 N 254.90 N 279.88 N 308.86 N 341.36 N 373.51N 404.69 N 435.42 N 464.83 Iq 491.98 N 516.29 N 537.40 N 556.77 N 575.89 N 594.58 N 612.30 N 629.39 Iq DEPARTURE FEET 1.36 E 5.79 E 13.68 E 26.53 E 44.20 E 63.75 E 83.50 E 103.69 E 124.17 E 145.25 E BOSS-16981 MARCH 9, 1982 VERTICAL DOG SECTION LEG 1.42 0.00 6.07 3.04 14.38 3.04 27.80 3.64 46.06 2.25 66.19 0.04 86.48 0.38 107.22 0.54 128.27 0.02 149.90 0.71 166.90 E 172.11 0.02 188.58 E 194.33 0.02 210.74 E 216.99 0.77 233.65 E 24.0.42 0.55 256.96 E 264.21 0.82 280.52 E 304.68 E 331.64 E 362.11E 394.28 E 427.83 E 462.55 E 498.26 E 535.14 E 572.03 E 288.22 0.25 312.84 0.50 340.28 2.87 371.25 1.53 403.88 0.84 437.96 1.13 473. I5 0.25 509.33 1.00 546.88 4.01 584.82 4.29 609.00 E 623.07 1.05 645.69 E 661.26 4.04. 681.67 E 698.91 0.51 717.44 E 736.35 1.00 752.80 E 773.32 0.53 787.78 E 821.85 E 853.20 E 881.16 E 907.55 E 933.97 E 960.58 E 987.23 E 1014.05 E 1041.03 E 809.89 0.62 845.49 1.70 878.24 3.11 907.46 2.59 934.94 1.79 962.36 0.67 989.95 0.36 1017.56 0.68 1045;29 0.61 1073.14 0.43 NL SPERRY-SUN, INC. PAGE 2 UNION OIL CO. OF CA. G-4 RD (SEC29 T?N R13W) TOTAL DIRECTION ANGLE DEPTH BEG DEG MIN 5500 5600 5700 5800 5900 N 55.5 E 18 30 N 63.2 E 17 2.9 N 65.5 E 17 37 N 66.3 E 18 3 N 68.0 E 18 17 6000 6050 6100 6150 6200 N 72.8 E 20 35 N 77.1E 23 9 N 81.0 E 25 7 N 81.3 E 26 32 N 79..9 E 28 51 6300 6400 6500 6600 6700 N 80.6 E 30 53 N 81.3 E 3I 19 N 82.4 E 31 40 N 83.8 E 32 2 N 84.3 E 31 35 6800 6900 7000 7100 7200 N 82.4 E 31 57 N 82.8 E 31 15 N 83.4. E 31 25 N 83.9 E 30 7 S 88.5 E 30 23 7300 7400 7500 7600 7700 82.7 E 30 33 80.6 E 30 14 78.0 E 28 47 78. I E 2.9 1 77.3 E 28 32 7800 7900 8000 8100 8200 77.1E 27 38 75.7 E 27 3 75.1E 26 46 73.2 E 26 48 70.2 E 27 47 8300 84.00 8500 8600 8700 S 65.0 E 28 57 S 64.0 E 2.9 20 S 62.5 E 28 19 S 62.2 E 28 4 S 61.3 E 28 23 8800 8900 9000 .9100 .9200 S 5.9.8 E 28 53 S 58.3 E 29 41 S 57.1 E 30 16 S 55.8 E 30 22 S 53..9 E 31 I VERTICAL LATITUDE DEPTH FEET 5271.75 646.86 N 5366.86 662.60 N 5462.21 675.65 N 5557.40 688.16 N 5652.41 700.27 N 5746.71 711.43 N 57.93.11 716.27 N 5838.74 720.15 N 5883.75 723.50 N 5.928.02 727.29 N 6014.74 735.73 N 6100.37 743.85 N 6185.64 751.26 N 6270.58 757.60 N 6355.55 763.06 N 6440.57 76.9.16 N 6525.75 775.90 N 6611.16 782.15 N 6697.0.9 787.8.1 N 6783.47 78.9.83 N 6869.66 785.94 N 6.955..91 778.59 N 7042.95 76.9.45 N 7130.49 75.9.44 N 7218.14 74.9.1.9 N 7306.37 738.76 N 7395.20 727.96 N 7484.38 716.56 N 7573.65 704.25 N 7662.52 689.85 N 7750.51 671.75 N 7837.85 650.7.9 N' 7925.46 62.9.08 N 8013.59 607.16 N 8101.70 584.77 N 818.9.46 561.21N 8276.68 536.05 N 8363.30 509.35 N 8449.62 481.45 N 8535.62 452.07 N B088-16.981 MARCH 9, 1982 DEPARTURE VERTICAL DOG FEET SECTION LEG 1067.77 E 1100.77 0..90 1094.34 E 1128.14 2.59 1121.52 E 1155.98 0.71 1149.48 E 1184.57 0.49 1178.22 E 1213.91 0.58 120.9.56 E 1245.81 2.7.9 1227.55 E 1264.02 6.05 1247.61 E 1284.27 5.05 126.9.13 E 1305..94 2.85 12.92.05 E 1329.03 4.82 1341.13 E 1378.48 2.06 1392.14 E 1429.86 0.57 1443.85 E 1481.88 0.67 14.96.23 E 1534.54 0.83 1548.66 E 1587.18 0.53 1600..95 E 1639.72 1.07 1652..91E 16.91.97 0.73 1704.53 E 1743.85 0.35 1755.37 E 1794.91 1.32 1805.71 E 1845.29 3.84 1856.27 E 1895.57 2.94 1906.33 E 1945.16 1.11 1954.72 E 1993.00 .1.93 2001..9.9 E 2039.67 0.24 2049.02 E 2086.08 0.62 20.94..92 E 2131.36 0..90 213.9.56 E 2175.36 0.87. 2188.35 E 2218.48 0.40 2226.6.9 E 2261.10 0.86 2270.22 E 2303.80 1.6.9 2314.14 E 2346.70 2.73 2358.0.9 E 2389.47 0.62 2401.15 E 2431.30 1.24 2443.00 E 2471.92 0.29 2484.67 E 2512.34 0.53 2526.40 E 2552.75 0.87 2568.35 E 25.93.30 1.09 2610.58 E 2634.05 0.83 2652.65 E 2674;57 0.66 2694.38 E 2714.66 1.17 NL SF'ERRY-SI.IN, INC:. PAGE,-.'--' LINION OIL CO. OF CA. G-4 R[I (:E;ER29 I'9N R13W) TOTAL D I REE:T I ON ANGLE DEPTH DEG BEG MIN 9300 9400 9500 9600 9700 53.0 E 30 31 61.5 E 31 22 66.6 E 33 37 66.7 E 33 11 65 7 E ""'- . ..:.:Z 21 9800 9900 10000 10100 10200 65.0 E 31 41 64,9 E 31 29 64.2 E 30 44 63.9 E 30 11 64.1 E 2'..~ 45 10300 104 ¢] 0 64.1 E 29 29 65.0 E 28 36 VERTICAL LATITUDE DEPTH FEET 8621.54 421.61 N 8707.31 393.79 Iq 8791.66 370.29 N 8875.14 348.47 N 8959.22 326.63 N 9044.01 304.51N 9129.19 282.34 N 9214.81 260.13 N 9301.00 237.95 N 9387.63 216.05 N 9474.57 194.46 N 9561.98 173.60 N BOSS- 16981 MARCH 9, 1982 DEPARTURE VERTICAL DOG FEET SECT I ON LEG 2735.47 E 2754.07 0.67 2778.72 E 2795.77 4.45 2827.02 E 2842.75 3.54 2877.56 E 2892.05 0.42 2927.08 E 2940.34 1.00 2975.27 E 2987.28 0.76 3022.72 E 3033.48 0.22 3069.37 E 3078.88 0.82 3114.96 E 3123.22 0.57 3159.86 E 3166.89 0.45 3204.32 E 3210.13 0.27 3248.14 E 3252.78 0.98 THE DOGLEG SEVERITY IS IN DEGREES PER ONE HUNDRED FEET. THE VERTICAL SEC]'ION WAS COMPUTED ALONG N '~ ~,6 56 E BASED UPON AVERAGE ANGLE TYPE CALCULATIONS. THE BOTTOM HOLE DISPLACEMENT IS 3252.78 FEET, IN THE DIRECTION OF N 86 56 E BOTTOM HOLE DISPLACEMENT IS RELATIVE TO WELLHEAD. VERTICAL SECTION IS RELATIVE TO WELLHEAD. Union Oil of California Our Boss Gyroscopic Survey Job No. Boss-16981 Well: G-4 RD (SEC29 T9N R13W) McArthur River Field Kenai, Alaska Survey Date: March 9, 1982 Operator: Marvin Milam Scale: 1" = 500' TRUE NORTH Surface Location (1882FSL 1389FEL) -50~. O0 -500. O0 soo[ oo ~oob. oo l_500. O0 HOBIZONTRL 3252-78' @...N860. 56'.E ~ob. Oo ~oob. oo ~sob. oo soob. oo PROJECTION 0.00 ,.- (" Union Oil 'of California Our Boss Gyroscopic Survey Job No. Boss-16981 Well: G-4 RD (SEC29 T9N R13W) McArthur River Field Kenai, Alaska Date of Survey: March 9, 1982 Operator: Marvin Milam Scale: 1" = 2000' 2000.00 4000.00 6000.00 8000.00 ~0000.00 3252.78''@ N86° 56'E 20~)0. O0 10400 4000. O0 VEBT I CBL PBOJECT I ON March 11, 1982 Mr. Gary Bush Union Oil of California P. O. Box 6247 Anchorage, Alaska 99502 Re: Our Boss Gyroscopic Survey Job No. Boss-16981 Well: G-4 RD (SEC29 T9N R13W) McArthur River'Field Kenai, Alaska Date of Survey: March 9, 1982 Operator: Marvin Milam Dear Mr. Bush: Please find enclosed the "Original" and seven (7) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. This survey is a combination of Scientific Drilling Control data from 0 to 5600 feet, and NL Sperry-Sun, Inc. Boss gyro data from 5600 to 14,000 feet. Each folder presents the survey in Radius of Curvature, Average Angle, Tangential, and Trapezoidal Calculations. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. ~" 'i'~ '~ C Kirk Afflerbach- District Supervisor KA/pr Enclosures ,. ""',,~ Oil &~C~orag~,~?s Cons UNICIN OIL COMPANY OF CALIFORNIA G-4 RD (SEC29 T?N R13W) MCARTHUR RIVER FIELD ALASKA SF'ERRY--SLIN WELL SL /EYING COMF'ANY ANCHORAGE AI_A:Z:KA C:OMPLITA-FiON riATE MARCH il. 1982 VERTIC:AL SECTI¢~N CALCULATED ALONG CLOSLIRE DATE OF .SLIRVEY MARC:H BOSS GYRO '.3URVEY ,..lOB NUMBER BOSS-16981 KELLY BUSHING ELEV. = OF'ERATOR-M I LAM 'F;'.P. 00 F"F. 'TRUE SUB-SEA COURSE MEASLIRED VERT I CAL VERT I CAI_ I NCL I NAT I ON DEPTH DEPTH DEPTH DEG MIN COURSE DIRECTION DEGREES. DOG-LEG TOTAL SEVER I TV RECTANGULAF~ CC,~(F,'D I NATE'.3 '- VERT I IZ:AL BEG/100 NORTH/SOUTH EAST/WE'._--;T :=':Er:T I C~N 15'¢~0 14:/;¢'-'-. ,~c,.. ,_, 16~'~(-~.. 1599 .7q,_ 1700 16 'F/'F/. 1 ...,":' 1 :-3c),r) 1797.67 1900 1 '-"- :' ,=..¢._,. 39 2000 19'?/2.82 2100 2090.26 2200 21 ,_=:7.60 2300 2284.83 2400 2'381.97 2500 247.9.00 2600 2576.03' 2700 '~' ". .-' _,7._-: 00 28¢]0 2769 '-"-' 2900 2866.58 3000 2963.34 31 O0 "-'(]M'-? ~3 3200 3155.74 :::~,C)C) '-"-'M ' ' .... · _- .-- ._ o. '42 3400 :.'-:344. M -_4 · :,._ U L) 3438 21 3700 3624.36 3800 3716.35 3900 3807.01- 40C~0 38'P6.5(3 4100 3984.93 4200 4072.3(2' 4300 4160.05 4400 4248.25 4149.25 15¢~0.78 5 0 1600.13 8 0 16 ~7..~. 67 '11 30 1796 ""- · ~:/ 13 0 1893.82 13 0 '1 '~".~ 1.2-/_-: 1 ::i 2088.60 1:2: 30 21'~ 83 ,:,... 13 :30 2282. '~7 - i-~ 0 2380. O0 ' 14 0 2477.03 14 0 ~57Zl:'."CiO .... -1 2670.82 14 45 2767.58 14 30 '28~4.34 14 45 2960. ~ '-' ' .~o 15 15 3056.74 18 0 :3 '~ ......... . ..... i: 1 ._ 1.42 I '-.-, :~c~ .:, ..' 4._,. 54 20' 0 :333':.-,. 21 21 0 3432.48 "2-1 15 '--: 2 36 2'--' 15 ~'5 '5. .. 3617.35 24 0 -' 3-7i58. O' i ....... :;'-?_-: ..... o 37~/7.50 27 0 '-"-',q ~ '.~.3 28 45 ..:,r-_,,_ ._ . ~::v73. ~,P ...... ~';~ .... i5 4061.05 28 15 2F: 0 N'-5i. o ~ N 42.10 E N 46. :_:0 E N 52. :--::-? is N 60. :30 E N 60.50 E N' '62.19 'E-- N 61.:':-:0 E N 61.39 E 'N 6~. 50' E N 63.60 E N 63.69 E 3.04 .5.43 N :;.64 E :3.04 1:3.4:3 N 13.57/ E ............... · ~ ~'W,,~i' - ~' 3.-6~!: 24. :37 N- z ....o ~ ..~._, 36.02 N 44.19 E 0.04 47.13 N 63.75 E "o.._'~=:~ ........ ~?'; '~"~'- '.. ~ ~ ......b~ . ~!¢'--~-'-- 0.54 68.77 N 103.68 E 0.03 79.96 N 124.17 E o. 7 t ........... e'b-:"95" N ..... ~'45-1 ~4'- E ........... 0.02 101.72 N 166.90 E 0.02 112.46 N 188.58 E N 65.80 E N 68. :39 E N '-~S'. OE N 69. 0 E N 71.89 E - N "76.':4'~ ~:'- N 72.89 E N 74.. 3';' E ' -N- "74'-' 5o :' N 74.50 E N 65.30 E 14 <' 27.7':'." 46.05 66.18 8 ,/:,. 46 107.20 1 ';'8.26 14?. ::::9 172.09 1.94. :::1 2-1-/*,. ,~7' 0.55 132.78 N 2.-:~.-: 64 E 240 . :--:',-¢_. 0.82 142.?]' Y._, E 264. 17 ._ o N 256. "- '~ 0.25- l':'..., 1 '. -e_~, .......... 7 N ~d--','-6'.-~C~-' E -' - z' .... ~.: ~ . 18 O. 50 160.84 N 304.66 E :312. ::_~: 2.87 170.36 N 331.63 E ,:: 340.2 ..... -i-: S-::,: .............. t.=,'~-,'., :%~'-~' ............ :5~,:~ ;-b,-:¢-'~ .......... :'-':'~ 1 .2 0.84 191. 11 N :394.20 E 40:2:.:::,, 1. 1:3 200.96 N 427. :31 E 4:37. '~.>'.2 1·00 220·52 N 498.2:3 E 509.29 4.01 234.0.9 N 534.97 E ._46..:; 70, 571 70 E ~'-' . .... =,4 4:--: 608./-'.6 E /_'.22.72 =,4._ 22 E 66¢) 7:_:: ' 'dll~--~--I ........ · I ~'~-- ............................. e I~l I~fl~]ll 4 716.97 E 735.¢7 752.32 E 772.84 · _ L%, · .- t.I -- ~T · ." .. .,::.._l "1- = ! ._l I N I',1 55.60 Z 1.05 279.74. N N 47.80 Z 4.04 :308.7:':: N -~'-'"4-~. 0-' ':: 0': 5-i' .............. ~,,-4-:[-::~-.'::i-i4-"' N 48.10 : 1.00 373.:39 N N 49.10 _ O. 5.2: 404.._,6 N LINION OIL COMPANY OF CALIFORNIA 0-4 RD (SEC29 TgN R13W) MCARTHUR RIVER FIELD ALASKA SPERRY-SLIN WELL. L-;, ¢i-_¢IN_, COMPANY ANCHORAGE ALA:::KA C 0 Id P U T A T 113 N D A'F E - MARCH 11, 1 ':)"=";'.. ,_,- AE;E DATE OF SURVEY MARCH '?, 1'~8'.7 BASS GYRO L=;URVEY ,JOB NUMBER BLi._o- 16981 KELLY BUSHING ELEV. = 99.00 FT. OPERATOR-M I LAM - . TRUE SUB-SEA MEASLIRED VERTICAL ' VERTICAL DEPTH DEPTH DEF'TH 4~,00 43:37:,. 7;4 .......... 4/_-,00 442/=,. 03 4700 4.517.02 4800 4609. 4900 4704. O0 5000 47'28.48 51'00 4892. '2/=; 5200 4987.52 5:300 5082.21 540¢) 517/=_-,. '27 5500 5271.73 5600 ~'-' . · _ o66 8/=, ._,70L~ F, F '-' ~ 4 =,-'. 2¢) 5:::0C) 5557. :39 5900 5/=,5:.2'. 41 6¢;00 ._,746.71 /=,050 5793 · 11 61 O0 ~ .... _ .~ _,._-~,. 73 6 ~ 50 ~,=,c,.-., 74 ...... · _ .,...! i_! ._! · 6200 ~ cr-.,o 00 · ...J ,' i_i. 6300 /_-,(') 14.71 64-00 6500 6~00 6?00 6800 6900 7000 7100 7200 _ _ COLIRSE I NCL'I NAT I ON BEG MIN COURSE D i REcT I ON DEGREES DOG-LEG TOTAL :_::EVER I TY .... ~'ECTANOI-ILAR ..... ~.".)30 R]~[I ~q T~S ........ VER T I C:AL r/EG/1 O0 NOR]'H/SOUTH EAST/WEE:T ::;EE:T I FiN 4327.03 26 0 4418.02 2:3 0 4 ~, 1 u, ~ ../ 20 :.'-;0 4605.00 19 0 4699.48 19. I ~, ~ "-4793 .]~'6 .... 1'-9- 0 4888.52 19 0 498:3.21 18 30 5077~-97 "i8 '45 5172.73 18 30 5267.86 17 28 .~, -5/_ O- - --~ ~'~ " ........... ~,., 17 ~45o. . 18 3 5553.41 18 17 ~647 71 20 34. · _,6 Y4.11 '23 5739.73 25 6 ~7~4.74 26 31 5829.00 28 5¢15.7i 30 6185.61 6086.61 31 39 6270.55 6171.55 82 2 .... ~R~--~2 ...... -'-;~'~6z._,6 ...... ...... R'~ .............................. 31 34 64.40.._M~._ /=.341.55 c:1~ ~R 6 :,5z.:,.72 6426.72 6611 14 6512.14 ~1 24 6697.06 6598.06 30 7 6789.47 6684.47 30 23 N 4,_,.30 E 0.62 4:35.29 N N 50.10 E 1.70 464.71 N N 48.10 E 3.11 491. :_=:2 N N 4~.8'2 E ....... 2:~c) ............ F~'i'/_-,,i~'"'N'' N 52.80 E 1.79 5:--:7.27 N N 54.69 E 0.67 55/=,.64 N 787.30 E 809., 821.36 E 6:44.9 :~52.72 E 877.7'. .... i~'-~2,-0'. 66 E .......... 906.95 907.02 E 934.40 ;-.:,o. 44 E 961.81 56. 0 E 0./=,8 594.45 N 986.70 E 57.10 E 0./=,1 612.17 N 1013.'-51 E 58.19 E '0.43 ...... 629'. 2~, N ' ' ~O'l)'Cf.'Z~-/"~' 55.50 E 0.90 646.71 N 1067.23 E 63.19 E 2.59 662.47 N 1093.71 E ~-~-'_ ~,...~'"'-v '~ ..... U.~ .................... 71 6 ~---~=:~/._,.._,~ .................. N 1120 '-'":~ E . ,:,; 66.30 E 0.4'2 688.02 N 1148.85 E 68 0 E 0 58 700,, 13 N 1177 7~. 80 E 2.79 ..... ~'I'~". 2'1-"N .... 77,10 E 0~, 716.00 N 1226.91 E 81. 0 E ~.05 719.85 N 1246.'26 E 1017, 01 1044.7:3 i 072.59 1100.21 1127.50 i i 55. :'::4 I 18:'4.92 121.2:. 2/=, i 245. 1.5 12/=,3. 1283. d. "~'-]_~". 30---E ........~.]3-]t%-. ........ 723.20 i~ ..........~&~J. 4:-=: E i-!~ij.5.% 2, N 79.89 E 4.82 727.01 N 12'21.4C) E 1:328..3.t, N 80.60 E 2 06 '"'= '- 7.:,...,. 4:-: hi 1'-' '. _ _ . .:, 40 47 _ 1:3 7 7. :::(] N" ~F~'. 30' E -' ' O-'SV ............ '~-~]-~,~,-N ......... -f~';~] :'4-¢'--:_' .............. i'429, fi7 750.95 N 757.~9 762.76 N 768.86 N 775.61 N 781.85 N 787.51 N 78'?. ~'" ~,' N N 82. .... · ~ E 0.67 N' 83.80' E 0.83" ..... N--S]~'.'~-b-'--~ ........... -~':-~,~ ....... N 82.3'2 E 1.07 N 82.80 E 0.73 N"- ~:3..'2:9 E ..........0.;~s'.% N 8:3.89 E 1.32 L:: oA._O~' E '-' o4 ,..m _, ]. ...]' n L'i'~ 1443.18 1'495.56 1547.99 1600.27 1652.23 1703.85 1754.68 1804.~4 -_- 1481.1'2 = 1533. o4 ,~lli,.I ' · ......... · -- 1 ._ ,=,/=, 48 E 16:2:9.02 1691. :2/=, = 1 ~43. 14 E 1794.21 1844.49 UNION OIL COMPANY OF CALIFORNIA G-4 RD (SEC29 TgN R1BW) MCARTHUR RIVER FIELD ALASKA SPERRY-SUN WELL SL /EYING I]:f-~MF'ANY ANCHORAGE A[_ASKA COMF'LITA'r ION DATE MARCH '1-1, 1982 VERTIC:AL SECTION CALCULATED ALONG 'l.]:[Oi.~:-l-iRE DATE OF SLIRVEY MAR_.H '2 1982 BOSS GYRt] :E:URVEY dOB I -' - , - ........................ N_IMBER DOS'S- 16981 KELLY BUSHING ELEV. = 9.9.00, FT. OF'ERATOR-M I LAM :':: . TRUE SUB-SEA COUR:E:E MEASURED VERTICAL VERTICAL INCE'INATION DEF'TH DEPTH DEPTH DEG M I N 7300' '~867;'&8-" 7400 6955.94 7500 7042.96 7600 7130.52 7700 7218.17 7800 7306.40 7900 "' 7395.23 8000 7484.40 8100 7573.68 8200 7662.54 8300 7750.55 8400 7837.89 8500 7~25-;'50 8600 8013.63 8700 8101.73 8800 8189.50 8900 8276.72 ¢000 8363.34 9100 8~49'.b7 ..... ~200 8535.66 9300 8621.59 ~400 '¢707~3'~ .... 9500 8771.75 ~600 8875.24 9700 8959.32 9800 904.4.11 9900 9129.29 10000' ~21-4.~i-' 10100 ~301.10 10200 ~87.7~ 6856.94 30 6943.96 28 7031.52'- 7119.17 28 7207.40 27 1:_'-: 46 0 31 37 '-729~.'23 ........ 27 ...... 7385.40 26 45 7474.68 26 48 7563;54 ...... 7651,55 '28 56 7738.'89 '29 19 ..... ~2~]5~ ........... 2~ ....... I~- 7914.63 28 4 8002.73 28 23 8090.50 28 52 8177.72 -29 41 8264.34 30 16 ~35~,~'7 .... 30"21 8436.66 31 0 8522.59 30 31 8608';'3~P .... 3i-'-22' 8692.75 33 36 8776.24 33 11 886~.'9~ ............ !~E ..... 2i 8945.11 31 41 9030.29 31 '28 9i-i5.9i'- 30--44 9202.10 30 1i 9288.73 29 4.5 COURSE DIRECTION DEGREES; DOG-LEG TOTAL SEVER i T'Y .... RE'Oi'ANC.~LiLAR .... '~:,]iOR[i'i-~'T'ES BEG/100 NORTH/SOUTH EAST/WEST ,. VERT I F:AL SECT I ON 80.60 E 1.I1 78. 0 E 1.93 -78.' 10 E l' 0:- 23 ........ 77.30 E O· 62 77.10 E 0.90 75 :~,¢"'-E ................. b'7~7 ..... 75.10 E O. 40 73.1:-.? E 0.86 7 _,:,~,,-~ Z-:5 .............. 778.2'.-"'.." N 769. i7 N 7._,.~ · 16 "N 748.91 N 738.49 N 727.69 N 716.29 N 703 ,~c.. N . ,' l~l S6.5. OE S ~;'Z~. OE S 62.19 E S 61.30 E S' ¢~/' 80 'E S 58.30 E S 57.10 E 1:::..5.44 E 1S:'.-74 1905.4.9 E 1944. :3,. 195:3.87 E 1992.1' 2048.16 E 2085.21 2094.06 E 2130.49 -i,T~J~ 7o '-E' ......... 5~ i17'4. 4i3 21 :_--:2.49 E 2217.6o 2225· 83 E 2260.22 2.73- 671. 45 N 231'~..,. 20 E ..'..:,4....,'"'-' ""-. 74 0 62 650.48 N 2357 15 E .... .--,o 50 I · ~ ~l ~l l__l . l, 24 628.79 N .... 2400.21 E 24.:~ii.]".':='4-4 ..... 0.27,' 606.87 N 24.42.06 E 2470.96 0· ~3_ ._ ,_ _ .:,; a. 48 N248:3 .72 E ....._";-'~111 · :_..'.7 o. 8'7 ...... ~i~,6'. 92 N .,..'-"e :;"~ -..:, .......,. 4~-" E .... '-,"'-"-'" .,_ ...... · . 76: 1 · 09 535.76 N 2567 · 39 E 259'2. :'::"'~-. O. 83 .='~09.05 N -'-60~. 62 E -. 263:'::. 0 F; 53. '-"- ... ,:. :,' E S 53. 0 E :~ 'l ~1ll . 15 0 llE I I l S 66.69 E 65. 0 E S 64.89 E S 63. :::9 E 237.86 N S 64.10 E 215.96 N · P; . '269:'::. 40 E 1 17 4._1 77 N 0,.67 421.32 N 27:34.49 E :3.54 :370. 18 N 0.42 :348.36 N O. 76 :::04.4-2 hi 0.2.2 282.24 N 0.57 O. 45 27 J. :'::.. 67 · -i- K.- .... 2~94.7'1 2825.96 E 2841.68 '~'~/- 49 E '-"-'"' ~,:, Y 0 99 2974.21 E 2986.21 :3021.66 E :30:32.41 .................................... 3068. :31 E 3077.82 3113.90 E 3122.16 ~ 1 ~ '~ 80 E 31 ~',~. "'~ ................... UNION OIL COMPANY OF C'ALIFOR'NIA G-4 RD (SEC29 TgN R13W) MCARTHUR RIVER FIEED- ALASKA SPERRY-'.-':;UN WELL '..:-':, 2EYING C:OMPANY ANCFIORAGE ALASKA VERTICAL SECTION c~LCUL'NYED ~il--"~.iN~-'i~'E~iSl_'iRE COMF'UTATION RATE MARCH ~1, 1'~82 AOF 4'- I]A]'E OF SURVEY MARCH '?, 1982 BOSS GYRO :_--;URVEY ,-lob NUMBER B0~?.-]-1~;9:::1 '-' KELLY BUSHING ELEV. =.' 99. O0 F'T. OPERATOR-M I LAM TRUE MEASURED VERT I ;_-:AL DEPTH DEPTH 0300 9474.67 0400 'P 5 /_:, ' --.. '. 09 SUB-SEA C:OLIR:=;E C:OURs--;E DOG-LEG T'OTAL VERTICAL INCLINATION D'IR~'CTION SEVERITY -RECTANGULAR C6~o~'DIN~TES 'VERTIC:AL DEPTH BEG M I N DEGREES DEG / 1 O0 NORTH/SOUTH EAST/WEST :_--:ECT I ON 9'-;-~=' 67 29 o,::, - /.;2~..t O'E '0'. 2'7 .... i'?.',z~ :--?7- N 3'~ 0'3 . ".5-' ;(=,- -I:3- ........ :ii:209. ,. .~/._l. .. ,_, ~._-~ 9463.09 .-"--'8 :=:t'~,.__._c; 65. O. E O.. ,:7,,q. _ 173.51 N :'::247.08 E 32.Sl._ .7 HORIZONTAL DISPLACEMENT '= 32~1' 71 FEET-AT-NORTH :--:6 DEG. 5~," M~-~i. EAST AT MD = i04'00 ..... THE CALCULATION PROCEDURES ARE BA._,E£ ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATLIRE METHOD. UNION OIL COMPANY OF CALIFORNIA G-4 RD (SEC2? T?N R13W) MCARTHLIR RIVER FIELD ALASKA SPERRY-:---;UN 'WELl_ :_=;L,.,:.:.'"""FI NG :]:OMPANY ANCHORAGE ALASKA CF~MPL.ITA T I ON DATE MARCH 11, 1782 DATE OF SLIRVEY MARL-:H ?, 17:32 JOB NUMBER BO:_:::-_-';- 16981 KELLY BLISHING ELEV. = 99.00 F-I', OPERATOR-M I LAM ... I '-' '- '-'11 ' IN'FERF'OLATED VALJE.:. I:'FJR EVEN 1(')0C) FEET OF M,"'A~_RED DEF'TH MEASLIRED BEF'TH TRUE SUB'SEA TOTAL .... VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 1500 1499.98 1400.98 2500 247?.00, 2380.00 3500 3438.21- 333¢.21 4500 4336.74 4237.74 5500 5271.73 5172.73 6~00 6185.~1 ..... 7500 7042.96 8500 7925.50 7826.50 9500 8791.75 8692.75 10400 9562.07 9463.09 1. 1(') N 1.36 E 101.72 N 166. "' 2(]0.96 N ' -' ~2'~":8'1 s '-"=' 2?/ N 787, 30 :" · ~,,_I. 646.71 N 1067.23 ..... 7-E]O. ~. ,-, N 144.-,.'" 1 ,=,'--' -:. 769. 17 N 1 628.7? N 24C)0.21 '-' 370.18 N ...... 9.c:c,5: {~/=,' "E 173.51 N 3247.08 E 0.02 21.00 20.98 -~'i\-~'~, ..........4 ~: ~ ~ ............ 163.26 101.46 228.27 65.01 -~'~ .............. ~i~':'-i~ ..... 457.04 142.64 574.50 117.47 ' '7~8,25 i'~:-~4 .... 837,71 129.66 THE CAi'CHLnTi'ON PROi":EDU'F~ES---ARE---BASEb "'~N '"fI:IC'-"-I:F'S~- 0'1e'''i';RffEF~'-'fi~-'r;FE-;~''F]'F,i~E'-'F~-~L,'~'-I_IS GF L-:I_IRVA]'LIRE METI--tL-:i~:i. Union Oil of California Our Boss Gyroscopic Survey Job No. Boss-16981 Well: G-4 RD (SEC29 T9N R13W) McArthur River Field Kenai, . Alaska Survey Date: March 9, 1982 Operator:.~ Marvin Milam Scale: 1" = 500' TRUE NORTH Surface Location (1882FSL 1389FEL) -~o~' oo -500. O0 @ N86© 3251.71' /o. oo ~o°'. oo- ~ oob. oo ~ sob. oo 56'E 104~ ~oob. oo ~so%. oo ~oob. oo '-500. O0 HOB I ZONTRL PROJECT I ON- O. O0 Union Oil of California Our Boss Gyroscopic Survey Job No. Boss-16981 Well: G-4 RD (SEC29 T9N R13W) Mc~rthur River Field Kenai, Alaska Date of Survey: March 9, 1982 Operator: Marvin Milam Scale: 1" = '2000' 2000.00 4000.00 6000.00 8000.00 i0000.00~ 3251.71 ' @ N86o 56' E 20~0.00 40~0.00 VERT I Cf:IL PROJECT I ON Suggested form to be inserted in each "Active" well folde-,' ko check for timely compliance with our regulations. ' 0~-r~tor, W~I 1 Name-and N~nber Reports and Materials to be received by: ~-~/--F~ Date _Required Date Received Remarks Completion Report Yes ,Yes Samples ~- ----- : ,. .44~ , ~u~ ~,o~ I;/¢ "- PI ~ ~ ./:" .. , ,,.,, , ., · Core Chips , Core Description , Registered Survey Plat /¢/~'~ -~- {? ,i%' Inclinat-i on Surve7 Directional Survey · ~ ~ .... ,,, ' ,H' ,L,:' Drill, Stun ~est Reports , ~. . Production Test. ReportS y~ ,...~. ,.~"-'.':,../'~A- ~ '"~ ~/X. '~'~"'.,, , .. - .... ...., .............. · ........ "~% ................. '~-.-,,~ '~-Bi~rtd.'~6q ~a~Ca- ... .~ ,_ , ~.......,. ..... ~, .. ~..,..j~ ~-' ~ ~G: ~ ,,-,~,..,, '". .............. ~orr.~.~.,.[~:~. ~.~.,.. ~.; .... ,~ .. - ."' STATE OF ALASKA t"" ~f ALAS~'" , . AND GAS CONSERVATION .% , ,~ISSION . MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] :2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 81-183 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 L. 4. Location of Well at surface Conductor 39, Leg #2, 1882'N & 1389'W of SW corner, Sec. 29, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) I:)T (3(3 ~ Mc::I ,.1 ...- , ,~ 6. Lease Designation and Serial No. ADL 1_8730 9. Unit or Lease Name TRADING BAY UNIT 10. Well No. TBUS G-4 RD 11. Field and Pool For the Month of MARCH ,1982 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Drilled f/ 10148-10450' Moved rig 3/22/82 TMD ~ 10450' 13. Casing or liner run and quantities of cement, results of pressur~ tests Ran 7" 29# N-80 butt csg to 10450' & cmtd'w/ 725 sxs el "G" - tested to 5000 psi - ok. 14. Coring resume and brief description None 15. Logs run and depth where run DIL-Sonic-GR f/ 10436-5970' FDC-CNL-GR f/ 10436-3000' CBL-VDL-GR f/ 10410-5900' Gyro f/ 10400-5600' 16. DST data, perforating data, shows of H2S, miscellaneous data Perfed: 9815-9843' Perfed & sqz'd: 9960-9962' 9965-10015' 10162-10164' 9852-9854' 9758-9760' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. AY'i 0 0il & Gas (,oas. ComrnjssWn NOTE'-Repo~ on this form is required for each c~endar month regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 ,/ Document Transmittal Union Oil Company of Cali! unlen DATE' SUI~'I~IITTED ACCOUNTING MONTH HAND DELIVERY 4-46-82 TO F'ROM Mr. Wm. Van Alen R.C. Warthen AT State "~T PO BOX 6247 3001 PorcuPine Driw Anchorage, Alaska A~lchuT'cL~e TELEPH6NE NO. ~)U~- TRANSMITTING THE FOLLOWING: -- TRII R-/t ~. 2" ~nd S" DIL 2 ..... " .... r,i F l~, 511, U'q.,~/ VI II ..... ,, FDC S" ,., CNL-FDC '5" .... CNL-FGC/CH 5" " Cybe)-look Radius of. C~-v., di~-~ct~onal Su,-v:j - Ta.i~§ential, ~ii--:~Cio ,al ~urvtz 'Ta.n~.j., ave angle dir.~ctional surve~ ~~PLE"AsE SIGN AND RETURN ON' COPY R~C~V~' ~ _ ~.,. [ ~C~,V "-~ .... m~ka Di & Gas ConsCommislion FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. Document Transmittal~-2~ Union Oil Company of Califc~gl~ unlen 'DAT~ SUBMITTED ' ACCOUNTING MON'~H HAND DELIVERY :4-21-82 'T'O ~"o~ " Nr. Harry Kugler R.C. Narthen ^T SL~Le O~i & Gas CC ^T PO Bcx 5247 3001 Porcupine Drive Anchroage, AK 99502 Anrhn~ao~ ' "~ TI:'LI:'pHoNE NO, TRA,NSWITT}NG THE FOLLOWING: i KU 14-32 i 1 · ea, Blueline and sepia of the followinI' , , , ,. ,~ BHC 2" and 5" , , ,, OIL 2" .and 5" , CNL-FDC 5" FDC ,5" 'G~"4" '"RD .... 1 ea. Rl~mlin~. and sepia of the q'ollowing' . ~" ACBL 5" ~ ' . ,9 LEASE. SIGN.AND RETURN .ONE. COPY - : .... , . ........ RF£FTVE~; ..-~ ' ' '~' :. ?.... I~ATI: ..... "~'~,"/ / :",: "" ?'' '~ i.. '.~' _. - . . ~. ,,~,.,..,..,,.~:. ~')'~1 ~', G~?,'~ Cons. ~ ~..,, ....... ~,, , .. , .... . .... i i i iii i i ii FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. .. .. , · "' . ..'.', ·. .. . · , ,,, ,~ . ,; , , '; . ,, , Document Transm:"al Union Oil ComDan¥ of ~ornia union DAT£ $'U~MITTE.~ ' AC'COUNTING MC~NTH 4-16-82 TO FROM Mr. Harry Ku~.ler R.C. Warthen , , AT State Oil and Gas AT Cons. Commission PO Box 6247 A.__L ,,, ' ' A----~Ar'~A 'Al" ~-~O /"~II~,,.IIU! a.~l~ /~1%. TELEPHONE/~iI(~IUJ tJ.~9 3.~'t.,~(... TRANSMITTING THE: FOLLOWING: , ,. ,, ,, 1 ea.. M=9.:+~r +=,n_o~.:"P._a R_n #6_~6'6 ~ Ca.. " ,, ~ o~ RD #521~* ~ PLEASE SIGN AND RETURN ONE COPY RECEIVED' _NaSlg 0ii l Gas Cons. Con~i~ ;J01t ,, , .... , ..... ,, ,,,, .... ,, , ,, , , , , , , , , , , ,, , FORM 1-2M02 (REV, 11-72) PRINTED IN U.S.A. - , ALASK _ .L AND GAS CONSERVATION ..,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. UNION OIL CONPANY OF CALIFORNIA 81-183 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 so- 733-20050-01 4. Location of Well at surface Conductor 39, Leg #2, 1882'N & 1389'W of SW corner, Sec. 29, T9N, R13~, 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RT 99' MSII ~DL 18730 9. Unit or Lease Name TRADING BAY UNIT 10. Well No. TBUS G-4 RD 11. Field and Pool Id~ADTlll ID EiT%II~E~ E-T~I PI i-i,1,..~1 i1%/i i~,.,~1% I%J- l J..I '~, I -Lm--JJ--U For the Month of FI~RR! I~RY ,19__82_ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations 00:01 hrs 2/3/82. Cut window f/ 5970-6032' THD ~ 10148' on 2/28/82 13. Casing or liner run and quantities of cement, results of pressur9 tests None 14. Coring resume and brief description " None 15. Logs run and depth where run None 16. DST data, perforating data, shows of H2S, miscellaneous data Sqz'd & abnd perf 9600-9628' 9648-9898 ' Perfed & sqz'd 6070-6072' 5960-5962' IViA,~ .7 9 1972 A,,~.s.~ Oil & ~a~ Coos 17. I hereby c/e~ that the foregoing is true and correct to the best of my knowledge. SIGNED_ __ E DIST DRLG SUPT DATE 3/15/82 NOT rt on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil an~ Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate ALASKA OIL AND GAS CONSERVATION COMMISSION THRU: Chat Chatterto~ ~ ~ Chairman Lonnie C. Smith Commi s s loner Edgar W. Sipple, Jr. Petroleum Inspector February 8, 1982 Witness a BOPE Test on Union Oil ' s Grayling Platform Rig 54 Sec. 29, T9N, RI~, MSM Parker Drilling Co. Saturday,k Februa..ry 6, 1982 - I traveled from Anchorage via AAI to Eena'~ to witness a BOPE test on Union Oil's Grayling Platform Rig No. 54, Parker Drilling Company. The BOPE test commenced at 8~45 a.m. and was concluded at 11:40 acme There were no 'failures. I filled out the A.O.G.C.C. BOPE test report which is attached. In summary I witnessed the BOPE test on Union Oil's Grayling Platform Rig No. 54. 4/80 . ALASKA OIL & GAS CONSERVATION COMMISSioN B.O.P.E. Inspection Report Inspector' Eb6~ g~]' ~/~_~[~/ %7'A-.. ope r'ator Lf/Uzn d ~);/ Well' T~ sr~:. ~,~ Location: Sec D T T~;/ R ..,.?~.~ N~/Q Drilling'COntractor ~ ~ Rig ~ g~ Well Representative ~' ~/~.Casing Set Representative ,, Location, General Well Sign General ..Housekeeping Reserve Pit Rig ' OF~. .. ,, · BOPE. Stack A n n~,ar P;~eve nter P, ipe ~%ms .... , Blipd R~s ~ .. ~.~.- Choke Line Valves ' ~ ~.C.R. valve Kill Line Valves Test Results: Failures' __ Test Pres.~re I.goo ,~000' C~o oo . 663 o ': . 3000" Accut. iuL;,'roa SYSTEM Full Charge Pressure 3~0C) psig ,, Pressure After Closu re_~_~O psig 200 psig Above Precharge Attained:-_O min'2~sec Full Charg~Press~e AttUned: N2~P2~.~'gOO ~/o~ Pg,~O ~si9. Controls: Master /]~ C.u,r,~J ~(~,oJ Remot=~.._~ ......... ~.~.~n~s switch cover Kelly and Floor Safety Valves Upper KellZ ~Test Pressure Lower Kelly '~ Test Pressure ~ooo Ball Type ~' ' '. Ins ide BOP Choke Manifold No. Valves ~ No. flanges~ ~ Adjustable. Chokes . Test Pressure 0~ Test Pressure O/~ /Test Pressure tlydrauica!ly operated, choke. [w- '~'OO O Tes'~ 'T'i];~- ..... ~7---1~'~:-~'.. ~j',,~ ,'"' Repair or Replacem.ent of 'failed equipment to be made within'--~ .---days and "'i',, ',. Inspector/Commission office notified. ~.A.'~.I~ ~'~,~-. ,,..~.,., ~.er~~D,~,.., 1,b .... ,,~' fl.~..., ( ~ .vc,,,~.~.,~,~',y,~.,.)~'~ ..... -. ," ~ ~~, E..~;..' . Distr±but ion orig.' - AO&GCC cc - Operator cc - Supervisor. Dece~,~ber 17, 1981 ~tr, Robert T, Anderson District Land Manager Union Oil. Company of Call fornia P. O. Box 624? Anchorat'e, Alaska 99502 Re ,' Trading Bay' Untt TBUS G-'4 ltd Union Oil 'comPany. of California Permit No. 81-183 Sur. Loc.~ 1882~N, 1389~'W of SW er Sec ~, T~N, R1.3W, .Botto~ole LOe.~ 2566~N, 18.30'E of SW.c~ See 28, T9N, RI3W, Dear Mr.. Ande~,son~ .t~neloSed. is the approved a'ppli.catl0n for permit to drill the above .referenced well, Well. samples and a nmd log are not required,. A continuous directional survey is required as per 20 AAC 25.0§0(b)(5). If available, a tape .containing the digitized log infor~ation · 'shall be submitted on all logs for eopyin.g except experimental logs, velocity surveys and dipmeter surveys. '~any rivers in Alaska and their drainage systems have been classified as important for the spawning'or migration of anadromous fish. Operations in these areas are .subJ. e.ct to AS ..16.50,870 .and the regulations prom. ulgated thereunder (Ti.tlc 5, Alaska Administrative Code). Prior to commencing operations' you may be contacted, by the Habitat Coordinat.or's office, ...Departrner~t of Fish and Game. PollUtion of any. waters of the 'State is prohibited'by AS 46, Chapter 3, Article ? and the regulations promulgated .thereunder' (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, .as. amended,. Prior to r~. Robert T. Anderson -2- Trading Bay Unit TBU$ G-4 RD December 17, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us' in scheduling field work, we would appreciate your notifying this office within 48 hours after the t?ell is spudded. We would also like to be notified so that a repre- sentative of the Commission may' be present to v~itness testing of blowout prevente~ equipment before surface easing shoe is dril led. In.the event of .,suspension or ,abandonment, please give this offtee adequate advance noti.fieation so that we may, have a wi tness present. Very t~u. ly yours, ". ' ' tiamt I t on Chai rman of '~:! ORD~;~ OF T~,~ COMMISSION Alaska Oil & Gas Conse~vation,,Commissi. on o sure Department.of Fish & Game, Habitat Section w/o ariel, Department of Environmental. Conservation w/o/anal. ALASKA OIL AND GAS CONSERVATION COMMISSION JAY $. HAMMOND, GOVERNOR 3001 PORCUPINE DRIVE.ANCHORAGE, ALASKA 99501 December 11, 1981 A D'M I N I S T R A T I V E A'P P R O V A L NO. 80.39 Re: Application of Union Oil Company of California, operator of the Trading Bay Unit, to redrill, complete and produce the ~rading Bay Unit_G-4...RD well as part of the pressure mainten- .ance ~roject approved by Conservation Order No. 80. Mr. Robert T. Anderson. District Land Manager Union Oil Company.of California P. O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Anderson: The referenced application was received on December 10, 1981 and stated that the drilling, completion and production of the Trading Bay Unit G-4RD'well will provide a crestal final with- drawal point in the'Hemlock Pool. The Alaska Oil and Gas Cons'ervation Commission hereby authorizes the drilling, completion and production of the referenced well pursuant to Rule 5 of Conservation Order No. 80. ..' Yours very truly, Harry W. Kugler, Commissioner BY THE ORDER OF THE COMMISSION HWK :be Union Oil and Ga~.'" ',4son: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unl®n Robert T. Anderson District Land Manager December 8, 1981 Mr. Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99504 TRADING BAY UNIT State of Alaska Permit to Drill Trading Bay Unit State G-4 Redrill (23X-28) ADL-18730 (8-86-71-5575-601352) Dear Mr. Hamilton: Enclosed for your approval are three (3) fully executed copies of the above captioned Permit to Drill TBUS G-4 Redrill. Also enclosed is our check No. 19172 in the amount of $100.00 to cover filing fees. sk Enclosures (4) Very truly yours, cc: J. C. Callender A. Lannin-LAOffice IJnion Oil and Gas''~,.. ,. :son:. Western Region Union Oil Compan(' ;alifornia P.O. Box 6247, Ancho, age, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager December 9, 1981 Alaska Oil & Gas Conservation Commission' 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska HcArthur River Field Application to Drill and Complete TBUS G-4 Redrill (ADL-18730) Gentlemen: Union Oil Company of California, as operator of the Trading Bay Unit, hereby requests approval to redrill, complete and produce Trading Bay Unit State G-4 well in the Hemlock Oil Rool pursuant to Rule 5, Conservatio'n Order No.. 80.' This proposed completion at a crestal final withdrawal point will result in additional recovery of Hemlock Rroduction. Your approval of this request will be appreciated. sk cc: C. Case R. Warthen Very truly yours, Robert T.' Anderson ALASKA C,,- AND GAS CONSERVATION C ,,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC I--I REDRILL J~ DEVELOPMENT OIL 5~ SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator UNION OIL COMPANY OF CALIFORNIA 3. Address PO BOX 6247, ANCHORAGE, ALASKA 99502 4. Location of well at surface ~ 9. Unit or lease name Cond. 39, Leg 2, 1882'N & 1389'W of., cot, S.29 T9N R13W SM Trading Bay Unit At top of proposed producing interval 10. Well number +_2580'N & +__1600'E of SW cor, S.28 TgN R13W SM TBUS G-4 RD At total depth 11. Field and pool +__2566'N & +_1830'E of SW cor, S.28 TgN R13W SM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RT 99' MSL ADL 18730 McArthur River Field 12. Bond information (see ~0 AAC 25.025) NaLiuual FiL-~ Insurance Company of Type Statewide surety and/or number Hartford (B5534278) Amount ~200,000o00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 57o 5 SW miles 1830 feet well +900 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 102.40' MD & 9617' TVD feet 3840 February 1, 1981 I ' 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures +2000 psig@ Surface KICK OFF POINT 5980 ' feet. MAXIMUM HOLE ANGLE 29 ° (see 20 AAC 25.035 (c) (2) +--3400 psig@ 9617ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT·" · , Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 8 1/ !" 7.. 29t! N-80 Butt. 4800 5480 I 10240'I 9617 +800 SXS " I I I ~ I I I I - I I 22. Describe proposed program: (See attachment) ~)~C~,/~/~, D£C' .. d 21Zr_/a&,a Oil & Gas Ooas 23' ' hereby certify that~-tJ3~°~e~L°ing is~-T~ue incorrect to the best of ~know~~ ' SIGN LE District Land Mgr. DATE 11/25/81 The space below for Commission use .. CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required I APl number []YES ~[NO []YES '~.O [~YES •NOI 50- '7'~'3- Permit number Approval date · J'l- /~ 19. I17/R1 SEE COVER LETTER FOR OTHER REQUIREMENTS ....~ ,,COMMISSl ONER DATE _r~_~_~.._l~e_~ '1 APPROVED BY by order of the Commission -' ' ....... Rev. 7-1-80 Submit in triplicate Permit to Drill TBUS G-4 RD 11/25/81 lo 2. 3. 4. 5. 6. 7. 8. 9. Move Rig ~/54 over conductor ~/39, Leg ~2, TBUS G-4 and rig up. Kill well, install BPV, remove tree, install and test BOPE. Pull and lay down existing completion equipment. Set retainer above perm pkr & sqz Hemlock perfs for abandonment. Mill window in 9 5/8" casing from +5970' to 6040'. Spot KOP f/ +6100' to +5900'. Directional drill 8 1/2" hole from 5980' KOP to +10240' TMD. Run logs. -- Run 7" csg. 10. Complete well as dictated by logs. 11. Install BPV, remove BOPE, install and test tree. 12. Place well on production. 2." ~ooo Fs;. g~o9 ~c~ .. · ~#GLED ,FILL UP ~ HYDRIL' ~L/A'~ ,c..'A/ff$ ~ · . CHECK V.~L VE HY~A~£1& OPEt~A T£D VALVE ' , ... . '. /. 6A TE' 0~'~' /. Lo-7'og~J£ klOTE ' Oki ALI.. CHANGES MUST HAVE WElT.TEN APPROVAL. BY THE DISTRICT DRILLING SUPERINTENDENT .._~ [:.~1. I DRTE i J , i i I -- I I I I I iiiii i · · ! I, ,--~ " .. :, .' '...'. ' .... ..' '.' ,. i ' . .. ..- ~ ~. ~ 2~ ~ "' . · . ..,. ~ , ~ ~ ."' .' h ,~ · .. .... ..,' ,. . . ... ' "..~ ....'. ..... '. ... ' .' .. · ..... .. .; . .. . ~ . .. . ... .. .. · .~ . ,.... ,..... .' ... . .. ,.. . . ' . ~ . .... .... .. , . ; '. ... .. .. . .' ~ .. · .~' · .... . . . . ... .. . .. . . .. .. .. '. '. . . . .. .. . . . . . '. . . . . . .. '.' .~t~t '. .. ' .'.; ~ . II ·, . . ., .. · [ . . '.'. .. ... . j'.' .. ..'.' . . ' . ". '. .' ..'.' .... . '~ ~/,**~ '~:~'~ .. ~. .. " .... ~07~"~..' c~/,:~.3 " [ ' ,,, ~~~ '~ .... ~ ~. DATE ~~ D~ C~D. I I [ II I , .... u~o~ ......" ' ' ' __ , OIL COMPANY OF C~I~RNIA ~H~ C~SINO STRZNG ~,~ . ~ ~ASlN~ SIZE W" HOLE SIZ~ CASING AND TJBING DESIGN STATE' Au~s~ A DAT~ II/z~-/~ ~ DESIGN BY ~SE . .. v-..,l/f~: x.s.P. DESC.~PT/ON ',;EIGHT TENSION l~-W IT/2~.~4 TDF COL~SE COLL~SE C~ B~T !ETEBi'~ ~'/ B~ -top of- ST~NG~ P~SS. ~ ~SIST. '?~SS~ 1.~.~ Grade Thread ~/0 BF~ section TENSION bott~ tension Y~LD lbs lbs 1000 lbs ~si psi. psi psi BDF .I.ol PF-VCE , COS~ PER PT. · , Formulae___._~ Collapse resistance in tension = X (Collapse pressure ratify) Burst Pressure = ~mP + Depth ( ~ya. or. z'r --.~) JIF (Bouyancy Factor) = 1.o0- (O.Ol~S X Mua Wt. I) Calculations: D tK76. Tc t G-19 _.[_ I~ ,~s, T GRAYLING G-5 -.o.--- i TO 1¢,016 K-IS RD 17~173 ~ ,0 ,~,,4,,,, .,~ K 7 ~ ~ ~, 1'0 14,700 ,~ ¢:,7 ',,,, "~ ~" K~2 RD~ . TD 13,990 ,, ~o,,,~o ~ -,,X ~o ,s.,.. ~ ' ~K-23 TO 13,~74 / ' / ~ TD 8,580 , ~,~ ,, ,o ,,G-32 G-I' i ,, G'9 \ I 9 '"D ~5.350 TRADING BAY UNIT G-4- RD ( 25 X-28) PROPOSED WELL LOCATION CHECK LIST FOR NEW WELL PER,MITS Company Lease & Well No. ITEM APPROVE DATE (3)' Admi~'~ ~- 0 thru 11) (4) cas~$k~ /<12 thru 20) (s) ,~o~~_ ,,' ~----//~'~' ~' t-f21 thru 24) 1 3. 4. 5. 6. 7. 8. 1 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO REMARKS Is the pemnit fee attached .......................................... Is well to be located in a defined pool ............................. Is well located.proper distance from property.line .................. · Is well located proper distance from other wells ....................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is well bo:?__ plat included ...... Is operator the only affected party', .................... Can permit be approved before ten-day wait .......................... Is enough cement used to circulate on conductor and surface ....... Will cement tie in surface and intermediate or production stringslii Will cement cover all known productive horizons ................. Will surface casing protect fresh water zones ................... Will all casing give adequate safety in collapse, tension ::J burst,... Is this well to be kicked off from an existing wellbore ...... Is old wellbore abandonment procedure included ' i0-403 ' . . Is adequate well bore separation proposed ..... Is a diverter system required ....................................... __~ Are necessary diagrams of diverter and BOP equipment attached , [. ~~. ,~,~ , Does 'BOPE have suffiCient .pressure rating - Test to ~o ,!!!~i,~ Does the choke manifold comply w/API RP-53 (Feb.78).":~]~ , . Additional requirements ' ~ Additional Remarks: Geology: Engineering: ,cs JAL ~f~.._..~"' ' -- rev: 03/10/81 INITIAL GEO. UNIT ION/OFF ' POOL CLASS STATUS AREA NO~ ,I SHORE L (. Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. .. To improve the readability of the Well History file and to simplify finding information, information, of this natUre is accumulated at the end of the file under APPEN. DIXi No 'special'effort has been made to chronologically organize this category of information. ~ . :- :'?.'-.~-/-'~'~ ..'/. ~2~?~~'!'.-' " ' "· .- <- -'<: '!!?::L-~<.~-~-.~, 'i~.j:,~:~>':~:~,~:~ ~/.-~:' %~':, - ..':.'.j~ -~ ...... ~ - _ . D~3'E: :8210~t 5 : '-"" ORIGIN ~ ~ Rk~b NAME IBgEh 1D ~ , PREVIOUS RE~ ~ COMMENTS :RB~L ~MMEN'TS TAPE HEADER #~ SERVlOf NAIVE g~ERV. IC ~ DATE :82/03/ 5 ; OR1GI~ :1070 { T~PE. NAME :A62b16 CONTZNUATICN ~ :01 ~v~ou~ ~A~ i SERVIO~ NA~E gRSI~N ~ : ~DATE ~ M%[IMUM bENGTH ~ 1024 Ibg TYPE : ~..P~vzuus F~ INFORNATXON RECORDS i MNEM CONTENTS- ~ !CN : · i FN : t RANG: ~. 1 To~ 'SECT j cooN , STAT · l :'-" I e.' .....j.... ·. ®'--!,' ' ONION OiL COMP OF C~LIFORNIA TBU~f-4RD(23X-28) MCARIHUR BIVER . 9N 29 KENAI AbA~KA USA DlbOC1F J# RECOBD TYPE 047 *'~ kECOHD TYPE 047 PAGE RECEIV£D' ... , UNIT ' TYPE CATE '-SZZE CODE 000 000 02g' 065 00O 000- 018 065 000 000 Olt' 065 000 000 0C3 0~5 000 003 002 065 000 000 002 0o5 000 003 00b 065 000 0C0 006 065 000 00) 004 065' 'CNIT TYPE CA?E S'IZE ICO£E 005 bVP 009.H03 VERI~ICATIUN LISTING COMPANY ~IELD ~OUNTY STATE = UNIG~ OIL Of CAUJF = ~BU G-4RD{23X-28) =.FCAR~BUR RIgE~ = KENA1 = AbAS~A dOB # 10707,62b16 DIL ~UN {1, LOG3ED BOaTUM LOG IN~ERVAb TOP LOG 1NTEBVAb CASING-LOGGER BlT $1ZE TYPE H0bE FbLID DENSITY VISCOSITY PH. FbUID bOSS 2-MAB-82 = 1O450 ET, = 5900 =-.9,b25 IN, 0 5970 I='T, = 8.5 IN. = ](C Lq{ L2M~R-FtE 21] NBA ' = 73 bb/G = 58 ,5 9,0 .- 8.2 tC 3 PAGE :' I YERIF'ICATIO~ L1S~ING TEMP, = 1.090 'g 65 ~ TEMP, = 1.110 @ ?? F TEMP, :: 1.110 @ 65 ~ = .4690 ~ 160 ~' MATRIX MANDSTONE ~mmmmmmmmmmmmmmmm. mmmmmmmmmmmm ** DATA [~ORMAT RECORD {*{* ENTRY ObOCK$ TYPE 0 D.~TUM ,5PE2.1I. ?ilCATI.i3N ObO~"KS MNEM SERV.]I( g ,gt, RVICE UN~]T ] O ORDEB # DLPT 6FLU DIL GriMM IbM DIb OHMN. ILO OIL OHMM SP CIL MV GR Olb GAP! DT .EHC US/J; SP BBC MV GR .EHC '{AP1 N PH.{. FDN RHUB FDN G/C3 DRHO FDN G/C3 CALl ~DN IN GR FDN GAP1 NCNb FDN ~CNb FON NRAT .~'DN .~IZE 1 4-- 4 1 AP1 AP1 LOG TYPE 0 ~C 7 0 7 0 7 12 7 1 7 31 60 52 60 60 31 42 68 42 35 42 44 42 42 31 42 42 '34 42 42 REP,9 CC DE 66 73 · 65 66 API -ItPl :}lie CLASS MOD NO. 0 0 0- 0 0 ' 0 0 0 -- 0 46 0 0 0 0 0 32' 0 0 32 0 0 0 0 0 -32 0 0 2 0. 0 ! 0 0 0 0 0 3 0 0 32 0 0 l~.2 0 0 93 0 0 ~ 0 0 ** DA~'A ** DI~PT SP GR CAbI NRAT 10476.500 SFbU '999.250 GR -999.250 NB~I 2.805 G~ 0.000- -999.250 -999.250 -0.586 0.000 1LM DT RHOB NCNb EN'I'~ ¥ 1 60 .lin 0 SIZE P~UO~ SS LEVEL, .4 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 ~4 0 4 0 4 0 4 0 4 0 4 0 -999.2[ 0 -999.250 SP .,1.984 0.000 FCNL o. SAMPLE 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 PAGE REPR CODE 6~ 68 68 68 68 68 68 68 68 68 58 68 68 68 68 68 -959.250 -~99.250 -6.926 0.000 i.bVP 009,H03 · DEP? SP 'CALl ~ NR~ T ~ DEP r~ GR CALl N SP GR CALl NR~T DEPT SP GR CALZ NRAI' ~ DEP'I' 'CA~I :' DEPT SP CAb1 NRAT DEPT SP CALl NR~.T DI~PT SP CALl N.RA~ DEBT SP GA CALl NRPT VERI[.' ICATION 10400.000 Sb'LU -46.719 GR 55.250 NRF. I 8,492 GR 2.391 10300.000 SFLU -56.500 GR 62,188 NPHI 7,789 GR 2,287 10200.000 SFLU -77.312 GR - 34. 406 Ni-tk 1 8,039 GR 1.349 10100.000 SFLU -73. O~ 3 GR 47.625 NPHI 7, 7S3 GR 1.548 10000.000 'SFLU -77,750' GR 47.625 N~kI 7,590 GR 1.571 9900.000 SFLU -81.5~3 54.938 NPHZ 7,262 GR 1.994 9800.000 SFLU -37.844 GR 103.312 N[4~i 7.328 GR 2.480- 9700.900 SFLU -2 1'. 2c. 7 GR ~0.D63 NPHI ']O.852 GR 2,828 ~S600.000 ' SFLU -69.188 GR 52.531 NRI- I 7.898 GR I .939 LISTING 14. rC9 55.250 24.805 59.500 PAGE 4 16,078 62.188 24.072 68,375 ILN. 10,7.~3 iLD': DT 73.375 SP -46.719 RHOB 2.412 :[RfO 0.126 NCNb 3025,000 F~NL 1209.000 50.5~:3 34.406 9.668 43.563 IbM 15.336 ILD 18,078 DT 79.750 SP -56.500 RHOB 2.314 DRHO 0.023 NCNb ~3492,000 FCNb 1513.000 51.906 ;47.625 12.988 ;43.563 1bM 23.6~6 /LC .;0.750 DT 61.000 SP -77.312 RHOB 2.582 :£RfO 0.074 NCNb 5100.000 FCNL' 3~2,000 45.188 47.625 13.525 45.344 IbM 33.906 IbP 46.312 DI 66,000 SP -73.003 RHOB 2.553 DRHO 0.096 NCNb ;4648.000 FCNL 2898.000 40.844 ,54,938 20,165 55,9u9 IbM '37.625 /LC I~. 9.0{ 3 DT 66.{88 ,SP -77,750 RHUB 2.430 :£R~O - 0.082 NCNb 4 26 ~', 000 F~"NL 2 ~6 9,000 ILM 2~.641 I[,D 31.688 DT 76.0C0 SP -81'.563 RHOB ~,355 :~RHO 0.090 NCNb 3736.000 C~L 1852.000 15.188 IbM 103.312 .-DT 27.393 BHOB 94.93a' NCNb 12.859 1bM 80,063 D~ 28,564 RHOB 90,375 NCNb 13,8~9 1bP 80.188 SP '37.844 2.539 :[RFO 0.091 2952.000 F.:Nh 1159.000 7.793 1LD 8,180 75.0C0 SP '21'.297 2,586 DRHO 0.034' ~3148,000 FCNL 1030.000 i18.906 ].LC .~ 3.32~ 75.375 SP -69.188 2.385 :[ 1{~ O 0.032 385 ~-. 000 FCNI, 1 ~0 ~. 000 1.9. 359 IbM' 52.53! 18.750 RHOB 53.905 NCNb ! , i DEPT ~ SP G~ {CaLi ( NR.qT i GR ~CALI ~ i-NRAT, {DEPT ~ NRAT , CALl '-IP' i OEPT , Sp ~CALI !N AT SP , GR 'CALl i NRAT !OEPT ~ GR ~ NRAT D~PT GR ~CAhl ~ , NRA~ D EPT' ~ CALl- .. NR~T ~ '~EPT 009.H03 VERIFICATION LISTING ;5500,000 SFLU -126,438 OR b6,188 8.375 GR 2.332 94OO 94 9 2 ,000 SFbU ,3~5 GR .813 NPH1 ,648 GR' ,395 9300.0C0 SfLO -84,62b GR '49,428 NPHI 8.47.7 GR 2,0fl 9200,000 SFLU -31.328. OR 95,125 NPHI 10.680 GR 2.734 91C0.0( 0 Sf'LU -53,875 GR 59.3;2 NPHi. 10.008 GR 4.234 9000,000 -59,031 GR 77,688 NPHI 9,727 GR 2,680- 89C0.000 SFLU -70,063 GU 88,563 NBfI 10,195 G~ 2,939 8800,000 SFLU -53,0(0 .GR 98,188 NPIdI 9.4~9 GR 2,639 %700,000 Sf'bU -46,438 GR 59,500 NBkl 8,523 GR 2,154 8b00 ,000 SFLU 28,4(6- 66,188 24.023 61,58~ 22.172 94.813 30,908 ~6,938 17,969 49,438 ,19.824 54.D63 11,031 95,125 27,J97 93,375 ,14,51b 59,312 .54,492 54,813 8,438 77,688 27,58~' 78,125 9.961 88.563 30.908 86,31'2 12,406 98,188 27,295 86,938 9.0(8 59.500 21.191 62.939' 6,656 DT ~HUB. NCNb IbM DT RHUB NCNb ILM DT NCNb IbM IET RHOB. NCNb lbM DT BHOB NCNb ibM- :LT RHOB. NCNL 1LM DT RHOB NCNb' IbM. DT I~HOB NCNb IbM DT RHOB NCNb 1LM .~6.922 lbD' 79,375' ~P 2.443 :[R[O 4564;000 FCNL 10,930 IbD 77,060 SP 2,531 DRHO .5444,0C0 FCNL 14,398 ILD 82.750 SP 2.389 D~HO 3568.000 F'CNL 10,055 lbD 74,000 SP 2,502 DBBO 28~0,000 :fCNL 13.2'6b IbD 110,188 SP 1,738 DRHO 1514.000 FCNL 8.563 IbD 77.000 SP 2.514- D~HO 2464,000 ;fCNb 8.1C2 1LD 79. O00 2.541 2t25,000 F2Nb 9.055 .ILD 74,563 SP 2.605 DRHO .:506.000 FCNL 9,0~ 0 IbP, 80. { 88 2.506 :[ RI- O 3122.000 F2NL 6,668 PAGE ~7.2~1 -126,438 0,020 215B.000 11.906 -5~.375 0,011 831.,0C0 20.938 -84.625 0.034 1674.000 9.898 -31.328 0.041 984.500 16,953 -53.875 -0.015 337.250 8,742 -59,031 0.006 898,500 8.836 -70.063 0,022 770.000 10.109 -53,000 0.062 929.0C0 ,]1,148 -46.438 0.140 1305,000 7,668 LVP SP GR CALl NR~T DEPT 'SP GR CALl NRAT DEPT SP GR CALl NRAT DEPT $P GR CAL, 1 NRAT DEPT SP G~ NRAT DEPT ~SP CALl ~DEPT =$p CALl N RAT ;DEPT $P GR CAL, I NRAT DEPT SP CALl ~RAT b~PT SP 009.H0j VERI~flCATiON L1STiNG -86,125 GR 41,063 NBEI 8,469 GR 2.387 8500.000 SFLU -71.,833 GR 51,500 NPHI 8.3~ 8 GR 2,285 84G0,0(0 $FLU ..54,531 OR 70,1~ 5 NPHI 8,219 GR 2.410 8300.000 SFLU -123,875 OR 74.688 NPHi 10.312 GR 3,098 82(]0,0(0 SFLU -120,563 GR 70,688 NPHI 11.875 GR 2.7;5 8100,000 SFLU -113,250 GH 94,312 NPH! 12,031 OR 3,203 80(0,0(0 $FLU -103,250 GR 40. t56 NPHi 8,414 GR 1,899 7900.000 $FLU -112,688 GR 87,375 NPHI 12,086 GR 2.973 78C0.0(0 SFLU -104.500 GA b3,L56 NPHI 12,523 GR 3,016 7700.00~ SFLU -154.750 GR 41.063 24.75b ' 40. 525'- 13,781 .51,500 23,486 ~53,094 8.703 7~!.125 25.391 68.000 7.312 74.688 33,154 69.750 8,820 73,.688 26,611 84.875 10.375 94.312 34.271' 92.000 )1 3,555 43~, 156 ~]7.480 42,4'06 6.734 87.375 30.225 93.938 5.715 63,156 :30.713 61,219 38,563 DT RHOB NCNb D~ BHOB NCNb 1LM DT NCNL :ET ~OB NCNb DT RHUB NCNb IbM RBOB, NCNb IbM DT BHOB NCNb IbM :ET RHOB NCNb DT RHOB NCNb IbM 87.000 2.361 :ERGO 3~82,000 F2NL 11.789 IbD 86.375 SP 2.340 DRHO ~426.060 FCNL 7.676 1LD 80.563 SP 2.455 DRHO 3474.000 FCNL 6.402 ILL' 7~.188 SP 2.602 DRHO 22~4,000 :~CNL 13,250 1LD 60,188 $P 2.576 DRHO 3510.000 FCNL 8.055 IbD 89.750 SP 2.449 DRHO 2702.000 ;FCNL 9.344 ILD 80.000 SP 2.424 DRHG 4672.000 FCNL 6.461 '~3.188 SP 2.564 DRHO 2708.000 :fCNL 5.910 ILL 83.563 SP 2,525 DRHO 2502.000 f'CNL 5~238 ILD '~0.375 SP PAGE -86,125 0.020 135~,000 18.422 -71.813 0.001 1.41~.0C0 8.109 -54,531 0.046 1395.000 6.922 -123,875 0.044 722.500 9.586 -120.563 0.145 1318.000 8.930 -113.250 0.156 772,000 9.984 -103.250 0.002 2476,000 6.715 -112.688 0.128 902.500 5.863 -104.500 0.039 817.500 4.531 -1'54.750 {LVP 009,H0:1 ! ~ GR :'CALl NRAT · ' DEPT SP ~, CALl !NRAT i UEPT SP !CALl ~NRAT DEPT 5P CALl ~ NRAT 'DEPT CALl , DEPT SP · GR CALl ~DEPT CALl NR~T ~DEPT SP , CALl , ;DEPT ~CALI 'N~AT VERli;ICATION L1,5~I'ING 8.5t3. NPH1 8.344 GR 1.970 76O -10 6 1 '; 50 -11 5 0,000 SFbO 6,312 GR 4,188 NPHI. 3.727 GR 3,085 0,0(0 SFLU 3,250 GR 5,319 NPHI 9,266 GR 2.240 7400,000 5FL0 -106.938 GR 86.063 NPHI 16,531 OR 3.037 730 -11 3 O.OCO SFLU 6.438 GR (::,. 0i 3 NPHI 8.664 GR 1.. 7.33 720 -12 5 9. 300 ,LFLU t:,. 250 GR 6.563 -NPHI 8.81 0 GR 2.453 7100.000- ,bFbO -111.188 GR 81.875 NBhl 14.125 GR 3.221 7000,000 ,bFLU -~12,1E8 GR 90,688 · NPHI 16,297 GR 3,031 ' 69C O. O( 0 ,5FLU -Is6.813 GR 6~.1~5 NPH1 17.156 GR 6800 -111 41 .000 SFLU ,438 GR .125 NPHI ~8.652 40,219 NCNb 4,063. 64,188 .ET 31,299 PHOB ' .63,563 NCNb 8.594 IbM 55.219 bT ~1,582 RBOB- 62.781 .NCNb 8,~86 1LM 6.063 ~[T 9.492 RHOB, 95.312 NCNb' 18,078 1bM 36,063 DT ~14.697 BHOB 41.031 NCNb 6.797 ibm 56.563 bT 25,293 ~HOB {49,0b3 NCNb 5,043 ibm 87.875 DT 33.154 RBOB 83.433' NCNb 13.312 IbM 90.688 DT. 29.492 BHOB 84.250 NCNb 7,793- 61.125 DT :30.225 64,813 NCNb 30.305 ]bt~ 41,125 :ET 17. ~{22 RHOB. 2.459 DRHO 4020.000 -FCNL 4.133 'E8.563 SP 2,395 DRBO 23S4,000 :FCNb 7.055 ILD 90.563 SP 2.410 DRHO 3118,000 FCNL 8.680 1LD 86.188 $P 2.453 DRHO 2238.000 :fCNL 13,492 lbD 75.375 SP 2,514 DRHO 4108,000 FCNL 6,152 ILD 81.375 6P 2.439 DRhO .;890.000 fCNL 5. ~{~ 1 IbC 88.563 ,bP 2.293' '.[.I4[O 214~..000 F2NI, 9.727 83.188 SP ~.477 DRHO 1916.000 :ECNL- 7.500 ILO q2.188 SP 2,418 D~HO 2612.000 fCNL 10,164 IbD 78,750 SP 2.506 DRHO PAGE 0.032 1947,000 4,281 '-106,312 0,032 721,000 8.688 -113.250 0.099 1340.000 9,000 -106,938 0.156 697.500 12,469 -116,438. 0.045 2330.000 6.707 -126,250 0,043 1187,0C0 5,4[0 -111.188 0.131 535.000 12,648 -112.188 0.06~ 601,500 7,477 -86,813 0,018 836,000 12.477 -111.438 0, O50 - . - .. . - : . CALl 8.969.. GR-" - '-. NRA? 1.967 --. -- --" .. I~gP~ bTO0.O00 8FLU SP -12J .000 G~ G~ 42,063 NPHI' . 'CALl 8,570 GR NRAT 2,727 D~PT 6bO0,OC 0 SFLU sP - 1 o8. 250 G~ 4b,4e9 NPB1 CALl "' 13,820 GR NRAT 3,935 D~PT bSOO,O00 SFLU' SP -95,813 OR G~ ~u.soo CALl 9,641 GR ~N~AT 3.06~ OEPT 64G0.0( 0' S~'LU SP -101.250 OR U~ 48,594 NPHi CALI 8.328 GR N~AT 2,094 u~P~ a~oo.ooo S~'LU CALl 12,023 GR NRAT 3,230 DEPT b2(0,010 · SFLU s~ -7~.813 O~ 53.oe3 NP~I CALl lb.625 OR NRAT 3.441 DEPT blOO.O00 SFLO SP -70,063 O~ 79,312 NPHi CAbl i4.352 OR NRAT 3,162 D~PT bOCO,O( 0 SFLU SP -Lb, 500 G~ 57.8~5 CAbl 15.664 GR ~A'I J,609 SP 9.000 ~ 54 , 719 NPH CAI, I -999.250 G~ .46,125 6.059 42,063 29.58g 49,688 NCNb ' . . , RHUB, ' .-' NCNb..'-'v 4,188 ILM 46.469 DT ~39.404 HHOB 61,906 NCNb 6.020 1LM- 68.500 :ET 34.033 ~HUB, 72.000 NCNb -11.297 IbM 48.594 DT 20.508 ~HOB 48.250 NCNb 7.129 IbM 69.563 iET 34.766 ~HOB, 87.312 NCNb 4.996 53.063 DT '~6.377 BHOB 61.688. NCNb 4.953 1bM 79.312 :ET 32.173' RHOB, 72.063 NCNb 3.217 57.875 DT :39.844 RHOB 62.281 NCNb 0.722 1bM 54.719 '£T -999.250 RHOB, -999.250 NCNb :.. 4196,000 FCNL .. . 5.820 ILD' - -{S6,188. SP 'mm'':'--' ...- 2.291--- DRHO..:..,i, 3078.000-:~CNL "-:','-. 3.990 91.000 2.371 2056.000 1LD SP DRHO-.' ECNL 6.074 {S5.188 2..369 2350.000 lbD SP DBHU :~CNL 9.570 103.750 2,303 3570.000. ILD SP DRHO FCNL 7.656 101,375 2.375 2%~6.000 I'bD SP DRHO :FCNL 6.984 96.750 2.342 2800.000 ILD SP DRHO FCIgL 5.406 1~5,563 2.383 2368.000 IbP SP DRH[) ;1~ CNL 3.295 90.563 2.084 1707.000 2303,000 56,594 -99~.250 .ge q DRH'0 FCNL ILD 8P ,r __ P~(E 8 2042,000 7.504 -121.000 0.012 1094.000 4.180 -108,250' ..... 0,063 542.500 6.723 "-95,813 0.023 751.500 13.516 -101.250 0.027 1552.000 8.578 -107.188 0,035 643.500 7.273 -73.813 0.072 787.500 5.609 -70.063 0,048 716.000 3,178 -66.500 0,013. 413.500 1.253 9.000 -)9~.250 VERIFICATION 'LISTING '~. bi/P 009.B05 . ~NRAT -999,250 · . ~ ~. FlbE TRAILER ~' .. FlbE NAME .'$gRVlC.O01 SERVI3E NASal : : V~RMION ~ ~ i ~ MAX1HUM b~NGTH ~ 102~ FILE TYPE : ~ , NEXT FILE NAME : EOf ~ TAPE TRAILER SERVI:E NAMgl :SERVi2~ ~ DATE :82/03/ 5 i ORiGiN.:1070 ~ ~APE NAME ~162616 ! CONTINUATION # NEXT { COMMENTS ;TiP.E] CO~MEN~$ ~. RE~L TBAIbER ~ SERVICE NAME :SERViC ! OATS :82/03/ 5 i ORIGIN R~EL NAME :R~EL ID ;CONTINUatION · NEXT RfEL NA~E : ;COMM~NT8 :REEL COMMENTS : I EOf' EOF PAGE VERIFICATION LISTING SERVICE >.! a f,.',.~ :SER¥IC DAT~; :82/03/ 5 CO:'~TI,qUaTIOM ~ :01 PREVIOUS REEL : .E~'~5 :R~EI, COMMENTS PAGE ** TAPE HEADER SERVICE NAM~] ,'SERVIC DAT.~: :82/03/ 5 ORIGEN 11070 TAPE NAME :A626J. 6 C 0,'4 T [ ,'.,~ !J A T I 0i4-# PREVIOUS TAP[: CO:4MENT8 :TAPE COMMENTS ** FILE H[::ADER FI,LE NAME :SERV~C.001 SERVICE IV A_~d g VERSION ~ : DATE : MAXI~4Ur',I LENGTH : 1024 PREVIOUS FILE ~ ** I~-IFF)HMATION RECORDS MNEN Ci~{ : lJ?iI{jf, i OiL COMP [3~' CALIFORNIA WI~, : Ti~U-G-4RD(23X-2B) FN : MCA~THU~ RIVER RANG: 13W TONN: 9N 8ECI: 29 C O U t,~: K E N A l SI'Al': AI, A~KA CTRY: U6A ~ MN E~', C{]N .['ENTS U~I? TYPE 'CATE SIZE CODE' 000 000 O28 O65 000 000 018 065 000 000 014 065 000 000 O03 O65 000 000 002 065 000 000 002 065 000 OOO O0~ 065 000 000 006 065 000 000 004 065 ~J N I '~.' T ~ P F; C A T i:; S £ Z E C 0 D E PRES: I)ILOOiF ** RECOF'O TYPE 047 ** o00 00O 007 065 Q. 5VP 009.H~)5 VERIFiCATiON LIS'I'ING $* R~CORD TYPE 047 ** RECORO '~YPE 047 I PACIFIC COA6T CO~PUTING CEMa'ER *=== .......... - ...... t dOB , 10707,62616 DI[, ~U'~! #1, bOGGED 2'.bAR'82 BOT'~O~{ bOG TOP LOG Ii\]TERqAb CAS I~G--I, OGG biR TYP~: H~]I.,E FbUID DE~!$.[TY VI" '" ,~ f.. o ~ .~ '[' y = 10450 F?. = 5900 = 9.625 IN. (a 5970 FT. = ~i.5 IN, = XC PObY~ER-RESII';EX = 73 = 5~ $ =9.0 P~GE 5¥P 009.H05 VERIFICATION LISTING : 8.2 C3 : 1.090 @ 65 F : 1.110 8 ?? F = !.110 ~ 65 F : ,4690 9 160 F ENTRY BLOCKS TYPE SIZC REPR CODE ENTRY 4 1 66 8 g 73 60 9 4 65 O 1 66 0 DATUm4 SFEC, IF~.CATION BLOCKS ~ MNEN SERVICE SERVICE UNIT APl AP1 f~PI API WILE SIZE PROCESS SAMpLe; REPR ID ORDER ~ LO(; TYPE CLASS MOD NO. bEVEL CODE 0 0 0 0 4 0 0 0 0 4 0 0 0 0 4 12 46 0 0 -4. ! 0 0 0 4 31 32 0 0 4 52 32 0 0 4 1 0 0 0 4 31 32 0 0 4 6~ 2 0 0 35 1 0 0 4 44 0 0 0 4 28 3 0 0 31 32 0 0 4 34 92 0 0 34 93 0 0 42 I 0 0 68 68 68 08 68 68 68 68 68 68 68 68 68 68 68 68 -999,250 -999,250 250 II,D ' · x, -999.250 -999.250 -0 hvP 009,Ho5 CALl NRA? 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