Alaska Logo
Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
Loading...
HomeMy WebLinkAbout198-0641. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,750 feet N/A feet true vertical 9,741 feet 9,878 feet Effective Depth measured 9,878 feet See schematic feet true vertical 8,884 feet See schematic feet Perforation depth Measured depth 9,614 - 9,935 feet True Vertical depth 8,628 - 8,939 feet Tubing (size, grade, measured and true vertical depth) 2-7/8" L-80 9,561 (MD) 8,664 (TVD) Packers and SSSV (type, measured and true vertical depth) See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Hemlock Oil / Middle Kenai G Oil 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: Other: Attempted JP Conversion 0 323-306 Sr Pet Eng: 7,020psi Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Rupert Ryan.Rupert@hilcorp.com 907 777-8503Operations Manager N/A 356 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 356 N/A 42 Size 356 822 0 2440 0 10420 13-3/8" 9-5/8" 8,160psi 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 198-064 50-733-20267-01-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018730 / ADL0017594 McArthur River / Hemlock Oil / Middle Kenai G Oil Trading Bay Unit G-21RD Plugs Junk measured Length measured TVD Liner Liner 7,850 3,571 3,204 Casing Conductor 6,991 6,738 7" 7,850 7,543 10,747 9,738 822 5,202 822Surface Intermediate Production 26" 20" 3,090psi 5,410psi 1,530psi 3,090psi 5,750psi 7,240psi 5,202 4,824 Burst Collapse 520psi 1,540psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 8:18 am, Nov 21, 2023 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.11.20 15:46:54 - 09'00' Dan Marlowe (1267) Well: G-21RD PTD: 198-064 API: 50-733-20267-01 Updated by: JLL 11/07/23 SCHEMATIC No Depth MD Depth TVD ID Item 42.15’ 42.15’ Hanger (CIW-DCB-FBB-CCL 11” X 3-1/2” EUE lift & susp w/3” type H BPV profile 1 370’ 370’ 2.313” Haliburton NE-TRSSSV 2 3,972’ 3,814’ 6.18” 7” WFD Liner top packer 3 7,543’ 6,738’ 7” ZXP Liner top packer 4 9,526’ 8,544’ 3.000” Packer – 7” 26-32 DLH Retrievable Hydraulic Set 5 9,550’ 8,567’ 2.310” X-Nipple – w/ 2.31” profile 6 9,561’ 8,577’ 2.441” WLEG w/ Half Mule Shoe 7 9,878’ 8,884’ <5.50” Unknown casing obstruction. Couldn’t make hole with 5-1/2” bit / cleanout assembly. Possibly collapsed casing? GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,362’ 2,361’ 2.347” PSPO-1M 16 DMY 08/09/2023 2 4,252’ 4,045’ 2.347” PSPO-1M 16 DMY 08/09/2023 3 5,737’ 5,263’ 2.347” PSPO-1M 16 DMY 08/09/2023 4 6,773’ 6,112’ 2.347” PSPO-1M 16 DMY 08/06/2023 5 7,642’ 6,818’ 2.347” PSPO-1M 16 DMY 08/09/2023 6 8,286’ 7,372’ 2.347” PSPO-1M 16 DMY 10/22/2023 7 8,804’ 7,856’ 2.347” PSPO-1M 16 EMPTY 10/27/2023 8 9,475’ 8,495’ 2.347” PSPO-1M 20 DMY 08/07/2023 OPEN HOLE / CEMENT DETAIL 20"23" hole: cemented with 579sxs of 13.1ppg class G lead followed by 200sxs 15.8ppg tail cement. Saw cement back to surface. 13-3/8" 17-1/2" hole: Primary job pumped 1150sxs (225bbls) class G lead followed by 400sxs (78bbls) class G tail cement. 12/1/74 CBL showed ToC at 1300’ MD. 2squeeze jobs pumped through DV collar at 2595’ MD. Squeeze #1 pumped 550sxs (108bbls) of 15.7ppg class G cement (no squeeze pressure established). Squeeze #2 pumped 600sxs (117bbls) of 16.0ppg class G cement (good squeeze pressure established).12/4/74 CBL showed ToC at 800’ MD (some patches of cement above that). 9-5/8" 12-1/4" hole: TD'd at 11,160' MD in G-21 parentbore (1974). Pumped 2000sxs (392bbls) of Class G. 12/28/74 CBL shows patchy cement up to 8500’ didn’t log any higher) 7"8-1/2” hole: Pumped 510sxs (100bbls) of 14.5ppg class G cement. Saw cement on top of 7” liner.5/30/98 cement log shows ToC at ToL. 6 RKB to MLLW 110.60’, MLLW to mudline 125’, RKB 42.15’ 7 13-3/8” DV at 2,595’ 2 5 4 1 3 9-5/8” Casing leak ±4,867 – ±4,899’ PBTD = 10,662’ MD TD = 10,750’ Max angle = 36 @ 6,600’ G-1 thru G-5 9-5/8” KOP @ 7850’ MD X CASING DETAIL SIZE WT GRADE Conn ID TOP BTM. 26” Surf 356’ 20” 94 H-40 Butt 19.124” 41.98’ 822’ 13-3/8”61 K-55 Butt 12.515” 42.60’ 2,431’ 68 K-55 Butt 12.415” 2,431’ 5,202’ 9-5/8” 40 N-80 Butt 8.835” 40.60’ 62’ 47 N-80 Butt 8.681” 62’ 98’ 40 N-80 Butt 8.835” 98’ 1,336’ 47 N-80 Butt 8.681” 1,336’ 7,850’ (TOW) 7”26 L-80 DWC/C 6.276” 3,972’ 7,543’ 29 N-80 Butt TKC 6.184” 7,543’ 10,747’ TUBING DETAIL 2-7/8” 6.5# L-80 8 rnd EUE 2.441” Surf 9,561’ Well: G-21RD PTD: 198-064 API: 50-733-20267-01 Updated by: JLL 11/07/23 SCHEMATIC Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date G-1 9,614' 9,645' 8,628' 8,658' 31' 2-1/2", 6spf 6/11/1998 G-1 9,615' 9,635' 8,629' 8,649' 20' 2 -1/2” 4 SPF 05/04/2008 - DIL G-1 9,620' 9,630' 8,634' 8,644' 10' 4 SPF 03/23/2015 G-1 9,625' 9,640' 8,638' 8,653' 15' 2”, 4spf 02/04/2004 G-1 9,675' 9,685' 8,687' 8,697' 10' 4 SPF 03/23/2015 G-2 9,668' 9,688' 8,680' 8,700' 20' 2 ½” 4 SPF 05/04/2008 - DIL G-3 9,737' 9,767' 8,747' 8,776' 30' 2-1/2", 6spf 6/14/1998 G-3 9,750' 9,768' 8,759' 8,777' 18' 2 ½” 4 SPF 05/04/2008 - DIL G-3 9,755' 9,765' 8,764' 8,774' 10' 2”, 4spf 02/04/2004 G-3 9,756' 9,766' 8,765' 8,775' 10' 4 SPF 03/23/2015 G-4 9,784' 9,794' 8,792' 8,802' 10' 2 ½” 4 SPF 05/04/2008 - DIL G-4 9,785' 9,793' 8,793' 8,801' 8' 2”, 4spf 02/04/2004 G-4 9,800' 9,815' 8,808' 8,822' 15' 2 ½” 4 SPF 05/04/2008 - DIL G-4 9,800' 9,832' 8,808' 8,839' 32' 2-1/2", 6spf 06/14/1998 G-4 9,808' 9,818' 8,816' 8,825' 10' 4 SPF 03/23/2015 G-4 9,825' 9,833' 8,832' 8,840' 8' 2 ½” 4 SPF 05/04/2008 - DIL G-4 9,825' 9,835' 8,832' 8,842' 10' 2”, 4spf 02/04/2004 G-5 9,894' 9,964' 8,899' 8,967' 70' 2-1/2", 6spf 06/03/1998 G-5 9,896' 9,906' 8,901' 8,911' 10' 2”, 4spf 02/04/2004 G-5 9,925' 9,935' 8,929' 8,939' 10' 4 SPF 03/22/2015 Rig Start Date End Date SL 8/1/23 10/30/23 ARRIVE at Grayling- Check in - Then Attend Pre Wireline Meeting- Complete Permit and JSA Bring down Basket of tools, Spot up Equipment- Rig Up Slickline P/T lub and WLV - fail. Lay down Lub and and C/O Oring- Pickup and Retest - fail. C/o Oring on Riser- P/T 2800 - PASS. RIH/w 2 7/8" Braided Line Brush/w 2 7/8" Slickline Scratcher to 5640' SLM. Cut light scale to 5700' SLM continue to 6270' SLM Encounter Light scale to 7386' SLM fall to 7492' SLM then cut moderate scale to 8520' SLM start cutting light scale build up to 8840' fall to 9382' SLM then cut moderate to heavy scale build up to 9513' SLM (9483' RKB), not making any more Hole. POOH. Discuss with Kyle- Lay down Lub for the night - Secure Riser and Area For the night. Turn in Permit and JSA- Lay down Crew 08/01/23 - Tuesday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name G-21RD 50-733-20267-01 198-064 08/02/23 - Wednesday Rig up Slickline. Add 5' Stem and P/T. RIH/w 2" x 4' DD bailer to 9264' SLM (9234' RKB) w/t fall to 9331' SLM (9301' RKB) w/t fall to 9513' SLM ( 9773' RKB) w/t fall thru out the Tail (9561' RKB). Tag at 9802' SLM ( 9772' RKB) w/t POOH OOH/w small sample of scale, mostly fluid in bailer. Suspect flapper got held open from scale chunks and had partial wash out. RIH/w KJ/w 3 1/2" Braided Brush/w 2.29" Gauge Ring to 9477' RKB w/t to 9504' RKB can not pass POOH. RIH/w KJ/w 3 1/2" Brush/w Slickline Scratcher (2.3") to 9534' SLM w/t 9591' SLM (heavy to moderate cutting) fall thru tail then make 10 passes from 9300' to 9595' SLM ( 9270' RKB to 9565' RKB) no longer seeing resistance, POOH. RIH/w KJ/w 3 1/2" Brush/w 2.29" Gauge ring to 9540' SLM w/t down to 9586' SLM can not pass POOH. RIH/w KJ /w 3 1/2" Brush/w 2.24" Gauge ring to 9586' SLM (9556' RKB) w/t until falling thru to 9610' SLM then Start 10 passes to 9450 to clean up tight spot POOH. RIH/w KJ /w 3 1/2" Brush/w 2.29" Gauge ring to 9589' SLM w/t getting stuck w/t free and try multiple times can not pass tail, POOH. RIH/w 2.2"(swell) x 12' Drift Dummies to 9430' fall slow to 9520' SLM then continue to tag at 9771' RKB light overpull at 9520' to 9430. RIH/w KJ /w 2 1/2" Xline R/T W/ 2 7/8" PX Plug to 352' SLM (370' RKB) bobble thru SSSV continue down to 9400' SLM start falling slow with partial set downs to 9492' SLM w/t lightly to 9542' SLM (9512' RKB) unable to pass. POOH with 600lbs overpull to 9380' SLM then have just fluid drag to 5870' SLM, start dragging heavy to 5240' SLM (fluid top at 5530') then lose overpull. Continue to surface OOH/w PX plug in good condition (possible scale on top of plug for drag). RIH/w 3 1/2" Braided Brush/w 2.3" scratcher to 4400' SLM, start having partial set downs to 4434' SLM. Set down w/t until 4600' SLM, fall free to 6500' SLM w/t to 6700' SLM, fall free to 7100' SLM w/t to 7800' SLM, fall free to 8000' SLM w/t to 8050' SLM, fall free to 9500' SLM w/t to 9532' SLM w/t to 9591' SLM (9561' RKB), fall out of tubing. Start making passes to 9000' 20 times until no overpull or set downs (high potiential some kind of trash had got pulled from a mandrel or from casing during prior runs in the day) POOH to surface do not see any overpull or drag at higher trouble spots. OOH, no trash on brush just very foamy oil and scale chunks. Lay down Lub for the night and secure area and wellhead. Rig Start Date End Date SL 8/1/23 10/30/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name G-21RD 50-733-20267-01 198-064 08/03/23 - Thursday C/O TS to 1 3/4" Slip 100' of line and repack stuffing box. Rig up slickline and P/T. RIH/w 2 7/8" Braided Brush /w 2.29" Gauge ring to 4500' SLM, light bobble thru. Continue to 9610' SLM (9580' RKB) POOH. RIH/w 2 1/2" Xline R/T /w 2 7/8" PX Plug (16" Closed 19" Open 2.3" Body) to fluid at 5480' SLM. Continue down to 9586' SLM ( 9556' RKB based on corrections). Come up and shift tool after locating at 9581' SLM (9551' RKB) come free, p/u 20' then go back down have partial set down at 9581' SLM. Try to set xlock keys 5 to 6 times until set down w/t lightly 15 spang licks then start tapping harder to shear. Tool fell thru nipple due to slack in line, fell past tubing tail at 9591' SLM (9561' RKB). Come up slowly thru tail, have 300lb overpull, lightly work tool up then reengage nipple. See drag thru nipple, pickup 10 ' then set down and work tools at nipple to set, fall thru again thru the tail, on pickup have slight hang up, no extra drag thru the nipple. Start POOH to check tools. Platform lost power - Standby unable to run unit (electric). Power restored- POOH- OOH/w NO plug on Xline. Contact PWL Supervisor, discuss with Kyle. RIH/w 2 1/2" GR (steel pin) to 9792' SLM (9762' RKB w/t lightly trying to bite plug in casing, see depths of set down at 9794' , 9788', 9791' approx 50 times at various speeds, see some overpull at deepest depths, work for about 30 Mins. POOH to check tools OOH-w no plug. RIH/w KJ , KJ, 2 1/2" GR to 9798', 9796', 9794', 9791', and 9789' SLM w/t can not latch, POOH. RIH/w 2.25" LIB to 9798' SLM tagging softly then try to stop quick 5times at 9794' SLM, no contact, pickup 20' then run in fast for one hit down tagging at 9794' SLM (9764' RKB) POOH. OOH/w small impression on the side, face mostly clean. RIH/w 2 7/8" Braided Brush/w 2 7/8" Slickline Scratcher 2.4"(oversize) to 352' SLM w/t thru SSSV then continue to Lower XNipple at 9551' RKB (9581' SLM ). Brush at 9540' to 9580' SLM for 45mins, POOH. Had trouble going in hole from 8800' to 9581' SLM, appeared to clean up a bit with the oversize scratcher. OOH, standby for chopper to land and leave. Secure area and well - Lay down Lub. 08/04/23 - Friday Rig up Slickline and P/T. RIH/w 2 1/2" Xline R/T /w 2 7/8" PX plug to 9560' RKB (9590' SLM) pickup slow to locate and shift tool at 9551' RKB, 9581' SLM. Come up to 9530' RKB then go down and set down at 9551' RKB w/t fall thru after 20 licks pickup to 9530' RKB, set back down at 9551' RKB w/t until shearing upper pin w/t and shear BTM, POOH. OOH with good set Xline coated in scale. RIH/w 2" SB /w 3' Prong to 9549' RKB (prong Top) w/t set w/t shear and POOH. RIH/w 2 1/2" GS /w Catcher Sub (OAL 51" x 2.3" OD) to top of prong set at 9545 ' RKB (9575 ' SLM) w/t shear and POOH. OOH Lay down lub and secure riser with cap. Assist with hooking up hose in wellroom. Standby for production to fill tubing (14.5 bbls) then MIT. Live valve or valves opened allowing fluid into the casing. Production continued on with Combo MIT, filling both T and IA. Check and secure equipment area for the night. Turn in Permit. Lay down Crew. Production plan forward is to fill and chart pressure during the night. Rig Start Date End Date SL 8/1/23 10/30/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name G-21RD 50-733-20267-01 198-064 08/05/23 - Saturday Fill wellbore with FIW and pressure up down tubing (communicating to IA, likely via leaking GLV). Pressure up for CMIT-TxIA per below. Starting pressures: Tubing 2600 IA 2404 OA 110 15 Minutes Tubing 2550 IA 2382 OA 110 30 Minutes Tubing 2550 IA 2377 OA 110 45 Minutes Tubing 2550 IA 2378 OA 110 60 Minutes Tubing 2550 IA 2379 OA 110 IA pressure loses of 22psi, followed by 5psi for overall loss <2%. CMIT-TxIA PASS to 2375psi. Standby for production to finish bleeding gas from IA until fluid packed. Start CMIT. Assist production with taking pressures every 5 mins over an hour- CMIT PASS. Start rig up while production bleeds well pressures down and drains riser. Rig up slickline and P/T. RIH/w 2 7/8" OK-5 KOT/w 1 1/4" JDC to Station 8 at 9475' RKB (appear to locate 9515' SLM) w/t cannot set down, make a couple attempts to then POOH to Station 7 8804' RKB w/t to locate. Get set down 8832' SLM w/t pop free, come back down and set down w/t down hard once pickup no overpull POOH to Check TOOL for Shear. OOH/w JD body damaged, appears to have egged JD Skirt. RIH/w 2 7/8" Braided Brush/w 2 7/8" OK-1 Kot/w 1 1/4" JDC to Station 8 9475' RKB (9515' SLM) w/t to locate then set down w/t to latch, start w/t 7 jar licks to come free POOH. OOH/w Station 8 Orfice Valve, all packing intact, light scale on latch. RIH/w 2 7/8" Braided Brush/w 2 7/8" OK-5 Kot/w 1 1/4" JDC to Station 7 8804' RKB (8832' SLM) w/t to locate cannot set down w/t. Pickup up and try at station 6 (8286' RKB) station 5 (7642' RKB) cannot locate either. Pickup to station 4 6773' RKB locate at 6763' SLM w/t latch w/t, multiple jar licks come free, POOH. OOH/w Station 4 GLV. RIH/w 2 7/8" Brush/w OK-1 Kot /w 1 1/4" JDC to Station 7 locate at 8823' SLM (8804' RKB) w/t Latch and PULL OOH/w ST 7. RIH/w same to Station 6 locate at 8290' SLM ( 8286' RKB) w/t latch w/t POOH OOH/w Station 6. RIH/w same to Station 5, trouble locating 7642' RKB. Work tools for a while then POOH. OOH, lay down lub and secure riser for the night. Turn in Permit and JSA. SUMMARY: Pull Live GLV's from stations 8, 7, 6, and 4. Open pockets now. Rig Start Date End Date SL 8/1/23 10/30/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name G-21RD 50-733-20267-01 198-064 08/06/23 - Sunday Rig up Slickline and P/T. RIH/w KJ/w 2 7/8" Brush/w 2 7/8" OK-5 KOT/w 1 1/4" JDC to 7638' SLM (7642' RKB) w/t until locating w/t come free POOH. OOH/w JDC sheared. RIH/w KJ/w Brush /w 2 7/8" OK-1 KOT /w JK R/T and DMV to Station 4 at 6773' RKB (6763' SLM) w/t to set w/t Shear POOH. RIH/w KJ Brush/w OK-5 Kot /w Jk R/T /w DMV to ST#6 at 8286' RKB can locate but cannot set down, after 20 mins continue to ST #7, same result, can locate cannot set down. Continue to ST#8 and attempt, locate have one set down w/t to set, appear to set w/t to shear and POOH. OOH, still have DMV, btm packing appears to have gone in pocket. RIH/w Brush/w OK-1 Kot/w Jk R/t with DMV to ST#6 8286' RKB locate w/t cannot set down, try for 30 mins POOH. RIH/w OK -1 KOT /w JK R/T with DMV to ST #6 8286' RKB (8292' SLM) locate w/t Set w/t shear and POOH. RIH/w OK-5 KOT/w JK R/T with DMV to ST#7 8804' RKB locate cannot set down POOH. Still have DMV. RIH/w KJ/w OK-1 Kot/w JK R/T /w DMV to ST#7 at 8804' RKB (8826' SLM) locate w/t Set w/t shear and POOH. RIH/w KJ/w OK-5 Kot/w JK R/T /w DMV to ST #8 at 9475' RKB (9515' SLM), locate multiple times, unable to set down POOH. OOH with DMV. Lay down equipment for the night and secure area and well. SUMMARY: Attempt to PULL Station 5 unable, SET DGLV in Station #4 at 6773' RKB, Set DGLV in Station #6 at 8286' RKB, set DGLV in Station #7 at 8804' RKB. Stations 4, 6 , and 7 are Dummied. Stations 1 2 3 5 Still contain Live valves, and station #8 is currently empty. 08/07/23 - Monday Slip 50' of wire check tool connections. Rig up Slickline and P/T. RIH/w 2 7/8" Brush /w Scratcher (oversize) to 1000' having trouble falling, POOH. OOH, beat down and trim. RIH/w 5' Stem /w brush/w Scratcher (oversize) to 4200' SLM w/t to 4800' SLM, having trouble falling, POOH. OOH, trim brush. RIH/w same to 4170' SLM, cut light scale to 4500' then med scale to 4800' SLM. Continue to Station 8 and brush 20 mins POOH. RIH/w KJ /w OK-1 Kot/ wJk R/T /w DMV to Station 8 (9475' RKB) locate at 9510' SLM w/t set w/t shear and POOH. RIH/w 2.25" LIB to 9532' SLM (9502' RKB) Set down w/t POOH OOH/w Impression of Scale Chunks. RIH/w KJ /w OK-1 Kot/w 1 1/4" JDC to Station 5 (7642' RKB) locate 7638' SLM w/t latch and Jar free POOH OOH/w ST#5. RIH/w KJ /w OK-5 Kot/w 1 1/4" JDC to Station 3 ( 5737' RKB) Locate at 5732' SLM w/t latch w/t 5 jar licks to free POOH. Standby for production crew change out. Also C/O Worner To Colbert. Break off and C/O tools. Recovered ST# 3 - OJS getting Spongy, break off redress, then make tools back up. RIH/w KJ /w OK-1 Kot /w 1 1/4" JDC to Station 2 (4252' RKB) 4239' SLM, locate set down w/t to latch make 2 jar licks come free, POOH. OOH, not sheared no vavle. Possible friction pull. RIH/w KJ /w OK-5 Kot/w 1 1/4" JDC to Station 2 (4252' RKB) locate cannot set down work 20 mins then POOH. OOH, lay down Lub and Secure well for the night. Clean and secure area. Turn in permit and JSA. SUMMARY: Brush Station 8, then Locate and Set DGLV in Station 8. Tag scale on top of catcher with LIB. Pull GLV's from Stations 5, 3, and 1 (station 2 possible pull and Drop). Rig Start Date End Date SL 8/1/23 10/30/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name G-21RD 50-733-20267-01 198-064 08/08/23 - Tuesday Attend Morning Meeting- Complete Permit and JSA. Rig up Slickline and P/T. RIH/w 2 7/8" Brush Oversize to 4252' RKB ST#2 (4239' SLM) Brush tubing 50' above to 50' Below for 20 Mins then POOH. RIH/w 2 7/8" Brush/w OK-5 KOT/w 1 1/4" JDC to ST#2 (4239' SLM) 4252' RKB. Locate multiple times cannot set down, after 30 mins POOH. RIH/w 2 7/8" Brush/w OK-1 Kot/w 1.25" LIB to ST #2 4259' RKB, locate 4239' SLM, cannot set down POOH. RIH/w 2 7/8" KJ /w OK-5 KOT/w JK R/T (Pinned) to ST # 2 4252' RKB w/t locate, set down w/t down 25 times POOH. OOH, have good half moon shears on Pins. This verifies valve is in pocket - probaly Scaled in. RIH/w KJ /w OK-5 Kot /w 1 1/4" JDC to ST #2 4252' RKB, locate cannot set down, attempts for 25 mins POOH. RIH/w KJ /w 2 7/8" Brush/w 1 1/4" JDC to ST# 2 at 4252' RKB, attempt to slop on to GLV- unable to after 25 Mins POOH. RIH/w KJ/w 2 7/8" OK-1 Kot /w JK R/T /w DMV to ST#1 at 2362' RKB (2346' SLM), locate set down w/t 20 Mins to set w/t POOH. OOH/w valve still ON, JK Pins not marred- DMV fully eeated up to Wobble Ring, looking at marks just no lock in. Lay down to tighten a Bowen Coller that was backing off. Chopper arrivial with new counter head. Replace, also repack, and slip 25' of wire. RIH/w KJ /w OK-5 Kot/w JK R/T /w DMV to ST#1 locate (2362' RKB). Set down W/t 35 Mins to beat in place to latch then w/t pooh. OOH, still have valve pins, not damaged. Remove oil jars to see if shock absorbing on next run. RIH/w KJ/w OK-1 KOT/w Jk R/t W DMV to ST#1 locate and W/t to Set w/t 20 Mins POOH. OOH still have valve - See marks on Wobble Ring. Discuss with slickline supervisor and Mike Abbott. Decide to run pocket brush in the morning. OOH Lay down Lub for the Night and Secure Wellhead. Break for dinner. Rebuild oil jars. Go thru kickover tools with helpers. All appear to be functioning correctly. Inspect 3 other kickover tools that came in on chopper with new slickline counter head. Button up equipment for the night. Lay down crew for the night. Rig Start Date End Date SL 8/1/23 10/30/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name G-21RD 50-733-20267-01 198-064 08/19/2023 - Saturday Rig up Slickline and P/T- Check Tool String - Add Oil Jars. RIH/w 2 7/8" OK-1 Kot /w Pocket Brush to ST# 1 2362' RKB (2342' SLM) locate w/t Set down w/t Brush Pocket POOH. RIH/w 2 7/8" OK-5 Kot /w JK R/T w/ DMV to ST# 1 2362' RKB (2342' SLM) locate w/t to set w/t POOH ST #1 no Set. RIH/w OK-1 Kot/w JK R/T /w DMV to ST#1 2362' RKB locate w/t to set POOH OOH Good Set. RIH/w OK-5 Kot/w JK R/T w/ DMV to ST#3 to 5737' RKB ( 5712' SLM ) locate w/t Set w/t Shear and POOH- Good Set. RIH/w OK-1 Kot/w JK R/T w/ DMV to ST #5 to 7642' RKB (7617' SLM) Locate w/t Set w/t shear and POOH- Good Set. RIH/w LD-2 Kot/w 1 1/4" Daniels P/T to ST #2 at 4252' RKB (4232' SLM) locate get 4 SD but everytime we beat down, fall thru POOH. RIH/w 2 7/8" Daniels Kot/w 1 1/4" JDC to ST # 2 at 4252' RKB (4232' SLM) locate w/t after Set down Beat down 50 times then start working up with small binds and beat down to cut scale on latch then Finish off with 2 Jar licks POOH. Standby for Helo to land, then break off OOH/w Station 2 GLV from Prior Run. RIH/w Daniels Kot/w Pocket Brush to ST#2 at 4252' RKB Locate w/t and Brush then POOH. RIH/w Daniels KOT w/ JK R/T w/ DMV to ST #2 at 4252' RKB Locate w/t and set w/t shear and POOH OOH Good Set. RIH/w 1 1/4" JDC /w 2.15" Bell Guide to 9507' SLM (9527 ' RKB) w/t sticky with overpull make 10 set downs and pull free then POOH. OOH/w No Valves- Pin Intact ( Prior depth was approx 9546' RKB with other counter head but due to major Slipping issues while working tools replaced with depths Obtained with higher Correction from ST#5 on this counter. Suspect our depth is within a couple feet of catcher up to 15' from catcher). OOH Lay down Lub and Secure area and well. Lay down Crew at 17:30. All GLM's are dummied as of 8/9/23. 08/09/2023 - Wednesday 09/01/2023- Friday Arrive PWL shop, gather tools and crew. Arrive OSK. Arrive platform. Meet w/ Kyle, discuss job scope. PJSM. Spot equipment, begin RU. Lunch. Con't RU. PT 250 psi Low/ 2500 psi High. Passed. RIH w/ 2 3/8" GS to 9543' KB, w/t. POOH w/ extra weight. OOH w/o catcher sub. GS pin unsheared. RIH w/ same to 9543' kb. W/t w/ several friction bites and used OJ (550# overpull twice). Come free, POOH. Prep pump bailers for next runs. OOH w/o catcher sub. GS pin unsheared. Lay down lubricator for the night, secure well and area. Pressured up tubing with FIW. Had to use small pump since waterflood was offline. Took 24+hrs to pressure up from 475psi. Target starting pressure was 3500psi. At 3200psi, pressure fell down to 0psi. No response on IA noted. Seems like TTP may have lost integrity. Rig Start Date End Date SL 8/1/23 10/30/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name G-21RD 50-733-20267-01 198-064 09/02/2023 - Saturday Attend morning meeting, PJSM, permit. RU, RIH w/ 1.75 x 8' Sand Pump bailer to 9570' kb, did not sit down, POOH. Talk to Kyle. RIH w/ 2 1/2" GS to 9543' kb, sit down. W/t w/ 7 OJ licks @ 1000-1050# pull, pulling free after each jar lick. Hit down hard several times. POOH. OOH w/ pin sheared. Re-pin GS. RIH w/ same to 9543' kb, w/t w/ 4 OJ licks @ 1100#. Come free after each jar lick. Hit downward, POOH.;OOH w/ pin 1/2 sheared. Lay down for boat, cut 20' of wire. RIH w/ 2.25 LIB to 9543' kb, w/t POOH w/ inconclusive results. Lay down for boat, talk to Kyle. RU. RIH w/ 2 7/8" TTL to 9583' kb.;W/t at 9583' kb, POOH w/ pin sheared in TTL finger. OOH w/ pin sheared in TTL finger. Lay down for the night. End ticket. 09/03/2023 - Sunday Morning meeting, permit, PJSM. Prep tools, RU, RIH w/ 2.30 gauge ring to 9583' kb, w/ no issue. POOH. While pooh hung up at 9543' kb, used OJ to come free. Work from 9535'-9583' for many runs until clear. POOH. RIH w/ 2.25 LIB to 9543', sit down, w/t. POOH. OOH w/ deep impressions on outer edges, face is clean. RIH w/ 2.30 gauge ring to 9583' kb w/ no issues. While POOH, hung up at 9577'- 9568', w/9530'-9583' kb, POOH w/ no issues. OOH. Check tool string. RIH w/ 2 7/8" x 16" Braided Line Brush to 9544' kb, sit out. W/t from 9544'-9583. POOH. OOH w/ catcher sub on brush. Fresh markings on outer edge of fishing neck. Talk to Kyle. RIH w/ 2" JDC to 9579' kb, w/t for 10 OJ licks. Came free. POOH. OOH w/ prong. Lay down to cut 30' of wire. RIH w/ 2" GS to 9584', latch and w/t. POOH. OOH w/o plug body. Lay down lubricator, secure area and well. Lay down crew for the night. 09/04/2023 - Monday Morning meeting, permit, PJSM. Prep tools, re-head, RIH w/ 2" GS to 9549' kb (corrected depth), latch and w/t. POOH. OOH w/o plug body, c/o GS. RIH w/ new GS to 9549' kb, latch plug. W/t, POOH. OOH w/o plug body. RIH w/ KJ above GS to 9549' kb, latch w/ 300# over pulls. W/t, POOH. OOH w/o plug body. GS pin partially sheared. RIH w/ 1.75 x 8' pump bailer to 9549' kb, w/t. POOH. OOH w/ 3 cups of thick scale slurry. C/o tools, stand by for crew c/o. RIH w/ KJ and 2" GS to 9543'' kb (corrected depth), sit down. W/t, fall to 9549' kb. W/t, POOH. OOH w/o plug. Talk to Mike. Lay down lubricator, secure well and area. Cut 20' of wire. Lay crew down for the night. 09/05/2023 - Tuesday Morning meeting, permit, PJSM. RU, RIH w/ 2 1/2" GS w/ KJ and centralizer to 9549' kb, w/t. OOH w/o plug body. RIH w/ 1.75 x 8' pump bailer to 9549' kb, w/t. POOH. RIH w/ KJ, 2.2 centralizer, and 2 1/2" GS to 9549', w/t. POOH. OOH w/ plug body. Secure well. Break for dinner. RIH w/ 2 7/8" braided line brush to 9560' kb. W/t through X-nipple and rough spots in tbg several times. POOH. RIH w/ 2 7/8 X-line and plug body to locate at 9551' kb. Unable to set in x- nipple after several attempts. POOH. OOH w/ plug body. X-line shifted. Lay down lubricator for the night, secure well, and area. Lay down crew for the night. Rig Start Date End Date SL 8/1/23 10/30/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name G-21RD 50-733-20267-01 198-064 10/17/2023 - Tuesday Perform JSA- Gain permit approval. PT to 250#low/2000#high. RIH W/ 2" Centrilizer W/ 2.3 WLB-Slow fall to 1500'KB- Pull up to 500'- Continue in hole to 9560'KB stopping to rebrush every 1000'. Light obstruction @ 3230'KB, 4200'KB, and 7640'KB on first passes- obstructions cleared. Standby for tubing flush RIH W/ 2.25 DDB to 9802'KB- No obstruction noted- POOH W/- Fluid only. Begin Lay down. Secure Well & Equipment for the evening. 10/18/2023 - Wednesday 10/04/2023 - Wednesday Ops pressured up the IA from 250 to 900 psi overnight. During this time the tubing pressure rose to 445psi. Stopped pumping and after 3 hours the IA had fallen to 450psi and the tubing had dropped to 150psi. Later that day the tubing had fallen to 25psi and the IA to 290psi. Appears maybe a DGLV is not holding. 09/06/2023 - Wednesday Morning meeting, permit, PJSM. RU, RIH w/ 2 7/8" X-line and plug body to 9560' kb. Pull up to 9551' kb, locate to shift X-Line tool. Pull up to 9535' kb and slowly fall to 9555' kb, unable to set in X-nipple after many attempts, POOH. OOH w/ plug, X-Line shifted. Begin complete RD. Clear deck of equipment. Stand by for chopper. Depart platform. Morning meeting- Perform JSA & Gain permit approval. Replace riser O-ring & begin R/U. RIH W/2" JDC W/2 7/8 D&D Hole finder to 9535'WL/9555'KB- W/T- Shear AD2- W/T- Set Hole finder. Standby for PT- Can't build pressure- Standby for swap to 2" hose- Resume PT- Cannot build pressure- W/T- Come free. Pull up to 9510'WL/9530'KB- Set Hole finder - Standby for PT- Cannot build pressure- W/T- Come free. Pull up to 9480'WL/ 9500'KB- Set Hole finder- Standby for PT- Cannot build pressure- W/T- JD sheared- POOH. RIH W/ 2" RB to 9480'WL/9500'KB- Tag- W/T- Latch- W/T- Come free- Pull up to 8500'WL/8520'KB- Standby for PT. Cannot build pressure- W/T- Come free- POOH W/ 2" RB W/ Hole finder assembly. Secure Well & Equipment for the evening. Rig Start Date End Date SL 8/1/23 10/30/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name G-21RD 50-733-20267-01 198-064 10/19/2023 -Thursday Morning meeting- Perform JSA & Gain permit approval. Prep Hole finder. RIH W/ 2" JDC W/ 2 7/8 D&D Hole finder to 7560'KB- W/T- Shear AD2 assembly- W/T- Set. Standby for pressure- Seal established- 2400#- bleed to 1000# and standby to moniter- Test good- W/T- Stuck- perform jarlicks starting @ 800# up to 1700# moving 20' before coming free- POOH- External seal element shredded and gone. Re-dress Hole finder assembly. RIH W/ 2" JDC W 2 7/8 D&D Hole finder to 7720'KB- Sit down- W/T- Fall to 7750'KB- W/T 7820'KB- W/T- 7850'KB- W/T- Cannot pass- Pull up to 7800'KB- W/T- shear AD2 assembly- W/T- Set- Standby for pressure. Successful seal- pressure up to 1050#- monitoer for 15 min- Test good- W/T- Come free- POOH. RIH W/ 2" Centralizer W/ 2.31 BLB to 8800'KB- W/T- fall through to 9470'KB- W/T- Fall through to 9545'KB- W/T- Fall through to 9570'KB- POOH to 8800'KB- Hang up- Perform multiple jarlicks & come free- POOH W/ 2 fragments of Sealing element. 10/20/2023 - Friday Morning meeting- Perform JSA & Gain permit approval RIH W/ 1.8 Guage ring to 9782'KB- Tag- POOH Standby for PT guages & CCL Hook up encoder- RIH W/ 1.8 GR to 500' for correlation run- POOH RIH W/ Survey package & CCL memory device- Perform Survey to 9750 @ specifications. OOH W/ Survey- Confirm data acquisition- PT & Encoder data good. Prep CCL & survey equipment for Transit- prep data package. Secure Well & Equipment for the evening. 10/21/2023 - Saturday Morning meeting- Perform JSA & Gain permit approval. Prep hole finder. RIH W/ 2" JDC W/ 2 7/8 Hole finder to 9366'KB- W/T- Shear- W/T- Set- Standby for pressure- Cannot build pressure- Pressure increase noted on IA- W/T- Come free- Pull up to 8750'KB- W/T- Set- Standby for pressure- Cannot build pressure- Pressure increase noted on IA- W/T- Come free- Pull up to 8200'KB- W/T- Set- Standby for pressure- Pressure up to 1030#- Hold for 15 min- Test good- W/T- Come free- POOH. RIH W/ 2 7/8 Daniels KOT W/ 1 1/4 JDC to #6 @ 8286'KB- W/T- Cannot locate- POOH RIH W/ Same W/ Knuckle joint to 8286'KB- W/T- Minore locate sign @ 8268'WL- Cannot trigger KOT- POOH Secure well & Equipment for the evening. Rig Start Date End Date SL 8/1/23 10/30/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name G-21RD 50-733-20267-01 198-064 10/22/2023 - Sunday Morning meeting- Perform JSA & Gain permit approval. Prep KOT assembly. RIH W/ 2.25 Centralizer W/ 2 7/8 Daniels KOTW/ 1/14 JDC to 8276'WL- W/T- Locate- Sit down- W/T- Latch- W/T- Come free- POOH W/ Station #6 Dummy valve. RIH W/ 2 7/8 X-line RT W/ 2 7/8 PX plug to 9590'KB- Pull up to 9510'KB- RIH to 9561'KB- Tag- W/T- Fall through to 9571'KB -Sit-W/T- Fall through to 9580'- Pull upt to 9571'- Hang up- W/T- Come free to 9561'- Hang up- W/T - Come free- Repeat process two two more times- POOH. RIH W/ 2.25 Centralizer W/ 2 7/8 Daniels KOT W/ RK RT W/ Dummy valve to 8276'KB- W/T- Locate- W/T- Sit- W/T Set valve-W/T- Come free- POOH W/ Valve set. RIH W/ 2" JDC W/ 2 7/8 Hole finder to 9490'KB- W/T- Shear anchor- W/T- Set hole finder. Secure Well & Equipment for the evening. 10/23/2023 - Monday Morning meeting- Perform JSA & Gain permit approval. Hole finder on depth @ 9490'KB- Standby for pressure- No pressure build up- W/T- Come free- Pull up to 8305'KB- W/T- Set-Standby for pressure- pressure up to 1000#- Hold for 15 min- Test good- POOH. RIH W/ Same to 9490'KB- W/T- Shear anchor- W/T- Set- Standby for pressure- Note Rise in IA pressure- W/T- Come free- Pull up to 8850'KB- W/T- Set- Standby for pressure- Note additional rise in IA pressure- W/T- Come free- POOH. RIH W/ 2 7/8 Daniels KOT W/ 1 1/4 JDC to 8804'KB- W/T- Cannot locate- Make multiple passes- POOH. RIH W/ 2.25 centralizer W/ Daniels KOT W/ 1 1/4 JDC to 8804'KB- W/T- note minor indications of locate, insufficient to trigger arm- Cannot seat- POOH. Secure Well & Equipment for the evening. 10/24/2023 - Tuesday Morning meeting- Perform JSA & Gain permit approval. Prep KOT. RIH W/ 2 7/8 Daniels W/ 2 7/8 BLB to 1600'- Note indication of premature trigger- POOH- Adjust tools. RIH W/ Same to 8804'KB- W/T- Cannot locate- Cannot sit- POOH. RIH W/ 2 7/8 OK-5 W/ 1 1/4 JDC W/ 2 7/8 BLB to 8804'KB- W/T- Minor indication of locate- Cannot sit- POOH. RIH W/ same W/ KJ to 8804'KB- W/T- Locate- Sit down- W/T- Latch- W/T- Come free- POOH W/ Station 7 Dummy valve. Find Hydralic leak on unit- Address- Determine to be failing gasket- monitor. RIH W/ same W/ JK RT W/ Dummy valve to 8804'KB- W/T- Locate- Cannot sit- POOH. Secure Well & Equipment for the evening Rig Start Date End Date SL 8/1/23 10/30/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name G-21RD 50-733-20267-01 198-064 10/25/2023 - Wednesday Morning meeting- Perform JSA & Gain permit approval Begin Unit swap Cut Wire & Re-pack/Re-head.- Prep KOT RIH W/ 2 7/8 BLB W/ OK-5 W/ JK RT W/Dummy valve to 8804'KB- W/T- Locate- Sit- W/T- Set Valve- W/T- Come free- POOH RIH W/ 2" JDC W/ D&D Hole finder to 9500'KB- W/T- Set- Standby for pressure- Cannot build pressure- W/T- Come free- Pull up to 8810'KB- W/T- Set- Standby for pressure- Cannot build pressure-Note pressure increase on IA W/T- Come free- Pull up to 8790'KB W/T- Set- Standby for pressure- pressure to 2000#- Bleed to 1000# & moniter- W/T- Stuck- Perform Jarlicks until Free- POOH & hang up- W/T- Come free- continue up catching every 40' & working free RIH W/ 2 7/8 BLB W/OK-5 W/ 1.19 LIB to 8804'KB- W/T - Locate- Sit- W/T- take imprint- POOH W/ Valve indication. Secure well & Equipment for the evening. 10/26/2023 - Thursday Morning meeting- Perform JSA & Gain permit approval RIH W/ 2" JDC W/ D&D Hole finder to 9540'KB- W/T- Shear anchor- Set- Standby for PT- Failure on tubing. Pressure up on IA to 1000psi. IAP drops and tubing pressure rises until both tubing and IA equalized at 750psi. Pressure IA back up (tubing jumpered at surface). Initial: 1000/1190/100 15mins: 786/800/100 30mins: 630/650/100 RIH 2 7/8 BLB W/ KJ W/ OK-5 W/ 1 1/4 JDC to 8804'KB- W/T- Locate- W/T- Sit down- Latch- W/T- Come free- POOH W/ DGLV. RIH W/ Same W/ JK RT to 8804'KB- W/T- Locate- W/T- Sit down- Set- W/T- Come free- POOH. Secure Well & Equipment for the evening. Rig Start Date End Date SL 8/1/23 10/30/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name G-21RD 50-733-20267-01 198-064 10/28/2023 - Saturday Morning meeting- Perform JSA & Gain permit approval RIH W/ 2 7/8 BLB to 8800'KB- POOH Standby for D&D Packoff RIH W/ GS W/ 2 7/8 D&D Packoff to 8830'KB- W/T- Set- W/T- Shear- POOH Standby for pressure test on IA- to 2200# - Test failure RIH W/ Equalizing prong to to 8832'KB- W/T- KO Kobe- POOH RIH W/ GS to 8832'KB- W/T- Latch- W/T- Come free- POOH W/ 2 7/8 D&D Packoff RIH W/ GS to 8835'KB- W/T- Latch AD2 Stop- W/T- Come free- Pull up to 8780'KB- W/T- Set- W/T- Shear- POOH- AD2 Set Secure well & Equipment for the evening. 10/27/2023 - Friday Morning meeting- Perform JSA & Gain permit approval RIH W/ 2" JDC W/ D&D Hole finder to 8830'KB- W/T- Shear anchor- Set- Standby for PT- Failure on tubing W/T- Come free- POOH RIH W/ OK-5 KOT W/ 1 1/4 JDC to 8804'KB- W/T- Locate- Set- W/T- Latch- W/T- Come free- POOH W/ Station 7 DGLV RIH W/ 2 7/8 AD2 Stop to 5720'KB- Preset - W/T- Come free- POOH- Repin RIH W/ Same to 8825'KB- W/T- Set- W/T- Shear- POOH W/- AD2 Set Standby for Packoff plug. RIH W/ GS W/ 2 7/8 Packoff plug to 370' W/T Fall through to 2362'KB- W/T- Cannot pass- POOH- Plug preset- Repin RIH W/ Same W/ KJ to 2362'KB- Sit down- W/T- Cannot pass- POOH- Repin RIH W/ Same W/ BLB to 2362'KB- W/T- Cannot pass- POOH Secure well & Equipment for the evening. Rig Start Date End Date SL 8/1/23 10/30/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name G-21RD 50-733-20267-01 198-064 Aborted JP conversion. Failing CMIT-TxIA on 10/28/23 against D&D hole finder set at 8830 (Below STA #7). Sta #7 had open pocket, so equalized above 8830' in tubing and casing, but still failed. Means leak point must be production packer, casing, or tubing between 8830' and 9526' MD. 10/30/2023 - Monday 10/29/2023 - Sunday Morning meeting- Perform JSA & Gain permit approval Redress D&D packoff plug RIH W/ GS W/ 2 7/8 D&D packoff to 8780'KB- W/T- Shear- W/T- Set- POOH Plug set Standby for PT- Conference W/ Production RIH W/ Equalizing prong to 8780'KB- W/T- POOH RIH W/ GS to 8780'KB - Sit down- Latch- W/T- Come free- POOH W/ D&D packoff RIH W/ GS to 8780'KB- Sit down- Latch- W/T- Come free- POOH W/ AD2 Stop Begin R/D- Hand well back to production- clean worksite. Standby for Flight Depart for shop. Close out ticket. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: McArthur River 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,750 9,878 Casing Collapse Conductor Surface 520psi Intermediate 1,540psi Production 3,090psi Liner 5,410psi Liner 7,020psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Convert to Jet Pump 9,741 8,884 1802 20"822 MD 822 822 Length Size 356 Proposed Pools: 356 356 TVD 7,240psi6,7387,543 8,160psi10,747 9,738 4,824 6,991 Perforation Depth MD (ft): 3,571 7"3,204 7" 9-5/8"7,850 13-3/8"5,202 5,202 7,850 Burst PRESENT WELL CONDITION SUMMARY 26" N/A9,878 5,750psi 1,530psi 3,090psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 198-064 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20267-01-00 Hilcorp Alaska, LLC Trading Bay Unit G-21RD Hemlock Oil / Middle Kenai G Oil Same N/A Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 6.5# / L-80 9,561 6/8/2023 See schematic See schematic 9,614 - 9,935 8,628 - 8,939 2-7/8" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Operations Manager Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:46 pm, May 24, 2023 323-306 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.05.24 12:03:07 - 08'00' Dan Marlowe (1267) Pressure test 7" casing to 2200 psi every 2 years. Safety valve system must conform to 20 AAC 25.265, except for modifications specific to jet-pump installation described in the attached email from Ryan Rupert dated 6/22/23. Corrosion protection measures described in attached email from Ryan Rupert dated 6/22/23 must be adhered to. Casing caliper log to be run on the 7" casing to evaluate the effectiveness of the corrosion protection measures any time the production tubing is pulled. BJM 7/24/23 SFD 5/27/2023 10-404 , ADL0017594 SFD DSR-5/24/23GCW 07/24/2023JLC 7/24/2023 07/24/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.24 19:04:12 -06'00' RBDMS JSB 072523 Jet Pump Conversion Well: G-21RD Well Name:G-21RD API Number:50-733-20267-01-00 Current Status:Shut-in Oil Producer Permit to Drill Number:198-064 First Call Engineer:Ryan Rupert (907) 301-1736 (c)Leg #3 (SE corner) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:2687 psi @ 8,850’ TVD 5/2/23 Static BHP measurement Max. Potential Surface Pressure: 1802 psi Using 0.1 psi/ft Brief Well Summary G-21RD is a shut in Middle Kenai “G” Oil Pool producer. It has been shut in since Gas Lift was permanently discontinued on Grayling in April-2023. Given the availability of high-pressure injection water on Grayling, this well is recommended for conversion to jet pump. No perforation, nor productivity changes are planned as part of this conversion. The goal of this project is to convert the lift mechanism to Jet Pump and return the well to production. Pertinent wellbore information: - Power fluid o Will utilize FIW: Filtered Inlet Water (8.4ppg) o Injection pumps operate in 3050 – 3200psi range o Jet pump will be forward circulating (power fluid injected down tubing, produced fluid up annulus) - Sail angle / max inclination of 36 degrees from ~3300’ to 8000’ MD - Min ID: 2.310” at 9550’ MD (2-7/8” X-nip) - SSSV: Not in use. No-Flow well - Well Integrity o 2018 RWO ƒ7” scab liner ran over leak in 9-5/8” at ~4,875’ MD ƒMIT-IA to 2650 PASSED ƒInstalled GL completion o Passed state witnessed NFT’s in 2004 and 2016 - 5/1/23: o SL D&T to 9,811’ MD with 1.75” sample bailer o Acquired SBHP - 9/5/19 o 2.25” gauge ring D&T to 9790’ MD Jet Pump Conversion Well: G-21RD SL Prep 1. MIRU SL and pressure control equipment 2. PT lubricator to 250psi low / 2000psi high 3. Set TTP 4. Load tubing and IA with FIW 5. CMIT-TxIA to 3200psi (charted) 6. DGLV (all 8 stations) 7. MIT-T to 3200psi (charted) 8. Pull TTP 9. RDMO SL E-Line procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2000psi high 3. Punch 2-7/8” tubing at ±9,520’ MD just above packer assembly top. Confirm circulation 4. RDMO EL SL Convert 1. MIRU SL and pressure control equipment 2. PT lubricator to 250psi low / 2000psi high 3. Set flow through tubing tail plug with packoff in X-nipple at 9550’ MD 4. Set standing valve on top of X-lock assembly with receptacle for pumped-down jet pump to land/seal on 5. RDMO SL Operations: 1. Circulate jet pump down tubing to seat 2. Put well on production via power fluid down tubing taking produced fluid returns up annulus 3. Perform SVS testing within 5 days Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. No-Flow Verification (2015) Pressure test to 2200 psi per attached email from Ryan Rupert 6/22/23. -bjm Well: G-21RD PTD: 198-064 API: 50-733-20267-01 Updated by: CRR 1/24/23 SCHEMATIC No Depth MD Depth TVD ID Item 42.15’ 42.15’ Hanger (CIW-DCB-FBB-CCL 11” X 3-1/2” EUE lift & susp w/3” type H BPV profile 1 370’ 370’ 2.313” Haliburton NE-TRSSSV 2 3,972’ 3,814’ 6.18” 7” WFD Liner top packer 3 7,543’ 6,738’ 7” ZXP Liner top packer 4 9,526’ 8,544’ 3.000” Packer – 7” 26-32 DLH Retrievable Hydraulic Set 5 9,550’ 8,567’ 2.310” X-Nipple – w/ 2.31” profile 6 9,561’ 8,577’ 2.441” WLEG w/ Half Mule Shoe 7 9,878’ 8,884’ <5.50” Unknown casing obstruction. Couldn’t make hole with 5-1/2” bit / cleanout assembly. Possibly collapsed casing? GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,362’ 2,361’ 2.347” PSPO-1M 16 DOME 1075 5/9/2018 2 4,252’ 4,045’ 2.347” PSPO-1M 16 DOME 1049 5/9/2018 3 5,737’ 5,263’ 2.347” PSPO-1M 16 DOME 1027 5/9/2018 4 6,773’ 6,112’ 2.347” PSPO-1M 16 DOME 999 5/9/2018 5 7,642’ 6,818’ 2.347” PSPO-1M 16 DOME 975 5/9/2018 6 8,286’ 7,372’ 2.347” PSPO-1M 16 DOME 950 5/9/2018 7 8,804’ 7,856’ 2.347” PSPO-1M 16 DOME 924 5/9/2018 8 9,475’ 8,495’ 2.347” PSPO-1M 20 ORIFICE 5/9/2018 OPEN HOLE / CEMENT DETAIL 20"23" hole: cemented with 579sxs of 13.1ppg class G lead followed by 200sxs 15.8ppg tail cement. Saw cement back to surface. 13-3/8" 17-1/2" hole: Primary job pumped 1150sxs (225bbls) class G lead followed by 400sxs (78bbls) class G tail cement. 12/1/74 CBL showed ToC at 1300’ MD. 2squeeze jobs pumped through DV collar at 2595’ MD. Squeeze #1 pumped 550sxs (108bbls) of 15.7ppg class G cement (no squeeze pressure established). Squeeze #2 pumped 600sxs (117bbls) of 16.0ppg class G cement (good squeeze pressure established).12/4/74 CBL showed ToC at 800’ MD (some patches of cement above that). 9-5/8" 12-1/4" hole: TD'd at 11,160' MD in G-21 parentbore (1974). Pumped 2000sxs (392bbls) of Class G. 12/28/74 CBL shows patchy cement up to 8500’ didn’t log any higher) 7"8-1/2” hole: Pumped 510sxs (100bbls) of 14.5ppg class G cement. Saw cement on top of 7” liner.5/30/98 cement log shows ToC at ToL. 6 RKB to MLLW 110.60’, MLLW to mudline 125’, RKB 42.15’ 7 13-3/8” DV at 2,595’ 2 5 4 1 3 9-5/8” Casing leak ±4,867 – ±4,899’ PBTD = 10,662’ MD TD = 10,750’ Max angle = 36q @ 6,600’ G-1 thru G-5 9-5/8” KOP @7850’MD X CASING DETAIL SIZE WT GRADE Conn ID TOP BTM. 26” Surf 356’ 20” 94 H-40 Butt 19.124” 41.98’ 822’ 13-3/8”61 K-55 Butt 12.515” 42.60’ 2,431’ 68 K-55 Butt 12.415” 2,431’ 5,202’ 9-5/8” 40 N-80 Butt 8.835” 40.60’ 62’ 47 N-80 Butt 8.681” 62’ 98’ 40 N-80 Butt 8.835” 98’ 1,336’ 47 N-80 Butt 8.681” 1,336’ 7,850’ (TOW) 7”26 L-80 DWC/C 6.276” 3,972’ 7,543’ 29 N-80 Butt TKC 6.184” 7,543’ 10,747’ TUBING DETAIL 2-7/8” 6.5# L-80 8 rnd EUE 2.441” Surf 9,561’ Well: G-21RD PTD: 198-064 API: 50-733-20267-01 Updated by: CRR 1/24/23 SCHEMATIC Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date G-1 9,614' 9,645' 8,628' 8,658' 31' 2-1/2", 6spf 6/11/1998 G-1 9,615' 9,635' 8,629' 8,649' 20' 2 -1/2” 4 SPF 05/04/2008 - DIL G-1 9,620' 9,630' 8,634' 8,644' 10' 4 SPF 03/23/2015 G-1 9,625' 9,640' 8,638' 8,653' 15' 2”, 4spf 02/04/2004 G-1 9,675' 9,685' 8,687' 8,697' 10' 4 SPF 03/23/2015 G-2 9,668' 9,688' 8,680' 8,700' 20' 2 ½” 4 SPF 05/04/2008 - DIL G-3 9,737' 9,767' 8,747' 8,776' 30' 2-1/2", 6spf 6/14/1998 G-3 9,750' 9,768' 8,759' 8,777' 18' 2 ½” 4 SPF 05/04/2008 - DIL G-3 9,755' 9,765' 8,764' 8,774' 10' 2”, 4spf 02/04/2004 G-3 9,756' 9,766' 8,765' 8,775' 10' 4 SPF 03/23/2015 G-4 9,784' 9,794' 8,792' 8,802' 10' 2 ½” 4 SPF 05/04/2008 - DIL G-4 9,785' 9,793' 8,793' 8,801' 8' 2”, 4spf 02/04/2004 G-4 9,800' 9,815' 8,808' 8,822' 15' 2 ½” 4 SPF 05/04/2008 - DIL G-4 9,800' 9,832' 8,808' 8,839' 32' 2-1/2", 6spf 06/14/1998 G-4 9,808' 9,818' 8,816' 8,825' 10' 4 SPF 03/23/2015 G-4 9,825' 9,833' 8,832' 8,840' 8' 2 ½” 4 SPF 05/04/2008 - DIL G-4 9,825' 9,835' 8,832' 8,842' 10' 2”, 4spf 02/04/2004 G-5 9,894' 9,964' 8,899' 8,967' 70' 2-1/2", 6spf 06/03/1998 G-5 9,896' 9,906' 8,901' 8,911' 10' 2”, 4spf 02/04/2004 G-5 9,925' 9,935' 8,929' 8,939' 10' 4 SPF 03/22/2015 Well: G-21RD PTD: 198-064 API: 50-733-20267-01 Updated by: CRR 05/22/23 PROPOSED No Depth MD Depth TVD ID Item 42.15’ 42.15’ Hanger (CIW-DCB-FBB-CCL 11” X 3-1/2” EUE lift & susp w/3” type H BPV profile 1 370’ 370’ 2.313” Haliburton NE-TRSSSV 2 3,972’ 3,814’ 6.18” 7” WFD Liner top packer 3 7,543’ 6,738’ 7” ZXP Liner top packer 4 ±9,510’ ±8,528’ Forward Circulating Jet Pump 5 ±9,520’ ±8,538’ Retrievable Standing Valve 6 9,526’ 8,544’ 3.000” Packer – 7” 26-32 DLH Retrievable Hydraulic Set 7 9,550’ 8,567’ 2.310” X-Nipple:X-lock installed as tubing stop 8 9,561’ 8,577’ 2.441” WLEG w/ Half Mule Shoe 9 9,878’ 8,884’ <5.50” Unknown casing obstruction. Couldn’t make hole with 5-1/2” bit / cleanout assembly. Possibly collapsed casing? GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,362’ 2,361’ 2.347” PSPO-1M 16 Dmy TBD 2 4,252’ 4,045’ 2.347” PSPO-1M 16 Dmy TBD 3 5,737’ 5,263’ 2.347” PSPO-1M 16 Dmy TBD 4 6,773’ 6,112’ 2.347” PSPO-1M 16 Dmy TBD 5 7,642’ 6,818’ 2.347” PSPO-1M 16 Dmy TBD 6 8,286’ 7,372’ 2.347” PSPO-1M 16 Dmy TBD 7 8,804’ 7,856’ 2.347” PSPO-1M 16 Dmy TBD 8 9,475’ 8,495’ 2.347” PSPO-1M 20 Dmy TBD OPEN HOLE / CEMENT DETAIL 20"23" hole: cemented with 579sxs of 13.1ppg class G lead followed by 200sxs 15.8ppg tail cement. Saw cement back to surface. 13-3/8" 17-1/2" hole: Primary job pumped 1150sxs (225bbls) class G lead followed by 400sxs (78bbls) class G tail cement. 12/1/74 CBL showed ToC at 1300’ MD. 2squeeze jobs pumped through DV collar at 2595’ MD. Squeeze #1 pumped 550sxs (108bbls) of 15.7ppg class G cement (no squeeze pressure established). Squeeze #2 pumped 600sxs (117bbls) of 16.0ppg class G cement (good squeeze pressure established).12/4/74 CBL showed ToC at 800’ MD (some patches of cement above that). 9-5/8" 12-1/4" hole: TD'd at 11,160' MD in G-21 parentbore (1974). Pumped 2000sxs (392bbls) of Class G. 12/28/74 CBL shows patchy cement up to 8500’ didn’t log any higher) 7"8-1/2” hole: Pumped 510sxs (100bbls) of 14.5ppg class G cement. Saw cement on top of 7” liner.5/30/98 cement log shows ToC at ToL. 8 RKB to MLLW 110.60’, MLLW to mudline 125’, RKB 42.15’ 5 9 13-3/8” DV at 2,595’ 2 6 1 3 9-5/8” Casing leak ±4,867 – ±4,899’ 4 PBTD = 10,662’ MD TD = 10,750’ Max angle = 36q @ 6,600’ G-1 thru G-5 9-5/8” KOP @7850’MD X 7 CASING DETAIL SIZE WT GRADE Conn ID TOP BTM. 26” Surf 356’ 20” 94 H-40 Butt 19.124” 41.98’ 822’ 13-3/8”61 K-55 Butt 12.515” 42.60’ 2,431’ 68 K-55 Butt 12.415” 2,431’ 5,202’ 9-5/8” 40 N-80 Butt 8.835” 40.60’ 62’ 47 N-80 Butt 8.681” 62’ 98’ 40 N-80 Butt 8.835” 98’ 1,336’ 47 N-80 Butt 8.681” 1,336’ 7,850’ (TOW) 7”26 L-80 DWC/C 6.276” 3,972’ 7,543’ 29 N-80 Butt TKC 6.184” 7,543’ 10,747’ TUBING DETAIL 2-7/8” 6.5# L-80 8 rnd EUE 2.441” Surf 9,561’ Well: G-21RD PTD: 198-064 API: 50-733-20267-01 Updated by: CRR 05/22/23 PROPOSED Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date G-1 9,614' 9,645' 8,628' 8,658' 31' 2-1/2", 6spf 6/11/1998 G-1 9,615' 9,635' 8,629' 8,649' 20' 2 -1/2” 4 SPF 05/04/2008 - DIL G-1 9,620' 9,630' 8,634' 8,644' 10' 4 SPF 03/23/2015 G-1 9,625' 9,640' 8,638' 8,653' 15' 2”, 4spf 02/04/2004 G-1 9,675' 9,685' 8,687' 8,697' 10' 4 SPF 03/23/2015 G-2 9,668' 9,688' 8,680' 8,700' 20' 2 ½” 4 SPF 05/04/2008 - DIL G-3 9,737' 9,767' 8,747' 8,776' 30' 2-1/2", 6spf 6/14/1998 G-3 9,750' 9,768' 8,759' 8,777' 18' 2 ½” 4 SPF 05/04/2008 - DIL G-3 9,755' 9,765' 8,764' 8,774' 10' 2”, 4spf 02/04/2004 G-3 9,756' 9,766' 8,765' 8,775' 10' 4 SPF 03/23/2015 G-4 9,784' 9,794' 8,792' 8,802' 10' 2 ½” 4 SPF 05/04/2008 - DIL G-4 9,785' 9,793' 8,793' 8,801' 8' 2”, 4spf 02/04/2004 G-4 9,800' 9,815' 8,808' 8,822' 15' 2 ½” 4 SPF 05/04/2008 - DIL G-4 9,800' 9,832' 8,808' 8,839' 32' 2-1/2", 6spf 06/14/1998 G-4 9,808' 9,818' 8,816' 8,825' 10' 4 SPF 03/23/2015 G-4 9,825' 9,833' 8,832' 8,840' 8' 2 ½” 4 SPF 05/04/2008 - DIL G-4 9,825' 9,835' 8,832' 8,842' 10' 2”, 4spf 02/04/2004 G-5 9,894' 9,964' 8,899' 8,967' 70' 2-1/2", 6spf 06/03/1998 G-5 9,896' 9,906' 8,901' 8,911' 10' 2”, 4spf 02/04/2004 G-5 9,925' 9,935' 8,929' 8,939' 10' 4 SPF 03/22/2015 Grayling Platform G-21RD current 05/16/2023 Tubing head, CIW-DCB-S, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X-bottom prep Valve, WKM-M, 2 1/16 5M FE, HWO, AA Qty 2 Casing head, CIW-WF, 13 5/8 3M X 13 3/8'’ SOW bottom, w/ 2- 2 1/16 5M EFO Valve, CIW-FC, 2 1/16 5M FE, HWO, AA Valve, Upper Master, CIW-FC, 3 1/8 5M FE, HWO, EE trim Valve, Swab, CIW-FC, 3 1/8 5M FE, HWO, EE trim Valve, Master, CIW-FC, 3 1/8 5M FE, HWO, EE trim Valve, SSV, FC, 3 1/8 5M FE, w/ 15'’ Safeco oper-air operated Tubing hanger, CIW-DCB- FBB-CCL, 11 X 3 1/2 EUE lift and susp, w/ 3'’ type H BPV profile, 6 ¼ EN, 2- ½ npt CCL ports Adapter, CIW-EN-CCL, 11 5M Stdd x 3 1/8 5M, prepped for 6 ¼ EN and 2- ½ npt CCL ports, EE material Grayling Platform G-21 13 3/8 X 9 5/8 X 2 7/8 BHTA, Bowen, 3 1/8 5M FE X 3'’ Bowen Quick Union Grayling Platform G-21RD Proposed 05/16/2023 Tubing head, CIW-DCB-S, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X-bottom prep Casing head, CIW-WF, 13 5/8 3M X 13 3/8'’ SOW bottom, w/ 2- 2 1/16 5M EFO Valve, CIW-FC, 2 1/16 5M FE, HWO, AA Valve, Masters, CIW-FC, 3 1/8 5M FE, HWO, EE trim Valve, SSV, WKM, 2 1/16 5M FE, w/ 10'’ Safeco oper-air operated Tubing hanger, CIW-DCB- FBB-CCL, 11 X 3 1/2 EUE lift and susp, w/ 3'’ type H BPV profile, 6 ¼ EN, 2- ½ npt CCL ports Adapter, CIW-EN-CCL, 11 5M Stdd x 3 1/8 5M, prepped for 6 ¼ EN and 2- ½ npt CCL ports, EE material Grayling Platform G-21RD 13 3/8 X 9 5/8 X 2 7/8 Kobe Catcher block Production flow line From Annulus Injection Down Tubing Due to limited space on platform, need a 90 degree block to install SSV and flowline Superseded CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Ryan Rupert To:McLellan, Bryan J (OGC) Cc:Rixse, Melvin G (OGC); Juanita Lovett; Dan Marlowe; Ryan Rupert Subject:RE: [EXTERNAL] TBU G-21RD (PTD 198-064) Jet pump sundry Date:Thursday, June 22, 2023 4:17:57 PM Attachments:G-21RD proposed jet pump wellhead drawing.docx 10-403 Trading Bay Unit G-21RD PTD 198-064.pdf Sorry for the delay Bryan, but I now have had the chance to QC the below between the Milne, Anna, and Bruce folks to ensure consistency. Let me know your thoughts, and if it’s easier Hilcorp can definitely withdraw the existing and submit a new sundry that. Thank you, 1. Corrosion protection a. Corrosion monitoring coupons will be installed on both the power fluid injection side and the produced fluids side. b. We will treat the power fluid (Filtered Inlet Water) with oxygen scavenger, scale inhibitor, and corrosion inhibitor, while also doing periodic batch treatments with biocide 2. Safety systems: a. Tubing (Power fluid injection side): i. Power fluid operating pressure is <= 3200psi ii. High trip: 1. No higher than Power fluid pressure + 150psi 2. 3350psi for this well iii. Low trip: 1. No lower than 50% of power fluid pressure 2. 1600psi for this well a. IA: (produced fluid side) i. Separator Inlet Pressure = 50psi (to be raised to ~250psi by year end) ii. High trip: 1. Limited by pipe class / spec break 2. 600psi for this well iii. Low trip: 1. Greater than 50% of separator inlet or 25% FTP per regulation 2. 35psi today, 135psi by year end when separator pressure is raised b. SSV’s i. Will be installed on both the power fluid injection side and the produced fluid outlet side ii. Power fluid SSV will trip closed when the production SSV is tripped iv. Existing waiver in place for SSV’s to be in the horizontal run platform-wide. 3. Periodic CMIT-IA’s a. Hilcorp commits to perform CMIT-TxIA’s every 2 years CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. b. Will be tested to 2200psi in this case. (0.25psi/ft x packer TVD of 8544’ TVD = 2136psi) c. I’ll adjust my initial CMIT-TxIA in the sundry to this pressure for consistency in an effort to not subject production casing to unnecessary forces d. Initial MIT-T will remain to power fluid pressure (3200psi) 4. Wellhead / tree configuration: a. See attached updated wellhead diagram b. The Kobe catcher acts as a flow cross for JP completions (Standard with existing Anna/Bruce configurations) c. No swab valve is needed, as any lubricator would bolt directly onto the top of the Kobe catcher 5. Other Jet Pump practices: Covered above Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, June 8, 2023 2:51 PM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] TBU G-21RD (PTD 198-064) Jet pump sundry Ryan, A couple questions about the sundry application for the jet pump: 1. What are you planning to do in terms of corrosion protection chemicals to protect the Inner casing string from produced fluids and FIW? 2. Hilcorp should discuss SSV configurations on tubing and IA a. What are tubing and IA trip pressures, high and low. b. Should be consistent methodology as used on the North Slope. 3. Periodic CMIT’s, consistent with North Slope methodology. 4. Why is there no swab valve or flow cross on the proposed tree? 5. Other jet pump operating practices consistent with Milne Point? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Grayling Platform G-21RD Proposed 06/20/2023 Tubing head, CIW-DCB-S, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X-bottom prep Casing head, CIW-WF, 13 5/8 3M X 13 3/8'’ SOW bottom, w/ 2- 2 1/16 5M EFO Valve, CIW-FC, 2 1/16 5M FE, HWO, AA Valve, Masters, CIW-FC, 3 1/8 5M FE, HWO, EE trim Valve, SSV, WKM, 2 1/16 5M FE, w/ 10'’ Safeco oper-air operated Tubing hanger, CIW-DCB- FBB-CCL, 11 X 3 1/2 EUE lift and susp, w/ 3'’ type H BPV profile, 6 ¼ EN, 2- ½ npt CCL ports Adapter, CIW-EN-CCL, 11 5M Stdd x 3 1/8 5M, prepped for 6 ¼ EN and 2-½ npt CCL ports, EE material Grayling Platform G-21RD 13 3/8 X 9 5/8 X 2 7/8 Kobe Catcher block Production flow line From Annulus Power fluid Injection Down Tubing w/SSV Due to limited space on platform, need a 90 degree block to install SSV and flowline • OF 77.1 • V I//j 7 THE STATE Alaska Oil and Gas • of T s KA Conservation C®mmlssion 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF SSP Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager Hilcorp Alaska, LLC soap NOV 0 ti 201- 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G Oil Pool, TBU G-21 RD Permit to Drill Number: 198-064 Sundry Number: 317-442 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this 2:1 day of September, 2017. RBDMS ULi - 3L( i7 • 0 ! RECEIVED STATE OF ALASKA SEP Z017 ALASKA OIL AND GAS CONSERVATION COMMISSION AOG APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 , Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing I Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing Other: Tie Back Liner&G/L Q Completion 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory 0 Development ❑ . 198-064 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20267-01-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ' Will planned perforations require a spacing exception? Yes 0 No 0 i Trading Bay Unit G-21 RD • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730 McArthur River Field/Middle Kenai G Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,750 - 9,740 9,878 , , 8,884 2,930 psi N/A 9,878 Casing Length Size MD TVD Burst Collapse Structural Conductor 356' 26" 356' 356' Surface 822' 20" 822' 822' 1,530 psi 520 psi Intermediate 5,202' 13-3/8" 5,202' 4,824' 3,090 psi 1,540 psi Production 7,850' 9-5/8" 7,850' 6,991' 5,750 psi 3,090 psi Liner 3,204' 7" 10,747' 9,738' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,614-9,935 , 8,628-8,939 2-7/8" 6.5#/L-80 2,106 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A N/A&N/A ' 12.Attachments: Proposal Summary 2 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 ' Service 0 14.Estimated Date for 15.Well Status after proposed work: 10/15/2017 Commencing Operations: OIL 2 - WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe@hilcorp.com QQ Contact Phone: (907)283-1329 Authorized Signature: w.r %...5Date: 1 l l a� Contact SE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. �f 3 i -7 -`-f`f2r Plug Integrity 0 BOP Test l!. Mechanical Integrity Test 0 Location Clearance 0 Other: ""'"�� 300D,,05_, 6c, f� /- Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes ❑ No V Subsequent Form Required: / U - 101 RDDGtJIS u,,i - J Ci i7 T APPROVED BY (�� Approved by: COMMISSIONER THE COMMISSION Date: (' ^ A Lal �� SubmForm ane Form 10-403 Revised 4/20178`fo r vEdve q^Q�S d for 12 months from the date of approval. Attachments in. Duplicate • • Well Work Prognosis Well: G-21rd IIilearp Alaska,LLCDate: 09/14/2017 Well Name: G-21rd API Number: 50-733-20267-01 Current Status: ESP Producer Leg: Leg#3 SE Corner Estimated Start Date: October 15, 2017 Rig: Moncla 404 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 198-064 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907) 777-8356 (0) Current Bottom Hole Pressure: 3,793 psi @ 8,628'TVD 0.440 lbs/ft(8.45 ppg)based on ESP Gauge SIBHP Maximum Expected BHP: 3,793 psi @ 8,628'TVD 0.440 lbs/ft(8.45 ppg)based on ESP Gauge SIBHP Maximum Potential Surface Pressure:2,930 psi*' Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Brief Well Summary G-21rd is a G zone producer completed with an ESP installed in March 2015. During a fall 2017 workover to cleanout the well, replacing the failed pump with a gas-lift completion, an unsuspected hole was discovered at ^'4,900.A kill string was installed to allow time to put together a repair plan and order materials.This workover will run a 7" casing tie-back to above the leak and install a gas-lift completion. I Last Casing Test: To be tested after casing repairs. Procedure: 1. MIRU Moncla 404 2. Circulate circulate hydrocarbon off the well to production through kill string. Work over fluid will be FIW. BOP's will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/3,000psi high /2,500 Annular. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with kill string. 6. RIH w/liner top dressing mills to±7,543'and prep liner top for tie back. POOH. 7. RIH with tie back liner to ±7,543'.Set hanger, POOH w/workstring. 8. RIH with test packer to ±9,550'.Test casing to 2,000psi and chart for 30 minutes. POOH. 9. PU and run Gas-Lift completion. 10. Set and test packer to 2,500 psig charting for 30 minutes. 11. Set BPV. NU tree,test same,turn well over to production. 12. Schedule SVS testing with AOGCC as per regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Diagram Current 4. Wellhead Diagram Proposed 5. BOP Drawing 6. Fluid Flow Diagrams 7. RWO Sundry Revision Change Form • II • SCHEMATIC • McArthur River Field,TBU Well: G-21RD nileorp.U".:k".IL( PTD: 198-064 API: 50-733-20267-01 Completed: 09/03/17 CASING DETAIL SIZE WT GRADE Conn ID TOP BTM. RKB 42.15 26" Surf 356' 20" 94 H-40 Butt 19.124" 41.98' 822' ';' ?'" 61 K-55 Butt 12.515" 42.60' 2,431' 26„ :: , 13-3/8" 68 K-55 Butt 12.415" 2,431' 5,202' L 40 N-80 Butt 8.835" 40.60' 62' 47 N-80 Butt 8.681" 62' 98' G..Y , 9 5/8 ,- 40 N-80 Butt 8.835" 98' 1,336' 20"Cmt .' ,. 47 N-80 Butt 8.681" 1,336' 7,850'(TOW) to Surf v 4, 7" 29 N-80 Butt TKC 6.184" 7,543' 10,747' .'= TUBING DETAIL ,'+• 2-7/8" 6.5# L-80 8 rnd EUE 2.441" Surf 2,106' DV at 2,595' (13-3/8") Leak±4,867- Jewelry Detail ±4,899 Plla Depth Depth 13-3/8" s......,-- ° MD TVD ID OD Item Cmt to Surf ", " iN.!",A / 2,106' 2,106' - - Kill String-2-7/8"6.5#/L-80 8rd EUE 9-5/8"TOW ' L @ 7850' Perforation Detail Top Btm Top Btm Zone (MD) (MD) (ND) (ND) Amt SPF Date µ G-1 9,614' 9,645' 8,628' 8,658' 31' 2-1/2",6spf 6/11/1998 1 G-1 9,615' 9,635' 8,629' 8,649' 20' 2-1/2"4 SPF 05/04/2008-DIL G-1 9,620' 9,630' 8,634' 8,644' 10' 4 SPF 03/23/2015 G-1 9,625' 9,640' 8,638' 8,653' 15' 2",4spf 02/04/2004 G-1 9,675' 9,685' 8,687' 8,697' 10' 4 SPF 03/23/2015 G-2 9,668' 9,688' 8,680' 8,700' 20' 2 W'4 SPF 05/04/2008-DIL G-3 9,737' 9,767' 8,747' 8,776' 30' 2-1/2",6spf 6/14/1998 G-3 9,750' 9,768' 8,759' 8,777' 18' 2'/::"4 SPF 05/04/2008 DIL G-3 9,755' 9,765' 8,764' 8,774' 10' 2",4spf 02/04/2004 G-3 9,756' 9,766' 8,765' 8,775' 10' 4 SPF 03/23/2015 G-1 G-4 9,784' 9,794' 8,792' 8,802' 10' 2 W'4 SPF 05/04/2008-DIL thru G-4 9,785' 9,793' 8,793' 8,801' 8' 2",4spf 02/04/2004 Washed/milled G-5 G-4 9,800' 9,815' 8,808' 8,822' 15' 2'A"4 SPF 05/04/2008-DIL to 9,878' On ,-.41.4.t G-4 9,800' 9,832' 8,808' 8,839' 32' 2-1/2",6spf 06/14/1998 8/27/17 ' G-4 9,808' 9,818' 8,816' 8,825' 10' 4 SPF 03/23/2015 G-4 9,825' 9,833' 8,832' 8,840' 8' 2 W'4 SPF 05/04/2008-DIL Landing .;' G-4 9,825' 9,835' 8,832' 8,842' 10' 2",4spf 02/04/2004 Collar at ';{ G-5 9,894' 9,964' 8,899' 8,967' 70' 2-1/2",6spf 06/03/1998 10,662' G-5 9,896' 9,906' 8,901' 8,911' 10' 2",4spf 02/04/2004 G-5 9,925' 9,935' 8,929' 8,939' 10' 4 SPF 03/22/2015 TD= 10,750' Max angle=36°@ 6,600' Updated: 09/14/17 byJLL • • • McArthur River Field,TBU PROPOSED well: G 21RD nilcorp Alaska,LLC PTD: 198-064 API: 50-733-20267-01 Completed: FUTURE CASING DETAIL SIZE WT GRADE Conn ID TOP BTM. RKB 42.15 26" Surf 356' rig 1' 20" 94 H-40 Butt 19.124" 41.98' 822' 61 K-55 Butt 12.515" 42.60' 2,431' 26" i 1 , 13-3/8" 68 K-55 Butt 12.415" 2,431' 5,202' Z. , 40 N-80 Butt 8.835" 40.60' 62' SOrfCmt to ' _ , 9 5/8" 47 N-80 Butt 8.681" 62' 98' 40 N-80 Butt 8.835" 98' 1,336' DV at 2,595' 47 N-80 Butt 8.681" 1,336' 7,850'(TOW) ret.b.-rlc. (13-3/8") i;',,,, t26 or 29 L-80 DWC/C ±4,700' ±7,543' Li„,,_ .A 4' LID 7 29 N-80 Butt TKC 6.184" 7,543' 10,747' 13-3/8"Cmt TUBING DETAIL to Surf h • • , ` 2-7/8" 6.5# L-80 8 rnd EUE 2.441" Surf ±9,550' Hole±4,867- 0CO y 7�✓ ±4,899' � t‘..---• 7 gib" Jewelry Detail E. No DepthMpDTVD epth ID OD Item 2-9 ` „ ' ' Hanger _+ T 7 -i 1 ±350' ±350' 2.313" SSSV it "•,t. 2 ±2,351' ±2,350' 2.441" . GLM#1 9-5/8"TOW Z. 3 ±4,259' ±4,050' 2.441" GLM#2 @ 7850' 4 ±5,722' ±5,250' 2.441" GLM#3 5 ±6,758' ±6,100' 2.441" GLM#4 6 ±7,620' ±6,800' 2.441" GLM#5 7 ±8,261' ±7,350' 2.441" GLM#6 Cal rA 8 ±8,797' ±7,850' 2.441" GLM#7 t , 9 ±9,460' ±8,423' 2.441" GLM#8 10 ±9,490' ±8,509' Packer 11 ±9,520' ±8,538' 2.313" X-Nipple 12 ±9,550' ±8,567' Tail/WLEG - ' 'i 10 Perforation Detail IA'' x 11 Top Btm Top Btm Igl 12 Zone (MD) (MD) (TVD) (TVD) Amt SPF Date G-1 9,614' 9,645' 8,628' 8,658' 31' 2-1/2",6spf 6/11/1998 i' - G-1 9,615' 9,635' 8,629' 8,649' 20' 2-1/2"4 SPF 05/04/2008-DIL �,,� = G-1 9,620' 9,630' 8,634' 8,644' 10' 4 SPF 03/23/2015 ' G-1 9,625' 9,640' 8,638' 8,653' 15' 2",4spf 02/04/2004 G-1 9,675' 9,685' 8,687' 8,697' 10' 4 SPF 03/23/2015 - G-1 G-2 9,668' 9,688' 8,680' 8,700' 20' 2'A"4 SPF 05/04/2008-DIL - thru G-3 9,737' 9,767' 8,747' 8,776' 30' 2-1/2",6spf 6/14/1998 G-3 9,750' 9,768' 8,759' 8,777' 18' 2%"4SPF 05/04/2008-DIL Washed/mille 3, _ G-5 G-3 9,755' 9,765' 8,764' 8,774' 10' 2',4spf 02/04/2004 to 9,878' on ;v t G-3 9,756' 9,766' 8,765' 8,775' 10' 4SPF 03/23/2015 8/27/17 a G-4 9,784' 9,794' 8,792' 8,802' 10' 2'A"4 SPF 05/04/2008-DIL G-4 9,785' 9,793' 8,793' 8,801' 8' 2",4spf 02/04/2004 Landing ) • G-4 9,800' 9,815' 8,808' 8,822' 15' 2'A"4 SPF 05/04/2008-DIL Collar ate G-4 9,800' 9,832' 8,808' 8,839' 32' 2-1/2",6spf 06/14/1998 10,662' \ G-4 9,808' 9,818' 8,816' 8,825' 10' 4 SPF 03/23/2015 G-4 9,825' 9,833' 8,832' 8,840' 8' 2''A"4 SPF 05/04/2008-DIL G-4 9,825' 9,835' 8,832' 8,842' 10' 2",4spf 02/04/2004 G-5 9,894' 9,964' 8,899' 8,967' 70' 2-1/2",6spf 06/03/1998 TD=10,750' G-5 9,896' 9,906' 8,901' 8,911' 10' 2",4spf 02/04/2004 Max angle=36°@ 6,600' G-5 9,925' 9,935' 8,929' 8,939' 10' 4 SPF 03/22/2015 Updated: 09/14/17 by DEM • ti • • Grayling Platform G-21 Current ESP 08/08/2017 Hilenrn Al,.ska,1.I4 Grayling Platform Tubing hanger,CIW-DCB-ESP, G-21 11 X 3 A EUE lift and susp,w/ 13 3/8 X 9 5/8 X 3 1/2 3"type H BPV profile,5'/4 EN, 2-3/8 continuous control line ports,prepped for BIW penetrator BHTA,Bowen,3 1/8 5M FE X 3" Bowen Quick Union III ! ni lin Valve,swab,WKM-M, 3 1/8 5M FE,HWO, r AI\,-q• T-24 Valve,wing,WKM-M, �' lia/ 'I �� ! Valve,WKM-M,3 1/8 5M FE,w/ 2 1 16 SM FE,HWO, � w "YT-24c," I. ill MA-16 operator p,:ct, Valve,lower master,WKM-M, j 3 1/8 5M FE,HWO,T-24 ,n7: III 111111 it, III III Adapter,CIW-Toadstool, 11 5M Stdd X 3 1/8 5M FE,prepped for 5'/,ESP neck,2-'/2 npt continuous _¶ control line ports Tubing head,CIW-DCB, _•;;,l glce 13 5/8 3M X 11 5M,w/ �• �'� _• 2-2 1/16 5M SSO, Ifs �� Ili Valve,WKM-M,2 1/16 5M FE, X bottom "` d , 4 HWO,DD l'igc, , � 1l1 ■ll111� �. '4.'1, 1 Whirs- Qty 2 III k I Iii al iRl�iy Casing head,CIW-WF, �I� Valve,CIW-F,2 1/16 3M FE, 135/83Mx133/8SOW w/ lil Itt HWO,AAtrim 2-21/16 SM SSO,CA slips in slips - E - > _ head � Oil IONa01(t 1111lII I,r,-i... F. r- a - = r =_ t - c . H • • Grayling Platform G-21 Proposed 08/08/2017 Hilrnrp Aura N,1.IA: Grayling Platform Tubing hanger,CIW-DCB- G-21 FBB-CCL,11 X 3 1/2 EUE lift 13 3/8 X 9 5/8 X 3 1/2 and susp,w/3"type H BPV profile,6'''A EN,2-'A npt CCL ports BHTA,Bowen,3 1/8 5M FE X 3" Bowen Quick Union 4 . Valve,Swab,CIW-FC, .1 p 3 1/8 5M FE,HWO, 4.Va' EE trim *t` '� Valve,SSV,FC,3 1/8 5M FE, ' � ij.i,tt�. w/15"Safeco oper-air -ghee: operated ?c,Valve,Upper Master, ,'4',t ., CIW-FC,3 1/8 5M FE,HWO, iA1, * l� EE trim �(!'.1. v -.I isiiIns if, 11--- Valve, Master,CIW-FC,3 1/8 SM FE,HWO,EE trim Adapter,CIW-EN-CCL,11 5M £ Stdd x 3 1/8 5M,prepped for �, - IIP• 6'A EN and 2-'A npt CCL Y� - ports,EE material Tubing head,CIW-DCB-S, 1= r 13 5/8 3M X 11 5M,w/2- =':'ll ■ , i li'•_'= Valve,WKM-M,2 1/16 2 1/16 5M SSO,X-bottom is — Ill 5M FE,HWO,AA prep Qty 2 l r�1ill st:: III _ 111 in g.4 Casing head,CIW-WF, ��� Valve,CIW-FC, 135/83MX133/8' SOW III 21/165MFE,HWO,AA bottom,w/2-2 1/16 5M III ' SI I EFO - - 'I `' , 1011 IN. 1 "!I('I ? 1" ! '-1 di_ . -, /w. • • Grayling Platform Moncla 404 BOP 09/14/2017 Hilrrarp:Hank.,LIA: ill Ill iiI'1t!!i�1 4.54' Hydril GK 13 5/8-5000 ill Ill Ill Illiii A 1 111 111 Ill III III CI\N-U Variable rams 2 7/8-5 4.67' 13 5/8-5000 (� Blind Rams lit lit ill ill lit Choke and Kill valves • 2 1/16 5M Irl 111111 lit Irl 226 �� il s. IIY1 ::41;104� t Pil 111111 111 �' ill ILI 111 III IU 7"casing rams CIW-ll 2.83'u _ 41 ..,.. lil 111 FII til tit 1 III 1!I III 111 III Riser 135/85M FE X135/85M FE ill III III III lit 14,111-01-1417 Spacer spool 135/85M FE X115M III tit lit lit Ili • .. •_ _n 0 i 4111 7Z1 n r C C o r - D D CO 7° � Z w m z (i) 0 I- 0 D � Z m r 02OOD n D 7] CD O C D D D z = O o _IG) O -P. CQ -o V m -1 H c EWr -op p3 m —IN Z- O 0 z D z 0 cn IIIIIIIIIIIIIII 0 m H m cn c0i -o ill �11!I�• ➢111111•■I- _ • y 2 �)1 ■ - A / 2 5 V Oni � O A p u =n - - =c o z ' ' w o A m m D m A v r L...-1 :•fJ "2>z n1 • Q1 (J7 CO ' V cD N) ►l // wn 1111 3 M p ?. o 0 o „AT o_v E a m N 3v+ n n n n n n n nn n n x x x 2222 -2 < R.; , a` o 0 0 0 0 0 0 0 o 0 o A - 3 3 3 3 3 ro < - r -° -° -° -° -° < ro m m m m m m m m m m fD d ,- x3333333333 c7 "„° 33333 o 0 — — — — - - N fl 0 0 0 0 0 o x Oa Oa x 0 0 0 0 0 0 0 0 a a a a a a a a a a a a 1-+ to 0o V 0 u, A W N In A l. NJ O r — n00000000 3 to Co 3 m N A W N^ EKEKKEE3 3 A 3 3 3 O .r O O 000000000000 0000 n O n O O ,�-_, 0 0 . o xi n C I- > o Z D Z CO v O Z m D C xj O 2 Z E Z ) ` N N 1- c 1- • * N , O Z �J * CDD * 1 n Z II Z c m� I Z O z z C r D D Z 0 m m m u) HW I' IfT1 X. P I] 11 =1 id t Ill \,,,,, ---..•111 tit PO o - . =A m O < A O DI<73 m .1r II oz '4 Coil cc C m mr m� v I r y. :.� ZZ mn 07 U1 ' co ' V (.O Ni 14 11 m. O r n MI o n p 0 ,. a a m 3 r n n n n n n n n n n n x m ac v v v < N 0 0 5', 0 0 0 0 0 0 5', p , - 3 3 3 3 3 c ,-9D FF A < 3 5 v -o v r' < � n3333333333 -. .5_= "tn t„ �, 33333 ° o A CD a a a a a a a a a a No = 0 0 0 0 0 0 0. 0. 0. 0. 0. .- . a0 N 01 Ln A W N . N to A W N f+ 0 n n n n n 3 n n n n 5-. 3awr3 to ca V O1 to A W N N O 13 0 0 n n o n n o n o n o n o ono 0 o n o n o .1_25' Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, 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 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.) . • Moncla Rig 404 BOP Test Procedure Hilrorp Alaska,LLC Attachment#1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug)in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close ft valve on standpipe manifold,close valves 1, 2, 10 on choke manifold and close the annular preventer,open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer,close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross,open 1st valve of standpipe,close valves 3,4&9 on choke manifold,open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross,close valves 5&6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to—1200 psi and bleed off 200—300#s recording change and stabilization. If passes after 5 minutes, bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross),open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. • • Moncla Rig 404 BOP Test Procedure tlilcarpAlaeka,LLC Attachment#1 g) Close inside valve/open outside valve(HCR)on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold,close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams,and HCR. Close 2nd set of pipe rams if installed(e.g.dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424)in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. 0 0 @ > > cn cn C) 0 / C § 0 _. % § / 2 Q CD Z r) / . . ® 0 / .1 x o \ E 0 E 0 m 71 2 5. \ I q 20 « E m CD k o x $ 9 r 0 2 / m 6 13 13 p CD o § k 3 ° C ■ ■ a g 73 § aCD § o � \ A 0. n � � @ xi E DO t Sc� o CD § Ef Q 13 0 CD / \ 3 X. e \ m0 13 % 2 c 3 ° 0. > m fCn c EE 0 / / / = -S � \k // 13 o 0 0 = 2 -I CD \ Q.\ o Q \ ¥ 2 % � ? B 0= � 2 \3 O O . k � co / ■ N. z � & mo « g % w Eq -0f R•1 _ \ / ox 7k • 0. oc a o /$ \ /2 = kk<• ■ = § co ] > � § 220 5 / o q E § k 0 9 / = 7J * J 0o. ) - CD a) z• g �0. STATE OF ALASKA AL KA OIL AND GAS CONSERVATION COMSSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Wet 0 Other: Kill String 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory 0 198-064 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service El 6.API Number: Anchorage,AK 99503 50-733-20267-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018730 Trading Bay Unit G-21 RD RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Middle Kenai G Oil Pool SEP 1 g 2017 11.Present Well Condition Summary: ��'� Total Depth measured 10,750 feet Plugs measured N/A feet OCC true vertical 9,740 feet Junk measured 9,878 feet Effective Depth measured 9,878 feet Packer measured N/A feet true vertical 8,884 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 356' 26" 356' 356' Surface 822' 20" 822' 822' 1,530 psi 520 psi Intermediate 5,202' 13-3/8" 5,202' 4,824' 3,090 psi 1,540 psi Production 7,850' 9-5/8" 7,850' 6,991' 5,750 psi 3,090 psi Liner 3,204' 7" 10,747' 9,738' 8,160 psi 7,020 psi Perforation depth Measured depth 9,614-9,935 feet �`i r c� 1 ? /, True Vertical depth 8,628-8,939 feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 2,106(MD) 2,106(TVD) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 80 58 413 66 66 Subsequent to operation: 0 0 0 205 225 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ 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: 317-387 Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe@hilcorp.com �"^ Authorized Signature: ✓ k q Date: y I (� 7 1 I Contact Phone: (907)283-1329 Form 10-404 Revised 4/2017 RBDMS l ._/ SE/ E L 5 L'i)a Submit Original Only • il • SCHEM • ATIC McArthur River Field,TBU n,l,nr,Ala�►A,,,,.� Well: G-21RD PTD: 198-064 API: 50-733-20267-01 Completed: 09/03/17 CASING DETAIL SIZE WT GRADE Conn ID TOP BTM. RKB 42.15 26" Surf 356' i y,• 20" 94 H-40 Butt 19.124" 41.98' 822' +' 61 K-55 Butt 12.515" 42.60' 2,431' 26"L Itia , . . 13-3/8" 68 K-55 Butt 12.415" 2,431' 5,202' " 40 N-80 Butt 8.835" 40.60' 62' �,1, };. 47 N-80 Butt 8.681" 62' 98' :" , 9-5/8" 40 N-80 Butt 8.835" 98' 1,336' 20"Cmt 47 N-80 Butt 8.681" 1,336' 7,850'(TOW) to Surf 7" 29 N-80 Butt TKC 6.184" 7,543' 10,747' tl ,-- TUBING DETAIL " ,r 2-7/8" 6.541 L-80 8 rnd EUE 2.441" Surf 2,106' DV at 2,595' (13-3/8") 'O- 4,899 Leak 4,867- t° Jewelry Detail , - " No Depth Depth ID OD Item 13-3/8" MD TVDIN r _ Cmt to Surf / 2,106' 2,106' - - Kill String-2-7/8"6.5#/L-80 8rd EUE ' x 9-5/8"TOW A @ 7850' Perforation Detail Top Btm Top Btm Zone (MD) (MD) (TVD) (TVD) Amt SPF Date G-1 9,614' 9,645' 8,628' 8,658' 31' 2-1/2",6spf 6/11/1998 G-1 9,615' 9,635' 8,629' 8,649' 20' 2-1/2"4 SPF 05/04/2008-DIL ,` G-1 9,620' 9,630' 8,634' 8,644' 10' 4 SPF 03/23/2015 G-1 9,625' 9,640' 8,638' 8,653' 15' 2",4spf 02/04/2004 � G-1 9,675' 9,685' 8,687' 8,697' 10' 4 SPF 03/23/2015 i G-2 9,668' 9,688' 8,680' 8,700' 20' 2''A"4 SPF 05/04/2008-DIL G-3 9,737' 9,767' 8,747' 8,776' 30' 2-1/2",6spf 6/14/1998 - G-3 9,750' 9,768' 8,759' 8,777' 18' 2%"4 SPF 05/04/2008-DIL `+4.; G-3 9,755' 9,765' 8,764' 8,774' 10' 2",4spf 02/04/2004 *' G-3 9,756' 9,766' 8,765' 8,775' 10' 4 SPF 03/23/2015 == G-1 G-4 9,784' 9,794' 8,792' 8,802' 10' 2'A"4 SPF 05/04/2008-DIL thriG-4 9,785' 9,793' 8,793' 8,801' 8' 2",4spf 02/04/2004 Washed/milled - G-5 G-4 9,800' 9,815' 8,808' 8,822' 15' 2'A"4 SPF 05/04/2008-DIL to 9,878'on 10:0G-4 9,800' 9,832' 8,808' 8,839' 32' 2-1/2",6spf 06/14/1998 8/27/17 G-4 9,808' 9,818' 8,816' 8,825' 10' 4 SPF 03/23/2015 '! G-4 9,825' 9,833' 8,832' 8,840' 8' 2'A"4 SPF 05/04/2008-DIL Landing is - G-4 9,825' 9,835' 8,832' 8,842' 10' 2",4spf 02/04/2004 Collar at . G-5 9,894' 9,964' 8,899' 8,967' 70' 2-1/2",6spf 06/03/1998 10,662' 41, G-5 9,896' 9,906' 8,901' 8,911' 10' 2",4spf 02/04/2004 G-5 9,925' 9,935' 8,929' 8,939' 10' 4 SPF 03/22/2015 TD=10,750' Max angle=36°@ 6,600' Updated: 09/14/17 by JLL • • 14 Hilcorp Alaska, LLC Iile„i,,Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-21RD 50-733-20267-01 198-064 8/23/2017 9/3/2017 Daily Operations: 08/23/17-Wednesday The tree adapter has a leaking penetrator that occurred while testing hanger void. Penetrator failed(moved up thru adapter)at 3000 psi test pressure releasing gas in well room.Well has since been kill w/FIW.Lifted carrier and set on SB beams-bolted down drawworks and A-frame-pinned and secured derrick in place.Mounted carrier walkways and stairways-positioned choke house and koomey as needed for well work.Brought rig tank and pump onboard positioning as needed-hooked up same.Quadco wired in PVT, return gas,pump and drawworks sensors.Setup stack on gas buster-positioned test pump under front of carrier-hooked up drive for draw works-removed drill line spool from derrick and installed drill line on draw works.Built 11"x 13 5/8"5M BOP assy w/riser,mud- cross and double gate w/2 7/8"x 5"VBR(blinds closed for well control).Checked well and set BPV.Worked ESP adapter flange using flange spreaders,wedges,sledge hammers and penetrating oil with 26K pull from crane to separate tree from tb head.Crane removed tree from well room thru drill deck hatch.NOS terminated control lines and checked hanger threads-installed LH test sub. N/U pre-assembled BOPE stack-added 13 5/8"5M annular.Raised and scoped out derrick.Finished torqueing all BOPE flange bolts/nuts to specs.Mounted rig floor.Moved tongs and handling equipment to rig floor. 08/24/17-Thursday Finished R/U McCoy tongs and hyd power pack-bolted up K3 valve on circ manifold-rigged up test pump and binded down BOP stack. M/U 2 7/8"test jt w/3 1/2"IF x-over on btm,3 1/2"PH-6 pumpin,SV,&IBOP on top w/x-over.Screwed onto LH test sub. Closed manual valves on choke and kill side-filled stack w/FIW and closed blinds-filled test jt w/FIW and closed IBOP.Shell tested to 3000 psi-released pressure and lined up for 1st test.Tested all BOPE to 250 psi low 3000 psi high as per Sundry in accordance with Hilcorp and AOGCC requirements.Tested w/2 7/8"tb only.Performed successful koomey draw down test.Witness waived by Mr.Regg via email 8/23/17 2:07 PM.B/D test jt-pulled BPV-M/U 2 7/8"landing jt with 3 1/2"8rd x-over and screwed into hanger-backed out load down pins.Pulled hanger off seat at 102k,moving uphole at 108k-P/U 3'and closed annular.Lined up to pump LW taking returns thru gas buster to rig tank.Circulate well LW with FIW at 3.0 BPM 450 psi-Total volume pumped=800 BBL(22,400 stks).Open annular,pull tubing hanger to rig floor-travel weight=104K-NOS rep on rig floor.ESP penetrator missing jam and thrust nuts at base of penetrator,below hanger,and power cable armor shield and insulation parted with 3 interior wires intact.(Pictures captured and saved to 0 Drive).NOS and Summit reps pull control lines and power cable from tubing hanger.LD 2-7/8"landing joint and tubing hanger.Repositioned Summit spooler,hung Summit sheaves in derrick.Pulled 2 stands 2-7/8"6.5#L-80 EUE 8RD production tubing, standing back in derrick,feeding power cable and flat pack through sheaves back to Summit spooling units.Secured flat pack and power cable to spoolers.POOH with 2-7/8"6.5#L-80 EUE 8RD tubing,standing back in derrick,spooling up flat pack and power cable. Stand#2 pitted above pin end of Jt.#3,Stand#4 severe pitting at collar of Jt#7(Picture saved to 0 drive).9 stands in derrick(564'), travelling weight=96K.13.5'up Jt#19(MD=8,935')start to overpull.Work pipe 120K PUW to 64K SOW-unable to pull thru. Decision was made to TBI w/9 stands then POOH laying down 17 jts(tb unsuitable to be reused in production string or to be used as work string).Summit cut and secured power cable-tripped in w/stands-presently laying down pipe at report time.Called for KCL and mixing tank to weight up.2#and ELine unit to cut pipe. • • • Hilcorp Alaska, LLC Ilitemp: LNka. Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-21RD 50-733-20267-01 198-064 8/23/2017 9/3/2017 Daily Operations: 08/25/17-Friday Finished POOH laying down 18 jts of 2 7/8"6.5#L-80 8rd prod tb.Pulled into tight spot at 8,935'and pulled loose at 120k.Moved beaver slide into position and restrung ESP power cable and flat pack thru Summit's sheaves-moved power cable spooler for better pathway and spool carrier to make room for pipe racks.Continued POH w/ESP prod string laying down 2 7/8"tb-occasionally having to overpull to free string(3 times in next 18 jts).Laid down 60 jts and reevaluated tb condition-pin and box end very good-no buildup,scale or pitting on id-no sign of pitting on tube or collar body-only sign of(slight,intermittent)pitting was on top flats of collar.POH racking back tb-at 25 stands+60 singles out(6,006'EOTs)Summit cut power cable.Changed power cable spools.POOH from 6,006'w/ESP assy racking back production tubing.1730 hrs found hole in tb and control line at 5,010'(pics in'0'drive)(btm jt in stand)-laid out both jts.Finished POOH with 2-7/8"6.5#L-80 8RD EUE production tubing standing back in derrick.M/V Titan arrived 20:00 HRS-worked boat onloading KOT mud motors and BHA basket,released boat.Summit BD and LD ESP assembly,intake-to- lower seal coupling torqued and twisted,pumps tight and rough to turn by hand.Filled hole with 6 BBL FIW.RD Summit sheaves. Cleared and cleaned rig floor,prepped for cleanout run.RD Summit spooling units.M/V Titan returns 00:00 HRS.Worked boat offloading Summit connex, flat pack and power cable spools,2 spooler skids,toolbox basket and pipe rack containing 62 joints of pulled 2-7/8"tubing and 6 pieces ESP assembly.Onloaded 4 bundles 2-7/8"production tubing.Moved KOT BHA components to rig floor.MU KOT Cleanout BHA#1(6"X-bar mill,4 3/4"mud motor,x-over to 2 7/8"8rd,5-stands tb,x-over,scraper f/7"casing,x-over to tb). Tied in rig pump and worked mud motor. 08/26/17-Saturday TIH w/KOTs clean-out BHA(6"mill w/motor-scraper spaced out 327'higher)on 2 7/8"6.5#L-80 8rd tb(from derrick),filling tb every 20 stands-total of 114 stands+BHA=7,385'.Picked up 2 7/8"6.5#L-80 8rd off deck strapping,drifting and torqueing to specs.Went thru TOL @ 7,543'no issues.Continued in 7"tagging 10'in on jt#292=9,536'.Laid down jt#292-N/U 13 5/8 x 7 1/16"spool w/ stripping head-R/U power swivel-P/U single#292 and installed stripping rubber-M/U to string and landed rubber.TIH washing/milling with#292,3.6 BPM 650 psi,PUW=67K SOW=54K.Washed/milled from 9,526'(292)to 9,682'(296)-appears to be chasing junk down hole.Washed/milled from 9,695'(297)to 9,713' with 3 stalls.Additional 8 stalls @ 9,713'-9,714'with no weight down.Shut down pump,tagged 9,714'with 5K down weight,PU to 110K and would not release.Started pump and worked pipe free. PU off bottom and circulated hole clean-370 BBL.R/D power swivel and stripper head.R/U Gill tongs.L/D single#297,TOH standing back 2-7/8"6.5#L-80 8RD EUE tubing in derrick-40-50k overpulls in every 7"casing collar.Pump 3 BBL FIW every 20 stands. 114 of 148 stands OOH at report time=2,489'. 08/27/17-Sunday Finished POH (wet)w/KOTs BHA#1(6"X-bar mill w/4 3/4"motor,scraper f/7"casing spaced out 360'above mill).B/D BHA-no unusual wear or markings on scraper,motor or mill(pics of mill in'0'drive)-scraper appears to have internal washout(leaking from around blades-ordered replacement). Took 7 bbls FIW to fill hole. M/U KOTs BHA#2(5 1/2"X-bar mill,4 11/16"x 1 1/2"DP sub,4 3/4"NOV mud motor,4 3/4"x 2 1/4"x-over sub,2 7/8"8rd pup jt,10-jts 2 7/8"8rd tb,4 3/4"x 2 7/16"x-over sub,4 3/4"x 1 1/2"DP sub,6"x 1 5/8"casing scraper,4 3/4"x 2 7/16"bit sub,411/16"x 2 3/4"x-over sub=366.13).TIH running BHA on 2 7/8"6.5#L-80 8rd tb(from derrick)to 9,682'(148 stands).Filling tb every 20 stands.Held muster and abandon platform drill directed by production.P/U power swivel and M/U#297-installed stripping rubber and screwed into string-landed rubber.Had minor issue with mud pump oiler. Washed/milled from 9,714'(#297)at 3.20 BPM 690 psi-PUW 70K SOW 54K.Washed/milled to 9,878'(#303+4')-could not work thru obstruction-decision was made to call that deep enough(scraper below pkr set depth).P/U off bottom. Circulated hole clean with FIW @ 3.20 BPM 675 psi. • • Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-21RD 50-733-20267-01 198-064 8/23/2017 9/3/2017 Daily Operations:;... 08/28/17-Monday :'`._ x, u. � < R/D power swivel-pulled stripping rubber.Laid down 6-singles with 35-40k overpulls every 30-32'.Pulled 20 stands w/same over pull- had two more overpulls at stand 30&35.Pulled to 7,446'(38 stands-97'above 7"liner top).Pumped displacement every 20 stands(3 bbls).TBI tagging at 9,839'(39'high).Laid down single(302)and P/U swivel-M/U single and installed stripping rubber-screwed into string and landed rubber.Began circ at 3.5 BPM 660 psi-washed/milled from 9,839'to 9,878'-milled for 45 mins @ 9,878'with 13 stalls-no new hole made-decision was made to cease and POOH.Backed out swivel and broke off safety valve from swivel-pulled stripping rubber with 1st jt(303).Laid down 23 jts of 2 7/8"8rd tb w/14 overpulls(10k-40k)-1730 hrs began pulling stands. 9 overpulls in 26 stands to get out of 7"casing.Pump 3 BBL FIW every 20 stands.7"scraper at rig floor.B/O and L/D KOT BHA#2.Mill 30%worn.Several tb collars(that were in 7")had flat spot on top.145 stands 2-7/8"6.5#L-80 8RD EUE tubing in derrick.Clean and clear rig floor,prep to run 2-7/8"SPM completion.Started in hole with 2-7/8"SPM completion assembly.MU WLEG and X-nipple sub according to Tripoint tally(as per proposed schematic)on 2-7/8"6.5#L-80 8RD EUE tubing.Gill tongs top door pin bracket ear broke off,swapped out Gill tongs for McCoy tongs.MU 7"packer and GLM#1,Tripoint rep on floor.TIH with 2-7/8"SPM completion assembly on 2-7/8"6.5"L-80 8RD EUE tubing.MU GLM's per Tripoint tally.MUT=2250 FPT.Drifted singles picked up under pkr then continuing to drift stands out of derrick.44(plus components)of 145 stands in hole at report time=2,868'. 08/29/17-Tuesday , rm r .,. r47:14, Tripped in hole from 2,868'w/WLEG,Xnipple,&Tripoint hyd set pkr running on 2 7/8"6.5#L-80 8rd tb-spacing out GLM as directed. Bottom 234 jts will be rerun tb(from this well)-top 62 jts will be(fresh)B-grade pipe.Installed 5 GLMs as directed(9,441',8,797', 8,247',7,608',6,748').On stand#69(4,453')drift was not accounted for and left in tb-received permission from Tripoint and reversed Teflon drift out w/7 strokes of pump-pulled that stand and redrifted tb-OK.M/U stand#69.Continue in hole from 4,453'-installed 3 GLMs as directed(5,726',4,269',2,332'). 1530 hrs M/U SSSV(to be positioned at 365')-functioned valve three times then held 5000 psi on line while finishing string M/U.Ran in 2 more stands and 6 singles=9,506'.Cut control line and N/D stripping head-M/U hanger w/landing jt and plumbed control line f/SSSV.Opened casing valve and drained stack.RIH to land hanger-PUW=68K,SOW= 46K.NOS rep started RILDS.RU Pollard SLU w/1-1/2"TS(05.'RS,2 X 5'STEM,0.67'KJ,3'OJ,7'LSSJ),NOS rep unable to RILDS,hanger is off seat.SLU RIH with 2.30"gauge ring to 9,468'SLM tag depth,POOH.SLU RIH with 1.75"gauge ring to 9,518'SLM tag depth, POOH.SLU RIH with 2.29"gauge ring to 9,472 SLM tag depth.Worked tools,bobbled and fell thru to 9,518'SLM.PUH and repeated pass down to 9,518'twice.POOH.SLU RIH with 2.30"gauge ring to 9,518'SLM,POOH.RD SLU.PU on landing joint with NOS rep on rig floor,re-orient tubing hanger.Eased down and landed hanger,NOS rep RILDS and packed off tubing hanger.Dropped bar,pumped FIW down tubing to set packer,Tubing Pressure=3800 psi.Tubing pressure fell off rapidly(under 30 seconds),no flow from IA. Repeated 2 times,same rate of pressure fall off and no flow from IA.RU SLU to RIH catch and set bar on plug seat.SLU RIH with 2"SB pulling tool to 9,513'SLM-Top of bar-close spangs to set SL tool string weight on bar.Pressured up on tubing,3800 psi,pressure fell off rapidly-2 attempts.SLU PUH lifting bar off seat,pumped to tubing with 1000 psi pump pressure,SLU set bar back on seat. Pressured up to 3800 psi-same pressure fall off.SLU POOH with bar,sealing surface of bar badly gouged and damaged(Pics on 0- drive).Ordered SL tools from Pollard. • S Hilcorp Alaska, LLC 11ilcorpAlaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-21RD 50-733-20267-01 198-064 8/23/2017 9/3/2017 Daily Operations., E. 08/30/2017-Wednesday Waiting on SL tools from Pollard.Pollard M/U S/L Run#6 2.5"GS w/1 1/2"tool string(RS,5'1 1/2"stem x 2,KJ,O&B jars,long stroke Si).TIH and pulled RHCP at 9,518'-POOH.B/0 GS&RHCP.Seat of RHCP plug has marking similar to end of prong-possible flow cut. Run#7 M/U PX plug on XLine running tool w/same tool string.TIH and set plug in Xnipple at 9,518'-POOH-B/O tools.Run#8 M/U 2" JDC and PX prong w/same tool string-TIH&set prong in plug at 9,518'.With SL in hole on prong,pressured up to 4100 psi down tb (as per Tripoint)and held on chart for 30 mins-good test.Bled pressure down to 2500 psi.Removed pump line from tb and lined up on casing valve(annulus was on vacuum)-began pumping on backside-could not pressure up-pumped away at 2.5 BPM 1200 psi. Passed info along to Eng and waited on orders.Pumped 40 bbls FIW down 9 5/8"@ 2 BPM 1100 psi-monitored 13 3/8"(140 psi w/ no increase),20"(133 psi w/no increase),26"(0 psi w/no increase)-relayed info.Pollard pulled off seat with PX prong and POOH- B/0 tools.Run#9 M/U pulling tool on same tool string and TIH-retrieved PX plug at 9,518'.POOH-R/D SL.NOS rep.B/O LDS.PU to 126K string weight,3 times,packer released and pulled free.MU 13-3/8"5M X 2'spool to annular.Pulled hanger to rig floor at 64K. L/D landing joint and hanger.Continued POOH standing back 2-7/8"6.5#L-80 8RD EUE tubing in derrick.SSSV at rig floor.Pollard reps secured and removed control lines,L/D SSSV(vertical wear marks length of SSSV,leak between top and middle subs,photos saved on 0-drive).31 stands in derrick,bottom of completion above 7"liner top at 7,506'.No overpulls while pulling out of liner.Continued POOH standing back 2-7/8"6.5#L-80 8RD EUE tubing in derrick.B/D 7"Tripoint pkr-rubbers undamaged-no marks on body-pics in 0 drive.Cleared&cleaned rig floor. 08/31/2017-Thursday ;;`; ., Prepped for BOPE test.M/U 2 7/8"test jt w/blanked&ported test plug on btm,pumpin,SV&IBOP on top-landed test plug and filled system w/FIW-shell tested to 3000 psi-worked thru minor leaks.Tested all BOPE to 250 psi low 3000 psi high as per Sundry in accordance with Hilcorp&AOGCC requirements.Tested w/2 7/8"and 3 1/2"tb. Performed successful koomey drawdown test. Witness waived by Mr.Regg verbally then followed by email 4:19 PM 8/30/17.B/D test equipment then cleared rig floor and changed out tongs.M/U Tripoint'JS'test packer(BHA#5-14.49')-TIH running 2 7/8"6.5#L-80 8rd tubing from derrick.Set 7" test packer @ 7608'- PUW 50k SOW 38k-pumped down 9 5/8" X 7"casing annulus @ 2 BPM 1100 psi- had communication through test pkr-shut down,unseated pkr.Cont RIH t/8,181'- set pkr and attempted to test casing @ 2bbls min 1100 psi- same results-communication through test pkr- shut down,unseated pkr.Continued RIH picking up 9 jts of 2 7/8" 6.5#L-80 8rd tubing.Set pkr at 9,505'and attempted to test with same results-communication through pkr,unseated pkr.POH standing back 2 7/8"tubing to test pkr. Examined Tripoint'JS'test pkr-outer rubber elements are undamaged-there is a metal to rubber seal when tool is set-both seals are bad,a piece of the rubber seal was pulled out at surface during inspection and the metal seal on btm piece was deformed.B/0 L/D pkr.M/U 9 5/8"casing scraper(BHA#6). 09/01/2017-Friday TIH w/KOTs scraper f/9 5/8"casing on 2 7/8"6.5#L-80 8rd tb to 7,548'(PM)(120 stands+9'elev+BHA).Circulated hole clean(LW) w/642 bbls FIW at 3 BPM 540 psi-very limited returns and increased pressure in two attempts to circ in reverse.POOH w/9 5/8" scraper pumping displacement every 20 stands.B/D scraper and M/U 9 5/8"Tripoint casing test tool(BHA#6).TIH w/test packer on 2 7/8"8rd tb to 7,535'(PM)Set 9 5/8 test pkr @ 7,530'-R/U and pumped down 9 5/8"casing annulus @ 2 bbls 1100 psi-No go.Shut down pump-pumped 12 bbls total-released test pkr.PUH to 6,530'-set pkr @ 6,530'and attempted to test 9 5/8"casing @ 2 bbls min w/1100 psi-No go-pumped 12 bbls away-released test pkr.PUH to 5,520'and set test pkr @ 5,520'attempted to test 9 5/8' casing @ 2 bbls min w/1150 psi- No go-pumped 12 bbls away-released test pkr.PUH to 4,530'and set test pkr-tested 9 5/8'casing to 2100 psi f/30 mins-All good-released test pkr.RIH to 5,023'and set test pkr-attempted to test 9 5/8" casing to 2100 psi-No go- pumped 12 bbls away-released test pkr.PUH to 4,961'and set test pkr-attempted to test 9 5/8"casing to 2100 psi-No go-pumped 12 bbls away-released test pkr.PUH to 4,899'and set test pkr-attempted to test 9 5/8"casing to 2100 psi-No go-pumped 12 bbls away-released test pkr.PUH to 4,836'and set test pkr-tested 9 5/8"casing to 2100 psi-All good-released test pkr.RIH to 4,867'and set test pkr-tested 9 5/8"casing to 2100 psi-All good-released test pkr.Leak located between 4,867'and 4,899'. Released test pkr. • ! Hilcorp Alaska, LLC Hilcorp Alaska.LL(: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-21RD 50-733-20267-01 198-064 8/23/2017 9/3/2017 09/02/2017-Saturday Started POOH w/test pkr standing back tb-received directions to lay down pipe keeping 2,000'of kill string in derrick.TBI to 7,349' leaving 33 stands in derrick.POOH laying down 2 7/8"6.5#8rd tb.Laid down 234jts.B/D Tripoint'JS'test packer and cleaned rig floor.RIH w/2 7/8"6.5#8rd kill string(66 jts=2062.05').M/U ciw-dcb-fbb-ccl,11 x 3 1/2'eue tubing hanger and landing jt-landed hanger(EOT @ 2,106.41')-RILDS w/string wt=16k. B/0 landing jt and laid down same-NOS set 3"type H BPV.R/D floor and removed choke&kill coflex hoses-removed driller side stairs.Packaged up hydraulic power pack-prep derrick then scoped in/laid over same.N/D BOPE-power washing as it hit deck.Began N/U tree. 09/03/2017-Sunday Finished N/U tree-NOS tested hanger void to 500 psi f/5 mins and 5000 psi f/15 mins-pulled BPV and set 2-way check-shell tested tree to 5000 psi f/5 mins-pulled 2-way check.Turned well over to production at 1100 hrs. Secured all cables in the derrick-removed drill line from draw works and placed on spool-positioned spool on derrick base-removed all tiedowns on carrier-R/D pump and rig tank,gasbuster,and driller's shack. Broke down koomey storing all hoses.Continued cleaning and prepping W/O package to be moved to King Salmon platform. 4110 Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Saturday, September 02, 2017 7:16 AM To: Quick, Michael J (DOA) Cc: Schwartz, Guy L (DOA);Juanita Lovett; Stan Golis Subject: RE: G-21rd PTD 198-064, Sundry 317-387 We found the leak at 5,000' We will install a kill string for now and evaluate design and timing for repairs thanks Original Message From: Quick, Michael J (DOA) [mailto:michael.quick@alaska.gov] Sent: Friday,September 01, 2017 4:53 PM To: Dan Marlowe Cc: Schwartz, Guy L(DOA);Juanita Lovett; Stan Golis Subject: Re: G-21rd PTD 198-064,Sundry 317-387 Dan Thanks for the update. I will be available on cell as needed at 317-2969. Call or text. Mike >On Sep 1,2017, at 3:48 PM, Dan Marlowe<dmarlowe@hilcorp.com>wrote: > Mike >As discussed this morning >We failed to get an IA test on our production packer at+/-9490' so we > pulled the completion and ran a test packer The test packer had a failure that now looks to be an internal seal failure so I don't know yet if I have a 7"casing issue or not. >Tonight we will test the 9-5/8" casing at+/-7500'and then attempt to >retest the 7" casing Depending on where we get a good test we will >re-run a completion string >Worst case we hope to be around 7500' best case we will get as close >to 9490' as possible > I will keep you informed of the outcome >A copy of the sundry is attached for your reference >thanks >Dan Marlowe > Hilcorp Alaska, LLC >Operations Engineer >Office 907-283-1329 1 P� ` o Regg, James B (DOA) From: Daniel Duckworth - (C) <dduckworth@hilcorp.com> ��i� r �)� Sent: Wednesday, August 30, 2017 2:33 PM ' t To: Regg,James B (DOA) Subject: Moncla 404 TBU G-21 RD Mr.Jim,we have landed our new completion as of 1 am this morning- in the process of testing tb and casing, we have found that we cannot hold pressure on 9 5/8"x 7" casings (packer is set at 9,460' in 7", liner top is 7,543')-we are able to pump (somewhere) at 2 BPM 1100 psi. Our BOPE test day would have been tomorrow if still running-which we may be if we're told to pull pipe. Just wanted to pass this info along(since I haven't sent in a witness request) and possible get some guidance/direction from you on test time,thanks! Damivvy DtkaaVarthi W5M @ Hilcorp Alaska/CIO dduckworth@hilcorp.com 907-776-6754 601-323-8099 • OFT • • cv-i yy�.6. THE STATE Alaska Oil and Gas �•► �� ofAT ASID Conservation Commission x 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Nur , : e. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager © A !G 2 5 2 1 j , Hilcorp Alaska, LLC �NE 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G Oil Pool, TBU G-21 RD Permit to Drill Number: 198-064 Sundry Number: 317-387 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, • Hollis S. French Chair DATED this - day of August, 2017. RBDMS L+•L ;j t 3 2017 • • EC yr; • Al: 0 9 n17 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALSt 4 ,` 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing D Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: G/L Completion 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 , 198-064 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ii 6.API Number: Anchorage,AK 99503 50-733-20267-01-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 / Trading Bay Unit G-21 RD . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730 McArthur River Field/Middle Kenai G Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,750. 9,740 . 9,899. 8,903• 2,930 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 356' 26" 356' 355' Surface 822' 20" 822' 821' 1,530psi 520psi Intermediate 5,202' 13-3/8" 5,202' 4,822' 3,090psi 1,540psi Production 7,850' 9-5/8" 7,850' 6,991' 5,750psi 3,090psi Liner 3,204' 7" 10,747' 9,737' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,614-9,935 . 8,628-8,939 2-7/8" 6.5#/L-80 9,365 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A N/A&N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 1 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9/15/2017 OIL 0 , WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe(Cahilcorp.com J , Contact Phone: (907)283-1329 Authorized Signature: LAD Date: el./1 / I 7 COMMISSION SE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 317-3 7 Plug Integrity ❑ BOP Test V/ Mechanical Integrity Test ❑ Location Clearance CI Other: 3 OO c st ALJ c' p Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ( Subsequent Form Required: /(. y OH RBDMS V/ AUu L 3 2017 APPROVED BY 1 Approved by: 4CCOMMISSIONER THE COMMISSION Date: ?'. - Il--t fika �ii� Sit,�C� aa� 1 �? �� 0 I ` 17 Submit Form and Form 10-403 Revised 4/20111G a�p1ti�ialid for 12 months from t e date of approval. Attachments in Duplicate 111 • 4111 Well Work Prognosis Well: G-21rd Mem)Alaska,IAA: Date: 08/03/2017 Well Name: G-21rd API Number: 50-733-20267-01 Current Status: ESP Producer Leg: Leg#3 SE Corner Estimated Start Date: September 15, 2017 Rig: Moncla 404 Reg.Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 198-064 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907) 777-8356 (0) Current Bottom Hole Pressure: 3,793 psi @ 8,628'TVD 0.440 lbs/ft(8.45 ppg) based on ESP Gauge SIBHP Maximum Expected BHP: 3293 psi @,8,628'TVD 0.440 lbs/ft(8.45 ppg)based on ESP Gauge SIBHP Maximum Potential Surface Pressure:(2,930 psi** Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) **This is a No-flow well as of 05/02/2015 Brief Well Summary G-21rd is a G zone producer completed with an ESP installed in March 2015. This workover will replace the failed pump with a gas-lift completion. ✓ Last Casing Test: 03/20/2015 Tested casing at 9,407'to 1,500 psi for 30 minutes on chart 14'- I6"514�• / Procedure: lJ 1. MIRU Moncla 404 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production. If necessary, RU e-line and RIH to±9,350' and punch tubing. Work over fluid will be FIW. BOP's will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/3,000psi high/2,500 Annullar. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. cs�s 5. Unseat hanger and POOH with ESP completion. � /31010›. 6. RIH w/casing scraper to ±9,500' 7. PU and run Gas Lift completion. z_zh c / v•)j- /7 8. Set and test packer tc : psig charting for 30 minutes. 9. Set BPV. NU tree,test same, turn well over to production. 10. Schedule SVS testing with AOGCC as per regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Diagram Current 4. Wellhead Diagram Proposed 5. BOP Drawing 6. Fluid Flow Diagrams 7. RWO Sundry Revision Change Form 11 • • SCHEMATIC McArthur River Field,TBU Well: G-21RD Ilflc"rp:Uaak".�.I C PTD: 198-064 API: 50-733-20267-01 Completed: 03/25/2015 CASING DETAIL SIZE WT GRADE Conn ID TOP BTM. RKB 42.15 26" Surf 356' 20" 94 H-40 Butt 19.124" 41.98' 822' 13 3/8" 61 K-55 Butt 12.515" 42.60' 2,431' 26 4, , 68 K-55 Butt 12.415" 2,431' 5,202' 740 N-80 Butt 8.835" 40.60' 62' � 9-5/8" 47 N-80 Butt 8.681" 62' 98' 40 N-80 Butt 8.835" 98' 1,336' 47 N-80 Butt 8.681" 1,336' 7,850'(TOW) 7" 29 N-80 Butt TKC 6.184" 7,543' 10,747' TUBING DETAIL 20"Cmt L IgM? , 2-7/8" 6.5# L-80 8 rnd EUE 2.441" Surf 9,365' to Surf DV at 2,595' (13-3/8") . r: Jewelry Detail .f,'`. „ No Depth Depth ID OD Item 13-3/8 MD TVD Cmt to Surf V .� ''i / Hanger ` 1 9,365' 8,389' 2.441 Discharge,Bolt-On `.'*.,. 2 9,367 8,391' 4.000 Pumps 3x-125 Stage SF-2250,Pump lx-76 9-5/8"TOW Z , Stage SF2500 @ 7850' 3 9,455' 8,476' - 4.000 Gas Separator x2 4 9,459' 8,479' - 4.000 Seals BPBSL 5 9,476' 8,496' - 4.560 Motor-Corsair FMS 240HP/2975V/58A 6 9,513' 8,531' - Gauge(GRC-3500)/Anode/Centralizer 1 2 iit 3 iii 45 i Perforation Detail ,, 1' 6 Top Btm Top Btm Zone (MD) (MD) (TVD) (ND) Amt SPF Date G-1 9,614' 9,645' 8,628' 8,658' 31' 2-1/2",6spf 6/11/1998 G-1 9,615' 9,635' 8,629' 8,649' 20' 2-1/2"4 SPF 05/04/2008-DIL - 6-1 9,620' 9,630' 8,634' 8,644' 10' 4 SPF 03/23/2015 +' G-1 9,625' 9,640' 8,638' 8,653' 15' 2",4spf 02/04/2004 G-1 9,675' 9,685' 8,687' 8,697' 10' 4 SPF 03/23/2015 G-1 G-2 9,668' 9,688' 8,680' 8,700' 20' 2%"4 SPF 05/04/2008-DIL } thru G-3 9,737' 9,767' 8,747' 8,776' 30' 24/2",6spf 6/14/1998 G-5 G-3 9,750' 9,768' 8,759' 8,777' 18' 2'A"4 SPF 05/04/2008-DIL .:..., G-3 9,755' 9,765' 8,764' 8,774' 10' 2",4spf 02/04/2004 '4i G-3 9,756' 9,766' 8,765' 8,775' 10' 4 SPF 03/23/2015 ht G-4 9,784' 9,794' 8,792' 8,802' 10' 2''A"4 SPF 05/04/2008-DIL `" G-4 9,785' 9,793' 8,793' 8,801' 8' 2",4spf 02/04/2004 Landing , G-4 9,800' 9,815' 8,808' 8,822' 15' 2'A"4 SPF 05/04/2008-DIL Collar at w t G-4 9,800' 9,832' 8,808' 8,839' 32' 2-1/2",6spf 06/14/1998 10,662' / \ 6-4 9,808' 9,818' 8,816' 8,825' 10' 4 SPF 03/23/2015 G-4 9,825' 9,833' 8,832' 8,840' 8' 2'A"4 SPF 05/04/2008-DIL G-4 9,825' 9,835' 8,832' 8,842' 10' 2",4spf 02/04/2004 G-5 9,894' 9,964' 8,899' 8,967' 70' 2-1/2",6spf 06/03/1998 TD= 10,750' G-5 9,896' 9,906' 8,901' 8,911' 10' 2",4spf 02/04/2004 Max angle=36°@ 6,600' G-5 9,925' 9,935' 8,929' 8,939' 10' 4 SPF 03/22/2015 Updated: 04/24/15 by ILL . n • • McArthur River Field, TBU nm,...,,,i,,.k,,.,.i.+ PROPOSED Well: G-21RD PTD: 198-064 API: 50-733-20267-01 Completed: FUTURE CASING DETAIL SIZE WT GRADE Conn ID TOP BTM. RKB 42.15 26, Surf 356' + x 20" 94 H-40 Butt 19.124" 41.98' 822' ear ta' 26" S«`, I 13-3/8" 61 K-55 Butt 12.515" 42.60' 2,431' L 68 K-55 Butt 12.415" 2,431' 5,202' 40 N-80 Butt 8.835" 40.60' 62' ' 9-5/8" 47 N-80 Butt 8.681" 62' 98' 40 N-80 Butt 8.835" 98' 1,336' 47 N-80 Butt 8.681" 1,336' 7,850'(TOW) �" 7" 29 N-80 Butt TKC 6.184" 7,543' 10,747' TUBING DETAIL 20"Cmt r'> ' 2-7/8" 6.5# L-80 8 rnd EUE 2.441" Surf ±9,550' to Surf DV at 2,595' (13-3/8") Jewelry Detail i .: No DMDh Depth ID OD Item TVD 13-3/8" ' 'i „ 1-8 )/ Hanger Cmt to Surf.` • ?> 1 ±2,351' ±2,350' 2.441 GLM#1 2 ±4,259' ±4,050' 2.441 GLM#2 «i. 3 ±5,722' ±5,250' 2.441 GLM#3 9-5/8" TOW - 4 ±6,758' ±6,100' 2.441 GLM#4 @ 7850' .L :+e`1- 5 ±7,620' ±6,800' 2.441 GLM#5 I K 6 ±8,261' ±7,350' 2.441 GLM#6 �t,S r 7 ±8,797 ±7,850' 2.441 GLM#7 8 ±9,460' ±8,423' 2.441 GLM#8 , 9 ±9,490' ±8,509' Packer 10 ±9,520' ±8,538' 2.313 X-Nipple 1 11 ±9,550' ±8,567' Tail/WLEG i' 4. ilm g X f Perforation Detail tk 10 Top Btm Top Btm +'4t 11 Zone (MD) (MD) (ND) (TVD) Amt SPF Date G-1 9,614' 9,645' 8,628' 8,658' 31' 2-1/2",6spf 6/11/1998 G-1 9,615' 9,635' 8,629' 8,649' 20' 2-1/2"4 SPF 05/04/2008-DIL 4 ' - G-1 9,620' 9,630' 8,634' 8,644' 10' 4 SPF 03/23/2015 G-1 9,625' 9,640' 8,638' 8,653' 15' 2",4spf 02/04/2004 G-1 9,675' 9,685' 8,687' 8,697' 10' 4 SPF 03/23/2015 G-1 G-2 9,668' 9,688' 8,680' 8,700' 20' 2'/:"4 SPF 05/04/2008-DIL ,* thru G-3 9,737' 9,767' 8,747' 8,776' 30' 2-1/2",6spf 6/14/1998 -* G-5 G-3 9,750' 9,768' 8,759' 8,777' 18' 2''A"4 SPF 05/04/2008-DIL +:v G-3 9,755' 9,765' 8,764' 8,774' 10' 2",4spf 02/04/2004 1, G-3 9,756' 9,766' 8,765' 8,775' 10' 4 SPF 03/23/2015 ' G-4 9,784' 9,794' 8,792' 8,802' 10' 2'A"4 SPF 05/04/2008-DIL G-4 9,785' 9,793' 8,793' 8,801' 8' 2",4spf 02/04/2004 Landing G-4 9,800' 9,815' 8,808' 8,822' 15' 2'A"4 SPF 05/04/2008-DIL Collar at +t G-4 9,800' 9,832' 8,808' 8,839' 32' 2-1/2",6spf 06/14/1998 10,662' '' N G-4 9,808' 9,818' 8,816' 8,825' 10' 4 SPF 03/23/2015 G-4 9,825' 9,833' 8,832' 8,840' 8' 2'A"4 SPF 05/04/2008-DIL G-4 9,825' 9,835' 8,832' 8,842' 10' 2",4spf 02/04/2004 6-5 9,894' 9,964' 8,899' 8,967' 70' 2-1/2",6spf 06/03/1998 TD= 10,750' G-5 9,896' 9,906' 8,901' 8,911' 10' 2",4spf 02/04/2004 Max angle=36°@ 6,600' G-5 9,925' 9,935' 8,929' 8,939' 10' 4 SPF 03/22/2015 Updated: 08/01/17 by JLL • S . II Grayling Platform G-21 Current ESP Hilrnrp Atomics',1.1.(: 08/08/2017 1 Grayling Platform Tubing hanger,CIW-DCB-ESP, G-21 li X 3'/EUE lift and susp,w/ 13 3/8 X 9 5/8 X 3 1/2 3"type H BPV profile,5'/.EN, 2-3/8 continuous control line ports,prepped for BIW penetrator BHTA,Bowen,3 1/8 5M FE X 3" Bowen Quick Union III 3 nl Am III.—In Valve,swab,WKM-M, 3 1/8 5M FE,HWO, = ,', 43 T-24 Cria I.I ON .in *Mk Valve,wing,WKM-M, �4' - I� i 2 1/16 5M FE,HWO, tig*114. .w�� � ! Q _ I Valve,WKM-M,3 1/8 SM FE,w/ T-24 - ohs '} MA-16 operator L _ Il III}/fitI.I k � Valve,lower master,WKM-M, -,® . 3 1/8 5M FE,HWO,T-24 IRI MI III IIIIII Adapter,CIW-Toadstool, 11 5M Stdd X 3 1/8 5M FE,prepped for r 5'/<ESP neck,2-%2 npt continuous .� I control line ports Tubing head,CIW-DCB, e.'sll 13 5/8 3M X 11 5M,w/ a is: 2 1/16 5M SSO, III �1 lel Valve,WKM-M,2 1/16 5M FE, X bottom {� �ass •' " '2-- in HWO,DD I �) L.1,.-: ■ � Q p�I I '� a Qty 2 i n ____, 111 i = ma { Casing head,CIW-WF, .'6 Valve,CIW-F,2 1/16 3M FE, 13 5/8 3M x 13 3/8 SOW w/ 1#1 I !;; i til AAtrim )111ilw�.1.. • 0 • siltGraylin. ' . _ , m G Proposed 081 : ! Hileurp:tlnrka,IAA. Grayling Platform Tubing hanger,CIW-DCB- G-21 FBB-CCL,11 X 3 1/2 EUE lift 133/8X95/8X31/2 and susp,w/3' type HBPV profile,6'EN,2-%npt CCL ports BHTA,Bowen,3 1/8 5M FE X 3" Bowen Quick Union O . .11�.11._�1 II Valve,Swab,CIW-FC, ,1 * 3 1/8 5M FE,HWO, g;NT'EE trim * •, Valve,SSV,FC,3 1/8 5M FE, Ow/15"Safeco oper-air IN • operated /, U, 0 .111.r Valve,Upper Master, "O CIW-FC,3 1/8 5M FE,HWO, " .2C EE trim Lail,. .,..,,,salt. It ,1�1b. Valve,Master,CIW-FC, OO 3 1/8 5M FE,HWO,EE trim N,1T' VO Adapter,CIW-EN-CCL,11 5M .•11ii l 10 x y Stdd x 3 1/8 5M,prepped for '4'1: 6,� '''AENand2-'AnptCCL '\\l _ ports,EE material Tubing head,CIW-DCB-S, �1— 13 5/8 3M X 11 5M,w/2- 24I I 1 11c Valve,WKM-M,2 1/16 2 1/16 5M SSO,X-bottom 1l1 1I1 5M FE,HWO,AA prep Qty 2 3,„ 111 cal illI Casing head,CIW-WF, if 'i ” Valve,CIW-FC, 135/83MX133/8"SOW • 2 1/16 5M FE,HWO,AA bottom,w/2-2 1/16 5M I11 ® r 1n1 EFO = el r r - II I I.h!I(1! 1h1 ,i Grayling Platform ‘ ll 2016 BOP Stack Moncla Htimerp Alaska,Is05/13/2016 111 lit lit Iitiii mg 4.54' °Ow Hy�a5driit114 GK13.5ggG ill tit it! 2 7/8-5.5Shaffer SL - variables 1111“111111 2.83' 0 0 _._. 0 (171 E\ 13 5/8 SM Blinds O® O 0 Choke and Kill valves ,�• IF Wring 1�1.l1 1�1 0 �. 21/1 5M 2.26' i it' / '1 -i Mud Cross 7-les : ' r ' 'I'� 7'� I�4 1/16 5M EFO x i 1J.•.�: II 1.1t1.if6111.1;1 --,',—; 110 — IX Ili TV LLIJ Riser 13 5/8 5M FE X 13 5/8 5M FE 14.20' III iil Iii lil 111 Spacer spool 1 1 I 1 I 1 1 I 1 1 t 1 1[I 135/8 SM FE X 11 SM 2.75' III Iii lil lii Ill • • V • Y o O o u o u OQUO o u o u o u o V u o u u o 2 - a m 'V in N Ln ID N CO m 2 a d v U u u v u u V u 0 ay N m Cr 01 al aH N m d' V1 LD h CO 01 a-1 O o 0 0 U ,-.4 O O D O O O O O O - v G i C d N C cc C C C C 'C C OL O j 1, E E g E EJ Jc ov Y 0a03 03 aaa03 v w t c .. a ' 2 2 u 0 0 0 0 0 0 ,1v> aa a YY2u uuuuuuuuuui2 v0 I!; U L . 14 14 N m .C2 L.L 0- CC Law a0 M . 't .• Z0 II 14 CC O CC O W 0 d LL �> N ■ :U 2< In I_ _... . .. .. _ to. Y III , 1.- . O ¢ m m F w Ha E. • 0 z u) z 0 o z Uw Z CO oH 1-11 a .41aC� A 0_ "(:D [ CO D z o O CD F- d" 0 FL- Z < -d" C7HzQ QQ �nD W U D .- < 00z ° J --I ... W oaaw � W ET i zZW a: ;D Z Q m J ~ ci U V rt U u • 0 O u O u 0 O O u 0 O u O u O u O u u O u u O 0 o .-1N C to , ;--,-- N m a t.0 I. CO Ol 2 a EL CL 1 1 - U U U U U U U U U O ry m v in v ti ry m a , to i. CO m .-I v v a U v 0 -o -0 -0 9 U -0 'O 9 U U 0 0 0 0 0 0 0 o 0 0 0 0 0 o v u ry o o cEEE . E J Y UN W N v y w v m m t �. uo Lo000 ° o00o ' w> � d2a a i = u u u u U U u V U u U ,, g vt a 9 v u 2 m O Ln _ co - O W az L1.1 Y Q aO N) , "4- ZO 00 - ¢U II H fJCC 2> W d 0 h H ■ T.0 m ;I ni - Y Ai — CL O Q u DO i- CO W Ha a 0 z Q u) a J D O Z I 0w a0z 0 j 411J CI) :J- Z Z ❑o H � a A 8 00 = a — Z N < COOMOO V D4 kV OO Z I aJ O O g g yw IL Z 0 OS z 1-OZ 0 5 I a • • Moncla Rig 404 BOP Test Procedure • trleorpAlaska,LLC Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, 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 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.) • • Moncla Rig 404 BOP Test Procedure • Hileorp Alaska,LLC Attachment#1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug)in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1st valve on standpipe manifold,close valves 1, 2, 10 on choke manifold and close the annular preventer,open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer,close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross, open 1st valve of standpipe, close valves 3,4&9 on choke manifold, open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross,close valves 5 &6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to 1200 psi and bleed off 200—300#s recording change and stabilization. If passes after 5 minutes, bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross), open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. • • Moncla Rig 404 • BOP Test Procedure Ililrp Alaska,LLC Attachment#1 g) Close inside valve/open outside valve(HCR)on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold, close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams,and HCR. Close 2nd set of pipe rams if installed (e.g.dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP,FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424)in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. • • -0 .m C; o6 Vaca c a)s 0 o E U U Q Qa E N Q E• o) ow c C) a• oai 2 am c T a L - -a 4) c L � � a) N Q 2 L = 0 0 c) a_ m .(r ) � - o o N Nr LZ U a� coim ma'>- c• o Z & c .c CD op . o a o TD o CD I- -0 L V a -0 Q m al a cG 20 L r a) C) N Q.•` CU 10 _ t m mU 0 0 m 4° a � m Q mE o a = ,'f' C 0 U O d o � a v a) c `i .n o L a _ C) CU d _ �,i m c ,� � c a) c w Uu) 0 ao � o oa)v Q. Q� R CU � O L a , � ctQ • o 0 m C. ai 0x U� X C -- OL03 O. im N N MO y t X 0 - N i. U U a Q ii CGO *k _0 .'�.y Q ''' p U 2 ..�" ,� a -a E U ° Q I.- C7 v I-LI 03 V O Q N Q a. • • ' Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday,August 22, 2017 9:32 AM To: Dan Marlowe Cc: Juanita Lovett Subject: RE:G-21rd Gas lift RWO (PTD 198-064) Dan, You have verbal approval to move rig over ASAP to G-21 due to wellhead leak as proposed in your sundry application. Only change to the procedure will be to test the production casing to 2000 psi before converting to gas lift. Also,with penetrator leaking the Initial BOPE test will have to be a rolling test...this is covered in the sundry contingency section. Regards, 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). From: Dan Marlowe [mailto:dmarlowe@hilcorp.com] Sent:Tuesday,August 22,2017 8:53 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Juanita Lovett<jlovett@hilcorp.com> Subject:G-21rd Gas lift RWO(PTD 198-064) Guy Compressor shut-down is set at 1310 psig so 1.2 x 1310= 1,572 psig As discussed,when testing the tree void this week the cable penetrator jumped approximately 4" and began leaking gas. We bled all pressure off the tubing and the IA and then circulated the oil off the IA. We request verbal Sundry approval to begin work on this one tonight to mitigate the issue Thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Email DMarlowe a(�hilcorp.com 1 + • • Hilcorp A Company Built on Energy From:Schwartz,Guy L(DOA) (mailto:guy.schwartz@alaska.gov] Sent:Tuesday,August 22,2017 8:30 AM To: Dan Marlowe<dmarlowe@hilcorp.com> Subject:G-21 Gas lift RWO(PTD 198-064) Dan, In reviewing the sundry to workover G-21 was wondering what your gas lift header pressure was. Want to make sure the casing is tested at least 20%above max pressure it will see. 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). 2 PtiOF ? • • I77, • THE STATE Alaska Oil and Gas 64,; � of LASI�;A Conservation Commission A 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pv Main: 907.279.1433 ALA`3� Fax: 907.276.7542 www.aogcc.alaska.gov February 10, 2016 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 SCANNED MAY 1 9 2016 RE: No-Flow Verification Trading Bay Unit G-21 RD PTD 1980640 Dear Mr. Golis: On May 2, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit G-21 RD 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-21 RD prior to the test. The well performance was monitored for three hours with resulting gas flow rate below the regulatory limit and zero liquid flow to surface, passing the no-flow test. Verbal approval was granted by the AOGCC Inspector to return the well to production 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-21 RD 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, Jac- James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors i r MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg zit DATE: February 9, 2016 P. I. Supervisor FROM: Johnnie Hill SUBJECT: No Flow Test Petroleum Inspector TBU G-21 RD Hilcorp Alaska LLC PTD 1980640 2/9/2016: After the flight to the Grayling Platform I was greeted by the Production Operator Wayne Johnson. We reviewed the well condition and their planned no flow test procedure. This test was run simultaneous with the no-flow test on TBU G-28RD. Well G-21 RD had been shut-in the previous day and depressured with the tubing and inner annulus open to communication and the flow line isolated from production. Test equipment was plumbed from the top of the tree cap through a 1/2" nipple up to a 3/4" x 3/" tee with a 0-30 PSI calibrated gauge and out to a 1" ball valve just upstream of the meter. The 1" flowline terminated through a crowfoot connection to an open-top barrel. The meter was an ERDCO Armor-Flow model 3461-03T0-13 scaled 0-1800 SCFH. Initial pressure and rates were taken and the tubing was closed upstream of the meter to start the test. The pressures were documented and the well was open to flow after 1 hour (open valve to allow the well to depressure). Flow rate and pressures were documented at 30-minute intervals for the next two hours. The following table shows test details: Time Pressures Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 830 0.5/0/11 700 0 Tubing open to vent 900 2.3/0/11 0 0 Shut tubing upstream of vent 930 4/0/11 1800 0 Open tubing; initial rate 1000 0.5/0/11 1200 0 Tubing open 1030 0.5/0/11 1100 0 Tubing open 1100 0.5/0/11 900 0 Tubing open 1130 0.5/0/11 750 0 Tubing open 1 Pressures are T/IA/OA Summary: No liquid was seen during the test. Gas rates steadily dropped below the maximum allowed rate after 1.5 hours of flow to atmosphere. TBU G-21 RD exhibits the characteristics of a passing no-flow test. Attachments: Photos (3) SCANNED SEF' 2 1 LU1t 2015-0502_No-Flow_TBU G-21 RD_jh.docx Page 1 of 3 0 i No-Flow Test—TBU G-21 RD (PTD 1980640) Photos by AOGCC Inspector J. Hill 5/2/2015 ql, , ...... it, „.: ...„, ..... ....... ....,..... ,.. .,«44.4.444 . ,.,-,,i,::, a ,..,1)...s.,* .. :,, ,. ,,, . Armor-FYo4 "` -$',::::;i.....:5.-4,.!•.A...:.; , f S# gg rrte�. K till = 1 111)C0 ' i1 I 14 az7 a„ 2015-0502_No-Flow_TBU_G-21 RD,jh.docx Page 2 of 3 • S Ir ; if i if v X iS r .. r a` - 1,1lhow. libiiiiii . „,..„ irMI, iiix tir 2015-0502—No-Flow ,j _TBU_G-21RDh.docx Page 3 of 3 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, January 29, 2016 9:43 AM To: 'Dan Marlowe' Cc: Juanita Lovett;Trudi Hallett; Stan Golis; Regg,James B (DOA) Subject: RE: G-21rd ESP Makeup water(PTD-198-064) Dan, Thanks for clarifying. I don't see any issues as long as there is a check valve as close as physically possible to the wellhead on G-21RD. ( I didn't see one on the P&ID you supplied). AOGCC will approve installation with the check valve stipulation . I would be curious to hear how this ESP water makeup works once in place. Regards, Guy Schwartz % ED JUL 2 5 2.016 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(Guv.schwartz@alaska.gov). From: Dan Marlowe [mailto:dmarloweOhilcorp.com] Sent: Friday, January 29, 2016 9:04 AM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett; Trudi Hallett; Stan Golis; Regg, James B (DOA) Subject: RE: G-21rd ESP Makeup water(PTD-198-064) Guy You are correct that no line is bullet proof.This would be very similar to numerous other 3/8"stainless lines, pressure gauges, chemical injection taps, or even steel gas lift lines, hooked to all other wells. We typically install a check valve as close to the tree as possible to minimize the hazard. Ultimately any gas leak will be detected by our gas detection system.This annulus typically will run about 170 psi where a gas lift well will be around 1200 psi. The water rate will be metered with FE-23 shown on drawing G-F-1003-001 which reads both live rate and daily total. The volume will be controlled by a manual valve based on what our downhole pump gauges are telling us.This volume will then be deducted from the gross volume of our well test to accurately report production volumes From: Schwartz, Guy L(DOA) [mailto:guy.schwartz(aalaska.gov] Sent: January 28, 2016 4:38 PM To: Dan Marlowe Cc: Juanita Lovett; Trudi Hallett; Stan Golis; Regg, James B (DOA) Subject: RE: G-21rd ESP Makeup water(PTD-198-064) 1 • • Dan, Looked over the attachments.. one issue I see may be that the 3/8" line could be broken accidently thereby it would vent gas from annulus.( 3/8" line is not exactly bullet proof). The SSV in the 3/8" line would only close due to production line break. How would the line be protected from getting damaged along its route? How is water rate metered and adjusted? Regards, 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). From: Dan Marlowe [mailto:dmarlowe(ahilcorp.com] Sent: Thursday, January 28, 2016 10:22 AM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett; Trudi Hallett; Stan Golis Subject: G-21rd ESP Makeup water (PTD-198-064) Guy As discussed, Our G-21rd ESP is struggling due to not enough inflow to keep the ESP in curve and stable. We would like to add a few hundred bbls of FIW down the backside as suction make-up for the pump.This line will have a flow meter so we can properly allocate our well tests and will have a solenoid valve on the 3/8" line.This solenoid valve (injection water SSV)will be tied in so that it shuts when the flowline SSV shuts to protect the wellbore. Let me know if you have any further questions. Thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe@hilcorp.com Hilcorp A Company Built on Energy 2 111 0 SCHEMATIC • McArthur River Field, TBU Hfl,nrp�Ia.A".l i i Well: G-21RD Completed: 03/25/15 RKB 42.15 CASING DETAIL ..] SIZE WT GRADE TOP BTM. 26" Surf 356' 20" 94# H-40 Surf 822' 13-3/8" 61/68# J-55 Surf 5201' 9-5/8" 40/47# N-80/P Surf 7,930' L 7" 29# N-80 7543' 10,747' DV at 2,595' TUBING DETAIL 2-7/8" 6.5# L-80 Surf 9,365' / Z , Jewelry Detail No Depth ID Item KOP for L sidetrack Hanger At 7850' 1 9,365' 2.441 Discharge,Bolt-On 2 9,367' - Pump(3)-125 Stage,Pump(1)-0760 Stage 3 9,455' - Gas Separator 4 9,459' - Seals 1 5 9,476' - Motor-456 Series IIII 2 6 9,513' - Anode 4 111 5 Perforation Detail 6 Top Btm Top Btm Zone (MD) (MD) (TVD) (TVD) Amt SPF Date G-1 9,614' 9,645' 8,628' 8,658' 31' 2-1/2",6spf 6/11/1998 G-1 9,615' 9,635' 8,629' 8,649' 20' 2-1/2"4 SPF 5/4/2008-DIL 6-1 9,620' 9,630' 8,634' 8,644' 10' 4 SPF 03/23/15 G-1 9,625' 9,640' 8,638' 8,653' 15' 2",4spf 2/4/2004 G-1 9,675' 9,685' 8,687' 8,697' 10' 4 SPF 03/23/15 G-1 G-2 9,668' 9,688' 8,680' 8,700' 20' 2 W'4 SPF 5/4/2008-OIL thru G-3 9,737' 9,767' 8,747' 8,776' 30' 2-1/2",6spf 6/14/1998 G-5 G-3 9,750' 9,768' 8,759' 8,777' 18' 2 W'4 SPF 5/4/2008-DIL G-3 9,755' 9,765' 8,764' 8,774' 10' 2",4spf 2/4/2004 G-3 9,756' 9,766' 8,765' 8,775' 10' 4 SPF 03/23/15 G-4 9,784' 9,794' 8,792' 8,802' 10' 2 W'4 SPF 5/4/2008-DIL 6-4 9,785' 9,793' 8,793' 8,801' 8' 2",4spf 2/4/2004 Landing9,815' 8,808' 8,822' 15' 2 W'4 SPF 5/4/2008-DIL ` Collar at <- G_q 9,800'G-4 9,800' 9,832' 8,808' 8,839' 32' 2-1/2",6spf 6/14/1998 10,662' / \ 6-4 9,808' 9,818' 8,816' 8,825' 10' 4 SPF 03/23/15 G-4 9,825' 9,833' 8,832' 8,840' 8' 2 34"4 SPF 5/4/2008-DIL 6-4 9,825' 9,835' 8,832' 8,842' 10' 2",4spf 2/4/2004 6-5 9,894' 9,964' 8,899' 8,967' 70' 2-1/2",6spf 6/3/1998 TD=10,750' G-5 9,896' 9,906' 8,901' 8,911' 10' 2",4spf 2/4/2004 Max angle=36° 6,600' G-5 9,925' 9,935' 8,929' 8,939' 10' 4 SPF 03/22/15 Updated: 04/24/15 by JLL s e i I I D m m M m 2 n rn y �g D Z - r N 0 0 M ' — �, Nye In I „,,,,,r,...%,,,",,1 N .-. /'\P IFIL ..:(-i._S ,”,, ]I. .. IIP \ji p-__Iii i F i'."-. i4K�1 �lG Ma r O 441 OQ sN _ 4_ _4 ?,IE xa"� z:!'2 E o'§ 8 4 44 mi. % :... , nn 41 C' 1 - J. C' 8S8< �� 2i Ili m `/v„,..--c_., ..P` c' (.. :-,moi y 1,_'r k"' K'�iiv-ioni j. rgg ItA i N Ili i( § "i_ 4 ,',-, " :.-•?. '''.:/': larl'-jiiv'----(---*'-'---;'(-:1).;--,-2'.-- t-. eC:3'-..T\ f71 B' 1 t� .) r., a Q itilli'•i . ,z r --Tr-t-11-1-;.--�,,, 1r t $ ,g �� , ; a v I . 46 441 L X © 14, i 'Pz a) col sii 7 > 8- 1 4 28 43 10. i 4Z 0P a --i 8 CD Ni yrr € D ; 2R 4 r �o m5A C P. 4,i to8 C- p ° Z t o cZ D _ O2 ti —1 ' I. 62,C dJ. N; r 1 • • p§T,4E eI m g m 31 R' RI }n m ` A '4 xr `IPo 'K t J a' 1,, S IDA.„,,, til 4 gP 1,611 fir 1H ' I ' invvo-mCi i I CA 1 Z b Q e 1. 5` E L INN --rd_ 4 ,.4 og< a > FIIQ a a= 02 t a cep ' NO 5" a r.-.gar-i ,' .r'' O 3 ;' l SII ^�_. AP j• 7I_1 R SO ?�i ...4. ;II S I. V, =� _.;48 ;c9 1 r(). et ir , , ,, (::: ),,,‘ ; _...... • 0,„„...;, 11111 I R 4 ( 'Vr_.. s ►� II.: '!IITTT 4 4 S MI g fp�yL x m III/Di (A 4 0 mm D mr- x ._< i F ,o_9 0 1 ^1,z -3 Sm 0o NOv 'T7 N Q o uu� V o i o - 4 61 Schwartz, Guy L (DOA) 166r/O(PLI From: Schwartz, Guy L (DOA) Sent: Wednesday, April 29, 2015 10:26 AM To: 'Juanita Lovett' Cc: Daniel Taylor; samantha.carlisle@alaska.gov Subject: RE: Please withdraw: Sundry#315-154/ G-21RD PTD: 198-064 Juanita, AOGCC will withdraw Sundry 315-154 to perforate as requested below. Fill Cleanout of well was under sundry#315- 086. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell SCANNED MAY 0 42015 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(Guv.schwartz@alaska.gov). From: Juanita Lovett [mailto:jlovett@hilcorp.cor; ] Sent: Friday, April 24, 2015 2:41 PM To: Schwartz, Guy L (DOA) Cc: Daniel Taylor Subject: Please withdraw: Sundry # 315-154/ G-21RD PTD: 198-064 Guy, While cleaning out G-21rd under Sundry#315-086 we were unable to get past 9,989'.Therefore, please withdraw Sundry#315-154(add perforations in the HK-1 bench from 10,113'—10,130') as we were unable to reach the depth necessary to perforate. 03/21/15-Saturday CONTINUE POOH. LAY DOWN PACKER AND MULE SHOE. FILLED HOLE 212 BBLS. PULLED WEAR BUSHING. INSTALLED TEST PLUG. TEST BOP'S AS PER AOGCC AND HILCORP SPEC/S 250 LOW 3000 HIGH.TESTED ON 3 1/2"AND 2 7/8"TBG. ALL TEST GOOD. ( NOTE PERMISSION GIVEN TO TEST BOP'S EARLY DUE TO CHANGES IN PROCCEDURE.JIM REGG W/AOGCC, WAIVED WITNESS). PULLED TEST PLUG AND INSTALLED WEAR BUSHING. PICKED UP BHA#5 5 3/4" OCEAN WAVE WASH PIPE SHOE W/CABLES,WASH PIPE EXTENSION,TOP BUSHING, BUMPER JAR, OIL JAR, 6 4 3/4" DC,X-O. TRIP IN HOLE WITH 3 1/2" PH6 WORK STRING TO 9,900'. INSTALL STRIPPER RUBBER. P/U POWER SWIVEL. BEGAN WASHING F/9,917'TO 9,989'. AT 9,989' HOLE TIGHT STARTED TO TORQUE UP, HANGING UP, HAVING TO JAR LOOSE. MADE SERVERAL ATTEMPTS TO GET PAST BAD SPOT WITH NO SUCCESS. CIRC HOLE CLEAN IN REVERSE POSITION. R/D POWER SWIVEL.PULL STRIPPER RUBBER. Thank you, Juanita Lovett Operations/Regulatory Tech 1 • Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Office: (907)777-8332 Email: jlovett@hilcorp.com 2 STATE OF ALASKA • AL...,.<A OIL AND GAS CONSERVATION COMA.._�SION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate CI Other CI Install ESP Performed: Alter Casing ❑ Pull Tubing CI Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory El 198-064 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphik❑ Service ❑ 6.API Number: ` ' Anchorage,AK 99503 50-733-20267-01 CEI\wJ ED 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018730 Trading Bay Unit G-21 RD APR 2 4 2 015 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Middle Kenai G Oil Pool / Q3 CC 11.Present Well Condition Summary: Total Depth measured 10,750 feet Plugs measured N/A feet true vertical 9,740 feet Junk measured N/A feet Effective Depth measured 9,899 feet Packer measured N/A feet true vertical 8,903 feet true vertical N/A feet Casing Length Size MD ND Burst Collapse Structural Conductor 356' 26" 356' 355' Surface 822' 20" 822' 821' 1,530 psi 520 psi Intermediate 5,201' 13-3/8" 5,201' 4,822' 3,090 psi 1,540 psi Production 7,930' 9-5/8" 7,930' 7,075' 5,750 psi 3,090 psi Liner 3,204' 7" 10,747' 9,737' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet �r pN�Ep tA�} h) 3 0 2. 15. Tubing(size,grade,measured and true vertical depth) 2-7/8" �ol� 6.5#/L-80 9,365'(MD) 8,389'(ND) Packers and SSSV(type,measured and true vertical depth) N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 142 38 393 650 110 Subsequent to operation: 76 66 381 74 114 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil p Gas ❑ WDSPL❑ GSTOR El WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-086 Contact Dan Taylor /' Email dtayloranhilcorp.com Printed Name Dan Taylor �i Title Operations Engineer Signature — Phone (907)777-8319 Date 4/24/2015 RBDMS j APR Z H 2015 Form 10-404 Revised 10/2012 1/-2 -,S. Submit Original Only 4 `171'//1 til SCHEMATIC McArthur River Field,TBU Well: G-21RD Completed: 03/25/15 RKB 42.15 CASING DETAIL L L SIZE WT GRADE TOP BTM. 26" Surf 356' 20" 94# H-40 Surf 822' 13-3/8" 61/68# 1-55 Surf 5201' 9-5/8" 40/47# N-80Surf 7,930' G L 7" 29# N-80 7543' 10,747' DV at 2,595' (9_5/8') TUBING DETAIL 1 2-7/8" 6.5# L-80 Surf 9,365' \ / L , Jewelry Detail No Depth ID Item KOP for L sidetrack Hanger At 7850' 1 9,365' 2.441 Discharge,Bolt-On 2 9,367' - Pump(3)-125 Stage,Pump(1)-0760 Stage 3 9,455' - Gas Separator • 4 9,459' - Seals t 5 9,476' - Motor-456 Series 11 2 6 9,513' - Anode Ili 3 - 4 111 5 Perforation Detail 6 Top Btm Top Btm Zone (MD) (MD) (TVD) (TVD) Amt SPF Date G-1 9,614' 9,645' 8,628' 8,658' 31' 2-1/2",6spf 6/11/1998 G-1 9,615' 9,635' 8,629' 8,649' 20' _ 2-1/2"4 SPF 5/4/2008-DIL - G-1 9,620' 9,630' 8,634' 8,644' 10' 4 SPF 03/23/15 G-1 _9,625' 9,640' 8,638' 8,653' 15' 2",4spf 2/4/2004 G-1 9,675' 9,685' 8,687' 8,697' 10' 4 SPF 03/23/15 G-1 G-2 9,668' 9,688' _ 8,680' 8,700' 20' 2'A"4 SPF 5/4/2008-DIL _ thru G-3 9,737' 9,767' 8,747' 8,776' 30' 2-1/2",6spf 6/14/1998 G-5 G-3 9,750' 9,768' 8,759' 8,777' 18' 2'A"4 SPF 5/4/2008-DIL G-3 9,755' 9,765' 8,764' 8,774' 10' 2",4spf 2/4/2004 G-3 9,756' 9,766' 8,765' 8,775' 10' 4 SPF 03/23/15 G-4 9,784' 9,794' 8,792' 8,802' 10' 2'A"4 SPF 5/4/2008-DIL G-4 9,785' 9,793' 8,793' 8,801' 8' 2",4spf 2/4/2004 Landing ---------�� G-4 9,800' 9,815' 8,808' 8,822' 15' 2'A"4 SPF 5/4/2008-DIL Collar at G-4 9,800' 9,832' 8,808' 8,839' 32' _ 2-1/2",6spf 6/14/1998 10,662' / \ G-4 9,808' 9,818' 8,816' 8,825' 10' _ 4 SPF 03/23/15 G-4 9,825' 9,833' 8,832' 8,840' 8' 2'A"4 SPF 5/4/2008-DIL G-4 9,825' 9,835' 8,832' 8,842' 10' 2",4spf 2/4/2004 G-5 9,894' 9,964' 8,899' 8,967' 70' 2-1/2",6spf 6/3/1998 TD=10,750' G-5 9,896' 9,906' 8,901' 8,911' 10' 2",4spf 2/4/2004 Max angle=36° 6,600' G-5 9,925' 9,935' 8,929' 8,939' 10' 4 SPF 03/22/15 Updated: 04/24/15 by 1LL Hilcorp Alaska, LLC HilwrpAlaska,LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date G-21RD 50-733-20267-01 198-064 3/14/2015 3/25/2015 Daily Operations: 03/14/15-Saturday INSTALLED BPV.REMOVED FLOOR PLATES AND H BEAM, DISCONNECT FLOW LINE. REMOVED SAFETY VALVE.N/D TREE AND REMOVE FROM WELL BAY. NIPPLE UP RISER AND BOP'S AND UNPLUGGING HARD LINES ON SUBSTRUCTURE AND CONNECT DISCHARGE LINE BACK. RIGGED UP SCAFFOLDING AROUND BOPS.REMOVE LIFTING PLATE.INSTALL FLOOR BEAMS,POLLUTION PAN AND INSTALL BELL NIPPLE. R/U TO TEST BOP'S.FILL STACK.SHELL TEST OK.START TESTING ALL BOP COMPONENTS TO 250 LOW 3000 HIGH AS PER HILCORP AND AOGCC SPECS.TEST LINE KEPT FREEZING UP.MADE UP SPARE HOSE FOR BACKUP.CONTINUE TESTING (NOTE BOP TEST WITNESS WAIVED BY JIM REGG ON THE 3/13/2015/1:50 PM )(TESTING ON 3 1/2"AND 4 1/2"TBG). 03/15/15-Sunday FINISH TESTING BOP'S TO 250 LOW 3000 HIGH.ALL TEST GOOD ON 3 1/2"AND 4 1/2"TBG.PERFORMED ACCUMALATOR TEST.R/D TESTING EQUIPMENT. PULLED TWO WAY CHECK.INSTALLED BELL NIPPLE,H BEAM AND RIG FLOOR BACK IN PLACE.BROKE LOOSE LINES THAT WAS FROZEN UP.UNPLUGGED AND BLOW DOWN AND HOOKED BACK UP. P/U LANDING JOINT.BACKED OUT HOLD DOWN PINS ON HANGER. BEGAN PULLING ON PIPE.PULLING 80%,WORK FROM 120K TO 170K WOULD NOT COME FREE. P/U TO 120K SET SLIPS AND R/U E-LINE AND LUB TEST LUB TO 1500 PSI.RIH W/RTC CUTTER-TO 9,433'.LOG ON DEPTH CUT TBG @ 9,433' POOH WITH E-LINE.RIG DOWN. PICK UP ON TBG STRING,TBG FREE,PULL TO HANGER L/D SAME.LAY DOWN 4 1/2" 12.6#L-80 TBG TO SSSV.LID SAME. POOH LAYING DOWN 3 1/2" 9.3#L-80 BUTT TBG AND GAS LIFT VALVES. 03/16/15-Monday POOH WITH PRODUCTION TUBING 3 1/2"9.3#L-80 AND GAS LIFTS LAYING DOWN. MAKE UP BHA,OVERSHOT DRESSED 3.5" GRAPPLE,BUMPER JARS,OIL JARS AND 3 STDS 4 3/4"DRILL COLLARS.P/U ACCEL JARS. TRIP IN HOLE WITH 3 1/2" PH6 WORK STRING OUT OF DERRICK. TOTAL 98 STDS. BEGAIN PICKING UP 3 1/2"PH6 PIPE OFF FROM PIPE RACK. 03/17/15-Tuesday CONTINUE TIH PICKING UP 3 1/2"WORKSTRING OFF PIPE RACK. SLACK OFF,ENGAGED TOP OFF FISH..@ 9,433'SLA_K_DQWN AND PICKED UP TO 200K.LET JARS GO OFF SEALS CAME FREE. POOH WITH 3 1/2"WORKSTRING.L/D OVERSHOT,CUT PIECE,SEAL ASSY& TAIL PIPE. CLEAR RIG FLOOR.PICK UP#2 BHA.P/U 4 3/4"PIONEER MILL AND SPEAR ASSY, MUD MOTOR,X-0,TWO BOOT BASKETS,X- 0,IN-LINE MAGNET,BUMPER JAR,OIL JARS,6 4 3/4"DRILL COLLARS. TRIP IN HOLE WITH WORK STRING.SHALLOW TEST MUD MOTOR. RIGGED UP POWER SWIVEL AND HOSES. MILL ON PACKER @ 9,455',WITH MOTOR TURNING 130 RPM,TORQUE 3500 FT.LBS,4 1/2"BPM 400 PSI.PUMP PRESSURE(MADE 6")STARTED GETTING OIL AND GAS BACK ON BOTTOMS UP 1800 UNITS. RIG UP HOSES TO PRODUCTION TAKING RETURNS TO TRADING BAY.CIRC OIL AND GAS ANNULUS SIDE. 03/18/15-Wednesday WHILE MILLING ON PACKER @ 9456',MUD MOTOR STALLED OUT.SHUT DOWN PUMPING.OPENED UP.BLEED OFF GOING TO PUMP. OPENED UP ANNULAR.HAD TRAPPED GAS UNDERNEATH. START MILLING ON PACKER TAKING RETURNS TO PITS AND PUMPING TO PRODUCTION.CLEAN WELL. PACKER STARTED TO MOVE DOWN HOLE. LAY DOWN POWER SWIVEL. PULL OUT OF HOLE SLOWLY, PACKER DRAGGING 5-10K THROUGH CSG COLLARS.CONTINUE POOH. Hilcorp Alaska, LLC IIileorpAlaska.I,lk Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date G-21RD 50-733-20267-01 198-064 3/14/2015 3/25/2015 Daily Operations: 03/19/15-Thursday LAY DOWN BHA#2. CLEAN OUT BOOT BASKETS. FINE METAL IN THEM. PICKED UP BHA#3-BUMPER AND OIL JARS.PICKED UP 7" CASING SCRAPER AND 6"BIT.TIH W/DRILL C.RAN 38 SIDS 3 1/2"PH6.MADE UP/PICK UP 9 5/8"CASING SCRAPER AND TIH TO 7,000'.DECISION WAS MADE TO PERF ANOTHER 17'BELOW PERF.PERF,POOH ADDED 2 MORE STDS TO SPACE OUT 9 5/8"SCRAPER FROM LINER TOP.TRIP BACK IN HOLE. PICK UP PIPE OFF PIPE RACK.TAGGED UP AT 9,550'.INSTALLED STRIPPER RUBBER.R/U POWER SWIVEL.FILLED PIPE. STARTED WASHING IN REVERSE POSITION.STRIPPER STARTED LEAKING. CHANGE OUT STRIPPER RUBBER. CONTINUE WASHING AND REAMING DOWN.DEPTH AT 6 AM 9,958'.CIRC TBG VOLUME BEFORE EACH CONNECTION GETTING SCALE AND SAND BACK. 03/20/15-Friday CONTINUE WASHING AND REAMING FROM 9,901'TO 9,917',INDICATION ON IRON.PICKED UP,CIRC HOLE CLEAN. RIGGED DOWN POWER SWIVEL. LAID DOWN.PULLED STRIPPER RUBBER. POOH 50 STDS ABOVE 7"LINER TOP. SLIP AND CUT DRILL LINE.SERVICE RIG.CONTINUE POOH,LAID DOWN 9 5/8"CSG SCRAPER. LAID DOWN 7"SCRAPER AND BHA.INDICATION ON BIT THAT IT WAS ON METAL. P/U 3 1/2"MULE SHOE AND 7"TEST PACKER. TRIP IN HOLE WITH PACKER TO 9407'. FILL HOLE. R/U AND SET PACKER.TEST 7"X9518"CASING TO 1500 PSI FOR 30 MIN ON CHART,TEST GOOD. R/D TESTING EQUIPMENT. UNSEAT PACKER,POOH.(NOTE: BOPE TEST WAIVED AND GRANTED TO TEST EARLY BY JIM REGG AT 3/20/2015 8:29 PM).HOLE TAKING 30 BBLS PER/HR.TOTAL FLUID LOST TO HOLE 2900 BBLS. 03/21/15-Saturday CONTINUE POOH.LAY DOWN PACKER AND MULE SHOE.FILLED HOLE 212 BBLS. PULLED WEAR BUSHING.INSTALLED TEST PLUG. TEST BOP'S AS PER AOGCC AND HILCORP SPEC/S 250 LOW 3000 HIGH.TESTED ON 3 1/2"AND 2 7/8"TBG.ALL TEST GOOD.(NOTE PERMISSION GIVEN TO TEST BOP'S EARLY DUE TO CHANGES IN PROCCEDURE.JIM REGGS W/AOGCC,WAIVED WITNESS). PULLED TEST PLUG AND INSTALLED WEAR BUSHING. PICKED UP BHA#5 5 3/4"OCEAN WAVE WASH PIPE SHOE W/CABLES,WASH PIPE EXTENSION,TOP BUSHING,BUMPER JAR,OIL JAR,6 4 3/4"DC,X-O. TRIP IN HOLE WITH 3 1/2" PH6 WORK STRING TO 9,900'. INSTALL STRIPPER RUBBER.P/U POWER SWIVEL. BEGAN WASHING F/9,917'TO 9,989'.AT 9,989'HOLE TIGHT STARTED TO TORQUE UP, HANGING UP, HAVING TO JAR LOOSE. MADE SERVERAL ATTEMPTS TO GET PAST BAD SPOT WITH NO SUCCESS. CIRC HOLE CLEAN IN REVERSE POSITION. R/D POWER SWIVEL.PULL STRIPPER RUBBER. 03/22/15-Sunday REMOVED POWER SWIVEL AND PULLED STRIPPER RUBBER. POOH ABOVE LINER TOP @ 7,543'44 STDS. HELD JSA.LAID DOWN 243 JTS 3 1/2"PH6 WORKSTRING. TRIP IN HOLE PIPE OUT OF DERRICK 44 STDS. POOH LAYING DOWN 3 1/2"WORK STRING 88 JTS.LAID DOWN BHA.REMOVED ALL TOOLS PLACED IN BASKET.HAD CUTS ON SHOE THAT LOOKED LIKE ON CSG. PULLED WEAR BUSHING.N/D FLOWLINE AND BELLNIPPLE.REMOVED FLOOR PLATES AND BEAM. PULLED DRIP PAN. P/U E-LINE FLANGE. N/U ON ANNULAR.M/U LUBRICATOR,SIDE ENTRY SUB,HUNG SHEAVE.FILLED LUB TEST TO 1500 PSI. M/U PERFORATING GUN#1 AND EQUIPMENT. RIH 4 5/8" PERF GUNS 4 SPF ON E-LINE LOG ON DEPTH PERF WELL @ 9,935'-9,925'. POOH W/E-LINE.NOTE ALL SHOTS FIRED.RIH WITH #2 PERF GUN. 03/23/15-Monday CONTINUE RIH W/4 5/8"PERF GUN#2 PERFORATED FROM 9,818'-9,808'.POOH.ALL SHOTS FIRED,4 SHOTS PER FOOT. RIH WITH GUN#3 PERF WELL FROM 9,756'-9,766'.POOH.ALL SHOTS FIRED. RIH WITH GUN#4,GUN DID NOT FIRE.POOH. RE-RUN GUN#4 PERF WELL FROM 9,675'-9,685'.POOH.ALL SHOTS FIRED. RIH WITH GUN#5 PERF WELL FROM 9,630'-9,620'.POOH.ALL SHOTS FIRED. RIGGED DOWN SHEAVES AND TOP PIECE LUB. REMOVED FLOOR PLATES,H BEAM AND INSTALLED HANDRAILS. NIPPLE DOWN LUB FLANGE. NIPPLE UP BELL NIPPLE. INSTALLED FLOWLINE BACK.INSTALLED FLOOR. HELD JSA SPOT ESP EQUIPMENT IN PLACE. START PICKING UP ESP ASSY. FILL MOTOR WITH OIL.HANG SHEAVES IN DERRICK.ATTACH ELINE AND TEST SAME. BEGIN PICKING UP 2 7/8"8 RD EUE 6.5#TUBING. DEPTH AT REPORT TIME 2,100'. Hilcorp Alaska, LLC [laeurpAlaska,LH Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date G-21RD 50-733-20267-01 198-064 3/14/2015 3/25/2015 Daily Operations: 03/24/15-Tuesday PICKING UP 2 7/8"6.5 L-80 EUE 8RD PRODUCTION TBG INSTALLING CANNON CLAMPS EVERY OTHER JT TESTING CABLE EVERY 1,000'. SPLICE CABLE @ 6,006',TEST SAME. CONTINUE PICKING UP PRODUCTION TBG AND INSTALLING CANNON CLAMPS EVERY OTHER JT, DRIFTING AND SLM SAME. PICK UP HANGER MAKE SPLICE IN CABLE LAND HANGER RAN TOTAL 297 JTS PLACING BOTTOM AT 9,519' AND INTAKE @ 9,465'. 03/25/15-Wednesday LAND HANGER AND TEST TO 5000 OK. LAID DOWN LANDING JT.REMOVED PLATES AND H-BEAM.REMOVED FLOWLINE AND BELL NIPPLE. INSTALLED LIFT PLATE. NIPPLE DOWN BOP'S SET TO SIDE. SECURED RIG FLOOR BACK. INSTALLED TREE. HOOKED UP FLOW LINE. PREP RIG TO SKID WHILE WAITING ON PRODUCTION TO RUN PUMP TO MAKE SURE IT WAS OK. R/D STAIRS TO RIG FLOOR. REMOVED CAT WALK.HOOKED UP JACKS TO BOTTOM SECTION. LOSING CLAMPS FROM BOTTOM SKID.HELD JSA ON SKIDDING RIG. o�� � THE STATE Alaska Oil and Gas mw '� o s -- ALASKA f Conservation Commission � - � 333 West Seventh Avenue Anchorage, Alaska 99501-3572 OF � � � GOVERNOR BILL WALKER 9 Main: 907.279.1433 -►LASS Fax• 907.276 7542 www.aogcc.alaska.gov Dan Taylor Operations Engineer SCANNED '" 1' h "' I CA Hilcorp Alaska, LLC `7 AJ 3 800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, TBU G-21 RD Sundry Number: 315-154 Dear Mr. Taylor: 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, gi41,4f Cathy P Foerster Chair DATED this d y of March, 2015 Encl. . RECEIVED • MAR 1 9 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ����� APPLICATION FOR SUNDRY APPROVALS 2QAAC 25280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate El. PuN Tubing El Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Atter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development E . 198-064, _ 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 • 50-733-20267-01 • 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 7 Trading Bay Unit G-21RD • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730 • McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): • 10,750 - 9,740 - 9,899 . 8,903 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 356' 26" 356' 355' Surface 822' 20" 822' 821' 1,530 psi 520 psi Intermediate 5,201' 13-3/8" 5,201' 4,822' 3,090 psi 1,540 psi Production 7,930' 9-5/8" 7,930' 7,075' 5,750 psi 3,090 psi Liner 3,204' 7" 10,747' 9,737' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 3-1/2"&4-1/2" L-80 9,535'&340' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker Perm Pkr&Baker TE-5 SSSV 9,450'(MD)8,471'(ND)and 315'(MD)315'(ND) 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch I] Exploratory 0 Stratigraphic❑ Development El . Service Cl 14.Estimated Date for 15.Well Status after proposed work: 3/20/2015 Commencing Operations: Oil 0 . Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: j WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtaylor@hilcorD.com Printed Name Dan Ta for / Title Operations Engineer Signature Phone (9Q)777-8319 Date 3/19/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315—/541 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: ,( 340400 e5:, BO 1 S� v Spacing Exception Required? Yes ❑ No lZr---- Subsequent Form Required: /D 1 p y / - APPROVED BY Approved by: C9R(7119 —/9-/.5 (F-1i� COMMISSIONER THE COMMISSION Date:3 7—/ R1 LNALSubmit Forth and Form 10-403(Revised 10/2012) p IIIr 12 months from the date of approval. Aft nts in Duplicate RBDMS APR - 1 2015 Well Prognosis Well: G-21RD IIil(mn=%ia.ka,LL, Date:03/19/2015 Well Name: G-21 RD API Number: 50-733-20267-01 Current Status: _ Producer Leg: 3 Estimated Start Date: March 20, 2015 Rig: Moncla 301 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 198-064 First Call Engineer: Daniel Taylor (907) 777-8319(0) (907) 947-8051 (M) Second Call Engineer: James Young (907) 777-8421 (0) AFE Number: Current Bottom Hole Pressure: 3,600 psi @ 9,454ft TVD/10,450ft MD 0.29 psi/ft at mid-perf, Survey 2009 Maximum Expected BHP: 3,600 psi @ 9,454ft TVD/10,450ft MD 0.29 psi/ft at mid-perf, Survey 2009 Max.Allowable Surface —2,654 psi 3,600psi-9,454ft(TVD)"0.1 psi/ft Pressure: Brief Well Summary (.,...,, Hilcorp re uests a Sundry to add perforations to the above well. Perforations to be added are highlighted below: Bench Top MD Btm. MD Feet MD Top TVD Btm. TVD_Feet TVD HK-1 10,113 10,130 17 9,113 9,130 17 All other well work and the re-perforating of existing intervals will be performed under Approved Sundry#315-086. Procedure: 1. After cleaning out well in Sundry 315-086(Step 15). 2. Rig up e-line, perforating guns, and run in hole to perforate across the following intervals: Bench Top MD Btm. MD Feet MD Top TVD Btm.TVD Feet TVD G-1 9,620 9,630 10 8,634 8,644 _ 10 G-2 9,675 9,685 . 10 8,687 8,697 10 G-3 9,756 9,766 10 8,765 8,775 _ 10 G-4 _ 9,808 9,818 _ 10 8,816 8,825 _ 10 G-5 _ 9,925 9,935 10 _ 8,929 8,939 _ 10 HK-1 10,113 10,130 17 9,113 9,130 17 a. A total of+/-6 run's will be required. b. After each run pull out of hole checking for all-shots-fired. 3. Rig down e-line and continue with Sundry 315-086 procedure(Step 19). Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic McArthur River Field,TBU • IIWell: G-21RD Nilrarp Alaska,Li.f. As Completed: 05/12/08 RKB 42.15 SIZE WT GRADE TOP BTM 1 26" Surf 356' 2[-I C) I 20" 94# H-40 Surf 822' 3 13-3/8" 61/68# J-55 Surf 5201' 9-5/8" 40/47# N-80/P-110 Surf 7,930' a 7" 29# N-80 7543' 10,747' JTubing: 3-1/2" 9.3# L-80 Imp. Butt 340' 9,535' 5 4-1/2" 12.6# L-80 Mod. Butt Tbg. Hgr. 340' L 16 J 7 DV at 2,595' JEWELRY DETAIL (9-5/8") NO. Depth Item J 8 1. 42.1' 4-1/2"EUE x BTC TBG Hangar J 9 2. 312' 4-1/2" 12.6 lb/ft Butt Tbg(To SSSV) 3. 315' 4-1/2" Baker TE-5 TRSSSV 3.8"Profile. L \ Jlo 2 x-over 4-1/2" x 3-1/2" Butt. SOP for sidetrack L in 4.-15. 3-1/2"MACCO GLM's 1t 7850' J12 2447,4310, 5311, 5712, 6210, 6674, 7170, 7669, 8168, 8571, 9001, 9401 113 114 16. 9,450' Baker 85-40 FB Permanent Packer 17. 9,467' 15' Seal Bore Extension 115 18. 9,502' "X"nipple profile(2.813") 19. 9,535' OTIS WLREG ml 16 II Rr. Perforations 19 TOP BTM ZONE Perf Method Date 9825 9833 DIL G-4 2 '/2"4 SPF 5/4/08 9800 9815 DIL G-4 2 '/2"4 SPF 5/4/08 9784 9794 DIL G-4 2 ''A"4 SPF 5/4/08 9750 9768 DIL G-3 2 'h"4 SPF 5/4/08 G-1 9668 9688 DIL G-2 2 ''A",4 SPF 5/4/08 thru = G-5 9615 9635 DIL G-1 2 1/2"4 SPF 5/4/08 G-5 9614 9645.5 0-1 2-1/2",6spf 6/11/98 9625 9640 Reperf 2",4spf 2/04/04 9675 9685 G-1 2",4spf 2/04/04 9737 9767 G-3 2-1/2",6spf 6/14/98 9755 9765 Reperf 2",4spf 2/04/04 Landing 9784 9794 G-4 2-1/2",6spf 6/14/98 >.< Collar at 9785 9793 Reperf 2",4spf 2/04/04 10,662' 9800 9832 G-4 2-1/2",6spf 6/14/98 / \ 9800 9815 Reperf 2",4spf 2/04/04 9825 9835 Reperf 2",4spf 2/04/04 9894 9964 0-5 2-1/2",6spf 6/3/98 9896 9906 Reperf 2",4spf 2/04/04 TD=10,750' Max angle=36°@ 6,600' G-21RD WBS 05.12.08.doc Revised 04/28/12 by MDD • 14 PROPOSED McArthur River Field, TBU Well: G-21RD Hiln,rp Hanka.I.I.0 Completed: Future RKB 42.15 CASING DETAIL L . . SIZE WT GRADE TOP BTM. 26" Surf 356' 20" 94# H-40 Surf 822' 13-3/8" 61/68# 1-55 Surf 5201' 9-5/8" 40/47# N-80/P Surf 7,930' z 7" 29# N-80 7543' 10,747' DV at 2,595' (9-5/8') TUBING DETAIL /; L-80 Surf / Jewelry Detail KOP for L No Depth ID Item sidetrack Hanger At 7850' 1 ±9,460' Pump Intake 111- Perforation Detail Top Btm Top Btm Zone (MD) (MD) (TVD) (TVD) Amt SPF Date G-1 9,614' 9,645' 8,628' 8,658' 31' 2-1/2",6spf 6/11/1998 G-1 9,615' 9,635' 8,629' 8,649' 20' 2-1/2"4 SPF 5/4/2008-DIL - G-1 ±9,620' ±9,630' ±8,634' ±8,644' ±10' Future G-1 9,625' 9,640' 8,638' 8,653' 15' 2",4spf 2/4/2004 G-1 ±9,675' ±9,685' ±8,687' ±8,697' ±10' Future G-1 G-2 9,668' 9,688' 8,680' 8,700' 20' 2 4"4 SPF 5/4/2008-DIL thru G-3 9,737' 9,767' 8,747' 8,776' 30' 2-1/2",6spf 6/14/1998 _ G-5 G-3 9,750' 9,768' 8,759' 8,777' 18' 2%"4 SPF 5/4/2008-DIL G-3 9,755' 9,765' 8,764' 8,774' 10' 2",4spf 2/4/2004 G-3 ±9,756' ±9,766' ±8,765' ±8,775' ±10' Future G-4 9,784' 9,794' 8,792' 8,802' 10' 2'''A"4 SPF 5/4/2008-DIL HK-1 G-4 9,785' 9,793' 8,793' 8,801' 8' 2",4spf 2/4/2004 LandingG-4 9,800' 9,815' 8,808' 8,822' 15' 2 34"4 SPF 5/4/2008-DIL Collar at G-4 9,800' 9,832' 8,808' 8,839' 32' 2-1/2",6spf 6/14/1998 10,662' / \ G-4 ±9,808' ±9,818' ±8,816' ±8,825' ±10' Future G-4 9,825' 9,833' 8,832' 8,840' 8' 2'A"4 SPF 5/4/2008-DIL G-4 9,825' 9,835' 8,832' 8,842' 10' 2",4spf 2/4/2004 G-5 9,894' 9,964' 8,899' 8,967' 70' 2-1/2",6spf 6/3/1998 TD= 10,750' G-5 9,896' 9,906' 8,901' 8,911' 10' 2",4spf 2/4/2004 Max angle=36°@ 6,600' G-5 ±9,925' ±9,935' ±8,929' ±8,939' ±1G HK-1 ±10,113' ±10,130' ±9,113' ±9,130' ±17 Updated: 03/19/15 by 1LL Schwartz, Guy L (DOA) From: Daniel Taylor <dtaylor@hilcorp.com> Sent: Thursday, March 19, 2015 3:20 PM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett; Bettis, Patricia K(DOA) Subject: RE:Grayling G-21RD, PTD: 198-064, Sundry:315-086 Guy, This well was originally slated as a G-Zone frac. Due to economic reasons the frac services have since pulled out of the inlet and are no longer available. The plan was then to move forward with deconstructing the current gas lift completion and place an ESP in the well until an opportunity presents itself for fracing once again. While we are planning to perforate we believe that this will be an ideal time to establish communication with Bench 1 of the Hemlock. It is also tight in this area and relatively un-swept. Should fracing be possible in the near future we may want to include it in our plans provided the production warrants it. Our Asset Team Leader has driven home the fact that these 11th hour decisions need to be made well before moving on to the well. We believe that this is a decision that will increase oil rate and provide decision making data for future field development. However, we should have (and in the future we will) come to this conclusion sooner. Thank you for considering expediting this application. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday, March 19, 2015 2:49 PM To: Daniel Taylor Cc: Juanita Lovett; Bettis, Patricia K(DOA) Subject: RE: Grayling G-21RD, PTD: 198-064, Sundry: 315-086 We are processing but require a written explanation ASAP Guy Schwartz Senior 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). From: Schwartz, Guy L(DOA) Sent:Thursday, March 19, 2015 12:38 PM To: 'Daniel Taylor' 1 ti Cc: Juanita Lovett; Bettis, Patricia K(DOA) Subject: RE: Grayling G-21RD, PTD: 198-064, Sundry: 315-086 Dan, The AOGCC can't make promises to expedite sundries. There have been several last minute perforation changes to approved sundries in the last few months ...while minor tweaks to pre-approved perforation zones are sometimes verbally approved by email adding a whole new zone (and pool) at the last minute is not acceptable. Additionally, if you are asking for expedited sundry review then an explanation of why the request is last minute is also required by email and should accompany the requesting documents. Guy Schwartz Senior 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(Guv.schwartz@alaska.gov). From: Daniel Taylor [mailto:dtaylor@hilcorD.com] Sent: Thursday, March 19, 2015 11:39 AM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett Subject: RE: Grayling G-21RD, PTD: 198-064, Sundry: 315-086 Guy, Please see the attached Sundry Application for Approval for the additional perforations on G-21 RD. The hard copy will be arriving at your office shortly via courier. I do hope that I am not out of line sir but would it be possible for you to consider this application urgent and place at the top of your list for consideration? We are currently cleaning out the well in preparation for perforating. Thank you. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, March 19, 2015 11:03 AM To: Daniel Taylor Cc: Juanita Lovett Subject: RE: Grayling G-21RD, PTD: 198-064, Sundry: 315-086 Dan, You will need sundry approval to perforate the Hemlock. Change from TCP to Eline is approved however by verbal. 2 '1 s GUy Schwartz Senior 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). From: Daniel Taylor [mailto:dtaylorc hilcorp.com] Sent: Thursday, March 19, 2015 10:37 AM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett Subject: Grayling G-21RD, PTD: 198-064, Sundry: 315-086 Guy, We are preparing to perforate on the G-21RD well. Our Sundry has only G1-5 perforations approved. I would like to make two changes to the Sundry procedure. We are now planning on perforating on wireline as opposed to TCP. Also, with your permission we would like to perforate the bench 1 of the Hemlock in this well. The total perforations would include: Bench Top MD Btm MD Feet MD Top TVD Btm TVD Feet TVD, AOGCC Status G-1 9,620 9,630 10 8,634 8,644 10 Approved G-2 9,675 9,685 10 8,687 8,697 10 Approved G-3 9,756 9,766 10 8,765, 8,775 10 ,Approved G-4 9,808 9,818 10 8,816 8,825 10 Approved G-5 9,925 9,935 10 8,929 8,939 10 Approved HK-1 10,113 10,130 17 9,113 9.130 17 tin-Approved Do we have your permission to proceed with these changes? Thank you sir. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 3 '' OF Thr, Alaska Oil and Gas 4, ...,,.\ �j, sA THE STATE f�`' -iM °fALAS� Conservation Commission 4 -�2_=__y _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 r Main: 907.279.1433 F ALAS—?- Fax: 907.276.7542 www.aogcc.alaska.gov Dan Taylor Operations Engineer �- Hilcorp Alaska, LLC 12- --6' . -1 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil & Middle Kenai G Oil Pools Trading Bay Unit G-21RD Sundry Number: 315-086 Dear Mr. Taylor: 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, 1).- e_..i--,_____ Cathy P. oerster Chair DATED this / ay of February, 2015 Encl. RECEIVED ' FEB 13 2015 r►r STATE OF ALASKA 077'5 (c //3 ALASKA OIL AND GAS CONSERVATION COMMISSION AOG APPLICATION FOR SUNDRY APPROVALS I'! �+ 2QAAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program El Suspend❑ Plug Perforations El Perforate 0 • Pull Tubing El • Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Install ESP ID- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 • 198-064• 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20267-01 • 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 El / Trading Bay Unit G-21RD• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730 • McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): - 10,750 . 9,740 . 9,899 • 8,903 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 356' 26" 356' 355' Surface 822' 20" 822' 821' 1,530 psi 520 psi Intermediate 5,201' 13-3/8" 5,201' 4,822' 3,090 psi 1,540 psi Production 7,930' 9-5/8" 7,930' 7,075' 5,750 psi 3,090 psi Liner 3,204' 7" 10,747' 9,737' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic r See Schematic 3-1/2"&4-1/2" L-80 9,535'&340' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker Perm Pkr&Baker TE-5 SSSV • 9,450'(MD)8,471'(ND)and 315'(MD)315'(ND)• 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 3/5/2015 Commencing Operations: Oil El • Gas El WDSPL El Suspended ❑ 16.Verbal Approval: Date: WINJ El GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR El SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtaylorna.hilcorp.com Printed Name D,,;,te Title Operations Engineer Si.natur %� t_ Phone (907)777-8319 Date 2/13/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �/ ? o jlS - O%C• Plug Integrity ❑ BOP Test III Mechanical Integrity Test ❑ Location Clearance ❑ ' Other: 3c C a �� i /.L .) •_-(}-- ( l ti,—5/ 9 cam 6• ,v p s- ) Spacing Exception Required? Yes ❑ No [2" Subsequent Form Required: /0 '/(,(/ APPROVED BY / Approved by: P;)„...e.i.„1(47...__ � COMMISSIONER THE COMMISSION Date: Z ! —45 67 1114 j Submit Form and Form 10-403(Revised /2012) AOOR twoNA or V 12 months from the date of approval. Attachments in Duplicate RBDMS FEB 2 3 2015 Well g Well:ProG-21RDnosis Hilcorp Alaska,LLQ Date:2/13/2015 Well Name: G-21 RD API Number: 50-733-20267-01 Current Status: Producer Leg: 3 Estimated Start Date: March 5,2015 Rig: Moncla 301 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 198-064 First Call Engineer: Daniel Taylor (907) 777-8319(0) (907)947-8051 (M) Second Call Engineer: James Young (907) 777-8421 (0) AFE Number: Current Bottom Hole Pressure: 3,600 psi @ 9,454ft TVD/10,450ft MD 0.29 psi/ft at mid-pen`, Survey 2009 Maximum Expected BHP: 3,600 psi @ 9,454ft TVD/10,450ft MD 0.29 psi/ft at mid-pert, Survey 2009 Max.Allowable Surface -2,654 psi3,600psi-9,454ft(TVD)*0.1 psi/ft Pressure: / Brief Well Summary Grayling G-21 RD is currently a gas lifted oil producing G-Zone & Hemlock completion. G-21 RD is currently producing 155bopd. This well has had significant issues with sand and scale which hampers efficient production. This program outlines the procedure of removing the current gas lift completion, adding perforations,and re-completing the well with an ESP.., Procedure: 1. Bleed off well. 2. Identify fluid level. 3. Rig up e-line line on shert-stfing. 4. Run in hole and punch tubing below#15 gas lift mandrel. a. Rig down e-line. 5. Circulate until clean returns down tubing until well is dead. a. Work over fluid will be filtered inlet water unless well conditions dictate heavier brine is required. 6. Set back pressure valve. 7. Nipple down tree and nipple up BOP. 8. Perform BOP test in accordance with AOGCC regulations(250psi low, 3,000psi high). a. Note: 3.5in work string. b. If back pressure valve will not set with tree on notify AOGCC and refer to attached rolling test procedure. 9. Install landing joint and pull hanger to floor. 10. Attempt to pull tubing and 15ft seal assembly. a. Dry weight to packer=88klbs 11. If seal assembly does not come: a. Rig up a-line, run in hole with 2.5in cutter to+/-9,430ft and cut. b. Pull out of hole with tubing. c. Rig down a-line. d. Run in hole with overshot, engage and pull seal assembly. 12. Pick up 7in 291b test packer. a. Run in hole and set at+/-9,400ft. b. Test casing(mechanical integrity test) 1,500psi for 30min and chart. rh 13. Pick up packer mill and spear assembly. a. Run in hole and burn over 7in 291b packer at+/-9,450ft b. Pull out of hole with packer,seal bore, 'X' nipple,and WLEG. 14. Pick up and run in hole with 9-5/8in clean out assembly. a. Clean out to top of 7in liner at+/-7,543. 15. Pick up and run in hole with 7in clean out assembly. a. Clean out to+/-10,650ft. 16. Pick up TCP assembly, space out over the following intervals and perforate. .• Well Prognosis Well: G-21RD Mean)Alaska,LL Date:2/13/2015 Zone Top MD(ft) Btm MD(ft) Total(ft) G-1 9,620 9,630 10 a G-2 9,675 9,685 10 ""t' G-3 9,756 9,766 10 l I"' G-4 9,808 9,818 10 G-5 9,925 9,935 10 17. Close annular and circulate out gun gas ensuring well is static. 18. Pull out of hole laying down TCP assembly ensuring all shots fired. 19. Pick up and run in hole with completion: a. ESP b. Cable c. Capillary Tubing d. Set ESP Intake at+/-9,460ft MD. 20. Land hanger and test. 21. Turn well over to production. 22. Complete a surface safety valve test and`no flow'test in compliance with AOGCC regulations. • a. See 20 AAC 25.265.Well safety valve systems. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. Current Well Head 4. Proposed Well Head 5. BOP Stack 6. Rolling Test Procedure .• fl McArthur River Field,TBU Well: G-21 RD ' "''op%IRA 1.I.f. As Completed: 05/12/08 RKB 42.15 SIZE WT GRADE TOP BTM 1 26" Surf 356' 2 I 20" 94# H-40 Surf 822' 13-3/8" 61/68# J-55 Surf 5201' L —4C ) 3 9-5/8" 40/47# N-80/P-110 Surf 7,930' J 4 7" 29# N-80 7543' 10,747' Tubing: 3-1/2" 9.3# L-80 Imp. Butt 340' 9,535' J s 4-1/2" 12.6# L-80 Mod. Butt Tbg. Hgr. 340' L J6 N J 7 DV at 2,595' JEWELRY DETAIL (9-5/8") NO. Depth Item J 8 1. 42.1' 4-1/2"EUE x BTC TBG Hangar J 9 2. 312' 4-1/2" 12.61b/ft Butt Tbg(To SSSV) 3. 315' 4-1/2" Baker TE-5 TRSSSV 3.8" Profile. L \ J10 / x-over 4-1/2" x 3-1/2" Butt. KOP for sidetrack L J11 4.-15. 3-1/2"MACCO GLM's At 7850' II 112 2447, 4310, 5311, 5712, 6210, 6674, 7170, 7669, 8168, 8571, 9001, 9401 J13 J la 16. 9,450' Baker 85-40 FB Permanent Packer 17. 9,467' 15' Seal Bore Extension 115 ,,.• 18. 9,502' "X"nipple profile(2.813") 19. 9,535' OTIS WLREG 16 1 1x Perforations 19 TOP BTM ZONE Perf Method Date 9825 9833 DIL G-4 2 i/2'4 SPF 5/4/08 9800 9815 DIL G-4 2 1/4"4 SPF 5/4/08 9784 9794 DIL G-4 2 '/2"4 SPF 5/4/08 9750 9768 DIL G-3 2 '/2"4 SPF 5/4/08 thru 9668 9688 DIL G-2 2'/2",4 SPF 5/4/08 G-5 9615 9635 DIL G-1 2 1/2"4 SPF 5/4/08 9614 9645.5 G-1 2-1/2",6spf 6/11/98 9625 9640 Reperf 2",4spf 2/04/04 — 9675 9685 G-1 2",4spf 2/04/04 9737 9767 G-3 2-1/2",6spf 6/14/98 9755 9765 Reperf 2",4spf 2/04/04 Landing 9784 9794 G-4 2-1/2",6spf 6/14/98 �. Collar at 9785 9793 Reperf 2",4spf 2/04/04 10,662' 9800 9832 G-4 2-1/2",6spf 6/14/98 / , 9800 9815 Reperf 2",4spf 2/04/04 9825 9835 Reperf 2",4spf 2/04/04 9894 9964 G-5 2-1/2",6spf 6/3/98 9896 9906 Reperf 2",4spf 2/04/04 TD= 10,750' Max angle=36°@ 6,600' G-21RD WBS 05.12.08.doc Revised 04/28/12 by MDD • • .• ti PROPOSED McArthur River Field,TBU Hil,.np Un.ku.IJ.0 Well: G-21RD Completed: Future RKB 42.15 CASING DETAIL L , SIZE WT GRADE TOP BTM. 26" Surf 356' 20" 94# H-40 Surf 822' 13-3/8" 61/68# J-55 Surf 5201' 9-5/8" 40/47# N-80/P-0Surf 7,930' L 7" 29# N-80 7543' 10,747' DV at 2,595' (9-5/8") TUBING DETAIL 2-7/8" 6.511 I RO Surf ±9,400' \ / Jewelry Detail KOP for L No Depth ID Item sidetrack Hanger At 7850' 1 ±9,460' Pump Intake e a t; Perforation Detail Top Btm Top Btm Zone (MD) (MD) (TVD) (ND) Amt SPF Date G-1 9,614' 9,645' 8,628' 8,658' 31' 2-1/2",6spf 6/11/1998 G-1 9,615' 9,635' 8,629' 8,649' 20' 2-1/2"4 SPF 5/4/2008-DIL - G-1 ±9,620' ±9,630' ±8,634' ±8,644' ±10' Future G-1 G-1 9,625' 9,640' 8,638' 8,653' 15' 2",4spf 2/4/2004 thru G-1 ±9,675' ±9,685' ±8,687' ±8,697' ±10' Future G-5 G-2 9,668' 9,688' 8,680' 8,700' 20' 2'''A"4 SPF 5/4/2008-DIL - G-3 9,737' 9,767' 8,747' 8,776' 30' 2-1/2",6spf 6/14/1998 G-3 9,750' 9,768' 8,759' 8,777' 18' 2'A"4 SPF 5/4/2008-DIL G-3 9,755' 9,765' 8,764' 8,774' 10' 2",4spf 2/4/2004 G-3 ±9,756' ±9,766' ±8,765' ±8,775' ±10' Future Landing G-4 9,784' 9,794' 8,792' 8,802' 10' 2'A"4 SPF 5/4/2008-DIL at G-4 9,785' 9,793' 8,793' 8,801' 8' 2",4spf 2/4/2004 Collar ' G-4 9,800' 9,815' 8,808' 8,822' 15' 2 A"4 SPF 5/4/2008-DIL 10,662 G-4 9,800' 9,832' 8,808' 8,839' 32' 2-1/2",6spf 6/14/1998 / \ G-4 ±9,808' ±9,818' ±8,816' ±8,825' ±10' Future G-4 9,825' 9,833' 8,832' 8,840' 8' 2'''/"4 SPF 5/4/2008-DIL G-4 9,825' 9,835' 8,832' 8,842' 10' 2",4spf 2/4/2004 G-5 9,894' 9,964' 8,899' 8,967' 70' 2-1/2",6spf 6/3/1998 TD= 10,750' G-5 9,896' 9,906' 8,901' 8,911' 10' 2",4spf 2/4/2004 Max angle=36°@ 6,600' G-5 ±9,925' ±9,935' ±8,929' ±8,939' ±10' Future Updated: 02/13/15 by JLL . .. II Grayling Platform G-21RD Current 02/04/2015 Hilrurp Vaasa.LU Grayling 21 Tubing hanger,CIW-DCB, 133/8X95/8X41/2 11X4%2EUE8rd lift and 4 1/2IBT susp,w/4"type H BPV profile,7" EN,%" non continuous control line BHTA,CIW,4 1/16 5M FE X Internal Acme knockup iIltlw III L gl '''K° -*, - - 111/ Tree, Block,CIW-F, 11 5M FE X 4 1/16 5M,single master 1109 and swab,w/7" FBB pocket, -4_, --------, ..ilL,..,___ . 1/2 control line exit, EE trim -r• o vi; \�/ c"r aii . . Ii.. Tubing head,CIW-DCB, III ISI Valve,CIW-F, 2 1/16 5M FE, 13 5/8 3M X 11 5M,w/2- , c fo1.; : it HWO,AA 2 1/16 5M SSO,X-bottom I en(P:,ell 1■,-j.. prep, o 1%2 VR profile I11 ' lin 1111 5__ a . aI' Valve,CIW-F,2 1/16 5M FE, Casing head, I11 1 I I I Cameron WF, _ _ HWO,AA 13 5/8 3M X fill �o/.,133/8SOW,w/2-21/16 •1pI &Pt1' ' ' 5M EFO P, .. ,.. II Grayling Platform G-21 Proposed ESP 02/04/2015 Hilnorp:Mario.LIM Grayling Platform Tubing hanger,CIW-DCB-ESP, G-21 11 X 3''A EUE lift and susp,w/ 13 3/8 X 9 5/8 X 3 1/2 3"type H BPV profile,5'/.EN, 2-3/8 continuous control line ports,prepped for BIW penetrator BHTA,Bowen,3 1/8 5M FE X 3" Bowen Quick Union III n. .' Valve,swab,WKM-M, / O 0 31/85MFE,HWO, 8141(r"-) 4) T-24 0'6-10,r .. y Valve,wing,WKM-M, F-ASA7 0 Fr i 2 1/16 SM FE,H WO, u�_o1O,I 1 O Valve,WKM-M,3 1/8 5M FE,w/ MA-16 operator T-24 1 .I/MI 1.. 0 Valve,lower master,WKM-M, n� -o 4) 31/85MFE,HWO,T-24Q-• ' ..._1O III 11 III II Adapter,CIW-Toadstool, 11 5M Stdd X 3 1/8 5M FE,prepped for [_ 5'/.ESP neck,2-1/2 npt continuous tVi _ control line ports t or _! i______ . Tubing head,CIW-DCB, 11111111— �G.c 135/83MX115M,w/ 2 21/16 SMSSO, SI i III Valve,WKM-M,2 1/16 5M FE, X bottom J 11 ' HWO,DD � t_j r o' °o III I Iii 1.1 ilw..4. or Casing head,CIW-WF, yI� ! Valve,CIW-F,2 1/16 3M FE, 13 5/8 3M x 13 3/8 SOW w/ III 111 HWO,AAtrim 2-2 1/16 5M SSO CA slips in ',• - head Ilia Illialtr>, 411111111: • . __. 11 Grayling Platform BOP Stack Moncla 04/24/2014 Iililrnrp Utast.1.IA: Grayling Platform 2014 Workovers BOP Drawing Moncla tit iii iiiiii iii •ii 3.75' Shaffer 13 5/8 5M SI 1 I til til iii Jj UL ttinw L 4.67' C U '. 2 7/8-5 variables * , ' =egtlmp— Blinds iii ill.II iii iii iii iii iii iii i!i . 2.00' Kill Side r� - � r Choke side 3 1/8 SM w/HCR ��'�.4 } r .:F?.�� 3 1/8 5M w/HCR %�� ,� = iii ii'"'1',iii iit' �' �! `�' 1.00'to 2.00' „, , ,,, in ,,, Drill deck 14.20' Riser 13 5/8 5M FE X 13 5/8 5M FE di in III in AU4U J Spacer spool 3.00' 13 5/8 5M FE X 13 5/8 5M FE �t in(nun LIMP 01.1.1. 2.83' Spacer spool 13 5/8 5M FE X 11 5M FE • Moncla 301 BOP Test Procedure Hilrorp Uaskn.i.i.c Attachment#1 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Moncla 301, Grayling Platform 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. 2) 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 • Moncla 301 BOP Test Procedure Hilcorp Alaska,LU; 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. 3) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 4) 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) Test all Rams and Valves 1) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 2) 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. RCVCIVED STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COM ION ~AY Y 5 ZOOS. REPORT OF SUNDRY VIIELL OPERATIONSjq+~a Olil 8 ~~ Cons. Commission ._ . 1. Operations Abandon Repair Well Plug Perforations Stimulate Other Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well 2. Operator Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number. Name: Development Q • Exploratory^ 198-064 ~ 3. Address:. PO Box 196247, Anchorage, AK 99519. Stratigraphic^ Service ^ 6. API Number. 50-733-20267-01 ' 7. KB Elevation (ft): 9. Well Name and Number: 42' G-21 RD ' 8. Property Designation: 10. Field/Pool(s): Grayling Platform ADL0018730 ~ "G" Zone 11. Present Well Condition Summary: Total Depth measured 10750' MD feet Plugs (measured) true vertical 9740' TVD ~ feet Junk (measured) Effective Depth measured 9899' MD feet true vertical 8903' TVD feet Casing Length Size MD TVD Burst Collapse Structural Conductor 356' 26" 356' .355' Surface 822' 20" 822' 821' 1530 psi 520 psi Intermediate 5201' 13-3/8" 5201' 4,822 3090 psi 1540 psi Production 7930' 9-5/8" 7930' 7075' 5750 psi 3090 psi Liner 3204' 7" liner 10,747 9737 8160 psi 7020 psi , Perforation depth: Measured depth: 9614' - 9964' ~yw~~~ ~~iA1~NE® MAY 2 '2 2008 True Vertical depth: 8,628' - 8967 Tubing: (size, grade, and measured depth) 3-1/2", 4-1/2" L-80 9535'; 340' Packers and SSSV (type and measured depth) Baker 85-40 Perm Packer @ 9450', 4-1/2" Baker TE-5 SSSV @315' 12. Stimulation or cement squeeze summary: Intervals treated (measured): S ~L MAY 2 21008 n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing. Pressure Prior to well operation: 64 2093 171 780 100 Subsequent to operation: 61 1935 283 835 100 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory^ Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: OilO Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 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: N/A Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 907-276-7600 Date 5/7/2008 Form 10-404 Revised`04/2004 ~ ~ (~ I n' ~ ~ t~~'~~~ Origirl~0'nlys~• tlg Chevron Chevron -Alaska Daily`Operations Summary Well Name Field Name APWWI LeaselSerial Orig KB Elev (ftK6) Water Depth (ft) G-21 RD MCARTHUR 507332026701 ADL0018730 .99.0 Jobs AFE No. Qt: UWDAK-D8029-FJ(P Daily Operations 5/1/2008 00:00 - 5/2/2008 00:00 Operations Summary Run 2.7" GR and 2 7/8" Spent dummy gun in preperation for pert. Tagged fill at 9899' RKB 5/4/2008 00:00 - 5/5/2008 00:00 Operations Summary Rig up and begin G-zone RE- erfi 9616'-9636' 9669'- 9689' 9751'- 9769', 9785'-9795', 9801'-9816', 9826'-9834'. 5/5/2008 00:00 -5/6/2008 00:00 Operations Summary Complete reperf and turn well to production • • Trading Bay Unit, Grayling Platform Well G-2112D Completion 6/98 RKB 42.15 1 SOP fo ~t 785( SIZE WT GRADE TOP BTM 26" Surf 356' 20" 94# H-40 Surf 822' 13-3/8" 61/68# J-SS Surf 5201' 9-5/8" 40/47# N-80/P-110 Surf 7,930' 7" 29# N-80 7543' 10,747' Tubing: 3-1/2" 9.3# L-80 Imp. Butt 340' 9,535' 4-1/2" 12.6# L-80 Mod. Butt Tbg. Hgr. 340' 5, JEWELRY DETAIL NO. Degth Item 1. 42.1' 4-1/2" EUE x BTC TBG Hangar 2. 312' 4-1/2" 12.6 lb/ft Butt Tbg (To SSSV) 3. 315' 4-1/2" Baker TE-5 TRSSSV 3.8" Profile. x-over 4-1 /2" x 3 -1 /2" Butt. 4.-15. 3-1/2" MACCO GLM's 2447, 4310, 5311, 5712, 6210, 6674, 7170, 7669, 8168, 8571, 9001, 9401 16. 9,450' Baker 85-40 FB Permanent Packer 17. 9,467' 15' Seal Bore Extension 18. 9,502' "X" nipple profile (2.813") 19. 9,535' OTIS WLREG Perforations TOP BTM ZONE Perf Method Date 9825 9833 DIL G-4 2 ''/z" 4 SPF 5/4/08 9800 9815 DIL G-4 2 ''/z" 4 SPF 5/4/08 9784 9794 DIL G-4 2 ''/z" 4 SPF 5/4/08 9750 9768 DIL G-3 2 ''/z" 4 SPF 5/4/08 9668 9688 DIL G-2 2 ''/z", 4 SPF 5/4/08 9615 9635 DIL G-1 2 1/2" 4 SPF 5/4/08 9614 9645.5 G-1 2-1/2", 6spf 6/11/98 9625 9640 Reperf 2", 4spf 2/04/04 9675 9685 G-1 2", 4spf 2/04/04 9737 9767 G-3 2-1/2", 6spf 6/14/98 9755 9765 Reperf 2",4spf 2/04/04 9784 9794 G-4 2-1/2", 6spf 6/14/98 9785 9793 Reperf 2", 4spf 2/04/04 9800 9832 G-4 2-1/2", 6spf 6/14/98 9800 9815 Reperf 2", 4spf 2/04/04 9825 9835 Reperf 2",4spf 2/04/04 9894 9964 G-5 2-1/2", 6spf 6/3/98 9896 9906 Reperf 2", 4spf 2/04/04 TD =10,750' Max angle = 36° @ 6,600' G21 RD Schem updated OS-08.doc REVISED: S/7/2008 JLD DRAWN BY: DNM RECE\vfo MAY 1 5 'lOOB Union Oilanpany of California 909 W. 9th .ue Anchorage, AK 99501 Tele: (907) 263-7889 E-mail: oudeand@chevron.com Fax: (907) 263-7828 Chevron . . ".. r· .' Clìnl!l~~jiou Debra Oudeqo;.M Uti f... b,~::¡>Ü{\:>' . Technologist Ao<x\\)(ðí1J To: AOGCC Helen Warman 333 W. 7'h Ave. Ste#100 Anchorage, AK 99501 196-013 i 507332047000 .. .... ... . .L.m .mm .m ............. .....m 1 204-186 i 502312002800 ¡ HAPPY VALLEY- . A10 Date: May 11, 2006 ,,:j(..:~i¡\h\ì£1,.. 'ii/)~!J W;,;I v,. "'_Y" o~'1íS1 \Ò\lb~ '\ ~ \ (1" ~ ¡ MUL TIFINGER IMAGING TOOL i COMPLETION RECORD 2' · OMEGA HSD 6SPF . . . . . i 7250:8020" . : pds,txt 5 INCH ~ ................... .. ._.._~.', ~ ,....,.,.. ....,----.----,....... ............,.,..-..--.----- -' -' ',-' -' -....---................-... -' -' HAPPY VALLEY- 0 HALLIBURTON MAGNA CIBP A 11 1 SETTING RECORD ¡ 204-207 1502312002900'¡ HAPPY VALLEY: '!2.5poijIÊRGETH§OGuí\i1 . TŠÎí\iCH : A11 ' PERFORATION RECORD . 204-207 0 502312002900 16-Nov- . 6720-7190 1 05 16-Nov-T^¡¡à3ö:6990' '2' : 05 11 5 INCH pds .,....., o 1 , pds,txt o 204-207 ¡ 502312002900 HAPPY VALLEY- i COMPLETION RECORD . 51NCH 10-Nov- 7990-9085 ¡ A11 . HALLIBURTON CIBP FOR 3.5' . . 05 1 CASING /2.5 HSD POWER . ¡ JET 6 SPF PERF 199-054 501331012501 : SCU 21A-09 190-147 507331005501 TBF A-01RD 167-080 507332006800 m ¡ TBU D-01 198-064 507332026701 TBU G-21 RD 169-086 507332049800 TBU G-32 .-...'..".""...---.---....--....,-............---------.........".......---.----.....,......... · COMPLETION RECORD 2.5 i OMEGA HSD 6 SPF '1 1 1 ¡ pds 1 51NCH 01-May- o 06 10095- 10450 .....__....___....._,....""'....________......""......,.,..uuu_..__"... , COMPLETION RECORD 2 · HSD POWER JETS 4SPF 5 INCH : 02·Feb- 5300-6015 1 06 . pds ¡cÖMPLEiïÖÑRECORÓ331à ¡ 51NCH 1 Heb- i 9280-9414 , HSD POWER JET 6 SPF, 60 : 06 : PHASING . 1 o pds ...u..".".,......" uu..."""......, .."""".. COMPLETION RECORD 2.25 5 INCH : 29-Jan- ¡ 9615-9833 POWERJET HSD GUNS, 4 i 06 SPF, 60 DEG, GAMMA RAY / CCL CORRELATION : pds, pdt COMPLETION RECORD 2.875 f 5 INCH POWERJET HSD GUNS, 4 · SPF, 60 DEG, GAMMA RAY / 1 CCL CORRELATION ..,_........u....uu_uu_... 31-Jan- . 9180-9950 o 06 ; pds, pdt Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. I ReceIved By: C. ~__--- I Date S-¡;'>If!1y- STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 7 2006 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Convnission Anchør~ U Stimulate U Other l.j Reperforate D Waiver D Time Extension D D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 198-064 ServiceD 6. API Number: 50-733-20267-01 9. Well Name and Number: G-21 RD 10. Field/Pool(s): McArthur River Field, HEMLOCK OIL; MIDDLE KENAI G OIL ~,(.. 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 42.15' RKB to TH 8. Property Designation: Grayling Platform/Cook Inlet 11. Present Well Condition Summary: RECEIVI::U Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development 0 Stratigraphic D Total Depth measured 10,750' feet true vertical 9,740' feet Effective Depth measured 10,662' feet true vertical 9,653' feet Casing Length Size MD Structural 356 26" 356 Conductor 822 20" 822 Intermediate 5,201 13-3/8" 5,201 Intermediate 7,930 9-5/8" 7,930 Liner 3,204 7" 10,747 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 4,291 189 820 2,423 257 780 15. Well Class after proposed work: ExploratoryD Development 0 16. Well Status after proposed work: Oil0 Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Perforation depth: Measured depth: 9,614 to 9,964' True Vertical depth: 8,628 to 8,967' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 130 170 x Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Signature ?~::0. G/\-7~ /' /," ? / Form 10-404 Revised 04/2004 Plugs (measured) 10,662' landing collar Junk (measured) TVD Burst Collapse 355 821 1,530 psi 520 psi 4,822 3,450 psi 1,950 psi 7,057 9,440 psi 5,310 psi 9,737 8,160 psi 7,020 psi S(;ANNEJ) f E. B {) 7 2006 3-1/2" 9.3# L-80 @ 9,535',4-1/2" 12.6# L-80 @ 340' 4-1/2" Baker TE-5 TRSSSV @ 331', Baker 85-40 Permanent Packer @ 9,450' n/a RBDMS BFL FEB 0 8 2006 Tubing Pressure 110 115 Service 0 GINJ 0 WINJ 0 WDSPL D Sundry Number or N/A if C.O. Exempt: n/a Title Drilling Manager Phone 907-276-7600 Date Z - 7- --c:b AFE 164857 Submit Original Only .----.-11..' Well Name G-21 RD Primary Job Type Perforating Jobs Lease/Serial ADL0018730 I Primary Wellbore Affected Main Hole AFE No. QC Eng 164857 Daily Operations 1/23/200600:00 -1/24/2006 00:00 Operations Summary MI/RU. RIH with dummy gun and work wellbore. 1/24/200600:00 -1/25/2006 00:00 Operations Summary RIH with dummy gun to work wellbore. Wait on perforating. 1/29/200600:00 -1/30/2006 00:00 Operations Summary Gun run #1. Tie into SLB CEL dated 5/30/98. reperforate G-Zone 9,825 to 9,833' (9825' - 9833' DIL); 2.25" HSD hollow carrier, 4SPF, 60 deg phasing, all shots fired. Gun run #2. Tie into x-nipple and tubing tail. Perforate 9,815 to 9,800' (9800' - 9815' DIL); 2.25" HSD hollow carrier, 4SPF, 60 deg phasing, all shots fired. Gun run #3. Tie into tubing tail. Perforate 9,795 to 9,785' (9784' - 9794' DIL); 2.25" HSD hollow carrier, 4SPF, 60 deg phasing, all shots fired. 1/30/200600:00 -1/31/2006 00:00 ·Operations Summary Gun Run #4. Tie into x-nipple and tubing tail. Perforate 9,769 to 9,751' (9750' - 9768' DIL); 2.25" HSD hollow carrier, 4SPF, 60 deg phasing, all shots fired. Gun Run #5. Tie into x-nipple and tubing tail. Perforate 9,615 to 9,630' (9615' - 9630' DIL); 2.25" HSD hollow carrier, 4SPF, 60 deg phasing, all shots fired. RD/MO. Turn well over to production. w........ ~ Trading Bay Unit, Grayling Platform Well G-21RD Completion 6/98 RKB 42.15 SIZE WT GRADE TOP BTM 1 26" Surf 356' 2 20" 94# H-40 Surf 822' _I C :) I 3 ~ 13-3/8" 61/68# J-55 Surf 5201 ' L 9-5/8" 40/47# . N-80/P-110 Surf 7,930' - 7" 29# N-80 7543 ' 10,747' 4 Tubing: .~ 3-1/2" 9.3# L-80 Imp. Butt 340' 9,535' 5 4-1/2" 12.6# L-80 Mod. Butt Tbg. Hgr. 340' L _6 ~ .~ 7 DV at 2,595' JEWELRY DETAIL (9-5/8") NO. Depth Item .18 1. 42.1' 4-1/2" EVE x BTC TBG Hangar .J9 2. 312' 4-1/2" 12.6 lb/ft Butt Tbg (To SSSV) 3. 331 ' 4-1/2" Baker TE-5 TRSSSV 3.813" Profile. "'- .~ 10/ x-over 4-1/2" x 3-1/2" Butt. ¿ ~ ill 4.-15. 3-1/2" MACCO GLM's ¿ ~ 2447,4310,5311,5712,6210,6674,7170, 12 KOP for 7669,8168,8571,9001,9401 13 sidetrack .~14 16. 9,450' Baker 85-40 FB Permanent Packer At 7850' _15 17. 9,467' 15' Seal Bore Extension 18. 9,502' "X" nipple profile (2.813") 19. 9,535' OTIS WLREG - - 2{ ~ 16 17 lR "---./ Perforations 19 0-1 TOP BTM ZONE Perf Method Date through 9614 9645.5 0-1 2-1/2",6spf 6/11/98 0-5 9615 9630 0-1 Reperf 4spf 1/30/06 9675 9685 0-2 2-1/2",4spf 1/ 1 0/03 9737 9767 0-3 2-1/2",6spf 6/14/98 9769 9751 0-3 Reperf 4spf 1/30/06 9784 9794 0-4 2-1/2",6spf 6/14/98 9795 9785 0-4 Reperf 4spf 1/29/06 9800 9835 0-4 2-1/2",6spf 6/14/98 9815 9800 0-4 Reperf 4spf 1/29/06 9825 9833 0-4 Reperf 4spf 1/29/06 9894 9964 0-5 2-1/2", 6spf 6/3/98 >< Landing Collar at 10,662' / " TD = 10,750' Max angle = 36° @ 6,600' Wellbore _Diagram REVISED: 2/7/2006 DRAWN BY: DNM ., ) STATE OF ALASKA ALASKK~bIL AND GAS CONSERVATION COMMI:.. bN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Ope rat. Shutdown 0 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 Stratigraphic 0 Stimulate U Other ~ Reperforate, Add Perf Waiver 0 Time Extension 0 G Zone Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 98-64 Service 0 6. API Number: 50-733-20267 -01 9. Well Name and Number: G-21 RD 10. Field/Pool(s): "G" Zone 7. KB Elevation (ft): 42' 8. Property Designation: Grayling Platform 11. Present Well Condition Summary: Total Depth measured 10750' MD feet true vertical 9740' TVD feet Effective Depth measured 10,662' MD feet true vertical9,604'TVD feet Plugs (measured) Junk (measured) Casing Length Size MD TVD Burst Collapse Structural Conductor 356' 26" 356' 355' Surface 822' 20" 822' 821' 1530 psi 520 psi Intermediate 5201' 13-3/8" 5201' 4,822 3090 psi 1540 psi Production 7930' 9-5/8" 7930' 7075' 5750 psi 3090 psi Liner 3204' 7" liner 10,747' 9737' 8160 psi 7020 psi Tubing: (size, grade, and measured depth) 3-1/2", 4-1/2" L-80 95~g';;34Ö1 Perforation depth: Measured depth: 9614 - 9964' True Vertical depth: 8,628 - 8967' Packers and SSSV (type and measured depth) Baker 85-40 Perm Packer @ 9450',4-1/2" Baker TE-5 SSSV @315' , 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: SCANNED FEB 1. 5 2005 RBDMS BFL FEE 1 4 200S 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 3692 252 1020 4092 294 1030 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: Oil0 Gas D WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 217 172 Tubing Pressure 105 100 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service D x GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Signature - ? ::YC þ Form 10-404 Revised 04/2004 ;;7 Title Drilling Manager Phone 907-276-7600 Date 2/1/2005 Submit Original Only 4 5 6 7 8 9 10/ 11 ~ 12 13 14 16. 9,450' 17. 9,467' 15 18. 9,502' 19. 9,535' 16 '" ) UNOCAL8 RKB 42.15 L 1 2 ....... c ) 13 L ~ ~ DV at 2,595' (9-5/8") " L KOP for sidetrack L. At 7850' - - ~ ,X 17 1 X ~ 19 0-1 I through 0-5 >< Landing Collar at 10,662' / " TD = 10,750' Max angle = 36° @ 6,600' SIZE 26" 20" ~ 13-3/8" 9-518" 7" Tubing: 3-1/2" 4-1/2" NO. Depth 1. 42.1' 2. 312' 3. 315' 4.-15. ') Trading Bay Unit, Grayling Platform Well G-21RD Completion 6/98 WT GRADE TOP BTM Surf 356' 94# H-40 Surf 822' 61/68# 1-55 Surf 5201' 40/47# N-80/P-II0 Surf 7,930' 29# N-80 7543' 10,747' 9.3# L-80 Imp. Butt 340' 9,535' 12.6# L-80 Mod. Butt Tbg. Hgr. 340' JEWELRY DETAIL Item 4-1/2" EVE x BTC TBG Hangar 4-1/2" 12.6 lb/ft Butt Tbg (To SSSV) 4-1/2" Baker TE-5 TRSSSV 3.8" Profile. x-over 4-1/2" x 3-1/2" Butt. 3-1/2" MACCO GLM's 2447,4310,5311,5712,6210,6674,7170, 7669,8168,8571,9001,9401 Baker 85-40 FB Permanent Packer 15' Seal Bore Extension "X" nipple profile (2.813") OTIS WLREG Perforations TOP BTM ZONE Perf Method Date 9614 9645.5 0-1 2-1/2", 6spf 6/11/98 9625 9640 Reperf 2",4spf 2/04/04 9675 9685 0-1 2",4spf 2/04/04 9737 9767 0-3 2-1/2", 6spf 6/14/98 9755 9765 Reperf 2",4spf 2/04/04 9784 9794 0-4 2-1/2", 6spf 6/14/98 9785 9793 Reperf 2",4spf 2/04/04 9800 9832 0-4 2-1/2", 6spf 6/14/98 9800 9815 Reperf 2",4spf 2/04/04 9825 9835 Reperf 2",4spf 2/04/04 9894 9964 0-5 2-1/2",6spf 6/3/98 9896 9906 Reperf 2",4spf 2/04/04 021RD Schem 6-14-98 REVISED: 1/25/2005 CRW DRAWN BY: DNM ') ) 2/4/04 MI/RU. PJSM. PT 500/2500 psi. WIH with gun # 1, GRICCL, tool saver, and weight bar. Tied in wi GR on Schlumberger CBL 5/30/98. CCL could not distinguish collars. Logged up into tubing jewelry. CCL of little benefit. No tight spots inlout several times. TD at 9914. Using GR located WLRG at 9530. Fired gun. Perforated 9896- 9906 (10 feet). No indication on line gun fired. Refired. Positive firing on computer. Logged up and POOH. WIH with gun # 2, GRICCL, tool saver, and weight bar. Tied in wi line flag and GR to Schlumberger CBL 5/30/98. Initiated firing of gun. Looked good. Logged up and POOH. Gun did not fire. RD for night wi cap on pump-in sub. Checked out tool string 2/5104 PJSM. RU. PT 2500#. RIH with gun # 2 and CCL. Tied in wi collars on Schl CBL 5-30-98 and jewelry on completion log, January 2003. Fired gun. Perforated 9825-9835 (10 feet). Logged up and POOH. RIH with gun # 3 and CCL. Fired gun. Perforated 9800-9815 (15 feet). Logged up, jewelry right on. POOH. RIH with gun # 4 and CCL. Tied in wi collars and jewelry as before, and marked line. Fired gun. Perforated 9785-9793 (8 feet). Refired. Logged up and POOH. RIH with gun # 5 and CCL.Tied in as before. Fired gun. Perforated 9755-9765 (10 feet). Logged up into tail, marked line. POOH. RIH with gun # 6 and CCL and tied in as before with collars and jewelry. Fired gun. Perforated 9675-9685 (10 feet). Logged up and verified tie-in. POOH. RIH with gun # 7 and CCL and tied in. Fired gun. Perforated 9625-9640 (15 feet). Logged up and verified tie-in. POOH. RD. Turned well over to production. SDFN. SUMMARY: Perforated all 7 intervals per program. (78 total feet of Gzone). 9625-9640, 9675-9685, 9755-9765, 9785-9793, 9800-9815, 9825-9835, 9896-9906 No problem with scale in tubing. One tool string malfunction, misfire. G-21 RD (161728) morning report summary, CONFIDENTIAL: last revised 1/25/2005, Page 1. ') ) ~~IÆ~! :F fÆ~fÆ~~fÆ AI1ASHA. OILAlVD.GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR December 10, 2004 333 w. -¡nt AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dwight Johnson Field Superintendent Unocal PO Box 196247 Anchorage, Alaska J:t1 (,tj~ \ 4~;;;¡jP~ 99519 RE: Safety Valve System Inspections No Flow Tests Trading Bay Unit, Grayling Platform Dear Mr. Johnson: On November 23, 2004 the Alaska Oil and Gas Conservation Commission ("AOGCC") inspected Unocal's Grayling platform, Trading Bay Unit. The Commission's inspection included witnessing semi-annual safety valve system ("SVS") tests, no-flow tests on four wells, and general platform safety inspections. The platform was found to be clean, orderly, and in good condition. The SVS associated with thirteen of the platform's wells were tested. Eleven wells were not tested during the November 23 inspection - four wells were shut in for no-flow testing, two wells were not tested at the request of the platform supervisorl, and five wells were not tested due to their "long term shut in" status. Unocal must provide a schedule for completing the semi-annual testing of the six wells2 that would normally be in operation, and provide the Commission with sufficient notice when SVS testing will be conducted so these tests can be witnessed. The Grayling platform production wells utilize artificial lift gas to produce hydrocarbons. It is unclear if a catastrophic failure of a well or flowline component will automatically shutdown artificial lift gas, or if the well will flow for several hours until it depressures. Unocal is requested to provide an explanation and relevant supporting flow schematics with sufficient detail to demonstrate the emergency shutdown system and its control over the artificial lift gas. 1 TBU G-14 (PTD 168-080) and TBU G-18DPN (pTD 183-135); reason for not testing was concern about disrupting the platform's fuel gas supply 2 TBU G-12 RD3, G-14, G-18DPN, G-21, G-31, and G-33 SCANNED DEG 1 420D¿¡ ) ) Dwight Johnson December 9, 2004 Page 2 of2 We also note that safety valve system test results at Grayling are not routinely provided to the Commission. Unocal should begin reporting all safety valve system tests to the Commission, particularly those tests that are not witnessed by a Commission inspector. Please contact Mr. Bob Fleckenstein at 793-1242 to get the proper reporting format. No Flow Tests Wells G-12RD3, G-21, G-31, and G-33 were no-flow tested on November 23 to determine if they qualify for removal of the subsurface safety valve. Each well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored for 3 hours. Gas flow rates less than 180 SCF per hour, and total liquid recovery less than ~ gallon during the 3-hour monitoring period were determined for each well tested. Based on the results of no flow tests, the subsurface safety valve may be removed from service in Wells G-12RD3, G-21, G-31, and G-33. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in each well 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, S~t:r~~ James B. Regg ( ( Petroleum Inspection Supervisor cc: Bob Fleckenstein File: TBU G-12RD3 (pTD 202-055) TBU G-21RD (pTD 198-064) TBU G-31 (pTD 169-072) TBU G-33 (pTD 170-011) ') ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~ d3/D4- DATE: November 23, 2004 FROM: Jeff Jones Petroleum Inspector SUBJECT: No-Flow Test Unocall Grayling PL T G-21 PTD .1980640 McArthur River Fieldl TBU November 23,2004: I traveled to the Grayling Platform in Cook Inlet to witness a No-Flow Test on Unocal's McArthur River Field well G-21. Unocal representative Darrel Bruce performed the test today in a safe and proficient manner. Well G-21 was lined up from the production tubing through a 1" hose terminating in an open top drum. Gas flow from this well was such that it was below the amount measurable (180 SCFH) with the Armor-flow model 3461-03TO flow meter usually used for No-Flow Tests. This well utilizes artificial lift gas to produce hydrocarbons, which was shut in at least 12 hours previous to the test, and the well was allowed to depressure into the test separator. This artificial lift gas. may not be automatically shut off in the event of a catastrophic failure of well head or flow line components, depending on the nature of the failure. In the event of such a failure, it may be necessary to block in the lift gas manually, and in any case the well may flow for several hours unassisted until it depressures. Flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas flow from the well during the test did not exceed the maximum permissible 900 SCF hourly flow rate and no significant amount of fluid was produced. Summary: I witnessed a successful No-Flow Test on Unocal's McArthur River Field well G-21 on the Grayling Platform in Cook Inlet. Attachments: none ÇÇ¡ Dwight Johnson I J.C. Watski (Unocal) . , , .", ...:'::-.We# No-FloW :.Tešì Dåtå ".< - .. , . . .:. ,'- "."...:. ',.' Operator: Operator Rep: AOGCC Rep: FieldlU nitJPad U nocal Darrell Bruce Jeff Jones MRFffBU Gra lin PLT Well: G-21 Date 11/23/2004 :~ " ~ Gas <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH Liquid < 1 cup < 1 cup <1 cup <1 cup < 1 cup < 1 cup < 1 cup Start Test 11:45 AM 12: 15 PM 12:45 PM 1: 15 PM 1:45 PM 2:15 PM 2:45 PM End Test Produced to open top container. Total liquid produced: < 1/2 gallon SCANNED DEC 142004 RJF 09/19/02 Page 1 of 1 NO-FLOW Grayling PLT G-2111-23-04 JJ.xls Unocal Alaska 909 W 9th Ave Anchorage, AK 99501 T ele: (907) 263-7889 Fax: (907) 263-7828 Email: oudeand@unocal.com UNOCAL8 ..-Alaska Debra A Oudean G & G Technician January 29~ DATA TRANSMITTAL To: From: Lisa Weepie Debra Oudean 333 W 7tn Ave, Suite 100 909 W. 9th Avenue Anchorage, AK 99501-3539 Anchorage, AK 99519-6247 AOGCC Unocal Alaska Transmitting as follows: :.{~-,~.~~4}::;];:, .i\.;p~i\\;V.:;.~;-¡;\§.::'f/:'~¥~.:l:i: ~~~JYP.E:.';t.¡:~~:? . . /~ ~ÇA~~.~~. ~o.q.D~!:E J~'~~~\ï~¡:, ~~~I~.~t,;.: FlLM Ç.D 1~f.~~. 1~-dPL{ TBU G-21RD .COMPLETIONRECORD 5 INCH 9380-9900 1 L 1 1 q 17~-Œ7 . l~i~-~¡3~~w~~~i::;;~:;~:~::~--~~{~--I~¡~~~iiE~~~-M~~----- f ~f!3 r:~ ~:::--f:~p~:~:~~~~~~=s-l:~~==-!::~-lP¡~ ---I TBU M-16RD CEMENT BOND LOG ¡5INCH 111/13/200313859-3958 1 ~o ~Cß- '8 TŠUM:j6RDr~g~~t~~~~~~~~:Hsõ-PÖWERFLõwsr-1iÑcH-111ï3í2õÕ~27s5-38õ6----11:¡¡4i1rr-rlõ----- J 8q -1.13 ~Bu-M:5-----1~§:~Ê~~~~~~~¡¡D\iELõc¡TŸ-šTÃiNGPACKER---liÑëft---PiÏ25f2ÕÕ31~335õ-l/;m~1---rlo--~ RECEIVED f:~~.p 2 6 ?ô04 -_U ....I.i t~a5ka OU & Gas Cons. Commission ¡'l.nfMrage of this transmittal or FAX to 907 263-7828. Date: ~CIÅ\\N\~E[' ~~lA~~ 1 î~ 20B{~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 2O ACC 25.280 1. Type of request Abandon E) Suspend El Operation Shutdown El Perforate X Variance Alter Casing Q Repair Well Q Plug Perforations Q Stimulate El Time Extension Change Approved Program El Pull Tubing r~ Perforate New Pool Q Re-enter Suspended Well 2. Operator Name: 4. Current Well Class 5. Permit to Drill Number: Union Oil Company of California/Unocal 98-64 3. Address: Development X Exploratory Q 6. APl Number: PO Box 19-0247, Anchorage, AK 99519 Statigraphic ~ Service E) 50-733202670~ 7. KB Elevation (ft): 9. Well Name and Number 99 KB above MSL G-21RD 8. Property Designation: Steelhead Platform, Cook Inlet 10. Field/Pool(s): Trading Bay/Grayling Gas Sands Pool 11. Present well condition summary Total depth: measured 10,750 Feet Plugs (measured) true vertical 9,740 Feet Effective depth: measured 10,662 Feet Junk (measured) true vertical 9,653 Feet Casing Length Size MD 'I'VD Burst Collapse Structural 356 26" 356 355 Conductor 822 20" 822 821 1,530 psi 520 psi Intermediate 5,201 13-3/8" 5,201 4,822 3,450 psi 1,950 psi Intermediate 7,930 9-5/8" 7,930 7,057 9,440 psi 5,310 psi Liner 3,204 7" 10,747 9,737 8,160 psi 7,020 psi Perforation depth: measured 9,614-9,646; 9,737-9,767; 9,784-9,794; 9,800-9,832; 9,894-9,964; true vertical 8,628-8,658; 8,746-8,775; 8,791-8,801; 8,807-8,838; 8,899-8,967; Tubing (size, grade, and measured depth) 3-1/2" 9.3# L-80 @9,449', 4-1/2" 12.6# L-80 @331' Packers and SSSV (type and measured depth) 4-1/2" Baker TE-5 TRSSSV, Baker 85-40 Permanent Packer 12. Stimulation or cement squeeze summary Intervals treated (measured) n/a Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to Well operation 127 3 86 1100 150 Subsequent to operation 137 131 1192 1160 190 Daily Report of Well Operations: X 16. Well Status after proposed work: Oil X Gas I~i Copies of Logs and Surveys Run WAG El GINJ E] WlNJ O WDSLP 17. I hearby certify that the foregoing is true to the best of my knowledge. Sundry Number: Contact: Printed Name: Steve Tyler Title: Workover Foreman/Engineering Technician Signature: ....-"~ . Phone: 907-263-76,~ _~' ~ ~ ! ~_/. ~,'!9_~!:05/28/03 ORIGINAL JUN 0 2 2003 Alaska Oi{ & Gas Cons. Commi: sion Anchorage SIZE 26" 20" 13-3/8" 9-5/8" 7" Tubing: 3-1/2" 4-1/2" Trading Bay Unit, Grayling Platform Well G-21RD Completion 6/98 WT GRADE TOP BTM 94# H-40 61/68# J-55 40/47# N-80/P-110 29# N-80 9.3# L-80 Imp. Butt 12.6# L-80 Mod. Butt Surf 356' Surf 822' Surf 5201' Surf 7,930' 7543' 10,747' 315' 9,449' Tbg. Hgr. 331' (.OP for sidetrack it 7850' DV at 2,595' (9-5/8") NO. Depth 1. 42.1' 2. 312' 3. 315' 4.-15. 16. 9,450' 17. 9,467' 18. 9,502' 19. 9,535' JEWELRY DETAIL Item 4-1/2" EUE x BTC TBG Hangar 4-1/2" 12.6 lb/ft Butt Tbg (To SSSV) 4-1/2" Baker TE-5 TRSSSV. x-over 4-1/2" x 3-1/2" Butt. 3-1/2" MACCO GLM's Baker 85-40 FB Permanent Packer 15' Seal Bore Extension "X' nipple profile (2.813') OTIS WLREG 19 16 G-1 ~ough G-5 Landing Collar at 10,662' TOP 9614 9737 9784 9800 9894 Proposed Perforations BTM 9645.5 9767 9794 9831.5 9964 ZONE G-1 G-2 G-3 G-4 G-5 PerfMethod Date 2-1/2", 6spf 6/11/98 2-1/2", 6spf 6/14/98 2-1/2", 6spf 6/14/98 2-1/2", 6spf 6/14/98 2-1/2", 6spf 6/3/98 TD = 10,750' Max angle = 36° ~ 6,600' G-21RD completion 6-14-98 REVISED: 5/28/2003 DRAWN BY: DNM January 8, 2003: Mobilize Slick line crew & send in E-line Crew; Change out Tree cap; RU lubricator, Test wire (ok); M/up BHA #1; Test lubricator t/2100 psi (ok); RIH w/2.7" star bit (BHA #1) noting jewelry (noted 9800-9820' RKB WLM weight loss bobble & fall thru & work tools thru same w/no problem) continue; RIH t/set dn@ 10189' RKB SLM three times; POOH w/BHA #1 no problems. LD & ck BHA #1, PU BHA #2; RIH w/BHA #2 (2-1/2" dummy gun 20') & set dn@ 9450'; RKB WLM Work dummy gun f/9440' t/9550'; EOT till little to no resistance either way RIH & tag TD @ 10189'; POOH w/BHA #2 w/no problems; LD, bkdn & ck BHA #2, RD lubricator; Flow testing & set up E-line for "G" zone perforations; January 9, 2003: Continue Flow test well; RD SWS Flange X 5" hydro lux conn, pump in sub & night cap off G-24 & install new 4-1/8" flange X 5"; Tree cap on G- 24, Remove 4-1/8" flange X internal; RU lubricator & sheaves & pressure test lubricator t/2100 Psi (ok); Arm & PU Gun #1 RIH w/Gun run #1 (BHA #3) 2-1/2" power jet 20' w/6 spf @ 60 deg phasing; Noting jewelry. Set dn@ 9452' RKB WLM Work Gun #1 (BHA #3) F/9448' t/9478' with up to 500# over pulls; POOH LD Gun #1 (BHA #3) & rig off; Lubricator to RU slick line t/run Gauge Ring; Move Slick line Equipment From west pipe rack to east pipe rack; MU tools (BHA #4) & RU on SWS lubricator RIH w/2.75" Gauge Ring (BHA #4) & set dn@ 9458' RKB WLM Work Tools & chip scale f/9458' t/9536' RKB WLM fell out of EOT. RIH & stop @ 9625' RKB wlm; POOH t/9420' & Work tools f/9420' t/9580' till little to no resistance; POOH LD BHA #4 & rig off SWS Lubricator; RU SWS back up; RIH w/RR Gun #1 (BHA #3RR) 2-1/2" power jet 20'wi 6 spf @ 60 deg phasing; Noting jewelry & tight spot t/9550' RKB WLM & pull back thru tight spot; RIH t/10047' & pull tie in t/9480'; RIH & place Gun on depth & perf G-5 interval f/ 9944' t/9964'; POOH t/9700' & flag line; Continue POOH noting tight spot & jewelry (ok); LD & ck RR Gun #1 (BHA #3RR) (all shots fired); PU & m/up, Arm gun #2 (BHA #5); RIH w/Gun run #2 (BHA #5) 2-1/2" power jet 24'w/6 spf @ 60 deg phasing; Tie into flag @ 9700'; RIH & pull tie in pass f/10140' t/9780' & place gun on depth & perf interval G-5 fl 9920' t/9944'; POOH t/9700' & flag line. Continue POOH noting tight spot & jewelry (ok) LD & ck Gun #2 (BHA #5) (all shots fired); January 10, 2003: RIH wi Gun run #3 (BHA #6) 2-1/2" power jet 24'w/6 spf @ 60 deg phasing; Set down @ 9455' KB & work gun thru t/9503' & fell thru; RIH to flag @ 9700' & tie in to same; Pull back thru tight spot T/9380' w/up to 220# over pulls; RIH & work gun back thru tight spot f/9455' t/9503' RKB WLM; Continue RIH t/10130'; Pull tie in pass f/10130' t/9892' & place gun on depth & perf interval G-5 f/9896' t/9906'; POOH t/9300' & flag line; Continue POOH noting tight spot & jewelry (pulled max 120# over thru tight spots); LD & ck Gun #3 (BHA #6) (all shots fired); PU & MU, Arm gun ~, (BHA #7) RIH w/Gun #4 (BHA #7) 2-1/2" power jet 15' w/6 spf @ 60 deg phasing; Continue RIH t/10072'; Pull tie in pass f/10072' t/9821' & place gun on depth & perf interval G-4 f/9825' t/9835'; POOH t/9300' & Re-flag line; Continue POOH noting tight spot & jewelry (pulled max 430# over thru tight spots); LD & ck Gun #4 (BHA #6) (all shots f~ & MU, Arm gun #5 (BHA #8); RIH wi Gun #5 (BHA #8) 2-1/2" power jet 20' w/6 spf @ 60 deg phasing; Noting jewelry & tight spots; Tie into flag @ 9300'; Continue RIH; Pull tie in pass f/10072' t/9792' & place gun on depth & perf interval G-4 f/9800' t/9815'; POOH t/9300' & Re-flag line; Continue POOH noting tight spot & jewelry (pulled max 210# over thru tight spots) LD & ck Gun #5 (BHA #8) (all shots fired) PU & m/up, Arm gun #6 (BHA #9); RIH w/Gun #6 (BHA #9) 2-1/2" power jet 10'wi 6 spf @ 60 deg phasing (dn loaded t/7') Noting jewelry & tight spots; Tie into flag @ 9300'; Continue RIH & set dn@ 9498' kb (X nipple) & work thru same; RIH & set dn@ 9800' KB (top shot of last gun run) attempt to work gun thru same; Pull tie in pass f/set dn@ 9800' t/9778' & place gun on depth & peri: interval G-4 f/9785' t/9792'; POOH t/9300' & re-flag line. Continue POOH noting tight spot & jewelry (pulled max 170# over thru tight spots); LD & ck Gun #6 (BHA #9) (all shots fired); PU/MU, Arm gun #7 (BHA #10); RIH w/Gun #7 (BHA #10) 2-1/2" power jet 10'wi 6 spf @ 60 deg phasing; Noting jewelry & tight spots Tie into flag @ 9300'; Continue RIH & set dn@ 9800'; KB (same as last run); Pull tie in pass f/set dn@ 9800' t/9470" & place gun on depth & perf interval G-3 f/9755' t/9765'; POOH t/9300' & re-flag line. Continue POOH noting tight spot & jewelry (pulled max 490# over thru tight spots); LD & ck Gun #7 (BHA #10) (all shots fired); PU/MU, Arm gun #8 (BHA #11) RIH wi Gun #8 (BHA #11) 2-1/2" power jet 10' w/6 spf @ 60 deg phasing; Noting jewelry & tight spots Tie into flag @ 9300'; Continue RIH & set dn@ 9800' KB (same as last two run); Pull tie in pass f/set dn @ 9800' t/9470" & place gun on depth & perf interval G-2 f/9675' t/9685'; POOH t/9300' & Re-flag line; Continue POOH noting tight spot & jewelry (pulled max 180# over thru tight spots); LD & ck Gun #8 (BHA #11); PU/MU, Arm gun #9 (BHA #12); RIH w/gun #9 (BHA #12) 2-1/2" power jet 20'wi 6 spf @ 60 deg phasing; Tie into flag @ 9300' continue RIH & set dn @ 9800' KB (same as last three run) & attempt to work thru same no-go; Pull tie in pass f/set dn@ 9800' t/9470" & place gun on depth & perf interval G-1 f/9675' t/9685'; POOH noting tight spot & jewelry (pulled max 20# over thru tight spots) January 11, 2003: Continue POOH noting jewelry LD & ck Gun #9 (BHA #12); Rig off well & turn well over to production for flow test & secure equipment; RD/MO. Beverly Harrison Business Ventures Assistant Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (@07) 263-7828 E-mail: harrisonb~unocal.com UNOCAL May 30, 2002 To: Lisa Weepie AOGCC 333 W. 7th Ave. Anchorage, AK 99501 DATA TRANSMITTAL- Alaska / Offshore / Grayling Platform Dry Samples G-5RD 7290'-9000' Box 1 of 3h_ J q } ~-]~ 0 9000'-9960' Box 2 of 3 '/nc 9960'-10650' Box 3 of 3 G-2I_RD 7870'-9300' Box I of 3 9..r~t.~ 9300'-9890' Box 2 of 3 / 9890'-10950' Box 3 of 3 Please acknowJcd~¢/ receipt by~igning .~gd/e~rnir/g one copy of this transmittal or FAX to (907) 263-7828. Received by: ~ '~[ Date: ~ ¢ X ~ Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: childersd@unocal, com UNOF. AL( Debra Childers Geotech Assistant DATA TRANSMITTAL February 16, 1999 To: Laurie Taylor From: Debra Childers 3001 Porcupine 909 W. 9th Avenue Anchorage, AK 99501 Anchorage, AK 99519-6247 Alaska Oil & Gas Unocal Transmitting the following items: DATE Well Medium SCALE LOG TYPE DATE ON CHECKED-IN LOG ; 2/8/99 D-42 B-Line 5 Perforation Correlation Log 10/10/98 2/8/99 D-42 B-Line 5 Perforation Summary Log 10/13/98 2/8/99 , D-42 Film 5 Perforation Correlation Log 10/10/98 12/8/99 . D-42 Film 5 Perforation Summary Log 10113198 2/8/99 G-21 RD B-Line 5 Perforation Summary Log 11/16/98 2/8/99 · G-21RD Film 5'Perforation Summary Log 11/16/98 2/8/99 ~1, (_, G-40 B-Line 5!Through Tubing Inflatable Packer Summary 11/20/98 2/8/99 u/ . G-40 Film 5 Through Tubing Inflatable Packer Summary 11/20/98 2/8/99 G-6 RD B-Line 5 Production Profile-Long String Flowing 12/8/98 2/8/99 G-6 RD B-Line 5 Production Profile-Short String Flowing 12/8/98i 2/8/99 , G-6 RD Film 5 Production Profile-Long String Flowing 12/8/981 2/8/99 o G-6 RD Film 5 Production Profile-Shod String Flowing 12/8/98 2/8/99 G-6RD B-Line 5 Production Profile-Both Strings Flowing 12/8/981 2/8/99 · G-6RD Film 5 Production Profile-Both Strings Flowing 12/8/981 2/8/99 K-25 B-Line 5 Perforation Summary Log 9/23/98 2/8/99 o K-25 Film 5 Perforation Summary Log 9/23/98 2~8/99 t.x.~ r...K-4RD B-Line 5 Perforating Record 12/29/98 2/8/99 J K-4RD B-Line 5 Perforating Record 12129/98 2/8/99~ · K-4RD Film 5 Perforating Record 12/29/98 2/8/99 K-4RD Film 5 Perforating Record 12/29/98 2/8/99 M-1 B-Line 5 Perforation Summary Log / Gamma Ray / CCL 11/1/98 2~8/99 , M-1 Film 5 Perforation Summary Log / Gamma Ray / CCL 11/1/98 2/8/99 M-29 B-Line 5 Digital Fluid Entry Tool 12/21/98 2/8/99 M-29 B-Line 5 Perforation Summary Log 12/5/98 2/8/99 M-29 B-Line 5 Production Profile __ __ ~. _.__ ,, ~.1;~/~5/98 ~{0,0o3 g?,,, 0'5% ;rfr~ _ ¥-,s~gmng rang one copy al or Date: t 7 1999 ~'~% O{t & Gas Cons. C0mmi~n ~aska And 0ra e STATE OF ALASKA ALASKA , ND GAS CONSERVATION CL -- ,'IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Union Oil Company Of Califonia (UNOCAL) 98-64 3. Address 8. APl Number P.O. Box 196247, Anchorage, AK 99519 50-733-20267-01 4. Location of well at surface Conductor No~.2;-~-,eg~._3..Grayling Platform , ,,~.,~,,,~,~-~. 9. Unit or Lease Name At Top Producing Interval i i 1' ;~--- 10. Well Number 115 FSL, 1668 FWL, Sec28,T9N, R13W, SM ?: .~¥~i~J3 i ! G-21RD At Total Depth -~ ~ - 11. Field and Pool ?.~ '7 ....... -~ ~'~ 30'FSL, 1875' FWL, Sec 28, T9N, R13W, SM ~'; .................. :" McArthur RivedMiddle Kenai "G" Zone/ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Hemlock 99' KB above MSL ADL-18730 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 5/15/98 5/24/98I 6/3/98 (Completed)I 99' RT feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 119. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10,750' MD/9740' TVD 10,662' MD/9,604'TVD Landing CoilI Yes: X No:I 331' feet MD N/A 22. Type Electric or Other Logs Run GRIDITEICNTHILD TDISD T IAMS 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 26" Drive Pipe 42.5 356' Driven 0 20" 94 H-90 42.5 822' 26" 779 sx 0 13-3/8" 61/68 K-55 42.5 5201' 17-1/2" 1550 sx 0 9-5/8" 40/47 N-80/P-110 42.5 11,160' 12-1/4" 2000 sx 0 7" liner 29 L-80 7543' 10,747' 8-1/2" 510 sx 0 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9,449' MD 9,450' MD G-5 Interval 9894-9964' MD (8899-8966' TVD), 6spf 4-1/2" 331' MD G-1 Interval 9614-9645.5' MD (8628-8659' TVD), 6spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. G-3 Interval 9737-9767' MD (8741-8775' TVD) 6spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED G-4 Interval 9784-9794' MD (8792-8802' TVD) 6spf G-4 Interval 9800-9831.5' MD (8807-8838' TVD) 6spf 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 6/4/98I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 6/4/98 24 TEST PERIOD => 582 1900 1026 209/64I 326 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 110 1040 24-HOUR RATE => 30 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. 6 1998 · , Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Middle Kenai G-1 9612' 8626' Middle Kenai G-2 9662' 8674' Middle Kenai G-3 9738' 8748' Middle Kenai G-4 9783' 8991' Middle Kenai K-5 9893' 8898' Hemlock B-1 10112' 9112' Hemlock B-2 10150' 9149' Hemlock B-3 10250' 9247' Hemlock B-4 10347' 9244' Hemlock B-5 10435' 9429' Hemlock B-6 10558' 9551' 31. LIST OF ATTACHMENTS directional survey, completion drawing, summary history 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.~~ ~"~ c..4.,.._~ Title ~"~,'~ '~\~j /¢L~v- Date Oc.-I'.~ I, t~* INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each 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- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Grayling G-21RD Summary History Grayling G-21RD was spudded on 15 May 1998. The well was sidetracked from the existing 9-5/8" casing at 7,850' MD (6,989' TVD) and drilled directionally to TD at 10,750' MD (9,740' TVD). A 7" liner was mn and cemented at 10,747' (TOL at 7,543') and the well was subsequently completed 3 June 1998 as a 3-1/2" single string gas lift producer in the Middle Kenai "G" Zone as follows: G-1 Interval 9894-9964' 6spf G-3 Interval 9737-9767' 6spf G-4 Interval 9784-9794', 9800-9831.5' 6spf G-5 Interval 9894-9964' 6spf Trading Bay Unit, Grayling Platform Well G-21RD Completion, 6/3/98 KOP for Redrill @ 7850' DV at 2,595' (94/8-) SIZE WT GRADE TOP BTM 26" 20" 94-g 13-3/8" 61/68# 9-5/8" 40/47# 7" 29# Tubing: 3-1/2" 9.3# 4-1/2" 12.6# NO. Depth Surf 356' H-40 Surf 822' J-55 Surf 5201' N-80/P-110 Surf 7,930' N-80 7543' 10,747' L-80 Imp Butt. 341' 9,449' L-80 Mod Butt Tbg. Hq. 331' JEWELRY DETAIL Item 1. 42.1' 2. 312' 3. 315' 4.-15. 16. 17. 18. 19. 9,450' 9,467' 9,502' 9,535' 4-1/2" EUE x BTC TBG Hangar 4-1/2" 12.6 lb/fl Butt Tbg (To SSSV) 4-1/2" Baker TE-5 TRSSV. Xover 4-1/2" x 3-1/2" buttress Twelve 3-1/2" MACCO GLM's Baker 85-40 FB Permanent Packer 15' Seal Bore Extension "X" nipple profile (2.813") OTIS WLREG Landing Collar @ 10,662' N-~719 16 G-1 Thru G-5 ttB-1 liB-4 Perforations TOP BTM ZONE 9614' 9645.5' G-1 9737' 9767' G-3 9784' 9794' G-4 9800' 9831.5' G-4 9894' 9964' G-5 Later Later Perf Method 2-1/2", 6spf 2-1/2", 6spf 2-1/2.", 6spf 2-1/2", 6spf 2-1/2", 6spf Date 6/11/98 6/10/98 6/10/98 6/10/98 6/3/98 TD = 10,750' Max angle = 36° @ 6,600' G-21RD 1.doc REVISED: 6/16/98 DRAWN BY: DNM Grayling G-21 Re-drill Daily Summary May 1998 5/7/98 5/8/98 5/9/98 5/1 O/98 5/11/98 5/12/98 5/13/98 5/14/98 5/15/98 Skidded rig to G-21rd, leg #3, slot #2. Assembled crown attachment for top drive torque rail and lifted to crown. Installed crown attachment for top drive torque tube. Picked up swivel, top drive and torque tube. Installed upper rail braces and straps. Pulled service lines to rig floor. Rigged up top drive in derrick. Hung kelly hose from standpipe. Moved drill pipe to drillers side of pipe rack. Rigged up APRS 2 1/4" jet cutter. Set down in GLM ~ 8165' and hung up. Worked loose and down through mandrel. Located cutter ~ 9292'. Attempted to cut tubing, POH, cutter had not tn:ed. Made up cutter w/new cap and RIH & placed cutter ~ 9297'. Cutter fired. Pressured tubing to 500 psi and perforated tubing w/(5) .22" holes ~ depth 8700'. No pressure bleed off, POH. Rigged up #2 tubing perforating gun. Placed @ depth 7404' and perforated w/(5) .22" holes. Communication to annulus. Circulated well. Shut down and observed well. Nippled down and removed Cameron 4" block tree. Pressure tested all BOPE. Performed accumulator test. Pulled two way check. Cut tubing at 7896'. Circulated bottom up, some gas and oil off bottom. Pulled hanger and laid down landing joint. POOH laying down 2- 7/6" single gas lift completion. Rigged up Dowell. Changed top pipe rams to 5". Laid down test plug and ran wear bushing. RIH with clean out assembly. Install stops on top drive. R/up SWS and complete perforating/explosives checklist. Set EZSV at 7873'. Pressure test 9-5/8" casing to 2500 psi. RIH w/whipstock and tag EZSV ~ 7874'. Sheer off'whipstock .Break circulation and displace well to mud. Mill window f/7850' t/7862'. Mill formation f/7862' t/7877' and dress window. Perform FIT to 14ppg EMW. POOH for drilling assembly RIH with directional assembly and drill from f/7876' t/7908'. 1998 5/16/98 -5/23/98 Directionally drilled with motor from 7908' to 10750' TD. 5/25/98 5/26/98 5/27/98 5/28/98 5/29/98 5/30/98 5/31/98 6/1/98 6/2/98 6/3/98 POH w/bit and rigged up Schlumberger. Logged interval from 10750'- 7870'. Rigged down Schlumberger. Changed top pipe rams to 7". Pulled wear bushing, set test plug and pressure tested door seals to 250 & 3000 psi. Ran 3185' of 7" liner. Cont. RIH with 7" liner assembly to 10,700'. Began mixing cement. Dowell densiometer was not working so the decision was made to abort the job. Circulated out cement and POOH with liner running tool. Made up and RIH with tieback seal assembly to perform cement job. Stab into top of liner. Pumped cement. Dropped Baker plug and displaced w/139 bbls mud. POOH with seal assembly. Test BOP's 250- 5000 psi. R/H with clean out assembly and tag cement stringer at 6778'. Clean out to liner top and POOH Make up 6" bit and 7" scraper. Hydromatic main beating went out. Removed broken hydromatic brake from rig #54. Removed hydromatic & clutch assy from rig #77 and installed and tested in rig #54. RIH with clean out assembly. Circulate bottoms up. RIH and tag T.O.L ~ 7543'. Test casing, lap, & liner to 2592 psi. Change hole over to F.I.W and dump mud system. Continue to displace hole with FIW. POOH and lay down clean out assembly. Rig up SWS. RIH and log CBT-GR-CET f/10662' t/7543'. Rig down SWS. Make up TBE polishing assy. Polish TBE and POOH. RIH w/ZXP tie-back packer. Set prk ~ 7530', rotate offpaker, pressure up twice to 4000 psi to shear ball seat. POOH. Run 3-1/2" gas lif~ completion. Hook up control SSSV control line and pressure test to 5000 psi. Displace hole over to paker fluid. Land hanger and test seals to 500 psi. ND stack and NU tree. Installed SSSV control line, tested neck seals and ring gasket t/5000 psi. Pulled BPV & installed 2-way check and tested tree to 250 psi and 5000 psi. Moved rig equipment and cleared rig floor for perforating. Perforated the G -5 sand interval from 9894-9964'. Released well to Production. 6/10/98 -6/11/98 Perforated the remaining G-I, G-3, and G-4 intervals as follows: 9614-9645', 9737-9767', 9784-9794' and 9800-9831.5'. UNOCAL GRAYLING Platform G-21Rd slot %3-2 McArthur River Field TBU, Cook Inlet, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : PMSS <7938-10750> Our ref : svy5767 License : Date printed : 26-May-98 Date created : 14-May-98 Last revised : 26-May-98 18.018 18.018 46.577 212269.859 1415.40 W Clarke - 1866 Field is centred on n60 50 4.803,w151 36 Structure is centred on n60 50 4.803,w151 36 Slot location is n60 50 22.565,w151 36 Slot Grid coordinates are N 2502351.945, E Slot local coordinates are 1803.80 N Projection type: alaska - Zone 4, Spheroid: Reference North is True North Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0 00 100 00 200 00 300 00 400 00 5OO 00 600 00 700 00 800 00 900 00 1000 00 1100 00 1200 00 1300 00 1400 00 1500 00 1600 00 1700 00 1800 00 1900 00 2000 00 2100 00 2200 00 2300 00 2400 00 2500 00 2600 00 2700 00 28OO 00 2900 00 3000 00 3100 00 3200 00 3300 00 3400 O0 3500 O0 3600 O0 3700 00 3800 00 3900 00 4000 00 4100 00 4200 00 4300 00 4400 00 4500 00 4600 00 4700 00 4800 00 4900 00 5000 00 5100 00 5200 00 5300 00 5400 00 5500 00 5600 00 5700 00 0 0 0 0 0 0 0 1 1 2 5 8 9 12 15 17 17 18 20 27 33 33 33 33 32 0 00 0 50 198 0 68 197 0 70 201 0 68 204 0 70 186 0 75 171 0 73 170 0 73 162 0 77 179 0 67 183 0 67 181 0 67 184 68 182 67 177 68 180 75 144 83 141 92 138 00 129 25 306 27 315 50 114 23 99 33 86 83 99 85 108 88 106 17 106 83 107 57 107 62 108 17 109 00 110 72 110 20 110 17 110 83 111 0 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 32.58 112.00 32 57 113 00 33 34 35 35 35 35 35 35 36 34 34 32 32 33 34 35 36 35 27 113 00 68 114 00 72 114 00 72 114 00 67 115 00 45 115 00 32 116 00 12 116 00 15 116 00 87 117 00 08 118 00 73 118 00 67 119 00 68 119 00 70 119 00 15 120 00 50 120 00 33 120 00 0 00 100 00 199 99 299 99 399 98 499 97 599 96 699 96 799 95 899 94 999 93 1099 92 1199 92 1299 91 1399 90 1499 90 1599 89 1699 88 1799 87 1899 86 1999 86 2099 83 2199 81 2299 57 2398 87 2497 62 2595 66 2692 53 2788 39 2883 76 2978 76 3072 97 3164 35 3250 84 3334 36 3417 79 3501 49 3585 35 3669 50 3753 77 3837 71 3920 64 4002 35 4083 54 4164 76 4246 11 4327 64 4409 34 4490 61 4572 02 4654 45 4737.93 4822 08 4905 78 4988 50 5070 49 5151 56 5232 55 RECTANGULAR COORDINATES 7 8 9 11 12 13 14 15 16 18 19 20 2O 2O 18 18 20 20 21 26 33 41 49 59 69 82 98 117 136 155 174 194 214 235 258 281 305 329 354 379 404 429 455 481 507 533 560 587 615 644 674 0.00 N 0.41 S 1.40 S 2 54 S 3 65 S 4 81 S 6 06 S 34 S 58 S 85 S 10 S 27 S 43 S 61 S 78 S 96 S 09 S 18 S 34 S 93 S 29 S 87 S 98 S 58 S 78 S 61 S 39 S 60 S 44 S 98 S 11 S 21 S 10 S 86 S 67 S 52 S 24 S 31 S 11 S 72 S 95 S 24 S 69 S 43 S 62 S 20 S 13 S 41 S 95 S 85 S 99 S 83 S 61 S 14 S 38 S 58 S 84 S 17 S 0 00 E 0 13 W 0 44 W 0 84 W 1 30 W 1 60 W 1 57 W 1 35 W 1 04 W 0 83 W 0 85 W 0 89W 0 94 W 1 01 W 1 00 W 0 97 W 0 58 W 0 26 E 1 25 E 1 79 E 0 91 E 0 76 W 0 45 E 6.95 E 18.69 E 34 35 E 53 37 E 77 10 E 104 44 E 133 27 E 163 14 E 195 12 E 233 4 9 E 280 70 E 332 37 E 384 18 E 435 61 E 486 63 E 536 90 E 586.64 E 636.67 E 687 91 E 740 57 E 7 93 90 E 846 99 E 899 69 E 951 95 E 1003 78 E 1056 15 E 1108 13 E 1158 34 E 1206 95 E 1254 43 E 1302 29 E 1351 43 E 1401 26 E 1451 95 E 1502 75 E Dogleg Deg/100ft 0 00 0 5O 0 18 0 05 0 04 0 22 0 20 0 02 0 10 0 22 0 11 0 02 0 03 0 O3 0 06 0 04 0 45 0 09 0 10 0 92 1 25 0 20 3 71 2 89 3 44 2 53 3 49 3 07 1 28 0 73 0 73 2 08 6 56 5 85 0 72 0 52 0 03 0 64 0 60 0.54 0 70 1 52 1 03 0 00 0 59 0 22 0 59 0 20 1 03 1 41 0 97 1 35 0 54 1 02 1 02 0 73 1 35 1 17 Vert Sect 0.00 0.20 0 69 1 22 1 69 2 30 3 22 4 27 5 37 6 43 7 31 8 11 8 90 9 69 10 54 11 40 12 47 13 84 15 36 16 16 15 08 12 90 13 83 19 53 27 92 39 51 56 27 78 07 102 85 129 18 156 65 186 30 222 42 267 51 317 19 366 99 416 44 465 84 515 25 564 84 615 09 666 94 720 62 774 97 829 48 883 99 938 44 992 83 1047 79 1102 74 1156 60 1209 14 1260 84 1313 33 1367 24 1422 30 1478 74 1535 29 5800.00 5900.00 6000.00 6100.00 6200.00 6300 O0 64O0 O0 6500 00 6600 00 6700 00 6800 00 6900 00 7000 00 7100 00 7200 00 7300 00 7400 00 7500 00 7600 00 7700 00 7800 00 7938 00 8058 00 8120 00 8158 00 8192 00 8224 00 828 6 00 8380 00 8474 00 8534 00 8630 00 8694 00 8721 00 8854 00 8913 00 9007 00 9099 00 9198 00 9287 00 9471 00 9665 00 9759 00 9851 00 9943 00 10036 00 10128 00 10154 00 10693 00 34 34 33 34 34 34 34 35 35 35 35 35 35 36 36 35 34 33 33 28 27 26 25 25 24 23 20 20 19 19 19 19 18 18 18 17 17 16 15 14 13 13 12 11 11 8 36 30 121 0 35 77 121 35 63 121 93 119 38 120 90 120 15 119 50 119 50 120 88 120 08 121 58 121 83 121 58 121 32 120 60 121 27 121 10 122 67 122 25 124 33 126 30 136 10 139 10 140 20 137 40 133 30 132 00 133 00 124 80 121 10 118 80 119 60 118 40 118 00 118 90 117 70 117 20 119 60 118 40 118 40 117 50 117 60 117 80 116 10 114 30 113 50 112 30 111 00 112 5313 64 00 5394 00 5475 00 5557 00 5639 00 5722 00 5805 00 5887 00 5970 00 6052 00 6134 00 6215 00 6297 00 6378 00 6459 00 6541 00 6622 00 6702 00 6784 00 6865 00 6949 00 7064 00 7167 00 7222 50 7256 60 7287 60 7316 60 7372 20 7458 70 7545 40 7602 58 7692 90 7752 90 7778 00 7903 60 7959 60 8048 50 8135 40 8229 00 8314 10 8490 30 8677 00 8768 60 8857 30 8946 50 9037 00 9127 60 9153 00 9684 51 72 35 60 37 25 84 25 47 40 98 18 38 85 30 27 98 01 96 07 48 63 58 54 15 07 42 65 87 09 33 58 03 63 44 42 69 90 78 83 36 14 33 80 53 55 04 34 Single Shot Survey 10750.00 8.00 112.00 9740.78 Projection to T.D. - NO SURVEY DATA 703 88 S 734 17 S 764 23 S 793 11 S 821 11 S 849 17 S 876 73 S 904 06 S 931 95 S 960 41 S 989 51 S 1019 30 S 1049 36 S 1079 42 S 1108 85 S 1138 30 S 1168 52 S 1199 37 S 1230 43 S 1261 62 S 1293 50 S 1343 08 S 1388 14 S 1409 97 S 1422 79 S 1433 35 S 1442 71 S 1460 38 S 1483 89 S 1502 99 S 1513 49 S 1529 36 S 1539 90 S 1544 26 S 1565 10 S 1574 03 S 1588 07 S 1601 98 S 1616 71 S 1629 35 S 1654 10 S 1678 47 S 1689 61 S 1699 79 S 1708 99 S 1717 28 S 1724 62 S 1726 53 S 1760 03 S 155. 7 E 1603.59 E 1653.61 E 1703 62 E 1753 12 E 1801 72 E 1850 42 E 1899 74 E 1949 04 E 1998 33 E 2047 72 E 2097 30 E 2147.32 E 2197 35 E 2247 32 E 2297 31 E 2347 61 E 2397 95 E 2447 65 E 2495 71 E 2541 27 E 2598 30 E 2639 76 E 2658 42 E 2669 65 E 2680 00 E 2690 00 E 2708 89 E 2737 93 E 2767 32 E 2785 46 E 2814 11 E 2832 93 E 2840 82 E 2879 28 E 2896 22 E 2923 07 E 2948 64 E 2975 27 E 2998 85 E 3046 27 E 3093 69 E 3115 40 E 3135 55 E 3154 86 E 3173 55 E 3191 04 E 3195 81 E 3279 71 E 1 13 0 53 0 13 1 35 0 79 0 48 0 61 0 35 0 57 0 38 0 61 0 50 0 25 0 25 0 64 0 65 0 67 0 61 0 43 1 82 1 44 3 98 4 52 1 78 3 78 5 52 1 37 2 20 4 12 2 54 2 25 0 52 0 48 0 74 0 37 0 28 0 21 0 85 0 70 0 26 0 56 0 46 0 96 0 88 0 96 0 88 0 93 0 83 0 61 1591 85 1648 83 1705 35 1761 03 1815 73 1869 84 1923 65 1977 75 2032 22 2087 10 2142 51 2198 52 2255 06 2311 59 2367 64 2423 71 2480 55 2537 86 2594 88 2650 83 2705 53 2780 87 2842 06 2870 71 2887 72 2902 51 2916 20 2942 04 2979 17 3013 41 3033 62 3065 04 3085 77 3094 41 3136 25 3154 51 3183 36 3211 22 3240 40 3265 97 3316 89 3367 53 3390 72 3412 11 3432 22 3451.25 3468.76 3473.47 3556.24 1763.00 S 3287.06 E 0.00 3563.52 Ail data is in feet unless otherwise stated. Coordinates from slot %3-2 and TVD from wellhead (99.00 Ft above mean sea level). Bottom hole distance is 3730.01 on azimuth 118.21 degrees from wellhead. 135.39 degrees. method. Vertical section is from S 0.00 W 0.00 o ~ ~' D Calculation uses the minimum curvature 6 998 _~. : ell Compliance Report File on Left side of folder 198-064-0 TRADING BAY UNIT _ . MD 10750 TVD 09740 Completion Date: G-21RD 50- 733-20267-01 6~/3/98 Completed Status: 1-OIL UNOCAL Current: Name Interval Sent Received T/C/D L AST/GR (..,.¢~L MYLAR 7870-10696 OH 8/4/98 8/10/98 L CBL/GR ~q~AI~ MYLAR 7555-10634 5/30/98 CH 5 8/6/98 8/6/98 L CET -"F-'~AL 7555-10655 5/30/98 CH 5 8/6/98 8/6/98 L CN/LDT/GR ~ MYLAR 7870-10676 OH 8/4/98 8/10/98 L COMP RCD FINAL MYLAR 9400-10640 CH 5 8/4/98 0/10/98 L COMP RCD c-f~AL MYLAR 9614-9831 ~,// O/C{~ CH 5 8/4/98 0/10/98 L FEL -""~INAL MYLAR 7870-10696 OH 5 8/4/98 8/10/98 L PERF z--PINAL 9615-9964 CH 5 2/16/99 2/17/99 L PIL-SFL/GR ,-g~AL M.Y~R 7870-10748 OH 8/4/98 8/10/98 R SRVY LSTNG BH 0-10693. OH 7/1/98 7/5/98 Daily Well Ops 5/?/c[? (4/1~aO Are Dry Ditch Samples Required? yes ~nd Re~ Was the well cored? yes ~- Analysis Descriptiog. lbRe~civ~--at~? yc.r. qub-~ Sample St-t// Comments: Tuesday, May 30, 2000 Page I of I UNOCAL ) To' From: Name' Company: Fax Number: I.III Company: Fax Number: Phone' Date: 05/26/98 Jack Hartz AOGCC 907-276-7542 Mitch Datum UNOCAL Alaska Resources (907) 263-7884 (907) 263-7679 Number of Pages: 2 including cover sheet. Subject: Mr. Hartz: G-21 Redrill Directional Surveying I .11 R.II UNOCAL drilled to 10,232' with Bottom-Hole Assembly (BHA) number 3. The last survey taken with BHA# 3's MWD was ~ 10,154'. As per the variance given by yourself on May 22, 1998, we la.id down the MWD tool and finished drJllJJag G-21RD with BHA g4. At TI) (10,750'), a single shot survey was taken before POOH. Attached is a copy of the directional surveys taken for G-21RD. As discussed, the MWD tool was not included in BHA#4 to reduce the lost-in hole costs if BHAg4 became stuck. Historically, the coals above the G-zone, m the G-zone, and in the Hemlock have stuck tool s~ngs. If you have any questions, feel free to contact me. Mitch ~Oila O~sCons. Con~i~ FAX I AOOCC Q-Z1F,.D .doc Z,/; '~ q~t/'oI't 'd~O3 qVOONR ~Vg¢'6 866t 'gg'xe~ Comlr~y UNOC,~L , 1~ Cost~c~r & No, Pool ~[ ~- ~55 ' ~ MC~ ~BR ~D .... ~L DATA ~ ~~c6p6oa T~LCoo~, ~V S~t~. ~V -t415,~ M~. Decl~n 21.7~ C~uMe~d ~~ C~VA~ .... , . ............. ' D~ Teal ~p~ ~lc Db~fion ~ ~ g~fon ~-~Y48 ~ ~43.~ 13.10 114.30 ~.~ a946.80 343!.21 -170S.9~ 3154,88 0.96 ~.76 4,50 ......... _ ~-~Y-98' ~ i~,~ 123~ ll3,X0 ~.~' ~.~ 3451.23 -1717.24 3171.57 ...... _ ..... .. . ..... ~Y-PB '~ 10~4.~ 1L30 t11.~ 26.~ '~i~3'.~ ...... ~7~.4~ -1~6.49 "' ~195.83 .0.~3 ~.~ -I,54 ;,' _ . ............. . , J ~-~Y-98 ~ 1~50,~ 7,50 ilZ. 10 ~7.~ ~.4~ 35~.14 ~.~ 3288J3 0.88 .- . ......... , ........ - . ........... ................. ~ ..... _ ............................ ...................................... , . ................. _ .......... : ...... ~- - ................. ~ - ~:-~. ................ ..... ~ ........... . ~ ' _ ~ ~ _ ............. _ _ , ............. ~ - , .~ ..... .............. . ..... , ................ ~ ............... ~ ..................... .. ~ - _. : .... ~ _ - ..... _ : : ~ .. ~ . ..... - , , ..- _. - ~ ......... _ .............. ........ . I >- n. -,,,.., .,.=.. , ...... ,..=. Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-maih childersd@unocal, com UNOCAL ) Debra Childers Geotech Assistant DATA TRANSMITTAL August 6, 1998 To: Laurie Taylor From: Debra Childers Alaska Oil & Gas 3001 Porcupine 909 W. 9th Avenue Anchorage, AK 99501 Anchorage, AK 99519-6247 Unocal · Transmitting the following items:. TBU G-15RD I I5",2" Array Sonic Tool TVD · ~ I 7/21/98 TBU G-15RD 1 15" Array Sonic Tool/Gamma Ray VDL log li7/21/98 TBU G-15RD I 15",2" Array Sonic Tool 1!7/21/98 TBU G-15RD I 15",2" Density-Neutron/Gamma Ray 'I'VD 1~7/21/98 TBU G-15RD I 15",2" Array Induction Tool/Gamma Ray 1 7/21/98 TBU G-15RD I 15",2" Array Induction Tool/Gamma Ray TVD I 7/21/98 TBU G-15RD 1 15",2" Density-Neutron/Gamma Ray 1 7/21/98 TBU G-21 RD I 15" Cement Evaluation/Gamma Ray Log 1 5/30/98 TBU G-21 RD 1 15" Compensated Cement Bond/Gamma Ray Log 1 5/30/98 TBU G-5RD 1 15",2" Platform Express/Array Induction Imager/Gamma Ray 1 7/1/98 TBU G-5RD 1 15" Gamma Ray Tie in Log 1 7/6/98 TBU G-5RD 1 15" Cement Bond Log 1 7/5/98 TBU G-5RD 1 15" Cement Evaluation Log 1 7/5/98 TBU G-5RD I 1i5",2" Platform Express/Three Detector LithoDensity 1 7/1/98 Compensated Neutron/GR TBU G-5RD I 15",2" Thermal Decay Time Log 1 7/5/98 TBU G-5RD 1 15" Digital Sonic Array/Gamma Ray 1 7/1/98 Please acknowl~.dge r, eceipt by signing _and returning one copy of this transmittal or FAX ~to (907) 263-7828 I Received by: - I Date:.,,, ~- ~.:,~U(~ 06 "l~c)~ ~mge Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: childersd@unocal, com UNOCAL ) Debra Chlldem Geotech Assistant DATA TRANSMITTAL August4,1998 To: Laurie Taylor From: Debra Childers 3001 Porcupine 909 W. 9th Avenue Anchorage, AK 99501 Anchorage, AK 99519-6247 Alaska Oil & Gas Unocal Transmitting the following items:. · .-/L/,coq 7s'.oz,f 7z.oo:5 TBU D-1 I 115in PERFORATION RECORD 1 6118198 TBU D-26 I l i5in WHIPSTOCK SET RECORD 1 5/30/98 TBU D-27 I 1!5in PERFORATION RECORD 1 6/23/98 TBU G-17RD I 15in PRODUCTION LOGGING SUITE WITH n/a 5/18/98 MERGED PASSES TBU G-17RD 1 1 DIGITAL FLUID ENTRY IMAGER WITH n/a 5/18/98 GAMMA RAY TBU G-19 1 15in PACKER SET ~,L/("_.-, 1 6/12/98 TBU G-21 1 15in PLUG SETTING RECORD 1 5/13/98 TBU G-21RD 1 15in COMPLETION RECORD 1 6/10/98 TBU G-21RD 1 15in COMPLETION RECORD I 6/2/98 TBU G-21 RD 1 15in FORMATION EVALUATION QUICK LOOK I 5/25?98 TBU G-21 RD 1 15in ARRAY SONIC/GAMMA RAY LOG 1 5/25/98 TBU G-21RD 1 12in,5in PHASOR INDUCTION-SFL GAMMA RAY 1 5/25/98 LOG TBU G-21RD 1 112in,5in COMPENSATED NEUTRON LITHO- I 5/25/98 DENSITY GAMMA RAY LOG TBU G-5 1 15in DEVICE SET RECORD AND DEPTH 1 6/20/98 CONTROL LOG April 2, 1998 Re' ADMINISTRATIVE APPROVAL NO. 80.71 The application of Union Oil Company of California, operator of the Trading Bay Unit (TBU), to drill, complete and produce the TBU G-21RD well. Mr. Rick D. Cross Senior Landman Unocal Alaska Resources UNOCAL Corp. P. O. Box 196247 Anchorage, Ak 99519-6247 Dear Mr. Cross' Your application of March 25, 1998 for a permit to drill the TBU G-21RD development oil well indicates that the drilling and completion of the well will provide additional oil recovery from the Middle Kenai G and Hemlock Oil Pools. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the TBU G-21RD well pursuant to Rule 5 of Conservation Order No. 80. SO Chairman BY ORDER OF THE COMMISSION TONY KNOWLE$, GOVERNOR .%LASKA OIL AND GAS CONSERVATION CO~IISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: ,1907) 276-7542 Dalc Haines Drilling Engineer UNOCAL PO Box 196747 Anchoragc. AK 9c)519 Rc' Trading Bay Unit G-21RD UNOCAL Pcrmit No. ~)8-64 Sur. Loc. 1802'FSL. 1415'FEL. SEC. 29. TO9W. RI3W. SM Btmnhole Loc. 209'FNL. 1945'FWL. SEC. 33. TOgN. R I3W. SM Dear Mr. Haines: Enclosed is tile approved application for permit to rcdrill tile above referenced well. Thc pcrmit to rcdrill docs not cxcmpt you from obtaining additional pcrmits rcquircd by law from othcr govcrnmcntal agcncics, and docs not authorizc conducting drilling opcrations until all othcr rcqt, ircd pcrlnitting dctcrminations arc madc. Blov,'out prcvcntion cquipmcnt (BOPE) must bc tcstcd in accordancc with 20 AAC 25 035. Sufficicnt notice (approximatclv 24 hours) nmst bc given to allow a rcprcscntativc of thc Commission to xx'itncss a tcst of BOPE installcd prior to drilling ncxv hole. Noticc may bo given bx' contacting tile Comnlission at 279-1433. Davidk~. Johnston '¢'xx Chainna~ BY ORDER OF THE COMMISSION dlffEnciosurcs ce: Dcpartmcnt of Fish & Gamc. Habitat Section xv/o cncl. Dcpartmcnt of Environmcntal Conscrvation xv/o cnct. STATE OF ALASKA ALASK,- OIL AND GAS CONSERVATI -, I COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill: Redrill: X lb. Type of well Exploratory: Stratigraphic Test: Development Oil: X Re-Entry: Deepen: Service: Developement Gas: Single Zone: Multiple Zone: 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California (UNOCAL) 99' KB above MSL feet McArthur River Field 3. Address 6. Property Designation Middle Kenai G/Hemlock P.O. Box 196247, Anchorage AK 99519 ADL 18730 4. Location of well at surface Conductor No.2 Leg 3 Grayling 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1802' FSL, 1415' FEL, Sec 29, T9N, R13W, S.M. Trading Bay Unit AK Statewide Oil & Gas Bond At top of productive interval 8. Well number Number U62-9269 66' FSL, 1671' FWL, Sec 28, T9N, R13W, S.M. G-21RD At total depth 9. Approximate spud date Amount $200,000 209' FNL, 1945' FWL, Sec 33, T9N, R13W, S.M. 4/4/1998 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line Steelhead M-32 approches within 3335' feet 118' at 7752' TVD feet 3840 10767' MD, 9700' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 7700' feet Maximum hole angle: 36 deg Maximum surface 1350 psig At total depth ('i-VD) 3900 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD -I-VD MD TVD (include stage data) Existing 26" 1" wall Driven 356' 42.5 42.5' 356' 356 Driven Existing 20" 94 Lb H-40 Butt. 822' 42.5 42.5' 822' 715' 779 sx Existing 13-3/8" 61/68 lb K-55 Butt. 5201' 42.5 42.5' 5201 4524' 1550 sx Existing 9-5/8" 47 lb N-80/P-110 Butt. 7700' 42.5 42.5' 7700' KOP 6865' 2000 sx 8-1/2" 7" 29 lb N-80 Butt. 3267' 7500' 6693' I 10767' 9700' 500 sx 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary .... ~ ?.~ ~;~. ~.~ Total depth: truemeasuredvertical 10767' feets700, feet Plugs(measured) 0 ~ I ~__, ~! A L~, ~ "::~, ~..~.~, (~ ' Effective depth: measured 10677' feet Junk (measured) true vertical 9614' feet Casing Length Size Cemented Measured depth T~~ depth Structural 356' 26" Driven 356' 356' Conductor 822' 20" 779 sx 822' 715' Surface 5201' 13-3/8" 1550 sx 5201' 4524' Intermediate 7700' KOP 9-5/8" 2000 sx 7700' 6865' Production Liner 3267' 7" 500 sx 10767' 9700' Perforation depth: measured See attached schematic true vertical See attached schematic 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Diverter Sketch: Drilling program: X Drilling fluid program: X Time vs. depth plot: X Refraction analysis: Seabed report: 20 AAC 25.050 requirements: 21. I herby certify that the foregoing is true and correct to the best of my knowledge: u Commission Use OnTy Permit Number I APl number I AP proval d ate?d_/,[,.~y!s~ ISee cover letter ~'<~'-, ~ ~ 50- ,7.~ - .2__ <~ ~_ ~ ~" ~/ for other requirements Conditions of approval Samples required: [ ] Yes j~ No Mud log requir ~,No Hydrogen sulfide measures [ ] Yes 'J~<] No Directional survey required ~ Yes [ ] No Requiredw°rkingpressuref°rBOPE []2M; []3M;~d~C~r5M; []10M; []15M (,,~..,/ Other: Original lea David W.Johns"~ P by order of Approved by ' ~ommissioner the Commission Date: Form 10-401 Rev. 12-1-85 Submit in triplicate Unocal Alaska Business Unit Grayling Platform Well G-21RD Prepared by: Nell Magee Date:3/12/98 UNOCAL Summary of Procedure Drilling Hazards Lost Circulation Zones: None Overpressured Zones: None No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) 1 Prepare for sidetrack operations. 20.0 20 0.8 2 Make up and RIH with bottom trip whipstock assembly q~,~G' 14.0 34 1.4 3 Set whipstock and kick-off. 8.0 42 1.8 4 POOH with whipstock assembly 10.0 52 2.2 5 Conduct Leak offtest ~'~[ ~'- 2.0 54 2.3 6 Make up directional assembly and RIH 14.0 68 2.8 7 Drill from KOP to'I'D at 10,767' (includes BOP test) 180.0 248 10.3 8 [Make wiper trip and POOH to log 18.0 266 11.1 9 Conduct wireline operations I6.0 282 11.8 10 Make wiper trip and la)' down 8-1/2" BHA 18.0 300 12.5 11 Change rams to 7" and test door seals 2.0 302 12.6 12 Make ,up and run 7" liner 18.0 320 13.3 13 Circulate and cement liner 10.0 330 13.8 14 POOH with liner running assembly 9.0 339 14.1 15 Pressure test BOP's and change rams to 3-I/2" 6.0 345 14.4 16 Clean out liner with 6" bit and scrapper (P/U 3-1/2" drill pipe) i6.0 361 15.0 17 Displace well to completion fluid and test casin~liner lap 9.0 370 15.4 18 POOH with clean out asssembly 7.0 3,77.. 15.7 19 R/U Schlumberl~er and run CBL/CET/GR/CCL 7.0 384 16.0 20 IMake up Halliburton TCP assembly 4.0 388 16.2 21 ~RIH with gu, n assembly to West Foreland 12.0 400 16.7 22 Correlate space out and TCP perforate 10.0 410 17.1 23 POOH and lay down TCP assembly 12.0 422 17.6 24 Run permanen.t pack. er on wireline 6.0 428 17.8 25 Run 3-1/2" completion tubing with seal assembly, 16.0 444 18.5 26 Stab seals in and space out 4.0 448 18.7 27 Land tubing hangar and set BPV 4.0 452 18.8 28 N/D BOP's and N/U and test tree 8.0 460 19.2 29 Release well to Production 4.0 464 19.3 EZSV at 7750' SIZE 26" 20" 13-3/8" 9-5/8" Tubing: 2-7/8" NO. 1.-4 5. 6. o 8. 9. Tubing top at 8000' Trading Bay Unit, Grayling Platform Well G-21 (Proposed Abandoned Status Pre-Redrill) 3/98 WT GRADE TOP BTM Surf 356' 94# H-40 Surf 822' 61/68# J-55 Surf 5201' 40/47# N-80/P-110 Surf 11,160' 6.4# N-80 Butt 8000' 10,428' Depth 10,361' 10,371' 10,377' 10,417' 10,451' JEWELRY DETAIL Item 2-7/8" MACCO GLM's OTIS XA (2.313" ID) OTIS BWD Permanent Packer (4" ID) Seal Bore Extension (7.7') OTIS "X" nipple profile (2.313") OTIS WLREG (2.44") 10,870' CMT. RET. 11,004' Baker F Packer Tubing perfs at 9650' 6 7 HB-1 HB-2 HB-3 HB-4 TOP 9902 9994 10042 10105 10228 10958 10904 10882 11042 10930 10810 10770 11060 10755 10735 10660 10540 10605 10730 10540 10478 10477 10729 TD -- 11,160' Max angle = 38° ~ 10,100' Perforation Record BTM ZONE SPF DATE CO~¥~:NTS 9939 G-2 3HPF 4/98 abandoned 10034 G-3 3HPF 4/98 abandoned 10081 G-4 3HPF 4/98 abandoned 10125 G-4 3HPF 4/98 abandoned 10252 G-5 3 HPF 4/98 abandoned 10987 HB-5 1/75 abandoned 10930 HB-5 1/75 abandoned 10900 I-t]3-5 1/75 abandoned 11084 HB-6 3HPF 1/75 abandoned 10980 HB-5 9/89 abandoned 10850 HB-4 abandoned 10800 HB-4 abandoned 11080 HB-6 9/89 abandoned 10800 HB-4 abandoned 10745 HB-4 abandoned 10690 HB-3 4HPF 5/75 squeezed 10590 HB-2 2/80 squeezed 10635 HB-2 5/75 squeezed 10840 HB-4 4I-[PF 2/80 abandoned 10580 HB-2 squeezed 10506 HB-1 4HPF 2/80 abandoned 10505 HB-1 abandoned 10859 HB-4 ab andoned CompletionG-21 after abandonment.rtf REVISED: 3/13/98 DRAWN BY: DNM SIZE 26" 20" 13-3/8" 9-5/8" Tubing: 3-1/2" 4-1/2" Trading Bay Unit, Grayling Platform Well G-21RD Proposed Completion, 4/98 WT GI:G~E TOP BTM Surf 3 56' 94# H-40 Surf 822' 61/68# J-55 Surf 5201' 40/47# N-80/P-110 Surf 7,900' 29# N-80 7500' 10,767' 9.3# L-80 EUE 12.6# L-80 Butt 315' 9,400' Tbg. Hangar. 315' KOP for sidetrack At 770O' DV at 2,595' (9-5/8") NO. . 2. 3. 4.-10. 11. 12. 13. 14. Depth JEWELRY DET,~L Item 42.7' 312' 312' 9,400' 9,417" 9,447" 9,477' 4-1/2" EUE x BTC TBG Hangar 4-1/2" 12.6 lb/ft Butt Tbg (To SSSV) SSSV. 3-1/2" MACCO GLM's Permanent Packer Seal Bore Extension "X" nipple profile (2.313") OTIS WLREG (2.44") 14 G-1 G-2 G-3 G-4 G-5 HB-1 HB-4 Proposed Perforations TOP BTM ZONE Perf Method 9590' 9625' G-1 TCP 9660' 9680 G-2 TCP 9745 9765 G-3 TCP 9775 9835 G-4 TCP 9945' 9990 G-5 TCP 10160 10195 HB-1 10410 10520 HB-4 2-1/2" HC 2-1/2" HC TD = 10,767' Max angle --- 36° ~ 6,600' CompletionG-21RD Proposed completion.rtf REVISED: 3/17/98 DRAWN BY: DNM oHemLock G-~9 0 Pene',,,'-o,~cion P I.~B 3/15/98 ~-~ 00~-~ H-3t 0 0 G-~ M-~S 0 ~'~0 G-?,R.~ 0 GRAYLING 0 G-33 0 K-3OD;-I 0 ~'470 0 G-ti 0 0 0 G-34 G'~ G-:lO STEELH 0 PRDP LDC G-81RD 0 0 33 © 0 D-~,7 0 DRILLING FLUIDS M-I DrlUing Fluids L.L.C. UNOCAL GRAYLING PLATFORM WELL G-21 RD DEPTH INTERVAL 7700' MD (6857' TVD) 10,767' MD (9700' TVD) 8 1/2" HOLE 7" LINER MUD TYPE GENERIC MUD #2 MUD ADDITIVES M-i GEL/M-I BAR/SODA ASH/ DRISPAC/G ELEX/TAN NATHi N /CAUSTIC/FLO-VIS/LUBE 167/ TEKMUD 8588/SODIUM BI C AR B O N ATE/SO LTEX/ RESINEX/PHPA POTENTIAL PROBLEMS COST PER BARREL , TIGHT HOLE/GAS KICKS/LOST CIRCULATION/COAL SLOUGHING/DIFFERENTIAL STICKING $25.00 ESTIMATED TREATMENTS/PROCEDURES : ' ' ¢"'""'" Build mud with prehydrated bentonite, Drispac, inlet water and barite. Dispta~e~'~,9 well prior to running whipstock. . Hole angles of less than 40 degrees should not cause significant problems. Higher hole angles increase the probability of cuttings bed formation. Elevated Iow shear rate rheologies can be increased with Fie-Vis to inhibit the formation of cuttings beds. Maintain 3 RPM readings > 6. Rotation and reciprocation are beneficial in removing cuttings beds. o Control density with barite, fresh water, inlet water, and solids control equipment. Dump all sand traps as required. Keep mud weights as Iow as possible. Mud weights should range from 9.0 ppg to 9.6 ppg. Note: Higher mud weights may be required. MI-377 S NOTE: SEE REVERSE SIDE FOR UABIUTY CLAUSE DRILLING FLUID5 M-I Drilling Fluids L.L.C. . . . o . , Potential problems exist in coal sections. Soltex should be added up to 4 ppb minimize these problems. Add PHPA (Alcomer 60) to improve hole stability and increase solids encapsulation. Report drill solids analysis on mud check sheet. Report hydraulics calculations on mud check sheet. If torque is a problem. Lube 167 and Tekmud 8585 are both permitted for discharge. Do not exceed 2% by volume. Drill to 10,767' T.D. Run 7" liner. Complete with 3% KCI. 8 1/2 Hole Mud Formation Fresh Water/Sea Water Polypac FloVis Soltex Resinex PHPA 1 - 2 ppb .25- 1 ppb 2 - 4 ppb 2 ppb .25-.Sppb , MI-377 $ NOTE: SEE REVERSE SIDE FOR UABIUTY CLAUSE DRILLING FLUIDS M-I Drilling Fluids L.L.C. ANTICIPATED 8 1/2" MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels APl Fluid Loss pH MBT Drilled Solids 9.O- 9.6 ppg 42-75 sec/qt 10- 15 cps 10 - 20 #/100ft2 8/12/18 #/100ft2 4-6cc 8.5 -9.5 <20 ppb <50 ppb Note: This mud program is a guideline only. Hole conditions should dictate actual mud properties. DO NOT EXCEED M.A.C. of products or use products not approved in the discharge permit. See letter requesting authorization for list of approved products and M.A.C. Stuck pipe contingency: Use mineral oil/kwikspot pill if required for differential sticking. Follow procedures outlined in N.P.D.E.S. Discharge permit. 'UNOCAL GRAYLING PLATFORM WELL G-21 RD ESTIMATED FLUID COST Estimated drilling fluid cost based on 9.6 PPG mud weights $75,0OO · Completion Cost 3% KCI $3,500 MI-377 $ NOTE: SEE REVERSE SIDE FOR LIABIUTY CLAUSE StrucJ'ure : GRAYLING Platform Wail : O-21Rd Field : McArthur River FieldLocation : TBU, Cool< Inlet, Alaska uNOCAL ) 68OO 7000 7200 7400 7600 63 7800 (- 8000 8200 .-- -+~ 8400 63 8600 I 88oo V 9000 9200 g400 9600 9800 1 i ~ I I I I I tI I I I I I I I II ! I i 2600 2800 3000 3200 3400 3600 3800 4000 4-200 4400 4600 Vertical Section [fee'r) -> Azimuth 120.03 with reference 0.00 N, 0.00 E from slot #3-2 WELL PROFILE DATA ..... Point ..... MD Inc Dir TVO North E(3st V. Sect Deg/lO0 KOP / Sidetrack 7700.00 34.25 124..006865.96-1261.62 24-95.712792.08 0.00 End of Build/Turn 7725.00 36.43 120.45 6886.36--1269.312507.95 2806.52 12.00 Beg~n Drop/Turn 7825.00 35.25 115.71 6967.44- -1296.87 2559.56 2865.00 3.00 End of Drop/Turn 853§.13 19.57 134-.977599.71-14-71.9628;31.685188.20 2.50 Target G-21Rd G1T 25-F 9607.1719.57 154-.978607.00-1725.00 3085.00 5534.16 0.00 End of Hold 10105.98 19.57 134-.979077.00-1845.07 320.3.213695.59 O.OO ~ T.D.___= ~ En.__.~d of ,o,..__~d 10767.1~7 _19.5.___~7 134..9._.__Z.7 9700.0{3 -~1999.5_..__._~7 3359.90 5909.5~7 0.00 ¢5.53% Eos ee -> 33.51 ~ 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500  ,,, OLS: 2.50 deg per 100 ff. 26.69 1 500 0 1600 :~' I ,G-21Rd G1T 25-Feb-98 ~ :7C3 ._,,. · F I ~- ~ 8CCV G-21Rd G1T 25-Feb-98 t- ", ~ ~- ~coc i22C0 Dote ptotted : lO-Mor-98 Plot Reference is C-21Rd Vets;ch Coordinates ore in feet reference s!c,: True Vertical Depths are reference Created by Sutherland For: N. Magee Dote plotted: lO-Mar-g8 Plot Reference is G-21Rd Version #4. ;oordinotes ore ;n feet reference slot #3-2. True Vertical Depths are reference wellhead. UNOCAL ...... Structure : GRAYLING Platform Well : G-21Rd Field : McArfhur River Field Location : TBU, Cook Inlet, Alaska East (feel) -> UNOCAL ) 2400 2440 2480 2520 2560 2600 2840 2880 2720 2760 2800 2840 2880 2920 2960 3000 5040 1080 5000 ~ :080 / 85OO / F 1120 6800 P !120 7300 p 1160 1200 1240 1280 1320 670O 72O0 6866 69O0 660O 7O0O -. '"'-.., 7100 -~. 7200 6400 -. '"-.~ 7300 6500 1360 1400 1440 1480 1520 1560 1600 1640 1680 1720 1760- 5100 5100 5900 58OO 5700 7100 )0 6000 6100 7300 6200 ?S00 '"-. 7600 .OO '-, "% 7700 'x 7800 7500 '",,, '-~ 7900 '~.800 7600 "-, 7700 5400 560O 8100 ,. %,. 1150 i200 1240 1800 t280 :320 !560 k U1 0 ~1400 ~ L - ~1440 .~M -..}_ ! 480 2400 2440 2480 2520 2560 2600 2640 2680 2720 2760 2800 2840 2880 2920 2960 3000 3040 Easf (feet) -> I1560 h !600 '-~'-,8200 '"'-...8300 r 1640 ~ ~ 68C 7800 ~ 1720 5700 !1800 1520 Created by !Suther:om~ For: N. M~gee Dote p[ottea -.' lO-Mar-98 Plot Reference :s G-21Rd Version ~4. Coord;nate:~ arc in feet reference slot #3-2. True Verticol Depths are reference wellheod. UNOCAL Structure : GRAYLING Platform Well : G-21Rd Field : McArfhur River Field Location : TBU, Cook Inlet, Alaska UNOCAL ) East (feet) -> 2800 .2840 2880 2920 2960 3000 3040 3080 3120 3160 3200 3240 3280 3320 3360 3400 3440 1320 t 1 I I I I I I I I I I I I t I I I ! I I I I I I I I I I I I I 1320 360 t// 1350 440 lk/~__x. ! ~'~0 ~ ",, 7600 480 1 '"'"' - ] z'SC '., 7700 1520 1560 1600 1640 1680 1720 I V 1760 1800 ',~ 7800 7500 "-,, ", 7900 ",, 800~ ,, 7600 ". 8100 ,, ',., 8200 7700 '"-.. '.. 8300 · ~ 8400 78OO '"", 5600 7900 1840 1880 1920 1960 2000 hi520 1550 1600 '.,...8..~ O0 ".%8600 O-21Rd G1T 25-Feb-98 \ '"'~ 8700 '-~, 8800 .. 8000 %...8..900 9000 5800 ".. "'-%9100 5900 % 9200 6000 "%. 9400 6 "'~ 9600 8400 6200 !6~C 1680 1720 ! 750 h; 8CC i 2080 ( . , , , , ,. , , , , , , , , , , , , , , , , , , , , , , , , , I 2080 2800 2840 2880 2920 2960 3000 5040 3080 3120 3160 3200 5240 3280 5320 5360 3400 3440 1840  1880 ~920 !~gsc 2000 East (feet) -> Created by Suthedcnd For: N. Magee Oote platted : lO-Uor-g8 Plat Reference ;s G-21Rd Version f~4. Coordinates are ;n feet reference slot #3-2. True Vertical Depths ore reference wellhead. 33O 32O 510 UNOCAL Structure: GRAYLING Platform Well : G-21Rd Field : McArfhur River Field Locotion : TRU, Cook Inlet, Alaska UNOCAL ) 550 TRUE NORTH 0 WELL PROFILE DATA 34.25124.00 M65.g6 -i~1.~2~5.7~ 36.43120.43 ~6.~ - 126g.31 2~795 ~.~5 115.71 6~67.~ - 1~6.87 2559.56 1g.~7I~.g7~9.71-1471.96 ~85LSe t~7 1~.a7S077.~ - 18~.07 3~.21 19.571~.979700,~ - 1~9.57 3~9.SG 10 2O 5O 4O 5O 300 6O 290 280 270 260 53 01~02 Q~ 250 240 12C 250 220 21C 8300 200 77OO 180 150 170 gooo 150 1 60 g2oo 140 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Refere"ce UNOCAL GP, AYLING Platform G-21Rd slot #3-2 McArthur River Field TBU, Cook Inlet, Alaska PROPOSAL LISTING Baker Hughes INTEQ Your ref = G-21Rd Version Our ref = prop2758 License ~ Date printed : 10-Mar-98 Date created : 9-Feb-98 Last revised : 10-Mar-98 Field is centred on n60 50 %.803,w151 36 18.018 Structure is centred on n60 30 4.803,w151 36 18.018 Slot location is n60 50 22.565,w151 36 %6.577 Slot Grid coordinates are N 2502351.9%5, E 212269.859 Slot local coordinates are 1803.80 N 1%15.%0 W Projection type: alaska - Zone %, Spheroid= Clarke - 1866 Reference North is True North UNOCAL GRAYLING Platform, G-21Rd McArthur River Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : G-21Rd Version Last revised : 10-Mar-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C 00 R D I N A T E S Deg/100ft Sect Easting Northing 7700.00 34.25 124.00 6865.96 1261.62S 2495.71E 0.00 2792.08 214733.95 2501029.67 7725.00 36.43 120.43 6886.36 1269.31S 2507.95E 12.00 2806.52 214745.99 2501021.68 7800.00 35.53 116.92 6947.06 1290.45S 2546.58E 3.00 2850.55 214784.09 2500999.60 7825.00 35.25 115.71 6967.44 1296.87S 2559.56E 3.00 2865.00 214796.91 2500992.86 7900.00 33.51 116.94 7029.34 1315.64S 2597.51E 2.50 2907.26 214834.40 2500973.17 8000.00 31.20 118.76 7113.81 1340.61S 2644.83E 2.50 2960.72 214881.09 2500947.05 8100.00 28.93 120.83 7200.35 1365.47S 2688.32E 2.50 3010.81 214923.96 2500921.13 8200.00 26.69 123.23 7288.80 1390.18S 2727.88E 2.50 3057.43 214962.90 2500895.46 8300.00 24.50 126.02 7378.98 1414.69S 2763.44E 2.50 3100.48 214997.85 2500870.10 8400.00 22.37 129.32 7470.73 1438.95S 2794.94E 2.50 3139.89 215028.75 2500845.07 8500.00 20.32 133.26 7563.87 1462.91S 2822.32E 2.50 3175.59 215055.53 2500820.45 8538.13 19.57 134.97 7599.71 1471.96S 2831.66E 2.50 3188.20 215064.65 2500811.17 9000.00 19.57 134.97 8034.90 1581.29S 2941.11E 0.00 3337.67 215171.39 2500699.20 9500.00 19.57 134.97 8506.02 1699.63S 3059.60E 0.00 3499.48 215286.95 2500577.99 9607.17 19.57 134.97 8607.00 1725.00S 3085.00E 0.00 3534.16 215311.72 2500552.01 10000.00 19.57 134.97 8977.14 1817.98S 3178.09E 0.00 3661.29 215402.51 2500456.78 10105.98 19.57 134.97 9077.00 1843.07S 3203.21E 0.00 3695.59 215427.01 2500431.09 10500.00 19.57 134.97 9448.26 1936.33S 3296.58E 0.00 3823.10 215518.07 2500335.57 10767.17 19.57 134.97 9700.00 1999.57S 3359.90E 0.00 3909.57 215579.82 2500270.80 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #3-2 and TVD from wellhead (99.00 Ft above mean sea level). Bottom hole distance is 3909.88 on azimuth 120.76 degrees from wellhead. Total Dogleg for wellpath is 23.83 degrees. Vertical section is from wellhead on azimuth 120.03 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ UNOCAL GRAYLING Platform, G-21Rd McArthur River Field, TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : G-21Rd Version #4 Last revised : 10-Mar-98 Comments in wellpath MD TVD Rectangular Coords. Comment 9607.17 8607.00 1725.00S 3085.00E G-21Rd GIT 25-Feb-98 Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised G-21Rd G1T 25-Feb-98 8607.00 172§.00S 3085.00E 26-Feb-98 UNOCAL GRAYLING Platform G-21Rd slot #3-2 McArthur River Field TBU, Cook Inlet, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref = G-21Rd Version #4 Our ref = prop2758 License = Date printed = 10-Mar-98 Date created = 9-Feb-98 Last revised : 10-Mar-98 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 36 18.018 Slot location is n60 50 22.565,w151 36 46.577 Slot Grid coordinates are N 2502351.945, E 212269.859 Slot local coordinates are 1803.80 N 1415.40 W Projection type= alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less tha~ 500 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by a~ asterisk, e.g. 487.4* Object wellpath PMSS <8988 - 12583'>,,M32St#2,STEELHEAD Platfo PMSS <12281 - 12660.>,,M32St#3,STEELHEAD Platf PMSS <1386 - 9833'>,,M-32,STEELHEAD Platform PGMS <O-927'>,,Bl-10,STEELHEAD Platform PMSS <9365 - 10588'>,,M32ST#1,STEEnWRAD Platfo PGMS <0-10938'>,,M-29,STEELHEAD Platform GSS <975-2660'>,,M-29,STEELHEAD Platform PMSS <10741-12018'>,,M-31St#1,STEELHEAD Platfo PMSS <10247-10355'>,,M-31,STEELHEAD Platform PGMS <O-14575'>,,M~30,STEELHEAD Platform PMSS <1334-3625>,,M~16,STEELHEAD Platform PMSS <1535-4500'>,,M-9,STEELHEAD Platform PGMS <0-6440'>,,M-7,STEELHEAD Platform PGMS <0-5185.>,,M-19,STEELHEAD Platform GSS <O~1421.>,,*M-4*,STEELHEAD Platform PGMS <O-7250'>,,M~3,STEELHEAD Platfo~-m PGMS <0-7419'>,,M-2,STEELHEAD Platform PGMS <0-7250'>,,M-1St#1,STEELHEAD Platform PMSS <6595-6988'>,,M-1,STEELHEAD Platform PGMS <0-5600'),,M-5,STEELHEAD Platfoz~n Closest approach with 3-D Minimum Distance method Last revised Distance M.D. 29-Jul-96 )62.8( 7825.0 10-Feb-98 )62.8( 7825.0 29-Jul-96 )62.8( 7825.0 29-Jul-96 )6181.9( 7700.0 29-Jul-96 )62.8( 7825.0 10-Feb-98 )23.3( 8631.0 29-Jul-96 )4534.8( 7700.0 29-Jul-96 1117.1 7700.0 29~Jul-96 1117.1 7700.0 29-Jul-96 2402.4 7700.0 29~Sep-97 4273.7 7700.0 26-Aug-96 )4004.8( 7700.0 29-Jul-96 )3807.9( 7700.0 29-Jul-96 3543.5 7700.0 29-Jul-96 )5690.0( 7700.0 29-Jul-96 )1836.0( 8166.7 29-Jul-96 )4585.7( 8400.0 29-Jul-96 )1775.5( 7700.0 29-Jul-96 )1790.4( 7700.0 29-Jul-96 )2682.0( 7700.0 Diverging from M.D. 7825.0 7825.0 7825.0 7700.0 7825.0 8631.0 7700.0 7700.0 7700 0 7700 0 7700 0 7700 0 7700 0 7700 0 9639 0 8166.7 8400.0 7700.0 7700.0 7700.0 PGMS <500-928t>,,B1-2~ ~Er~HEAD Platform PGMS <O-7434'),,M-13,STEELHEAD Platform PGMS <O-785~>,,B1-6,STEELHEAD Platform PGMS <O-8§7~>,,B1-8,STEELHEAD Platform MSS ~0-735~>,,0B #2,STEELHEAD Platform PMSS <808-1165'>,,RLF #2,STEELHEAD Platform PGMS <0-2310'),,RLF #1,STEELHEAD Platform MSS <1363-1859~>,,RLF #2,STEELHEAD Platform PMSS <lO06-1449'>,,M-15,STEELHEAD Platform PMSS <1006-7952~>,,M-15 St, STEELHEAD Platform PGMS <2700-9101~>,,M-14,STEELHEAD Platform MSS <1103-2265~>,,M-26,STEE~HEAD Platform PGMS <12486-15276~>,,M-27,STEELHEAD Platform PGMS <3700-11700~>,,M-25,STEELHEAD Platform PGMS ~O~12930~>,,M-28,STEEI~HEAD Platform MSS <2180-11319~>,,K-6Rd,KING SALMON Platform PGMS <O~13296~>,,K-6Rd,KING SALMON Platform PGMS <O-14325~>,,K-25,KING SALMON Platform MSS <2063~10825'>,,K-16,KING SALMON Platform GMS <O-12156t>,,K~9,KING SALMON Platform GMS <0-12900~,,K-21,KING SALMON Platform 29-Jul-96 )6176.6( ~0.0 29-Jul-96 )4248.3( 7700.0 29-Jul-96 )6321.7( 7700.0 29-Jul-96 )6252.6( 7700.0 29-Jul-96 )6366.5( 7700.0 29-~ul-96 )5966.0( 7700.0 29-Jul-96 )4987.1( 7700.0 29-Jul-96 )5511.4( 7700.0 29-Jul-96 )5775.5( 7700.0 29-Jul-96 )4880.6( 7700.0 29-Jul-96 )221.9( 9555.0 29-Jul-96 )4840.7( 7700.0 29-Jul-96 2628.7 7700.0 29-Jul-96 )327.3( 7775.0 29-Jul-96 )1866.5( 7700.0 29-Jul-96 11838.7 7700.0 29-Jul-96 10974.5 10125.0 29-Jul-96 2452.3 10224.0 29-Jul-96 10880.9 7700.0 29-Jul-96 )5167.9( 9819.0 30-Dec-97 )3871.6( 9951.0 )4367.1( 9798.0 GMS <10600-12540'>,,K-21Rd,KING SALMON Platfor 30-Dec-97 PGMS <O-12130'>,,K~18,KING SALMON Platform 29-Jul-96 GMS <O-13370'>,,K~5,KING SALMON Platform 29-Jul-96 GMS <2500-11240'>,,K-12,KIN~ SALMON Platform 29-Jul-96 PGMS <O-11400'>,,K-12Rd,KING SALMON Platform 29-Jul-96 PGMS <0-10400'>,,K-22Rd,KING SALMON Platform 29-Jul-96 MSS <5747-10904'>,,K-22,KING SALMON Platform 29-Jul-96 GMS <8900-13463'>,,K-lO,KING SALMON Platform 29-Jul-96 GMS <0-12822'>,,K-10Rd, KING SALMON Platform 29-Jul-96 GMS <2600-11767'>,,K-3,KING SALMON Platform 29-Jul-96 GMS <0-13413'>,,K-3Rd, KING SALMON Platform 29-Jul-96 MSS <l1494-13196'>,,K-30,KING SALMON Platform 29-Jul-96 MSS <2170-12600'>,,K-30Rd,KING SALMON Platform 29-Jul-96 GMS<O-2100'>,,K-30Rd, KING SALMON Platform 29-Jul-96 PGMS <O-12120'>,,K-17,KING SALMON Platform 29-Jul-96 GMS <O-14700'>,,K-23,KING SALMON Platform 29-Jul-96 MSS <5028-8580'>,,K-20,KING SALMON Platform 29-Jul-96 MSS <10836-12447'>,,K-15,KING SALMON Platform 29-Jul-96 GMS <O-12200'>,,K-15Rd,KING SALMON Platform 29-Jul-96 MSS <10683-11439'>,,K-4Rd,KING SALMON Platform 29-Jul-96 MSS <2910-11772'>,,K-4,KING SALMON Platform 29-Jul-96 GMS <0-2800'>,,K-4,KING SALMON Platform 29-Jul-96 MSS <2450-11094'>,,K-Ii,KING SALMON Platform 29-Jul-96 MSS <5142-14016'>,,K-13,KING SALMON Platform 29-Jul-96 GMS <0-12173'>,,K-13Rd,KING SALMON Platform 29-Jul-96 GMS <2403-12915'>,,K-2Rd,KING SALMON Platform 29-Jul-96 GMS 0-11288'>,,K-2,KING SALMON Platform 29-Jul-96 GMS <lO125-13990'>,,K-TRd, KING SALMON Platform 29-Jul-96 GMS <0-10150'>,,K-7,KING SALMON Platform 29-Jul-96 MSS <10249-14700'>,,K-7,KING SALMON Platfoz-m 29-Jul-96 MSS <9725-13224'>,,K-1,KING SALMON Platform 29-Jul-96 MSS <2380-12570'),,K-1Rd, KING SALMON Platform 29-Jul-96 GMS <0-2300'>,,K-1Rd, KING SALMON Platform 29-Jul-96 PGMS <9300-14384'>OLD,,K-24,KING SALMON Platfo 29-Jul-96 Steering Tool,,K-24,KING' SALMON Platform 29-Jul-96 PMSS <981-10956'>,,K-26,KING SALMON Platform 29-Jul-96 EMS <8955 - 11078'>,,K-26Rd, KING SALMON Platfo 29-Jul-96 GSS <492-855'>,,K-26,KING SALMON Platform 29~Jul-96 MSS <2622-13927'>OLD,,K-8,KING SALMON Platform 29-Jul-96 PGMS <0-2500'> NEW,,K-8Rd, KING SALMON Platform 29-Jul-96 PGMS <2600-14548'>OLD,,K-SRd, KING SALMON Platf 29~Ju1~96 PGMS <0~13771'>,,K-19,KING SALMON Platform 29-Jul-96 PGMS <0-10873'>,,D-48,DOLLY VARDEN Platform 29~Jul-96 GMS <800-2700'>,,D-10,DOLLY VARDEN Platform 29-Ju1~96 MSS <2742~13908'>,,D-10,DOLLY VARDEN Platform 29-Jul-96 MSS <10913-11930'>,,D-47,DOLLY VARDENPlatform 29-Ju1~96 PGMS <0-12970'>,,D-44,DOLLY VARDEN Platform MSS <3550-17010'>,,D-21,DOLLY VARDEN Platform MSS <3550-16606'>,,D-23,DOLLY VARDEN Platform PGMS <0~10450'>,,D~42,DOLLY VARDEN Platform GMS <0-11180'>,,D-34,DOLLY VARDEN Platform MSS <2730-13462'>,,D-24,DOLLY VARDEN Platform PMSS <12052 - 12438'>,,D~7Rd#2,DOLLY VARDEN P1 GMS <0-12900'>,,D-7Rd,DOLLY VARDEN Platform GMS <9600~13300'>,,D-7,DOLLY VARDEN Platform PGMS <8000-12100'>,,D-4Rd,DOLLY VARDEN Platfor GMS <0-11100'>,,D~4,DOLLY VARDEN Platform GMS <0-12050'>,,D-12Rd,DOLLY VARDEN Platform MSS <9453-12381'>,,D-12,DOLLY VARDEN Platform 10726.9 7700.0 65~9.1 10494.0 10965.8 7700.0 11289.3 7700.0 11951.4 7700.0 11951.4 7700.0 10647.1 7700.0 10647.1 7700.0 9323.5 7700.0 9538.2 7700.0 5794.7 10767.2 6062.7 10326.0 11416.2 7700.0 6983.4 9843.0 7179.8 10767.2 5621.1 7700.0 8830.1 9963.0 8827.9 9774.0 6081.1 9162.0 5837.5 9486.0 11007.8 7700.0 8990.2 7700.0 11433.1 7700.0 11194.5 7700.0 7573.4 10236.0 8233.9 9474.0 8867.8 10752.0 95'19.6 7966.7 9519.6 7966.7 10477.8 7700.0 10477.8 7700.0 11666.1 7700.0 4166.8 10767.2 4003.3 10260.0 12179.6 7700.0 12179.6 7700.0 12364.4 7700.0 7935.7 7700.0 11171.5 7700.0 9748.4 7700.0 10198.2 7700.0 7997.0 10767.2 12339.7 7700.0 9317.3 10767.2 )6295.9( 10767.2 29-Jul-96 )7205.4( 9804.0 29-Jul-96 )13120.9 7700.0 29-Jul-96 )13204.2 7700.0 29-Jul-96 )5787.0( 9027.0 29-Jul-96 )9343.8( 10767.2 29-Jul-96 )8329.5( 10767.2 29-Jul-96 4489.2 10719.0 29-Jul-96 )4153.0( 10767.2 29-Jul-96 )3757.8( 10767.2 29-Jul-96 )9596.8( 10767.2 29-Jul-96 )9576.1( 10767.2 29-Jul-96 )12273.2 7725.0 29-Jul-96 )12273.2 7725.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 9555.0 7700.0 7700.0 7775.0 7700.0 7700.0 10125.0 10224.0 7700.0 9819.0 9951.0 9798.0 7700.0 10494.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 10767.2 10326.0 7700.0 9843.0 10767.2 7700.0 9963.0 9774.0 9162.0 9486.0 7700.0 7700.0 7700.0 10677.0 10236.0 9474.0 10752.0 7966.7 10671.0 7700.0 7700.0 7700.0 10767 2 10260 0 7700 0 7700 0 7700 0 7700 0 7700.0 7700.0 7700.0 10767.2 7700.0 10767.2 10767.2 9804.0 10248.0 9996.0 9027.0 10767.2 10767.2 10719.0 10767.2 10767.2 10767.2 10767.2 10569.0 10569.0 MSS <2220-8175'),,D-18,1~ Y VARDEN Platform 29-Jul-96 GMS (0-12237'),,D-30Rd,DOLLY VARDEN Platform 29-Jul-96 MSS <10156-13600'>,,D-30,DOLLY VARDEN Platform 29-Jul-96 MSS <Oo12071~>,,D-1,DOLLY VARDEN Platform 29-Jul-96 GMS <0-10800'),,D-17Rd,DOLLY VARDEN Platform 29-Jul-96 MSS (10665-11808~),,D-17,DOLLY VARDEN Platform 29-Jul-96 MSS (2701-11682'>,,D-ii,DOLLY VARDEN Platform 29-Jul-96 PGMS <O-10900~),,D-gRd, DO~LY VARDEN Platform 29-Jul-96 GMS <5600-10700'),,D-9,DOLLY VARDEN Platform 29-Jul-96 PGMS (0-12345~),,D-46,DOLLY VARDEN Platform 29-Jul-96 MSS <2944-7950~>,,D-19,DOhLY VARDEN Platform 29-Jul-96 MSS (6059-16650~),,D-19St,DOLLY VARDEN Platfor 29-Jul-96 GMS <O-10650~>,,D-SRd, DOLLY VARDEN Platform 29-Jul-96 MSS <2642°10250~,,D-5,DOLLY VARDEN Platform 29-Jul-96 GMS <O-1093§~),,D-15Rd, DOLLY VARDEN Platform 29-Jul-96 PGMS <2100-10225'>,,D-15Rd2,DOLLY VARDEN Platf 29-Jul-96 PGMS <6600-10920~),,D-3Rd2,DOLLY VARDEN Platfo 29-Jul-96 GMS <O-10881~>,,D-3,DOhLY VARDEN Platform 29-Jul-96 PGMS <8700-11100'),,D-3Rd, DOLLY VARDEN Platfor 29-Jul-96 MSS <2727-11000'),,D-13,DOLLY VANDEN Platform 29-Jul-96 PGMS <0-10300~>,,D-45,DO~LY VARDEN Platform 29-Jul-96 GMS <O-11000~>,,D-27,DOLLY VARDEN Platform 29-Jul-96 GMS (0-12445~>,,D-28,DOLLY VARDEN Platform 29-Jul-96 MSS <2506-11160'),,D-32,DOLLY VARDEN Platform 29-Jul-96 PGMS <O-12520~),,D-40Rd,DOLLY VARDEN Platform 29-Jul-96 GMS <6100-12573~),,D-40,DOLLY VARDEN Platform 29-Jul-96 GMS <O-11600~),,D-41,DOLhY VARDEN Platform 29-Jul-96 MSS <8330~11350~>,,D-25,DOLLY VARDEN Platform 29-Jul-96 GMS <0-11510~>,,D-25Rd, DOLLY VARDEN Platform 29-Jul-96 PGMS <O-11150'),,D-43,DOLLY VARDEN Platform 29-Jul-96 GMS <100-13050'>,,D-29,DOL~Y VARDEN Platform 29-Jul-96 PGMS <0-13111'>,,D-29Rd,DOL~Y VARDEN Platform 29-Jul-96 PGMS <700-12250'>,,D-SRd,DOLLY VARDEN Platform 29-Jul-96 MSS <8722-13932'>,,D-8,DOLLY VARDEN Platform 29-Jul-96 MSS <l1790-15510'>,,D-6St,DOLLY VARDEN Platfor 29-Jul-96 MSS <6662-12195'>,,D-6,DOLLY VARDEN Platform 29-Jul-96 PGMS <0-13700'>,,D-6Rd,DOLLY VARDEN Platform 29-Jul-96 GMS <0-13600'>,,D-14Rd,DOLLY VARDEN Platform 29-Jul-96 MSS <7866-12700'>,,D-14,DOLLY VARDEN Platform 29-Jul-96 MSS <1205-10506'>,,D-20,DOLLY VARDEN Platform 29-Jul-96 PGMS <10000-14645'>,,D-16Rd, DOLLY VARDEN Platf 29-Jul-96 GMS <0-14600'>,,D-16,DOLLY VARDEN Platform 29-Jul-96 MSS <11209-14850'>,,D-22,DOLLY VARDEN Platform 29-Jul-96 MSS <9482-12425'>,,D-2Rd,DOL~Y VARDEN Platform 29-Jul-96 MSS <6927-12557'>,,D-2,DOLLY VARDEN Platform GMS <0-11356'>,,D-2ARd,DOLLY VARDEN Platform GMS <O-10628">,,D-31Rd,DOLLY VARDEN Platform MSS <2450-10125'>,,D-31,DOLLY VARDEN Platform GMS <0-13585'>,,D-24A,DOLLY VARDEN Platform GMS <O-11905'>,,D-26,DOLLY VARDEN Platform MSS <8491-11420'>,,G-1,GRAYLING Platform PGMS <O-11430'>,,G-1Rd,GRAYhING Platform GMS <0-10115'>,,G-ii,GRAYLING Platform MSS <0-11570'>,,G-32,GRAYLING Platform GMS <0-11750'>,,G-SRd,GRAYLING Platform MSS <7709°12175'>,,G-8,GRAYLING Platform MSS <0-16342'>,,G-14,GRAYLING Platform GMS <0-8860.>,,G-iBRd,GRAYLING Platform MSS <0-15330'>,,G-9,GRAYLING Platform GMS <1400-10400'>,,G-4Rd,GRAYLING Platform GMS <0-9000'>,,G°4,GRAYLING Platform PGMS <0-10100'>,,G-7,GRAYLING Platform MSS <0-12007'>,,G-13,GRAYLING Platform MSS <0-12291'>,,G-19,GRAYLING Platform GMS <0-13661'>,,G-16,GRAYLING Platform PGMS <0-9950'>,,G-5,GRAYLING Platform GMS <0-11900'>,,G-17Rd,GRAYLING Platform MSS <3991~15095'>,,G-17,GRAYLING Platform GMS <100-11050'>,,G-3Rd2,GRAYLING Platform GMS <0-8800' (ll050)>,,G-3,GRAYLING Platform MSS <9120-11278'>,,G-3Rd,GRAYLING Platform PGMS <O-10700'>,,G-2Rd,GI~.AYLING Platform MSS <10070-10975'>,,G-10,GRAYLING Platform GMS <0-11335'>,,G-22,GRAYLING Platform GMS <0-11544'>,,G-26,GRAYLING Platform GMS <0-10400'>,,G-24,GRAYLING Platform GMS <0-10642'>,,G-20,GRAYLING Platform GMS <0-12948'>,,G-27,GRAYLING Platform PMSS <l1830-12453'>,,G-36,GRAYLINO Platform PGMS <ll100-13380'>,,G-36DPN,~RAYLING Platform 29~Jul-96 29~Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29~Jul-96 30~Jul-96 30~Jul-96 30~Jul-96 30~Jul-96 30~Jul-96 30~Ju1°96 30~Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Julo96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Jul-96 30-Julo96 30-Jul-96 30-Jul-96 )6359.1( )4375.4( )3705.5( )5367.3( )9667.3( )9686.7( )7418.9( )11867.5 )12563.4 )11448.7 )8216.5( )6575.3( )9073.5( )11482.3 )9767.7( )10942.3 )7262.~( )7830.9( )7500.8( )12906.5 )10418.5 )7259.9( )5226.4( )6490.0( )6754.1( )7824.3( )6924.2( )11206.8 )10875.1 )8470.2( )4632.2( )5764.4( )12911.0 )12911.0 )11832.4 )11832.4 )11832.4 )12640.9 )12640.9 )8969.3( )13108.3 )13108.3 )13243.5 )6453.4( )6989.9( )8624.9( )6622.4( )7943.0( )8186.3( )5927.7( )1911.3( )1911.3( )2752.3( )2602.9( ) 1218.3 ( ) 1218.3 ( )2858.0( )3424.9( )3328.1( )1960.6( )2319.1( )1067.9( )5339.9( )4387.5( )2792.9( )3740.5( )6268.9( )6268.9( )2086.1( )2086.1( )2086.1( )2172.0( )4220.0( )3633.O( )2107.5( )1539.2( )1386.0( )5157.4( )1774.6(. )1774.6( 0.0 f0~0.0 10767.2 10767.2 10767.2 10767.2 10608.0 10767.2 7712.5 9174.0 7933.3 10767.2 10767.2 10767.2 10767.2 10767.2 10767.2 10767.2 10767.2 7700.0 10767.2 10767.2 10620.0 10767.2 10281.0 10212.0 10767.2 10767.2 10767.2 10713.0 10767.2 10767.2 7700.0 7700.0 7725.0 7725.0 7725.0 7700.0 7700.0 10767.2 7700.0 7700.0 7700.0 10767.2 10767.2 10767.2 10575.0 10767.2 10767.2 10767.2 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 10125.0 7700.0 10155.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 7700.0 10464.0 10650.0 10767.2 10767.2 10767.2 10767.2 10608.0 10767.2 10761.0 10527.0 7933.3 10767.2 10767.2 10767.2 10767.2 10767.2 10767.2 10767.2 10767.2 10611.0 10767.2 10767.2 10620.0 10767.2 10281.0 10212.0 10767.2 10767.2 10767.2 10713.0 10767.2 10767.2 10302.0 10302.0 10695.0 10695.0 10743.0 10038.0 10038.0 10767.2 9450.0 9450.0 10092.0 10767.2 10767.2 10767.2 10575.0 10767.2 10767.2 10767.2 7700.0 10434.0 7700.0 10737.0 8880.0 10300.0 7700.0 7850.0 7700.0 10125.0 7700.0 10155.0 7700.0 7700.0 7700.0 7700.0 9312.0 9207.0 10767.2 9930.0 10600.0 7700.0 10479.0 7700.0 10287.0 7700.0 7700.0 8889.0 7700.0 7700.0 MSS <2284-11655'>,,G-3.~.~RAYLING Platform GMS <0-10268'>,,G-3%Rd, GRAYLIN~ Platform GMS <0-11742'>,,G-23Rd,~RJ%YLING Platform G~S <O-12075'~,,~-23,G~AYLING Platform MSS <0-10790'>,,~-3~,GRAYLIN~ Platform PMSS <1395-12743'>,,~-14A Rd,~RAYLIN~ Platform MSS <10250-13700'>,,G-12Rd,GRAYLING Platform MSS <10250-13748'>,,G-12,GRAYLING Platform GMS <O-13800'>,,G-12Rd2,GRAYLING Platform PGMS <100-11000'~,,G-6Rd,GRAYLING Platform GMS <O-9600'>,,G-6,GRAYLING Platform GMS <0-12366'>,,G-2~,GRAYLIN~ Platform MSS <630-11451'>,,G-30,GRAYLING Platform GMS <0-12425'>,,G-28,GRAYLING Platform MSS <0-12736'>,,G-31,GP~AYLING Pl&tform MSS <0-12885'>,,G-15,GRAYLING Platform GMS <O-11150'>,,G-21,GRAYLING Platform 30-Jul-96 )2533.3( ..~.00.0 30-Jul-96 )2103.3( 10236.0 30-Jul-96 )1647.8( 7700.0 30-Jul-96 )1771.1( 7700.0 30-Jul-96 )1617.8( 10767.2 30-Jul-96 )1206.4( 7700.0 30-Jul-96 )2474.3( 7700.0 30-Jul-96 )2483.0( 7700.0 30-Jul-96 )2483.0( 7700.0 30-Jul-96 )497.~( 8300.0 30-Jul-96 )497.~( 8300.0 30-Jul-96 )3591.9( 7700.0 30-Jul-96 )581.8( 7700.0 30-Jul-96 )4940.6( 7700.0 30-Dec-97 )1819.2( 7700.0 30-Jul-96 )5792.8( 7700.0 30-Jul-96 )0.0( 8466.7 7700.0 10236.0 7700.0 7700.0 10767.2 10425.0 7700.0 7700.0 7700.0 10422.0 8300.0 9606.0 7700.0 9630.0 7700.0 10731.0 8466.7 UNOCAL GRAYLING Platform, G-21Rd McArthur River Field,TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 4 Your ref : G-21Rd Version #4 Last revised : 10-Mar-98 Reference wellpath M.D. T.V.D. Rect Coordinates Object wellpath : PMSS <8988 - 12583'>,,M325~#2,STEE~HEAD Platform Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates Bearing Dist SeD'n 7700.0 6866.0 1261.6S 2495.7E 7450.9 6971.1 1392.2S 2452.7E 198.2 173.0 )112.8( 7712.5 6876.2 1265.5S 2501.7E 7457.9 6976.7 1388.1S 2454.1E 201.2 165.5' )104.9( 7725.0 6886.4 1269.3S 2507.9E 7465.0 6982.3 1384.0S 2455.%E 204.6 158.5' )97.5{ 7750.0 6906.5 1276.7S 2520.8E 7479.2 6993.6 1375.8S 2458.1E 212.3 146.1' )84.2( 7775.0 6926.7 1283.7S 2533.7E 7494.2 7005.5 1367.2S 2461.0E 221.0 135.8' )73.7( 7800.0 6947.1 1290.5S 2546.6E 7508.9 7017.2 1358.7S 2463.9E 230.5 128.1- )66.2( 7812.5 6957.2 1293.7S 2553.1E 7516.4 7023.1 1354.4S 2465.3E 235.3 125.4, )64.0( 7825.0 6967.4 1296.9S 2559.6E 7523.9 7029.0 1350.1S 2466.8E 240.2 123.4' )62.8( 7850.0 6987.9 1303.1S 2572.4E 7539.0 7041.0 1341.3S 2469.7E 249.6 121.8' )63.9( 7875.0 7008.6 1309.4S 2585.1E 7554.9 7053.5 1332.1S 2472.8E 258.6 123.0 )69.2( 7900.0 7029.3 1315.6S 2597.5E 7570.1 7065.5 1323.3S 2475.8E 266.4 127.2 )77.6( 7933.3 7057.3 1324.0S 2613.7E 7591.1 7082.1 1310.9S 2480.0E 275.6 136.6 )92.4( 7966.7 7085.4 1332.3S 2629.5E 7611.5 7098.1 1299.0S 2484.1E 282.9 149.7 )109.7( 8000.0 7113.8 1340.6S 2644.8E 7632.1 7114.2 1287.0S 2488.3E 288.9 165.5 )128.6( 8033.3 7142.4 1348.9S 2659.8E 7653.7 7131.1 1274.3S 2492.8E 294.1 183.3 )148.3( 8066.7 7171.3 1357.2S 2674.3E 7674.3 7147.2 1262.1S 2497.1E 298.2 202.5 )168.6( 8100.0 7200.4 1365.5S 2688.3E 7695.8 7164.0 1249.4S 2501.7E 301.9 222.7 )189.3( 8133.3 7229.6 1373.7S 2701.9E 7716.6 7180.1 1237.1S 2506.2E 304.9 243.8 )210.4( 8166.7 7259.1 1382.0S 2715.1E 7737.8 7196.5 1224.6S 2510.8E 307.6 265.4 )231.7( 8200.0 7288.8 1390.2S 2727.9E 7758.7 7212.7 1212.2S 2515.4E 310.0 287.4 )253.2( 8233.3 7318.7 1398.4S 2740.2E 7779.5 7228.8 1199.8S 2520.1E 312.1 309.8 )274.8( 8266.7 7348.7 1406.5S 2752.0E 7800.5 72%4.9 1187.3S 2524.8E 314.0 332.4 )296.5( 8300.0 7379.0 1414.7S 2763.4E 7821.4 7261.1 1174.7S 2529.5E 315.7 355.3 )318.4( 8333.3 7409.4 1422.8S 2774.4E 7842.5 7277.2 1162.2S 2534.2E 317.3 378.3 8366.7 7440.0 1430.9S 2784.9E 7863.5 7293.5 1149.6S 2538.9E 318.8 401.4 )362.4( 8400.0 7470.7 1438.9S 2794.9E 7884.4 7309.5 1137.1S 2543.6E 320.2 424.6 )384.5( 8433.3 7501.6 1447.0S 2804.5E 7905.5 7325.7 1124.5S 2548.4E 321.5 %%7.8 )406.7( 8466.7 7532.7 1455.0S 2813.7E 7926.5 7341.8 1111.9S 2553.2E 322.8 471.1 )428.9( 8500.0 7563.9 1462.9S 2822.3E 7947.6 7358.0 1099.2S 2558.0E 324¥'0 %9%.5 )451.1( 8519.1 7581.8 1467.4S 2827.1E 7959.7 7367.3 1092.0S 2560.7E 32%.7 507.8 )463.9( 8538.1 7599.7 1472.0S 2831.7E 7970.9 7375.9 1085.3S 2563.3E 325.2 521.2 )476.7( All data is in feet u~less otherwise stated. Casing dimensions are not included. Coordinates from slot ~3-2 and TVD from wellhead (99.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 120.03 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRAYLING Platform,G-21Rd McArthur River Field, TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 5 Your ref : G-21Rd Version #4 Last revised : 10-Mar-98 Reference wellpath Object wellpath': PMSS <12281 - 12660'>,,M32St~3,STEELHEAD Platform Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 7700.0 6866.0 1261.6S 2495.7E 7450.9 6971.1 1392.2S 2452.7E 198.2 173.0 )112.8( 7712.5 6876.2 1265.5S 2501.7E 7457.9 6976.7 1388.1S 2454.1E 201.2 165.5' )104.9( 7725.0 6886.4 1269.3S 2507.9E 7465.0 6982.3 1384.0S 2455.4E 204.6 158.5- )97.5( 7750.0 6906.5 1276.7S 2520.8E 7479.2 6993.6 1375.8S 2458.1E 212.3 146.1, )84.2( 7775.0 6926.7 1283.7S 2533.7E 7494.2 7005.5 1367.2S 2461.0E 221.0 135.8' )73.7( 7800.0 6947.1 1290.5S 2546.6E 7508.9 7017.2 1358.7S 2463.9E 230.5 128.1- )66.2( 7812.5 6957.2 1293.7S 2553.1E 7516.4 7023.1 1354.4S 2465.3E 235.3 125.4' )64.0( 7825.0 6967.4 1296.9S 2559.6E 7523.9 7029.0 1350.1S 2466.8E 240.2 123.4- )62.8( 7850.0 6987.9 1303.1S 2572.4E 7539.0 7041.0 1341.3S 2469.7E 249.6 121.8' )63.9( 7875.0 7008.6 1309.4S 2585.1E 7554.9 7053.5 1332.1S 2472.8E 258.6 123.0 )69.2( 7900.0 7029.3 1315.6S 2597.5E 7570.1 7065.5 1323.3S 2475.8E 266.4 127.2 )77.6( 7933.3 7057.3 1324.0S 2613.7E 7591.1 7082.1 1310.9S 2480.0E 275.6 136.6 )92.4( 7966.7 7085.4 1332.3S 2629.5E 7611.5 7098.1 1299.0S 2484.1E 282.9 149.7 )109.7( 8000.0 7113.8 1340.6S 2644.8E 7632.1 7114.2 1287.0S 2488.3E 288.9 165.5 )128.6( 8033.3 7142.4 1348.9S 2659.8E 7653.7 7131.1 1274.3S 2492.8E 294.1 183.3 )148.3( 8066.7 7171.3 1357.2S 2674.3E 7674.3 7147.2 1262.1S 2497.1E 298.2 202.5 )168.6( 8100.0 7200.4 1365.5S 2688.3E 7695.8 7164.0 1249.4S 2501.7E 301.9 222.7 )189.3( 8133.3 7229.6 1373.7S 2701.9E 7716.6 7180.1 1237.1S 2506.2E 304.9 243.8 )210.4( 8166.7 7259.1 1382.0S 2715.1E 7737.8 7196.5 1224.6S 2510.8E 307.6 265.4 )231.7( 8200.0 7288.8 1390.2S 2727.9E 7758.7 7212.7 1212.2S 2515.4E 310.0 287.4 )253.2( 8233.3 7318.7 1398.4S 2740.2E 7779.5 7228.8 1199.8S 2520.1E 312.1 309.8 )274.8( 8266.7 7348.7 1406.5S 2752.0E 7800.5 7244.9 1187.3S 2524.8E 314.0 332.4 )296.5( 8300.0 7379.0 1414.7S 2763.4E 7821.4 7261.1 1174.7S 2529.5E 315.7 355.3 )318.4( 8333.3 7409.4 1422.8S 2774.4E 7842.5 7277.2 1162.2S 2534.2E 317.3 378.3 )340.4( 8366.7 7440.0 1430.9S 2784.9E 7863.5 7293.5 1149.6S 2538.9E 318.8 401.4 )362.4( 8400.0 7470.7 1438.9S 2794.9E 7884.4 7309.5 1137.1S 2543.6E 320.2 424.6 )384.5( 8433.3 7501.6 1447.0S 2804.5E 7905.5 7325.7 1124.5S 2548.4E 321.5 447.8 )406.7( 8466.7 7532.7 1455.0S 2813.7E 7926.5 7341.8 1111.9S 2553.2E 322.8 471.1 )428.9( 8500.0 7563.9 1462.9S 2822.3E 7947.6 7358.0 1099.2S 2558.0E 324.0 494.5 )451.1( 8519.1 7581.8 1467.4S 2827.1E 7959.7 7367.3 1092.0S 2560.7E 324.7 507.8 )463.9( 8538.1 7599.7 1472.0S 2831.7E 7970.9 7375.9 1085.3S 2563.3E 325.2 521.2 )476.7( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #3-2 and TVD from wellhead (99.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 120.03 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRAYLING Platform,G-21Rd McArthur River Field,TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 6 Your ref : G-21Rd Version #4 Last revised : 10-Mar-98 Reference wellpath Object wellpath : PMSS <1386 - 9833'>,,M-32,STEELHEAD Platform Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 7700.0 6866.0 1261.6S 2495.7E 7450.9 6971.1 1392.2S 2452.7E 198.2 173.0 )112.8{ 7712.5 6876.2 1265.5S 2501.7E 7457.9 6976.7 1388.1S 2454.1E 201.2 165.5' )104.9( 7725.0 6886.4 1269.3S 2507.9E 7465.0 6982,3 1384.0S 2455.4E 204.6 158.5' )97.5( 7750.0 6906.5 1276.7S 2520.8E 7479.2 6993.6 1375.8S 2458.1E 212.3 146.1, )84.2( 7775.0 6926.7 1283.7S 2533.7E 7494.2 7005.5 1367.2S 2461.0E 221.0 135.8' )73.7( 7800.0 .6947.1 1290.5S 2546.6E 7508.9 7017.2 1358.7S 2463.9E 230.5 128.1' )66.2( 7812.5 6957.2 1293.7S 2553.1E 7516.4 7023.1 1354.4S 2465.3E 235.3 125.4' )64.0( 7825.0 6967.4 1296.9S 2559.6E 7523.9 7029.0 1350.1S 2466.8E 240.2 123.4' }62.8( 7850.0 6987.9 1303.1S 2572.4E 7539.0 7041.0 1341.3S 2469.7E 249.6 121.8' )63.9( 7875.0 7008.6 1309.4S 2585.1E 7554.9 7053.5 1332.1S 2472.8E 258.6 123.0 )69.2( 7900.0 7029.3 1315.6S 2597.5E 7570.1 7065.5 1323.3S 2475.8E 266.4 127.2 )77.6( 7933.3 7057.3 1324.0S 2613.7E 7591.1 7082.1 1310.9S 2480.0E 275.6 136.6 )92.4( 7966.7 7085.4 1332.3S 2629.5E 7611.5 7098.1 1299.0S 2484.1E 282.9 149.7 )109.7( 8000.0 7113.8 1340.6S 2644.8E 7632.1 7114.2 1287.0S 2488.3E 288.9 165.5 }128.6( 8033.3 7142.4 1348.9S 2659.8E 7653.7 7131.1 1274.3S 2492.8E 294.1 183.3 )148.3( 8066.7 7171.3 1357.2S 2674.3E 7674.3 7147.2 1262.1S 2497.1E 298.2 202.5 )168.6( 8100.0 7200.4 1365.5S 2688.3E 7695.8 7164.0 1249.4S 2501.7E 301.9 222.7 )189.3( 8133.3 7229.6 1373.7S 2701.9E 7716.6 7180.1 1237.1S 2506.2E 304.9 243.8 )210.4( 8166.7 7259.1 1382.0S 2715.1E 7737.8 7196.5 1224.6S 2510.8E 307.6 265.4 )231.7( 8200.0 7288.8 1390.2S 2727.9E 7758.7 7212.7 1212.2S 2515.4E 310.0 287.4 )253.2( 8233.3 7318.7 1398.4S 2740.2E 7779.5 7228.8 1199.8S 2520.1E 312.1 309.8 )274.8( 8266.7 7348.7 1406.5S 2752.0E 7800.5 7244.9 1187.3S 2524.8E 314.0 332.4 )296.5( 8300.0 7379.0 1414.7S 2763.4E 7821.4 7261.1 1174.7S 2529.5E 315.7 355.3 )318.4( 8333.3 7409.4 1422.8S 2774.4E 7842.5 7277.2 1162.2S 2534.2E 317.3 378.3 )340.4( 8366.7 7440.0 1430.9S 2784.9E 7863.5 7293.5 1149.6S 2538.9E 318.8 401.4 )362.4( 8400.0 7470.7 1438.9S 2794.9E 7884.4 7309.5 1137.1S 2543.6E 320.2 424.6 )384.5( 8433.3 7501.6 1447.0S 2804.5E 7905.5 7325.7 1124.5S 2548.4E 321.5 447.8 )406.7( 8466.7 7532.7 1455.0S 2813.7E 7926.5 7341.8 1111.9S 2553.2E 322.8 471.1 )428.9( 8500.0 7563.9 1462.9S 2822.3E 7947.6 7358.0 1099.2S 2558.0E 324.0 494.5 )451.1( 8519.1 7581.8 1467.4S 2827.1E 7959.7 7367.3 1092.0S 2560.7E 324.7 507.8 )463.9( 8538.1 7599.7 1472.0S 2831.7E 7970.9 7375.9 1085.3S 2563.3E 325.2 521.2 )476.7( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #3-2 and TVD from wellhead (99.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 120.03 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL ' GRAYLING Platform, G- 21Rd McArthur River Field,TBU, Cook Inlet, Alaska CLEAk~iNCE LISTING Page 7 Your ref : G-21Rd Version #4 Last revised : 10-Mar-98 Reference wellpa~h Object wellpath : PMSS <9365 - 10588'>,,M32ST#1,STEEI~IEAD Platform Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 7700.0 6866.0 1261.6S 2495.7E 7450.9 6971.1 1392.2S 2452.7E 198.2 173.0 )112.8( 7712.5 6876.2 1265.5S 2501.7E 7457.9 6976.7 1388.1S 2454.1E 201.2 165.5' )104.9( 7725.0 6886.4 1269.3S 2507.9E 7465.0 6982.3 1384.0S 2455.4E 204.6 158.5' )97.5( 7750.0 6906.5 1276.7S 2520.8E 7479.2 6993.6 1375.8S 2458.1E 212.3 146.1- )84.2( 7775.0 6926.7 1283.7S 2533.7E 7494.2 7005.5 1367.2S 2461.0E 221.0 135.8, )73.7( 7800.0 6947.1 1290.5S 2546.6E 7508.9 7017.2 1358.7S 2463.9E 230.5 128.1' )66.2( 7812.5 6957.2 1293.7S 2553.1E 7516.4 7023.1 1354.4S 2465.3E 235.3 125.4- )64.0( 7825.0 6967.4 1296.9S 2559.6E 7523.9 7029.0 1350.1S 2466.8E 240.2 123.4- )62.8( 7850.0 6987.9 1303.1S 2572.4E 7539.0 7041.0 1341.3S 2469.7E 249.6 121.8' )63.9( 7875.0 7008.6 1309.4S 2585.1E 7554.9 7053.5 1332.1S 2472.8E 258.6 123.0 )69.2( 7900.0 7029.3 1315.6S 2597.5E 7570.1 7065.5 1323.3S 2475.8E 266.4 127.2 )77.6( 7933.3 7057.3 1324.0S 2613.7E 7591.1 7082.1 1310.9S 2480.0E 275.6 136.6 )92.4( 7966.7 7085.4 1332.3S 2629.5E 7611.5 7098.1 1299.0S 2484.1E 282.9 149.7 )109.7( 8000.0 7113.8 1340.6S 2644.8E 7632.1 7114.2 1287.0S 2488.3E 288.9 165.5 )128.6( 8033.3 7142.4 1348.9S 2659.8E 7653.7 7131.1 1274.3S 2492.8E 294.1 183.3 )148.3( 8066.7 7171.3 1357.2S 2674.3E 7674.3 7147.2 1262.1S 2497.1E 298.2 202.5 )168.6( 8100.0 7200.4 1365.5S 2688.3E 7695.8 7164.0 1249.4S 2501.7E 301.9 222.7 )189.3( 8133.3 7229.6 1373.7S 2701.9E 7716.6 7180.1 1237.1S 2506.2E 304.9 243.8 )210.4( 8166.7 7259.1 1382.0S 2715.1E 7737.8 7196.5 1224.6S 2510.8E 307.6 265.4 )231.7( 8200.0 7288.8 1390.2S 2727.9E 7758.7 7212.7 1212.2S 2515.4E 310.0 287.4 )253.2( 8233.3 7318.7 1398.4S 2740.2E 7779.5 7228.8 1199.8S 2520.1E 312.1 309.8 )274.8( 8266.7 7348.7 1406.5S 2752.0E 7800.5 7244.9 1187.3S 2524.8E 314.0 332.4 )296.5( 8300.0 7379.0 1414.7S 2763.4E 7821.4 7261.1 1174.7S 2529.5E 315.7 355.3 )318.4( 8333.3 7409.4 1422.8S 2774.4E 7842.5 7277.2 1162.2S 2534.2E 317.3 378.3 )340.4( 8366.7 7440.0 1430.9S 2784.9E 7863.5 7293.5 1149.6S 2538.9E 318.8 401.4 )362.4( 8400.0 7470.7 1438.9S 2794.9E 7884.4 7309.5 1137.1S 2543.6E 320.2 424.6 )384.5( 8433.3 7501.6 1447.0S 2804.5E 7905.5 7325.7 1124.5S 2548.4E 321.5 447.8 )406.7( 8466.7 7532.7 1455.0S 2813.7E 7926.5 7341.8 1111.9S 2553.2E 322.8 471.1 )428.9( 8500.0 7563.9 1462.9S 2822.3E 7947.6 7358.0 1099.2S 2558.0E 324.0 494.5 )451.1( 8519.1 7581.8 1467.4S 2827.1E 7959.7 7367.3 1092.0S 2560.7E 324.7 507.8 )463.9( 8538.1 7599.7 1472.0S 2831.7E 7970.9 7375.9 1085.3S 2563.3E 325.2 521.2 )476.7( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #3-2 a~d TVD from wellhead (99.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 120.03 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GP, AYLING Platform, G-21Rd McArthur River Field,TBU, Cook Inlet, Alaska CL~CE LISTING Page 8 Your ref : G-21Rd Version #4 Last revised : 10-Mar-98 Reference wellpath Object we11path : PGMS <O-10938'>,,M-29,STEELHEAD Platform M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 7700 7712 7725 7750 7775 .0 6866.0 .5 6876.2 .0 6886.4 .0 6906.5 .0 6926.7 1261.6S 2495.7E 7427.3 7101.0 1788.4S 2555.8E 173.5 579.9 )486.2( 1265.5S 2501.7E 7436.2 7108.7 1784.7S 2558.2E 173.8 571.6' )477.6( 1269.3S 2507.9E 7445.1 7116.4 1781.0S 2560.6E 174.1 563.5* )469.2( 1276.7S 2520.8E 7461.5 7130.6 1774.2S 2565.1E 174.9 547.4* )452.4( 1283.7S 2533.7E 7479.6 7146.3 1766.6S 2569.9E 175.7 531.7' )436.1( 7800. 7812. 7825. 7850. 7875. 0 6947.1 5 6957.2 0 6967.4 0 6987.9 0 7008.6 1290.5S 2546.6E 7498.0 7162.3 1759.0S 2574.9E 176.5 516.4' )420.2( 1293.7S 2553.1E 7505.1 7168.5 1756.1S 2576.8E 177.1 508.9* )412.1( 1296.9S 2559.6E 7514.5 7176.6 1752.2S 2579.3E 177.5 501.5' )404.4( 1303.1S 2572.4E 7533.2 7192.9 1744.5S 2584.3E 178.5 486.8* )389.2( 1309.4S 2585.1E 7549.4 7207.1 1737.8S 2588.6E 179.5 472.2* )373.7( 7900.0 7933.3 7966.7 8000.0 8033.3 7029.3 7057.3 7085.4 7113.8 7142.4 1315.6S 2597.5E 7568.3 7223.6 1730.1S 2593.7E 180.5 457.7* )358.7( 1324.0S 2613.7E 7593.6 7245.7 1719.8S 2600.4E 181.9 438.6* )338.9( 1332.3S 2629.5E 7618.1 7267.2 1709.9S 2606.9E 183.4 419.7' )319.1( 1340.6S 2644.8E 7643.7 7289.5 1699.5S 2613.6E 185.0 400.8* )299.7( 1348.9S 2659.8E 7669.9 7312.5 1688.9S 2620.6E 186.6 382.1- )280.5( 8066 8100 8133 8166 8200 .7 7171.3 .0 7200.4 .3 7229.6 .7 7259.1 .0 7288.8 1357.2S 2674.3E 7695.6 7334.9 1678.4S 2627.4E 188.3 363.5* )261.5( 1365.5S 2688.3E 7722.0 7358.0 1667.?S 2634.4E 190.1 345.1, )242.7( 1373.7S 2701.9E 7748.4 7381.0 1656.9S 2641.4E 192.1 326.7* )224.2( 1382.0S 2715.1E 7774.2 7403.6 1646.3S 2648.3E 194.2 308.6* )205.8( 1390.2S 2727.9E 7800.7 7426.7 1635.5S 2655.3E 196.5 290.6* )187.8( 8233 8266 8300 8333 8366 .3 7318.7 .7 7348.7 .0 7379.0 .3 7409.4 .7 7440.0 1398.4S 2740.2E 7826.6 7449.3 1624.8S 2662.1E 199.0 272.8* )170.0( 1406.5S 2752.0E 7853.1 7472.3 1613.9S 2669.1E 201.8 255.2* )152.8{ 1414.7S 2763.4E 7879.0 7495.0 1603.1S 2675.9E 204.9 237.9* )135.9( 1422.8S 2774.4E 7905.4 7518.0 1592.2S 2682.9E 208.4 221.0' )119.6( 1430.9S 2784.9E 7931.5 7540.6 1581.4S 2689.7E 212.3 204.5* )103.9( 8400 8433 8466 8500 8519 .0 7470.7 .3 7501.6 .7 7532.7 .0 7563.9 .1 7581.8 1438.9S 2794.9E 7957.9 7563.6 1570.4S 2696.7E 216.8 188.5' )89.1( 1447.0S 2804.5E 7984.0 7586.3 1559.5S 2703.7E 221.9 173.2' )75.0( 1455.0S 2813.7E 8010.3 7609.2 1548.6S 2710.7E 227.7 158.8' )62.1( 1462.9S 2822.3E 8036.4 7631.9 1537.7S 2717.6E 234.5 145.5' )50.3( 1467.4S 2827.1E 8051.4 7644.9 1531.4S 2721.6E 238.8 138.6' )44.2( 8538.1 8600.0 8700.0 8800.0 8900.0 7599.7 7658.0 7752.2 7846.5 7940.7 1472.0S 2831.7E 8066.3 7657.9 1525.2S 2725.6E 243.4 132.1' )38.6( 1486.6S 2846.3E 8114.8 7699.9 1504.9S 2738.5E 260.4 117.1' )25.4( 1510.3S 2870.0E 8193.0 7767.8 1472.1S 2759.4E 289.0 118.1 )33.0( 1533.9S 2893.7E 8270.9 7835.4 1439.4S 2780.1E 309.8 148.2 )66.0( 1557.6S 2917.4E 8348.5 7902.7 1406.7S 2800.7E 322.3 194.6 )107.2( 9000. 9100. 9200. 9300. 9400. 0 8034.9 1581.3S 2941.1E 8426.1 7970.0 1373.9S 2821.2E 330.0 248.2 )153.7( 0 8129.1 1605.0S 2964.8E 8502.9 8036.4 1341.2S 2841.6E 335.0 305.5 )205.0( 0 8223.4 1628.6S 2988.5E 8579.2 8102.2 1308.4S 2862.0E 338.4 365.0 )259.8( 0 8317.6 1652.3S 3012.2E 8654.1 8166.6 1275.9S 2882.2E 340.9 425.9 )317.3( 0 8411.8 1676.0S 3035.9E 8730.9 8232.5 1242.3S 2902.8E 342.9 487.8 )376.1( 9500.0 8506.0 1699.6S 3059.6E 8810.5 8301.0 1207.7S 2923.9E 344.6 549.9 )435.3( 9600.0 8600.2 1723.3S 3083.3E 8889.0 8368.9 1173.9S 2944.3E 345.8 612.1 )495.1( 9607.2 8607.0 1725.0S 3085.0E 8894.6 8373.7 1171.5S 2945.7E 345.9 616.6 )499.4( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #3-2 and TVD from wellhead (99.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 120.03 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRAYLING Platform, G-21Rd McArthur River Field,TBU, Cook Inlet, Alaska CLEARANCE LISTING Page 9 Your ref : G-21Rd Version #4 Last revised : 10-Mar-98 Reference wellpath Object wellpath : PGMS <2700-9101'>,,M-14,STEELHEAD Platform M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 8800.0 7846.5 8900.0 7940.7 9000.0 8034.9 9100.0 8129.1 9200.0 8223.4 1533.9S 2893.7E 8433.4 8110.9 1930.08 2589.8E 217.5 564.9 )454.0( 1557.6S 2917.4E 8519.1 8186.4 1897.6S 2614.1E 221.7 517.6' )407.0( 1581.3S 2941.1E 8600.9 8258.3 1866.4S 2637.5E 226.8 472.6* )362.3( 1605.0S 2964.8E 8682.0 8329.6 1835.4S 2660.9E 232.8 430.8* )321.2( 1628.6S 2988.$E 8763.7 8401.1 1804.0S 2684.5E 240.0 393.%* )285.1( 9300.0 8317.6 9400.0 8411.8 9500.0 8506.0 9600.0 8600.2 9607.2 8607.0 1652.3S 3012.2E 8844.9 8472.3 1772.6S 2708.2E 248.4 361.7' )255.6( 1676.0S 3035.9E 8927.1 8544.0 1740.5S 2732.4E 258.0 337.3* )234.5( 1699.6S 3059.6E 9007.4 8613.8 1709.1S 2756.3E 268.2 322.1, )223.3( 1723.3S 3083.3E 9086.3 8682.7 1678.4S 2779.6E 278.4 317.9- )223.3( 1725.0S 3085.0E 9092.1 8687.7 1676.1S 2781.3E 279.1 318.0 )223.8( 9700.0 8694.5 9800.0 8788.7 9900.0 8882.9 10000.0 8977.1 1747.0S 3107.0E 9101.0 8695.5 1672.7S 2783.9E 282.9 331.5 )241.0( 1770.68 3130.7E 9101.0 8695.5 1672.7S 2783.9E 285.8 372.2 )291.1( 1794.38 3154.4E 9101.0 8695.5 1672.7S 2783.9E 288.2 432.6 )361.3{ 1818.0S 3178.1E 9101.0 8695.5 1672.7S 2783.9E 290.2 505.7 )442.2( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #3-2 and TVD from wellhead (99.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 120.03 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRAYLING Platform, G-21Rd McArthur River Field,TBU, Cook Inlet, Alaska Reference wellpath CLEA~JtNCE LISTING Page 10 Your ref : G-21Rd Version Last revised : 10-Mar-98 Object we11path : PG~S <3700-11700'>,,M-25,STEELHEAD Platform M.D. T.V.D. Rect Coordinates M.D. 7700.0 6866.0 1261.6S 2495.7E 7712.5 6876.2 1265.5S 2501.7E 7725.0 6886.4 1269.3S 2507.9E 7750.0 6906.5 1276.7S 2520.8E 7775.0 6926.7 1283.7S 2533.7E 7800.0 6947.1 1290.5S 2546.6E 7812.5 6957.2 1293.7S 2553.1E 7825.0 6967.4 1296.9S 2559.6E 7850.0 6987.9 1303.1S 2572.4E 7875.0 7008.6 1309.4S 2585.1E 7900.0 7029.3 1315.6S 2597.5E 7933.3 7057.3 1324.0S 2613.7E 7966.7 7085.4 1332.3S 2629.5E 8000.0 7113.8 1340.6S 2644.8E 8033.3 7142.4 1348.9S 2659.8E 8066.7 7171.3 1357.2S 2674.3E 8100.0 7200.4 1365.5S 2688.3E 8133.3 7229.6 1373.7S 2701.9E 8166.7 7259.1 1382.0S 2715.1E 8200.0 7288.8 1390.2S 2727.9E 8233.3 7318.7 1398.4S 2740.2E Horiz T.V.D. Rect Coordinates Bearing 7286.8 6690.7 1193.5S 2882.3E 80.0 7294.5 6696.9 1189.4S 2884.4E 78.8 7302.4 6703.2 1185.2S 2886.5E 77.5 7317.9 6715.6 1176.8S 2890.7E 74.9 7334.1 6728.5 1168.1S 2894.9E 72.2 7350.0 6741.1 1159.4S 2899.1E 69.6 7358.0 6747.5 1155.0S 2901.2E 68.3 7366.2 6754.1 1150.5S 2903.4E 66.9 7382.4 6766.9 1141.7S 2907.6E 64.3 7397.5 6778.9 ' 1133.3S 2911.5E 61.7 7413.8 6791.8 1124.4S 2915.7E 59.0 7435.5 6809.0 1112.4S 2921.3E 55.5 7455.1 6824.6 1101.5S 2926.4E 52.1 7477.0 6841.9 1089.4S 2932.2E 48.8 7498.9 6859.2 1077.3S 2938.0E 45.7 7518.3 6874.4 1066.5S 2943.1E 42.8 7536.9 6889.0 1056.1S 2948.1E 40.0 7558.8 6906.1 1043.8S 2954.0E 37.4 7577.1 6920.4 1033.5S 2958.9E 35.0 7598.9 6937.4 1021.0S 2964.8E 32.7 7616.9 6951.3 1010.8S 2969.6E 30.6 Min'm Ellipse Dist Sep'n 429.9 )330.2( 429.4* )329.5( 428.9* )328.7( 428.1, )327.6( 428.0* )327.3( 428f8 )327.9( 429.5 )328.6( 430.3 )329.4( 432.7 )331.8( 436.2 )335.6( 440.7 )340.2( 448.3 )348.1( 457.7 )357.9( 468.7 )369.0( 481.1 )381.6( 494.9 )395.7( 510.0 )411.2( 526.3 )427.3( 543.7 )444.9( 562.0 )462.9( 581.2 )482.3( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #3-2 and TVD from wellhead (99.00 Ft a3oove mean sea level). Vertical section is from wellhead on azimuth 120.03 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ 3" KILL L~NE WITH TWO 5" 5M VALVES [ q; ,, ;!2 KILL LINE: FROM MUD PMF &: CEMENI' UNIT NIPPLE ANNULAR F J BLIND RAMS F, PIPE RAMS RISER F---- I I ~OWLINE 15-5/8" 5,U FLANGE ¢OUBLE CATE 5M ~z-a/a" 5',J FLANCS 4" CHOKE LINE WITH ONE REMOI-~ & I ,V&NUAL 4" 5M VALVE (f)" I CONNECTEE] l'O CHOKE NO~NIFOLD (SEE MANIFOLD DRAWING) i5-5//a" aM FLANGE SINGLE GATE .dM 13-5/8" I0" 5M x i5-5/a" aM ADAPTER CAMERON 5M SPOOL lZ-5/8" BOPE 5M STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) · ' '-i3[~WN: 0AC SCALE: NONE MIXINO PIT ,iD BBLS MIXINg PIT IS A ONE LEVEL BELOW THE ACTIVE SYSTEM TRIP 45 TANK BBLS 185 BBLS VOLUME PIT 185 BBLS SUCTION PIT 125 BBLS 67 BBLS DESILTER ! 24.0 BBLS SHAKER SHAKER --cENmIFUCE RESERVE PiT ~75 BBLS NOTE: THE SYSTEM WILL BE EQUIPPED WITH A DRILLING PIT LEVEL INDICATOR WITH AUDIO ~ VISUAL WARNING DEVICES. EQUIPMENT LIST 1) RESERVE PIT 2) DEGASSER' 3) (2) SHAKERS 4) PIT LEVEL INDICATOR (ViSLIAL & AUDIO) 5) FLUID FLOW SENSOR 6) TRIP TANK ?) PIT AGITATORS a) DESlLTER 9) CENTRIFUGE 10) MIXINg PIT UNOCAL GRAYLING MUD PlY DRAWN BY: DAC APP'D: SCALE: NONE DATE: 1 SCHEMATIC TO GAS 8.USTER /\ TO OE,=,RICK VENT 1'0 WELL CLEAN CROKE CHOKE FROM CHOKE LINE VALVES U,aSTT~EA~ OF CHOKES .ARE 1Q,QQQ PSt -GATE TYPE VALVES 00WNS'r~E,,k~ OF CHOKES ARE 5,C100 PS[ GATE TYPE CH 0[4, E klAN IFOLD G'RAYLIN0 PLATFORM UNION OIL C0kt~ANY OF CALIFORNIA (dba UNOCAL.) ORAWN: 0AC APP'O: SCALE: NONE OAT'S: Unocal Alaska Res( .~s Unocal Corporation ~-~ 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL Rick D. Cross Senior Landman March 25, 1998 Mr. Robert Crandall Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Trading Bay Unit State of Alaska Application to Drill and Complete Trading Bay Unit G-21RD McArthur River Field Dear Mr. Crandall, Union Oil Company of California, as Operator of the Trading Bay Unit, requests your approval to drill and complete the Trading Bay Unit G-21 RD well in the Middle Kenai G and Hemlock Oil Pools pursuant to Rule 5 of Conservation Order No. 80. Drilling from the Grayling Platform the well is Iocatedi 1,802' FSL, 1,41 5' FEL, Section 29, T9N, R13W, S.M. at the surface; 66' FSL, 1,671' FWL, Section 28, T9N, R13W, S.M. at the top of productive interval; and 209' FNL, 1,945' FWL, Section 33, T9N, R13W, S.M. at total depth. Completion of the well in the Middle Kenai G and Hemlock Oil Pools at a crestal final withdrawal point will provide additional recovery of production. Enclosed with this application is our check no. /~0~,~ in the amount of $100.00 as required under 20 AAC 25.005(c)(1). Should you have any questions, or need additional information, please contact Hal Martin, Advising Reservoir Engineer, at (907) 263-7675. Sincerely yours, UNION OIL COMPANY OF CALIFORNIA ' R~ck D. CrosS" ' Senior Landman FOR INQUIRIES CONTACT LOCATION WHERE INVOICES WEF' ',BMITTED ..'...VEN~O. :: DATE.".' .~ .. 10~?~348 )3-25-98 2002662 ,,, DATE INVOICE/CREDIT MEMO N©. vOUCHER NO: : ~RO~ 19-MAR-98 DRILLPERMITG21R 03983001636 100.00 100.00 FORM 4-2B181 (REV. 11-95) PRINTED IN U.S.A. DETACH STUB BEFORE DEPOSITING CHECK ::: : 100. O O 100 · O O · WELL PERMIT,CHECKLIST COMPANY~//¢¢,,¢ ~__~ /.~ WELL NAME ~'z~' ~_~__../,z~:~j PROGRAM: exp [] dev [] redrll'i~serv [] wellbore seg -' ann. disposal para req L: FIELD & POOL ~,~',~L 0 / 2_~/,.~.2- (~/uZ"4:~ INIT CLASS ,/'~z..,'~'"~'-"~'*- ~// OBOE AREA (~5>2~::~ UNIT# / ~ 0 7 0 ON/OFF SHORE O~'L) ADMINISTRATION ENGINEERING GEOLOGY A,~_R DAT~¢.~ · 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ....................... ~1~ Lease number appropriate ................... Unique well name and number .................. N . Well located in a defined pool .................. N Well located proper distance from drilling unit boundary .... N Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ . If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order. ....... W~,,/N ~) N~-.~. Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... Y N ',~ ~ 15. Surface casing protects all known USDWs ........... Y N } b,._. 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg ........ (,~h~,N, 18. CMT will cover all known productive horizons .......... p~ 19. Casing designs adequate for C, T, B & permafrost ....... ~N 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... -~~i ~__,~~ /~~m 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ..... ~ . ~ ...... 26. BOPE press rating appropriate; test to ,~5~L~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y-(~ 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... Y N 32. Seismic analysis of shallow gas zones ............. Y N -- 33. Seabed condition survey (if off-shore) ............. Y N 34. Contact name/phone for we,eklyjorog, ress repo, rts ....... Y N lexp~ora~ory omyj GEOLOGY: ENGINEERING: COMMISSION: JDH ~ v- coco Commentsllnstructions: HOW/Ijt - A:\FORMS\cheklist rev 09/97